Gedigitalenergy-referenceguide2018-web.pdf

GE Digital Energy

Protection & Control

reference guide

Worldwide Offices NORTH AMERICA / WORLDWIDE

EUROPE / MIDDLE EAST / AFRICA

650 Markland Street Markham, ON Canada L6C 0M1 Toll Free (NA Only): 1-877-547-8630 Tel: 905-927-7070

Avenida Pinoa 10-48170 Zamudio (Vizcaya), Spain Tel: +34 94 485 88 00

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GE Digital Energy reserves the right to make changes to specifications of products described in this reference guide at any time without notice and without obligation to notify any person of such changes.

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© 2015 GE Digital Energy

GEA-12909

VOLUME 23

PROTECTION & CONTROL reference guide

VOLUME

23

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PROTECTION & CONTROL

REFERENCE GUIDE

VOLUME 23

Table of Contents INTRODUCTION

DISTRIBUTION FEEDER PROTECTION

227

The Multilin Digital Advantage

3

Distribution Feeder Principles, Protection & Control

228

Table of Contents

6

Typical Applications

238

Technologies to Modernize The Grid

8

Technical Resources

244

Selector Guide & Featured Products

245

F60

Feeder Protection with Hi-Z Detection

247

F35

Multiple Feeder Protection

255

850

Feeder Protection System

263

F650

Feeder/Bay Protection

283

350

Overcurrent Feeder Protection

293

A60

Arc Flash Detection System

305

PROTECTION, CONTROL & AUTOMATION GENERATOR PROTECTION

25

Generator Priniciples, Protection & Control

26

Typical Applications

34

Technical Resources

36

Selector Guide & Featured Products

37

G60

Generator Protection System

39

G30

Generator Protection System

47

DISTRIBUTION AUTOMATION

311

GPM-F

Field Ground Protection

55

Distribution Automation – Featured Products

312

GPM-S

Stator Ground Protection Module

59

DGCM

Field RTU

313

ILMS

Intelligent Line Monitoring System

325

DGCS

Switch Controller

337

TRANSFORMER PROTECTION

63

Transformer Principles, Protection & Control

64

Typical Applications

74

MOTOR PROTECTION

345

Technical Resources

76

Motor Principles, Protection & Control

346

Selector Guide & Featured Products

77

Typical Applications

355

T60

Medium to Large Transformer Protection

79

Technical Resources

360

T35

6 Winding Transformer Protection

87

Selector Guide & Featured Products

361

845

Small to Large Transformer Protection

95

869

Motor Management System

363

345

Small to Medium Transformer Protection

113

M60

Medium to Large Motor Protection

383

339

Small to Medium Motor Protection

391

MM300

Low Voltage Motor Management

403

MM200

Low Voltage Motor Management

411

TRANSMISSION LINE PROTECTION

123

Transmission Line Principles, Protection & Control

124

Typical Applications

132

Technical Resources

138

SPECIALIZED PROTECTION, CONTROL AND RECORDING

419

Selector Guide & Featured Products

139

C90Plus

Automation Control System

421

L90

Line Current Differential Protection

141

C60

Breaker Protection System

437

L60

Line Phase Comparison Protection

149

C30

I/O Logic Controller

445

L30

Line Current Differential Protection

157

C70

Capacitor Bank Protection & Control

451

U90

Microgrid Control System

459

D90

Sub-Cycle Distance Protection

165

D60



Line Distance Protection

175

D30

Line Distance Protection

183

Plus

6

BUS PROTECTION

191

Bus Principles, Protection & Control

192

Typical Applications

196

Technical Resources



Plus

NETWORK PROTECTION

467

Product Listing

468

N60

469

Network Stability & Synchrophasor Measurement

P30

Phasor Data Concentrator

477

198

MultiSync™ 100

1588 GPS Clock

485

Selector Guide & Featured Products

199

B95Plus

Distributed Bus Protection

201

SINGLE FUNCTION & AUXILIARY RELAYS

B90

Multiple Section Busbar Protection

211

B30

Bus Differential System

219

Single Function Relays

491

Auxiliary Relays

492

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SUBSTATION AUTOMATION

493

COMMUNICATIONS

Featured Products

494

Ethernet Networking Principles

669

Modular Substation Automation

495

MultiLink Hardened Ethernet Switches

675

D20MX

Substation Automation Controller

509

Media & Protocol Converters

683

D400

Substation Gateway

517

Lentronics Fiber Optic Solutions Overview

685

D.20 RIO

Distributed I/O Controller

529

MDS Industrial Strength Wireless Solutions Overview

687

D25

Substation Controller

533

™

MONITORING & DIAGNOSTICS

IEC 61850 PROCESS BUS

541

Monitoring & Diagnostics Solutions for Power Transformers

IEC 61850 Process Bus Principles

542

POWER SENSING SOLUTIONS

HardFiber System

545

IEC 61850 Process Bus Solution

Instrument Transformers Product Listing

691

695

DIGITAL METERING

557

APPENDIX

Selector Guide & Featured Products

558

GE Locations & Where to Buy

697

EPM 9900

Advanced Power Quality Meter

561

ANSI Standard Device Numbers

707

EPM 9650/9450

Advanced Power Quality Meter

565

EPM 7000

Power Quality Meter

569

PQM II

Power Quality Meter

573

EPM 6000/6010

Multi-function Power Meters

577

EPM 2200

Digital Power Meter

581

EPM 4600

Multi-feed Power and Energy Meter

585

EPM 6100/7100

Energy Submeters

589

DEVICE AND CONFIGURATION SOFTWARE

593

Featured Products

594

Launchpad

Device Setup & Document Management

595

Viewpoint Engineer

Control Logic Creator & Commissioning Toolset

599

Viewpoint Maintenance Device Health & Security Reporting

605

Viewpoint Monitoring

Monitoring & Data Recording

609

Integrator

623 OPC/DDE Communications Server

621

PowerLink Advantage

Powerful SCADA & HMI Platform

625

CyberSentry™ SEM

Security Event Manager

633

VALUE ADDED SERVICES

637

Value Added Services Listing

638

PMCS Energy Management Systems

639

Advanced Training Services

647

Consulting Services

649

Packaged Solutions

651

PRODUCT UPGRADES & REPLACEMENT

663

Listing of Recommended Upgrades & Replacements

664

ACCESSORIES 667 Accessories – Featured Products

668

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7

DRIVING INDUSTRY ADVANCEMENTS Advancing Busbar Protection Multilin B95PLUS Bus Protection System

Reduced Implementation and Deployment Time Reducing the costs and risks associated with bus operations and circuit breaker maintenance, GE introduced the IEC 61850 Process Bus enabled B95Plus Busbar Protection System for distributed low impedance busbar applications.

Flexibility and Scalability With unique scalability, protecting up to 24 bays in a single scheme, utilities are able to greatly reduce the time and cost of field wiring and expansion to other zones of protection.

Fight Device Obsolescence and Upgrade with Ease Multilin UR Family Proven, State-of-The-Art Asset Protection

Simplified Upgrades & Modular Future-Proof Design With a unique chassis design, utilizing a common set of modules, the platform allows for easier and simplified upgrades of devices in the field - extending the life of your existing fleet.

Enhanced Network Features Gain performance improvements, the latest communications capabilities and cyber security features by replacing just with 2 modules, drastically reducing maintenance and hardware upgrades costs.

8

Enabling Reliable, Secure and Efficient Power Grids FROM POWER PLANT TO THE POWER CONSUMER Actionable Intelligence to Improve Grid Reliability Multilin Intelligent Line Monitoring System

Enhanced Network Visibility & Reduced Outage Duration Delivering situational awareness along distribution feeders, the system provides utilities with high quality and time coherent data throughout the distribution network, enabling utilities to take action when and where needed.

Increased Network Capacity With active line measurement, utilities are able to compute dynamic line ratings based on prevailing conditions as opposed to historical data tables, delivering greater network efficiencies.

Raising the Bar on Performance & Reliability Multilin 8 SERIES for Feeders, Motors, and Transformers

Ruggedized Design for Maximum Life Utilizing advanced design practices and superior technology, the 8 Series delivers greater reliability due to the elimination of electrolytic capacitors, a field swappable power supply, and conformal coating on all printed circuit boards as the standard.

Optimize Performance and Operations For maximum process uptime and device performance, the 8 Series delivers comprehensive motor management and detailed health monitoring with advanced communications including support for IEC 61850 and IEC 62439 PRP.

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DESIGN & MANUFACTURING EXCELLENCE Redefining the Standards for Performance & Reliability Committed to Innovation and Quality

10 YEAR WORLDWIDE

Illustrated through a 10 Year Worldwide Warranty for Multilin Protection, Control, and Automation solutions, GE is committed to innovation and quality, delivering products and solutions that offer long-term reliability.

WARRANTY

Interoperability and Communications Testing Ensuring Device Performance

Testing Environmental and Electrical Design Limits Ensuring Device Longevity (ALT, HALT & ESS Testing)

On-site Anechoic Chamber Ensuring Device Immunity from RF Emissions

Comprehensive Testing & Validation For Maximum Life With state-of-the-art manufacturing, type test facilities, and a RTDS Simulation Laboratory, GE’s Multilin Protection & Control and Automation solutions are tested under a comprehensive range of operating environments and systems, ensuring adherence to the highest reliability standards and performance requirements.

10

GRID IQ INNOVATION CENTER - ENABLING NEW EXPERIENCES to Explore, Learn & Interact Collaborating to Solve the Toughest Challenges Technologies and Solutions that Enable a Modern Grid Grid IQ™ Innovation Center, Markham, Canada.

From Power Plant to the Power Consumer Utilizing an expansive suite of 3D interactive and digital tools GE is working with customers to ensure a better understanding of the challenges of a modern grid, the impact of those challenges, and the new technologies available to solve those challenges – enabling a more reliable, secure and efficient grid.

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SMART TRANSMISSION Fast, Reliable Transmission Line Protection Multilin L90 Line Current Dif ferential System With over 100 years of experience, GE’s Transmission Protection solutions, including the Multilin L90 Line Current Differential System and the Multilin D90Plus Sub Cycle Distance Protection System, are used to provide high-speed fault clearance ensuring transmission grid reliability and stability.

Comprehensive Line Current Differential and Distance Protection Ensuring system balance and security during abnormal conditions, Multilin L90’s utilize synchronized sampling between devices to deliver high-speed current differential protection and complete distance protection.

12

Delivering RELIABLE POWER ACROSS THE ELECTRICAL NETWORK requires a self-healing grid Collect, Process, Record & Archive Phasor Data Multilin N60 Network Stability & Synchrophasors

Real-time system monitoring for decreased black outs and increased utilization of existing transmission lines using accurate synchrophasor measurement data.

The System Awareness Necessary to Enhance Grid Stability and Reliability Capable of streaming synchrophasor data based upon the latest version of the C37.118 standard, GE’s wide area monitoring solutions deliver the awareness necessary for effective grid monitoring.

Simplifying Analysis of Power System Events Reducing deployment and operation costs, and providing event recordings based on NERC-PRC-002-2 for compliant dynamic disturbance recording (DDR) systems, GE delivers a full suite of solutions to enable wide area system integrity.

Wide Area Monitoring & Dynamic Disturbance Analysis Multilin P30 Phasor Data Concentrator

Optimize System Analysis and Operations with Accurate Phasor Data The Multilin P30 Phasor Data Concentrator is a modular, substation rated, high performance device capable of collecting, processing, recording and archiving C37.118 compliant synchrophasor data connecting up to forty PMU devices for seamless wide area data analytics.

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SMART DISTRIBUTION Managing your Transformer’s Health to Extend its Life Multilin 845 Comprehensive Transformer Management GE’s advanced protection and control devices, including the Multilin T60, T35, 845, and 345 relays provide the necessary protection with condition based asset monitoring and industry leading communications to detect and even predict potential transformer issues before they become critical failures.

Ensuring a consistent supply of Power with Continuous Monitoring With high speed protection, detailed diagnostics and health reports, the latest in advanced communications capabilities including IEC 61850, and GE’s industry leading easy-to-use software for configuration and device management, the Multilin 845 works to mitigate the risks of expensive unplanned outages and equipment failures.

14

INNOVATIVE SOLUTIONS TO MODERNIZE THE GRID ensuring greater efficiency and resiliency Enabling Remote Monitoring & Network Visibility Multilin D400 Advanced Substation Gateway

Hardened Substation Gateways for Secure Local and Remote Access Enabling substation automation and centralized management of substation equipment, GE’s D400 Advanced Substation Gateway

Connectivity Enabling Seamless Integration Supporting the latest in communications protocols and built-in media conversion capabilities, the Multilin D400 simplifies substation automation and integration with Enterprise SCADA, EMS, DMS/OMS, and Data Historian systems.

Minimizing System Downtime and Improving Safety Multilin 350 Intuitive and Innovative Feeder Protection

Enabling Efficient Recovery from Power System Events With advanced feeder protection solutions, including the Multilin 350 Feeder Protection System, faults in the distribution system can be sensed quickly and immediately isolated to prevent additional faults or damage to downstream devices.

Minimizing Equipment Damage from Arc Flash Events Delivering the industry’s first arc flash detection system to utilize both pressure wave and light detection, GE’s Multilin A60 Arc Flash Protection System is capable of detecting an arc flash condition in as fast as 1 msec., minimzing equipment damage and costs associated with unplanned downtime.

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OVER 100 YEARS IN MOTOR PROTECTION Comprehensive Motor Protection and Management Multilin 869 Motor Management System

Flexible Protection to Maximize Motor Performance Across the Facility Centered around a proven and true thermal model, the Multilin 869 Motor Management System employs GE’s accurately mimics the motor’s empirical design, enabling it’s full potential without compromising protection and provides the sensitivity and performance required to maximize process uptime.

Intuitive and Simplified Protection of AC Motors Multilin 339 Motor Management System

Designed for medium voltage motors, the Multilin 339 delivers unparalleled protection, control, diagnostics and communications in an industry leading draw-out construction. With simplified setup and configuration via a graphical Motor Settings Auto-Configurator, advanced diagnostics with a graphical Motor Health Report, and support for advanced communications including IEC 61850, the Multilin 339 extends asset life.

16

PROVEN & TRUE THERMAL DESIGN to Accurately Mimic the Motor’s Empirical Design Asset Health Monitoring Comprehensive Condition-Based Monitoring to Improve Operational Efficiency

Broken Rotor Bar Detection Utilizing advanced Motor Current Signature Analysis (MCSA), GE’s Multilin 869 provides analysis, detection, and notification of broken rotor bar conditions, enabling a more cost effective and pro-active maintenance approach with less unplanned downtime.

Patented Environmental Health Monitoring Collecting key environmental and operational data while the relay is in service, the Multilin 8 Series provides critical environmental analysis allowing operators to predict maintenance requirements and reduce costs associated with unplanned or extended downtime.

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CONNECTING & PREDICTING Driving Communications Technologies & Standards Unparalleled Networking Capabilities Ensuring Data Reliability & Ease of Integration

Ethernet Communications

IEEE C37.94 Inter Relay Communications

IEC 61850 Configurable Datasets

TFTP Trivial File Transfer Protocol First to support UCA2.0 Peer-to-Peer Communications

SNTP Simple Network Time Protocol

IEC 61850 (GOOSE) Supported Across the UR Platform

Eliminate Costly Downtime with Predictive Analysis Continuously Monitor the Integrity of your Generator Stator Ground

FAULT DETECTION

In combination with the Multilin G60 Generator Protection System, the Multilin Ground Protection Modules (GPM-S & GPM-F) provides one-hundred percent stator and field ground fault protection that actively monitors a generator during startup, running, and stopped conditions, protecting a generator from potentially severe stator or field winding ground faults that can damage a generator beyond repair.

18

Supporting the latest technologies to deliver SECURE, RELIABLE NETWORKS and LONG ASSET LIFE

n

HardFiber System 61850 Process Bus Solution

Multiple (3) Independent Ethernet Ports

IEC 61850 (GOOSE) Supported Across the UR Platform

High Accuracy Time Synchronization IEEE1588 PTP, IEC 61850-90-5

PRP System Redundancy IEC 62439-3 Parallel Redundancy Protocol

Extended IEC 61850 capabilities, aligned to Edition 2 Complete device configuration via a single and standard SCL file Support for the latest in Secure File Transfer Services

Protection for Instantaneous Electrical Faults Multilin 345 Transformer Protection System

Addressing the Challenge of Aging Infrastructure Utility and energy intensive industrial customers are challenged with aging infrastructures. GE provides the visibility needed to monitor, detect, and protect critical transformers from both impending and instantaneous fault conditions that can severely damage equipment.

High-speed and Secure 2-winding Transformer Protection With advanced algorithms for automatic magnitude and phase compensations, fast and secure biased differential protection with dual slope, and dual breakpoint characteristic, the Multilin 345 provides comprehensive and cost-effective transformer protection.

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CYBER SECURITY SOLUTIONS Guarding Critical Power System Assets Reducing the Risks and Costs of Unauthorized Access GE is at the forefront providing industry based tools, systems and services that are needed to sense, react, and respond to publicly exposed vulnerabilities or intrusions, ensuring only secure access to critical power system assets and enabling compliance with the latest industry requirements (NERC/CIP 5.0).

Real-Time Monitoring, Control, and Tracking of Device Access GE’s cyber security tools and solutions provide the situational awareness needed to identify threats to systems and devices in real-time. With multiple levels of security, access controls and detailed data logging, including records of all setting file changes, operators gain the confidence that accidental or unwanted access to network devices is prevented.

20

SUPERVISION AND ACCESS CONTROLS ensures only authorized remote or local access Creating A Strong Perimeter of Defense Multilin CyberSentry Security Management and Monitoring System GE’s suite of cyber security tools have been specifically designed for power system and automation engineers, offering AAA Server Support (Radius), Role Based Access Control (RBAC), and Event Recording (Syslog) to enable compliance with the latest NERC/CIP and NITIR 7628 cyber security requirements.

Tested and Certified for Robustness To mitigate security risks GE is focused on providing protection and control devices and solutions that are tested and certified for robustness against cyber security attacks based on the IEC 62443-2-4 international Cyber Security Standards for use in Utility and Industrial environments.

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MAKING IT SIMPLE Simplifying Every Aspect of your Workflow Processes EnerVista™ Software Suite From device setup, logic design, and systems integration to asset monitoring and comprehensive setting file and document management, GE’s industry leading, easy-to-use suite of software tools simplify every aspect of managing Multilin protection and control devices.

Launchpad

Viewpoint Maintenance

Easy-to-Use Device Setup, Document and Site Management Toolset

Troubleshooting and Reporting Tool Simplifying All Maintenance Tasks

Viewpoint Monitoring

Integrator

System Monitoring and Data Recording for Small Systems

Powerful OPC Communications Server for Device Integration

22

Solutions to DESIGN, CONFIGURE, MANAGE, and ANALYZE the Power System Powerful Graphical Tool to Ease Commissioning Efforts EnerVista™ Viewpoint Engineer

Design with Ease and Improve Productivity GE’s powerful Viewpoint Engineer provides operators with the ability to design, optimize, test and validate complex logic schemes and relay wiring in real-time with drag and drop ease, including the configuration of IEC 61850 compliant devices and systems.

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FULLY INTEGRATED PACKAGED SOLUTIONS & ENGINEERING SERVICES Delivering Project Savings and Reduced Cycle Times Pre-Engineered, Pre-Packaged, and Pre-Tested

For power system applications spanning from generation to the power consumer. GE’s fully integrated and modular panel solutions include engineering, design, manufacturing, assembly, wiring, testing, and commissioning, reducing the costs and risks associated with traditional substation expansion or retrofit.

Proven Results With extensive experience delivering large complex projects, GE’s team of highly skilled engineers create solutions to meet your application requirements. With a team of project management professionals, project execution becomes seamless, delivering on-time and on-budget.

Leverage our Technical Power & Domain Expertise Professional Services Tailored For Each Unique Application

Solving Your Toughest Power System Challenges With technical representatives, field and application engineers located around the world, GE provides the knowledgeable, hands-on support when and where it is needed most.

Consulting Services From the design of protective relaying systems to the commissioning of power system devices, GE’s team of systems subject matter experts can engineer the protection schemes required for new power systems or can advise and assist with upgrading existing systems.

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Generator Protection Generator Principles & Protection

26

Electrical generating systems include several key components to ensure proper operation. This section provides an overview of these components and the details on different applicationspecific generating stations.

Typical Applications

32

Typical generator protection applications are shown detailing different schemes and applications including Pumped Storage, In-Zone Transformer & Low Impedance Grounding. Each application is identified with the corresponding protection relay.

Spotlight Application

34

This application will detail the overall protection of a hydro generator and identify the benefits of integrating the IEC 61850 HardFiber solution in order to minimize costs and provide safe and secure data transmission throughout the system.

Technical Resources

36

Access an extensive library of interactive tools and videos showcasing innovative solutions, as well as online publications, technical resources, how-to videos and generator protection configurators.

Selector Guide

37

A reference table highlighting the feature set for each generator protection system, allowing for quick and easy identification of products to assist in choosing the correct product for the specific application.

Featured Products Featured Products brochures for Multilin Generator protection systems.

38

Generator Principles

Generator Protection

Generator Principles Introduction

Generator

Electrical generating systems may be of great complexity and spread over large geographical areas. There are several components that make up the generating system with the main components being the following:

Generators are used to convert the supplied mechanical energy to electrical energy. They have a wide variety of power ranges up to and including 1500MW and are typically an AC machine. In some applications a DC generator may be used.

Energy Source The energy source may be coal, gas, or oil burned in a furnace to heat water and to generate steam in a boiler; it may be fissionable material, which in a nuclear reactor, will heat water to produce steam; it may be water in a lake or river; or it may be oil or gas burned in an internal combustion engine.

Prime Mover The prime mover may be a steam driven turbine, a hydraulic turbine or an internal combustion engine. Each one of these prime movers has the ability to convert energy in the form of heat, falling water or fuel into rotation of a shaft, which in turn will drive the generator.

Control System The control system is used to keep the speed of the machine constant and the voltage and frequency within prescribed limits even though the load may change. To meet the need of changing load conditions, it is necessary for the fuel input to change, which in turn varies the torque requirements to the prime mover and the generator in order to keep the generator at the required speed for the load. This control system constantly monitors the load requirements and generating needs and adjusts the system accordingly.

Dam

C

Penstock

A Energy Source

A built-up water reservoir provides the primary energy source required for generation

B

D

B

Prime Mover

C

Water flowing through the penstock spins the turbine

Generator The spinning turbine causes the generator to convert the mechanical energy into electrical energy

Figure 1. Cross section of a hydroelectric generating station

26

Substation

Generator Hall

A

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D

Control System Control system ensures the power generated is matched to the power demanded

Generator Principles

Synchronous Generators Stationary Field Synchronous Generator

Rotating Field Synchronous Generator In typical generator applications a rotating DC field is usually used. The rotating field synchronous generator has a stationary armature called a stator. The three-phase stator winding is directly connected to the load without going through large, unreliable slip rings and brushes. The stationary stator also makes it easier to insulate the winding because they are not subjected to centrifugal forces.

Synchronous generators are built with two types of rotors: salient-pole rotors and smooth, cylindrical rotors. Salient-pole rotors are usually coupled to low-speed hydraulic turbines where cylindrical rotors are driven by highspeed steam turbines.

Salient Pole Rotors Salient-pole rotors are typically used in most hydraulic applications, because they run at low speeds, typically in the range of 50 to 1500 rpm in order to extract the maximum power from the waterfall. Because the rotor is directly connected to the water-wheel and must maintain a frequency of 60 Hz, a large number of poles are required. Typically number of salient poles is between 4 to 60.

Cylindrical Rotors Cylindrical rotors are used in applications where they are connected to high-speed steam turbines. These units are smaller and more efficient than low speed turbines. Since these units are connected to high-speed steam turbines they are typically 2 or 4 pole machines that operate at either 3600 or 1800 rpm for 60 Hz systems.

Generator Cooling As the generators increase in size and power output, additional consideration must be taken into account for the cooling of the machine. Traditionally there have been three methods that have been used for cooling generators; cold air cooling, hydrogen cooling and water cooled conductors. The cooling method will be dictated depending on the size of the generator.

Figure 2. Typical operation of a hydraulic generator

Figure 3. Stator of an air-cooled generator

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Generator Protection

Synchronous generators are made with either a stationary or rotating DC magnetic field. The stationary field synchronous generator has the same appearance as a DC generator. The salient poles create the DC field, which is cut by a revolving armature. The armature possesses a three phase winding whose terminals are connected to three slip rings mounted on the shaft. A set of brushes, sliding on the slip rings, enables the connection of the armature to an external three-phase load.

The nominal line voltage of a synchronous generator depends on its kVA rating. In general, the greater the power rating, the higher the voltage. However, the nominal voltage rarely exceeds 25kV because the increased slot insulation takes up valuable space at the expense of the copper conductors.

Generator Principles

Generator Protection

Generating Stations Since electrical power demands vary throughout the day, week, year different types of power generating stations are better suited to react to required electrical demand. In power generating applications there are three areas of usage that must be taken into account: Base demand, Intermediate demand and Peak demand. Each demand type will have a different type of generating station associated with it because of the method of system startup.

Base Demand Power Stations Base demand power stations deliver full power all the time. The types of generating that are best suited for these applications are Nuclear generating stations and coal-fired stations. Nuclear generating stations can take up to several days to start and coal-fired stations can take up to several hours to start making them both ineffective to changing power demand, therefore limiting their applications to base demand power stations.

Figure 4. Nuclear generation

Intermediate Demand Power Stations Intermediate power stations are designed to react to slight changes in the power requirement and can respond relatively quickly to this need by adding or removing generating units as required. Hydraulic generating stations are best suited for intermediate generation applications.

Peak Demand Power Stations Peak demand generating stations are required to deliver power for brief intervals during the day. These stations must be put into service very quickly; therefore they are equipped with prime movers, such as diesel engines, gas turbines, compressed-air motors or pumped-storage turbines that can be started in a few minutes. Figure 5. Hydraulic generation

Figure 6. GE Jenbacher gas generator

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Generator Protection

Generator Protection There are many abnormal conditions that can result in damage to the generator. Some of these conditions are a result of a failure within the generator or one of its subsystems and others originate in the power system itself. The following table summarizes the types of failures that can occur and the associated methods of protection.

Stator Ground Faults The most commonly occurring failure of the stator winding is a break down of the insulation between a single phase and ground. Undetected, this fault can quickly damage the generator core. Fires are also possible on air-cooled machines. The ability of the stator differential element to detect a ground fault is a function of the available ground fault current. As such, dedicated ground fault protection is generally required for the stator.

Type of Fault Figure 7. integrated coal gasification combined cycle (IGCC) power plant Generators provide the energy used by all of the loads in the power system and much of the reactive power needed to supply the inductive elements thereby maintaining the system voltage at nominal values. Power systems have little capacity for energy storage. As such, lost generation must be immediately replaced or an equivalent amount of load must be shed. It is of primary importance that the protection system for the generator is highly secure during external disturbances. The generator is one component of a complex system that includes a prime mover, an exciter, and various auxiliary systems. In addition to the detection of short circuits, the generator protection IED is therefore required to detect an array of abnormal conditions that could damage the generator or one of its subsystems. Generators can be classified into two major types: induction and synchronous. Induction machines are typically smaller in size, ranging down to as little as one hundred kVA, and are normally driven from a reciprocating engine. Synchronous machines range in size from several hundred kVA to 1200 MVA. Synchronous generators may be driven by a variety of prime movers, including reciprocating engines, hydro turbines, combustion turbines, and large steam turbines. The type of turbine affects the design of the generator and can therefore impact protection requirements. The generator size and its method of grounding also affect its protection requirements. Small and medium sized machines are often directly connected to a distribution network (direct connected). In this configuration several machines can be connected to the same bus. Large machines are usually connected via a dedicated power transformer to the transmission network (unit connected). A second power transformer at the generator terminals provides auxiliary power for the unit. Generators are grounded in order to control from damaging voltage transients and to facilitate the operation of protection functions. Direct-connected generators are often grounded through a low impedance that limits the ground fault current to 200-400 amps. Unit connected machines are typically grounded through a high impedance that limits the current to less than 20 amps.

Protection Philosophy

Internal Fault Stator ground faults

Voltage displacement (59x), 100% stator ground (27TN/59N), 3rd harmonic neutral undervoltage (27TN), ground overcurrent (51G), restricted ground fault (87RGF), neutral directional (67N). 100% Stator Ground Fault Protection Using SubHarmonic Injection

Stator phase faults

Generator Stator differential (87G), phase distance (21P)

Inter-turn faults

Split phase (60SP)

Loss of excitation

Impedance (40), power factor (55)

Loss of prime mover

Reverse power (32R), low forward power (32L)

Overfluxing

Volts per hertz (24)

Overvoltage

Overvoltage (59P)

Abnormal operating speed

Underfrequency, overfrequency (81U/O)

External Fault Unbalanced loading

Generator unbalance (50_2/51_2)

System backup

Phase distance (21P), voltage restrained overcurrent (51V), ground overcurrent (51G)

Overloading

Overcurrent, thermal overload (49)

Mechanical

Vibration sensor (39)

Loss of synchronism

Power swing blocking (68), Out-of-step tripping (78)

Accidental energization

Accidental energization (27/50)

Table 1. Generator faults

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Generator Protection

Generator Protection Overview

For direct connected, low impedance grounded machines, a current-based detection method is used. This protection needs to be fast and sensitive for internal ground faults while at the same time secure during external disturbances. This can be achieved using a restricted ground fault element or a neutral directional element . The restricted ground fault element implemented in the G30 and G60 employs a symmetrical component restraint mechanism that provides a high degree of security during external faults with significant CT saturation. For unit connected, high impedance grounded machines, voltage-based methods are often used to provide ground fault detection. Using a combination of fundamental and third harmonic voltage elements, ground fault coverage for 100% of the stator winding can be achieved. GE relays employ a third harmonic voltage element that responds to the ratio of the neutral and terminal values of the third harmonic. This element is simple to set and insensitive to variations in third harmonic levels under normal operation.

Overload/Thermal

Stator Phase Faults

Percent of Rated

Generator Protection

Generator Protection

Phase faults not involving ground can occur at the winding end or within a slot in machines having coils of the same phase in the same slot. Although a phase fault is less likely than a ground fault, the current resulting from this fault is not limited by the grounding impedance. As such it is critical that these faults be detected quickly so as to limit the damage to the machine. Since the system XOR ratio is particularly high at the generator, the stator differential element is particularly susceptible to CT saturation due to the DC component of the current during an external disturbance. The G60 stator differential algorithm adds additional security in the format of a directional check when CT saturation is suspected due to either the AC or DC components of the current.

Figure 8 shows the permissible short-time loading limits of a generator according to C50.13-2004. Loading beyond these limits will quickly damage the machine. An overcurrent element with a very-inverse characteristic can be used to ensure that the generator is operated within permissible limits. GE IED’s are also equipped with RTD inputs. In addition to detection of overloading, RTDs can detect overheating due to a cooling system failure or localized overheating due to a failure of the insulation between the stator core laminations.

Inter-turn faults

Time (seconds)

The stator of some generators (hydroelectric in particular) are formed as a double-layer, multi-turn winding. In such machines a significant percentage of stator faults begin as turn-to-turn faults. Furthermore, these faults are not detectable by the phase or ground fault protections. If these faults can be detected before they evolve into phase or ground faults then the damage to the machine and associated downtime can be greatly reduced. The split phase element in the G60 and G30 has a unique operating characteristic that allows it to compensate for steady state errors in the split phase current (due to a winding repair, for instance) while allowing it to remain sensitive to an inter-turn (available in the G60 and G30).

Field Ground Protection Field ground protection identifies the occurrence of a ground fault in a generator field winding and helps to prevent serious damage to the generator, maximizing operational lifespan. The field ground protection module (GPM-F) works in combination with the G60 to detect ground faults in the field winding of the generator. The solution includes: two-stage field ground detection, injected voltage and current supervision, brush lift-off detection, field over and undercurrent elements and field ground fault location.

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Figure 8. Permissible short-time loading limits of a generator according to C50.13-2004

Tripping Faults There are a variety of faults or disturbances for which the generator protection IED must operate. For each fault type there are generally a set of actions that are carried out. These include tripping the generator breaker, tripping the field breaker, transfer of the auxiliaries, and tripping the prime mover. For example, an overfluxing condition requires a trip of the generator and field breaker, a transfer initiation, but no trip to the prime mover. This allows the machine to be resynchronized if the problem is resolved quickly. Internal programmable logic allows the tripping logic to be easily implemented. Additionally there are instances where the generator powerhouse is at a substantial distance from the switchyard. Using peer-peer messaging, tripping and status signals can be sent directly from the relay over fiber to a controller such as a C30 located adjacent to the generator breaker.

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Generator Protection

System Diagnostics Generator Protection

Modern microprocessor generator relays have superior operational recording capability that can be invaluable to both generator owners and generator system consultants. With this recording ability, generator operators can perform forensic engineering to get equipment back up and running, while at the same time, have all of the historical system operating information available to comply with statutory reporting requirements imposed by NERC and other regulatory bodies. Recording functions found in sophisticated generator relays include: • Event Recording with the ability to apply customized naming to inputs and elements shown in records • Waveform recording with both digital and analog information that includes naming of all inputs • Fault Reports with a summary of all critical info at the time of the fault

Figure 9. Advanced diagnostics using EnerVista Viewpoint Monitoring

• Trending reports for recording customize parameters to assist with specifying specific characteristics of the generator • Metering of voltage, current, power, frequency, power factor etc. Generator owners find recording capabilities invaluable for performing forensic engineering to get equipment back up and running and to comply with statutory reporting requirements imposed by NERC and other regulatory bodies.

Integration The integration of information collected from intelligent devices located throughout power plants into DCS and SCADA systems have provided a means for operational staff to get real time access to the status of their generators and have immediate control to the generators and their sub-systems. Through the use of robust , high-speed communications and industry standard protocols, modern generator relays can send data measured by the relays into dedicated power monitoring systems or balance of plant monitoring and control systems to allow for easy analysis of plant efficiencies.

PMU Power Authorities wishing to have synchronous measurement and reporting of power system phasor information can use a generator relay (G60) to provide this synchrophasor measurement of power being produced for integration into operation recording and monitoring systems. With this data available, power providers can accurately identify impending system problems and allow operators to react to these conditions that if left unresolved, could cause the generator to needlessly be brought offline, or worse, lead to an overall system collapse.

Figure 10. Generator event record data acquired using the Multilin G60 generator protection system

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Typical Applications

Generator Protection

Generator Protection – Typical Applications Direct Connection - Low Impedance Grounding

Typical Functions

Additional Functions

87G

Generator Stator differential

39

Vibration1

87RGF

Restricted ground fault

49

Thermal Overload

40

Loss of excitation

32R

Reverse Power

51V

Voltage restrained overcurrent

Functions

Typical Product Order Code

Typical Functions

G30-U00-HKH-F8L-H6L-M8N-PXX-UXX-WXX 489-P5-HI-A20-E

+ Additional Functions

G30-U00-HKH-F8L-H6L-M8N-P5C-U5F-WXX 489-P5-HI-A20-T-H

Lockout - Standalone Integrated

HEA61-A-RU-220-X2 G30-U00-HKH-F8L-H6L-M8N-P5C-U5F-W4L

1

External sensor or transducer module required

Unit Connected - High Impedance Grounding Typical Functions

Additional Functions

87G

39

Vibration1

49

Thermal Overload

64F

Field Ground Protection

64S

Sub-Harmonic Stator Ground Protection

Generator Stator differential

27TN/59N

100% Stator Earth Fault

40

Loss of excitation

32R

Reverse Power

21P

Phase Distance

Functions

Typical Product Order Code

Typical Functions

G60-U00-HKH-F8L-H6A-M8N-PXX-UXX-WXX 489-P5-HI-A20-T-H

+ Additional Functions

G60-U00-HKH-F8L-H6A-M8N-P5C-U5F-WXX 489-P5-HI-A20-T-H

Ground Protection

GPM-F-L (up to 600V) GPM-F-R with GPM-F-HM (above 600V) GPM-S-B (band pass filter) with GPM-S-G (20Hz generator)

Lockout - Standalone Integrated HEA61-A-RU-220-X2 G60-U00-HKH-F8L-H6A-M8N-P5C-U5F-W4L 1

32

External sensor or transducer module required

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Typical Applications

Hydro with Parallel Branch Winding Additional Functions

87G

Generator Stator differential

39

Vibration1

60SP

Split phase protection

49

Thermal Overload

40

Loss of excitation

64F

Field Ground Protection

32R

Reverse Power

64S

21P

Phase distance

Sub-Harmonic Stator Ground Protection

Functions

Typical Product Order Code

Typical Functions

G60-U00-HKH-F8L-H6A-M8N-PXX-UXX-WXX

+ Additional Functions

G60-U00-HKH-F8L-H6A-M8N-P5C-U5F-WXX

Lockout - Standalone Integrated

HEA61-A-RU-220-X2 G60-U00-HKH-F8L-H6A-M8N-P5C-U5F-W4L

1

Generator Protection

Typical Functions

External sensor or transducer module required

Pumped Storage Typical Functions

Additional Functions

87G

Generator Stator differential

39

Vibration1

27TN/59N

100% Stator Ground

49

Thermal Overload

40

Loss of excitation

32R

Reverse Power

21P

Phase distance

Functions

Typical Product Order Code

Typical Functions

G60-U00-HKH-F8L-H6A-M8N-PXX-UXX-WXX

+ Additional Functions

G60-U00-HKH-F8L-H6A-M8N-P5C-U5F-WXX

Lockout - Standalone Integrated

HEA61-A-RU-220-X2 G60-U00-HKH-F8L-H6A-M8N-P5C-U5F-W4L

1

External sensor or transducer module required

In-Zone Transformer Typical Functions

Additional Functions

87GT

39

Vibration1

49

Thermal Overload

Generator Transformer differential

27TN

3rd Harmonic Neutral Undervoltage

40

Loss of excitation

32R

Reverse Power

Functions

Typical Product Order Code

Typical Functions

G30-U00-HKH-F8L-H6L-M8N-PXX-UXX-WXX

+ Additional Functions

G30-U00-HKH-F8L-H6L-M8N-P5C-U5F-WXX

Lockout - Standalone Integrated

HEA61-A-RU-220-X2 G30-U00-HKH-F8L-H6L-M8N-P5C-U5F-W4L

1

External sensor or transducer module required

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33

Application Spotlight

Generator Protection

Advanced Generator Protection and Today’s critical generation systems require more sensitive, dependable protection. Coupled with the introduction of new regulatory requirements and a focus on infrastructure security, electrical system operators need real-time access to device status and metering value data from generating units and associated equipment, to effectively manage and maximize operational output and availability.

The G60 Generator Protection System is designed for medium & large sized generator applications and is well suited for applications where the generator is driven by turbines such as steam, gas or hydraulic. The G60 Generator Protection System also provides protection and control for pumped storage applications where the generator is used as both the generator and the pumping motor.

The Multilin G60 Generator Protection System sets a new standard in Generator protection and control with streaming synchrophasor measurements, advanced protection capabilities, cyber security features and tools and support for IEC 61850 communications.

With the ability to provide streaming synchronized phasor measurements according to the IEEE C37.118 standard, operators are able to maximize system availability with access to captured synchrophasor data to examine machine performance, including inter-unit oscillations, during power system disturbances.

Advanced Communications

Protection & Control

G60

HardFiber System

Generator Protection System

IEC 61850 Process Bus Solution

• Streaming Synchronized Phasor Measurements

• Hardened switchyard interface to acquire all measurement and I/O signals

• Industry leading cyber security including Dual Permission Access Control • Comprehensive support for IEC 61850 Process Bus with HardFiber System • Pumped storage generator applications • Advanced automation capabilities

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• Robust and secure communications via IEC 61850 over Fiber Optic cables • Reliable operation provided by integrity and self-check monitoring tools • Save up to 50% on Protection and Control Labor costs

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Application Spotlight

Communications Utilizing IEC 61850 With support for IEC 61850 communications, combine the Multilin G60 Generator Protection System with the Multilin IEC 61850 HardFiber System, to create a robust and secure Process Bus Solution. Eliminate the need for miles of long distance, point-to-point copper cabling that is traditionally required to obtain measurement and I/O signal data from generators and associated system devices that are interconnected over wide geographic areas. Utilities are able to gain significant reductions in costs and effort

associated with the engineering, installation and commissioning of new and retrofit generation systems while maintaining and gaining real-time access to generator status and metering values. Integrating the Multilin G60 Generator Protection System and the IEC 61850 HardFiber System, creates a robust process bus solution for generator station applications, provides detailed diagnostic information and secure control capabilities while reducing initial project capital costs and future maintenance costs.

Long Distance, High-Bandwidth, HardFiber Cable

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35

Generator Protection

Providing the latest in cyber security, the Multlin G60 Generator Protection System includes several layers of functions and tools to maintain secured device and system access including, Dual Permission Access Control, multiple passwords, and security event alarming and reporting.

Generator Protection

WATCH. INTERACT. LEARN. OVER 10,000 interactive tools and technical resources t hat showcase our Grid Modernization Solutions

Extensive library of interactive tools & videos 

Broad range of publications & technical resources

SOLUTIONS

SELECTOR GUIDES

to generator challenges

Discover innovative solutions for generators and DG (distributed generation) using our 3D power system.

“How To” videos &

for generator products

Compare, filter and select your product by protection, control, automation, and communications features to fit your application needs.

online product

TRAINING

CONFIGURATORS

Access over 60 step-by-step product videos and technical training to help you get the most out of your products.

Configure, price and easily order your generation protection products on the Digital Energy online store.

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Product Selector Guide

Generator Protection – Selector Guide APPLICATIONS & FUNCTIONALITY Small to Medium size generators Medium to Large size generators Low Impedance Grounded generators High Impedance Grounding generators Hydro plants with Split phases (parallel branch stator winding) Generators with In-Zone Transformer (in differential) PROTECTION & CONTROL Overspeed Distance Backup Volts/Hz Synchronism check Phase/Auxiliary Undervoltage Third Harmonic Neutral Undervoltage Directional Power Bearing RTD Loss of Field Loss of Field using Reactive Power Generator Unbalance Voltage phase reversal Thermal Overload Accidental Energization Instantaneous Overcurrent Phase/Ground/Neutral Timed Overcurrent Phase-Voltage Restraint/Ground/Neutral Split Phase Breaker Failure Overvoltage Phase/Neutral/ Auxiliary/Neg. Seq. 100% Stator Earth Fault using 3rd harmonic Undervoltage 100% Stator Earth Fault using 3rd harmonic Voltage Difference 100% Stator Earth Fault using sub-harmonic voltage injection Field Ground using low frequency injection Directional Overcurrent Phase/Ground/Neutral/Neg. Seq. Power Swing Blocking Out of Step Tripping Under/Overfrequency Rate of Change of Frequency Frequency Out-Of-Band Accumulator Lockout Generator Differential Generator & Transformer Differential Restricted Ground Fault Trip Bus AUTOMATION Contact Inputs (max) Contact Outputs (max) Analog Inputs (max) Analog Outputs (max) RTD Inputs (max) RRTD inputs (max) Virtual Inputs Virtual Outputs Direct Inputs Direct Outputs Teleprotection Inputs & Outputs Programmable Logic FlexElements Trip-Coil Supervision User-Programmable LED’s User-Programmable Pushbuttons Setting Groups Selector Switch Digital Counters Digital Elements Redundant Power Supply MONITORING & METERING Current Voltage Frequency Power Factor Power - Real, Reactive, Apparent Energy Demand - Current, MW, MVA, Mvar Temperature Event Recorder (number of events) Oscillography (max samples per cycle) Fault Reports (user programmable) Data Logger (max sample rate) VT Fuse Failure CT Failure Detector COMMUNICATIONS RS232/RS485 serial communications IEEE C37.94 fiber interface Ethernet Communications Fiber Optic Ethernet PROTOCOLS DNP 3.0 Protocol EGD (Ethernet Global Data) Protocol Modbus Protocol IEC 61870-5-103/104 protocol IEC61850 protocol Peer-to-Peer Communications (GSSE/GOOSE) CyberSentry Level 1 for cyber security Synchrophasors (PMU using IEEE C37.118) IEEE 1588 Parallel Redundancy Protocol (IEC 62439-3) Simple Network Time Protocol (SNTP) IRIG-B Input Process Bus (IEC 61850-9-2)

Device

489

G30

G60

•

• • • • • •

• • • •

• • P/X • • • • • •

• • • P/X • • • • • •

• •

12 21P 24 25 27P/X 27TN 32 38 40 40Q 46 47 49 50/27 50P/G/N 51PV/G/N 50SP 50BF 59 P/N/X/_2 27TN/59X 64TN/59X 64S 64F 67P/G/N/_2 68 78 81U/O 81R 81A 86 87G 87GT 87RGF TB

• • • P • • • • • • • • • P/G PV/G • P/X •

P/N/X/_2 •

G

P/N/_2

•

• •

•

9 6 4 4 12

•

• • • • • • • • 256 12 VTFF CTFD

• • P/G/N PV/G/N •

5s • • • • •

•

• • • •

Generator Protection

Features

• • P/G/N PV/G/N • • P/N/X/_2 • • • • P/N/_2 • • • • • • • • •

80 70 40 20 40 12 64 96 32 32 • • • • • • • • • • •

80 70 40 20 40 12 64 96 32 32 • • • • • • • • • • •

• • • • • •

• • • • • •

• 1024 64 • 15ms •

• 1024 64 • 15ms • •

• • • •

• • • •

• • • • • • • • • • • • •

• • • • • • • • • • • • •

For the most up-to-date selector guides, please visit

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37

Featured Products

Generator Protection

Generator Protection – Featured Products G60

Unparalleled Protection, Control, Diagnostics and Management of medium and large generators

39

Built on the industry-leading UR platform, the G60 offers superior protection for medium and large generators, including large steam and combustion turbines, combined cycle generators and multi-circuit hydro units. The G60 may also be used on pumped storage generators without the need of switching the CT secondary circuitry. The G60 provides advanced communication with the integration of a fully managed Ethernet switch reducing network installation costs while also supporting most industry standard communication protocols. It may be used as part of an automation control system with peer-to-peer communications or as a stand-alone protection device.

G30

Protection of small to medium sized generators and unit transformers

47

Built on the industry-leading UR platform, the G30 provides advanced protection for small to medium sized steam, hydraulic and combustion-turbine generators. The G30 is also well suited for applications where both the generator and transformer are in the same zone of protection providing the required protection in one device. The G30 provides advanced communication with the integration of a fully managed Ethernet switch while also supporting most industry standard communication protocols including IEC61850. The G30 also provides an advanced Security Audit Trail that records the setting changes and command made to the relay.

GPM-F

Field Ground Protection Module

55

Continuous monitoring for generator field windings. Working in combination with the Multilin G60 Generator Protection System, the GPM-F provides detection of ground faults in the field winding of the generator. For application flexibility the device can be configured for either single point or double point injection to ensure maximum asset life.

GPM-S

Stator Ground Protection Module Continuous monitoring and protection for a generator’s stator windings. The Multilin GPM-S Stator Ground Protection Module continuously monitors the integrity of the stator windings during stopped, starting and running conditions. This additional stator protection provides early detection of winding degradation, limiting potentially critical failures, costly asset damage, and costly system downtime.

Go online for the full listing of Multilin Protection & Control products

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59

Multilin™ G60 Comprehensive Protection for Generators

Protection and Control

The Multilin G60 generator protection system provides comprehensive protection for medium and large generators, including large steam and combustion turbines, combined-cycle generators and multicircuit hydro units.

• 100% Stator and Field Winding Ground Fault Protection (GPM-S & FPM-F Modules)

The G60 includes advanced automation and communication capabilities, extensive I/O options, and powerful fault recording features that can simplify postmortem disturbance analysis and help minimize generator downtime.

• Generator stator differential, loss of excitation, overexcitation and generator unbalance protection, and breaker failure • Power swing blocking and out-of-step tripping • Reverse/low forward power

Key Benefits • Secure, high-speed protection elements for complete generator protection, compliant with IEEE C37.102, extending asset life

®

• Available Ethernet Global Data (EGD) to ease integration with new and existing GE control systems • Embedded Synchrophasor measurement capabilities (per IEEE® C37.118), eliminating the need for dedicated PMUs and support for synchrophasor multi-cast (per IEC® 61850-90-5) reducing bandwidth and communications infrastructure costs • Advanced IEC 61850 Ed. 2 implementation, complete settings via SCL files and IEC 61850-9-2 process bus solution enable resource and platform managing optimization and reduce cost of ownership • Increased network availability via failover time reduced to zero through IEC® 62439-3 “PRP” support • CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC CIP, AAA, Radius, RBAC, Syslog) ®

• Advanced fault and disturbance recording, including internal relay operating signals, eliminating the need for external recording devices

Applications • Medium to large generators typically driven by steam, gas, or hydraulic turbines • Pumped storage generators used as pumping motors for reservoir storage • Stand-alone protection or component in automated substation control systems • Standard protection product offering on new GE generator installations

• Restricted ground fault, thermal overload protection, directional, time, instantaneous, phase, neutral, negative sequence and ground overcurrent protection

Communications • 3 independent Ethernet ports for simultaneous & dedicated network connections with IEEE 1588 support • Supported industry protocols: IEC 61850 Ed. 2, SFTP, MMS File Transfer Service, DNP 3.0, Modbus Serial/TCP, IEEE 1588, IEC 60870-5-104 and 103, PRP, SNTP, HTTP, TFTP

Cyber Security • CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog) • Setting for security audit trails, tracking changes to device configurations

Monitoring & Metering • P & M class synchrophasors of voltage, current and sequence components • Advanced recording capabilities with highcapacity event recorder, configurable and extended waveform capture and data logger • Metering: current, voltage, power, energy, frequency, and harmonics

G60 Generator Protection System

Generator Protection

Protection and Control

G60 - Protection, Metering, Monitoring and Control

As part of the UR family of Protection & Control devices, the G60 offers a high degree of modularity in its design and functionality, providing superior performance while meeting the toughest requirements of the marketplace. Advanced protection and control features of this relay includes:

Generator Stator Differential High-speed stator differential protection provides sub-cycle detection and high-speed clearing of stator phase faults. Advanced CT saturation and failure detection algorithms maintain immunity to high current AC and low current DC saturation conditions that may occur due to external disturbances, such as transformer inrush or near generator faults, without sacrificing speed or sensitivity.

100% Stator Ground 3rd Harmonic 100% stator ground fault protection is provided through a voltage differential feature that responds to the unbalance of the third harmonic at the machine terminals and at the neutral point. This method is insensitive to the absolute value of the third harmonic and is easily set without the need for on-line measurements. For generators with delta connected PTs, a third harmonic undervoltage element is also offered for detecting a loss of the third harmonic voltage at the generator neutral.

The G60 is the single point for protection, control, metering, and monitoring in one integrated device that can easily be connected directly into DCS or SCADA monitoring and control systems like Viewpoint Monitoring as shown.

Functional Block Diagram

SUPERVISED CLOSE

52

24

27P 2

3

3

3

EX

GPM-F

4

6

4

40 50/27 21P 50P 50N 51PV 50BF 51N 2

3

2

G

4

59P 59_2 59N 81O 81U 81R

3

32

Breaker Failure Protection The breaker failure protection element monitors for timely operation of the connected breaker. If a trip command is not successful in operating the breaker and clearing the fault, the breaker failure element can be used to send trip signals to upstream breakers to clear the fault.

25

TRIP

46

4

49

67P 67_2 67N 2

2

2

68

78

64F

Metering

87S

87G

2

GPM-S

50G 51G 27TN 27X 59X 2

2

64TN

R 64S

G60 Generator Protection System ANSI® Device Numbers & Functions DEVICE NUMBER

FUNCTION

DEVICE NUMBER

FUNCTION

DEVICE NUMBER

FUNCTION

21P 24 25 27P 27TN 27X 32 40 46 49 50G 50N

Phase Distance Backup Volts Per Hertz Synchronism Check Phase Undervoltage Third Harmonic Neutral Undervoltage Auxiliary Undervoltage Sensitive Directional Power Loss of Field Relay Generator Unbalance Thermal Overload Ground Instantaneous Overcurrent Neutral Instantaneous Overcurrent

50P 50SP 50BF 50/27 51G 51PV 51N 59N 59P 59X 59_2 64F

Phase Instantaneous Overcurrent Split Phase Instantaneous Overcurrent Breaker Failure Accidental Energization Ground Time Overcurrent Phase Time Overcurrent with Voltage Restraint Neutral Time Overcurrent Neutral Overvoltage Phase Overvoltage Auxiliary Overvoltage Negative Sequence Overvoltage Field Ground Protection

64S 64TN 67_2 67N 67P 68 78 81O 81R 81U 87G 87S

Sub-Harmonic Stator Ground Protection 100% Stator Ground Negative Sequence Directional Overcurrent Neutral Directional Overcurrent Phase Directional Overcurrent Power Swing Blocking Out-of-Step Protection Overfrequency Rate of Change of Frequency Underfrequency Restricted Ground Fault Generator Stator Differential

40

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G60 Generator Protection System

G60 Percent Differential Element

Restricted Ground Fault (87G)

Pumped Storage Generator

The G60 percent differential element has enhanced saturation detection algorithms to provide additional security against AC and DC saturation that can occur during faults near the generator.

Field Ground Protection Field ground protection identifies the occurrence of a ground fault in a generator field winding and helps to prevent serious damage to the generator, maximizing operational lifespan. The field ground protection module (GPM-F) works in combination with the G60 to detect ground faults in the field winding of the generator. The solution includes: two-stage field ground detection, injected voltage and current supervision, brush lift-off detection, field over and undercurrent elements and field ground fault location.

100% Stator Ground Fault Protection Using Sub-Harmonic Injection Protecting the generator from internal faults is critical to maintaining the overall life of the generator. Using the 100% stator ground fault protection based on sub-harmonic injection, a 20Hz voltage is injected to detect ground faults at any point across 100% of the winding. The stator ground module (GPM-S) works in combination with the G60 to provide 100% stator ground fault protection that is operational during generator start-up, running and stopped conditions. The solution includes: two-stage stator ground detection, injected voltage and current supervision and ground overcurrent element.

Loss of Excitation Generator loss of excitation protection is provided via two negative offset mho characteristics as per IEEE C37.102. Inadvertent

pickup time delay settings and blocking input provide security for blown VT fuses and power swing conditions.

Power Swing/Out-of-Step The power swing blocking element provides blocking of the backup distance element and other protections under power swing conditions. Negative sequence current supervisors provide extended selectivity for detecting evolving faults that may appear as a power swing event (faults with slow moving impedance locus). Additionally, the out-of-step tripping element can be used for tripping the generator when an unstable power swing is detected.

Backup Phase Distance Three separate phase distance elements provide time-delayed backup protection for generator faults that have not otherwise been cleared by the primary system and generator protection. Each zone can independently compensate for power transformers, so compensation can be applied for zones reaching out into the system through the unit transformer, while zones looking into the stator can remain uncompensated.

Sensitive Directional Power Two separate directional power elements are provided to detect generator motoring to protect the prime mover from damage. Each element responds to either reverse or low forward power flow and can be used to provide independent alarm and trip settings.

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The G60 can be used for protecting generators that are also run as pumped storage motors, without the need for switching the CT secondary circuitry. The G60 is able to automatically compensate for the phase reversal that occurs when the generator is being run as a motor.

Synchronism Check The G60 provides four elements to monitor differences in voltage magnitudes, phase angles, and frequencies to perform synchronism checks across breakers (up to four). The G60 can be used in conjunction with an external synchronizer as an independent check of the synchronizer prior to closing the generator breaker.

Temperature Protection (RTD Module Option 5C) The G60 RTD option provides 8 programmable RTD inputs per module that are used for temperature monitoring. Each RTD input has 2 operational levels: alarm and trip. The G60 supports RTD trip voting and provides open RTD failure alarming. Alternatively, a remote RTD module, “RRTD”, which supports 12 RTD inputs, can also be used with the G60 for temperature monitoring. The RRTD provides cost savings compared with standard RTD wiring.

IEC 61850 Process Bus The IEC 61850 Process Bus module is designed to interface with the Multilin HardFiber System, allowing bi-directional IEC 61850 fiber optic communications. The HardFiber System is designed to integrate seamlessly with existing UR applications, including protection functions, FlexLogic™, metering and communications. The Multilin HardFiber System offers the following benefits:

41

Generator Protection

RGF protection (also known as zero-sequence differential) extends protection coverage to the neutral point of the stator winding, where fault currents may be below the pickup of the main stator differential element. The low-impedance (87G) protection provided by the G60 uses an optimized adaptive restraint signal that provides security for external fault conditions that may cause CT saturation while still maintaining sensitivity for internal faults.

G60 Generator Protection System

Generator Protection

• Communicates using open standard IEC 61850 messaging • Drastically reduces P&C design, installation and testing labor by eliminating individual copper terminations • Integrates with existing G60’s by replacing traditional CT/VT inputs with the IEC 61850 Process Bus module • Does not introduce new cyber security concerns Visit the HardFiber System product page on the GE Digital Energy web site for more details.

Advanced Automation The G60 incorporates advanced automation features including powerful FlexLogic programmable logic, communication, and SCADA capabilities that far surpass what is found in the average generator relay. The G60 integrates seamlessly with other UR relays for complete system protection, including unit and auxiliary transformers, and balance of plant protection.

FlexLogic FlexLogic is the powerful UR-platform programming logic engine that provides the ability to create customized protection and control schemes, minimizing the need and associated costs of auxiliary components and wiring. Using FlexLogic, the G60 can be programmed to provide the required tripping logic along with custom scheme logic for generator breaker control (including interlocking with external synchronizers), transfer tripping schemes for remote breakers and dynamic setting group changes.

Scalable Hardware The G60 is available with a multitude of I/O configurations to suit the most demanding application needs. The expandable modular design allows for easy configuration and future upgrades.

• Multiple CT/VT configurations allow for the implementation of many different schemes, including concurrent split-phase and differential protection • Flexible, modular I/O covering a broad range of input signals and tripping schemes • Types of digital outputs include trip-rated Form-A and Solid State Relay (SSR) mechanically latching, and Form-C outputs • Form-A and SSR outputs available with optional circuit continuity monitoring and current detection to verify continuity and

42

health of the associated circuitry • Mechanically latching outputs can be used to develop secure interlocking applications and replace electromechanical lockout relays • RTDs and DCmA inputs are available to monitor equipment parameters such as temperature and pressure

Monitoring and Metering The G60 includes high accuracy metering and recording for all AC signals. Voltage, current, and power metering are built into the relay as a standard feature. Current and voltage parameters are available as total RMS magnitude, and as fundamental frequency magnitude and angle.

Fault and Disturbance Recording The advanced disturbance and event recording features within the G60 can significantly reduce the time needed for postmortem analysis of power system events and the creation of regulatory reports. Recording functions include: • Sequence of Event (SOE) - 1024 time stamped events • Oscillography - 64 digital & up to 40 analog channels - Events up to 45s in length • Data Logger and Disturbance Recording - 16 channels up to 1 sample/cycle/channel • Fault Reports - Powerful summary report of pre-fault and fault values The very high sampling rate and large amount of storage space available for data recording in the G60 can eliminate the need for installing costly stand-alone recording equipment.

Advanced Device Health Diagnostics The G60 performs comprehensive device health diagnostic tests at startup and continuously during run-time to test its own major functions and critical hardware. These diagnostic tests monitor for conditions that could impact security and availability of protection, and present device status via SCADA communications and front panel display. Providing continuous monitoring and early detection of possible issues help improve system uptime. • Comprehensive device health diagnostic performed at startup • Monitors the CT/VT input circuitry to validate the integrity of all signals

GEDigitalEnergy.com

Cyber Security – CyberSentry UR CyberSentry UR enabled UR devices deliver full cyber security features that help customers to comply with NERC CIP and NIST® IR 7628 cyber security requirements. This software option delivers the following core features:

AAA Server Support (Radius/LDAP) Enables integration with centrally managed authentication and accounting of all user activities and uses modern industry best practices and standards that meet and exceed NERC CIP requirements for authentication and password management.

Role Based Access Control (RBAC) Efficiently administrate users and roles within UR devices. The new and advanced access functions allow users to configure up to five roles for up to eight configurable users with independent passwords. The standard “Remote Authentication Dial In User Service” (Radius) is used for authentication.

Event Recorder (Syslog for SEM) Capture all cyber security related events within a SOE element (login, logout, invalid password attempts, remote/local access, user in session, settings change, FW update, etc), and then serve and classify data by security level using standard Syslog data format. This will enable integration with established SEM (Security Event Management) systems.

Communications The G60 provides advanced communications technologies for remote data and engineering access, making it easy and flexible to use and integrate into new and existing infrastructures. Direct support for fiber optic Ethernet provides high-bandwidth communications allowing for low-latency controls and high-speed file transfers of relay fault and event record information. The available three independent Ethernet ports, redundant Ethernet option and the embedded managed Ethernet switch provide the means to create fault tolerant communication architectures in an easy, cost-effective manner without the need for intermediary communication hardware. The G60 supports the most popular industry standard protocols enabling easy, direct integration into DCS and SCADA systems.

G60 Generator Protection System

• Configures GE Systems based on IEC 61850 using universal 3rd party tools

• DNP 3.0 (serial & TCP/IP)

• Multicast IEEE C37.118 synchrophasor data between PMU and PDC devices using IEC 91850-90-5

• Ethernet Global Data (EGD) • IEC 60870-5-103 and IEC 60870-5-104

• No external or handheld tester required to provide channel diagnostic information

LAN Redundancy

• Modbus RTU, Modbus TCP/IP

Direct I/O Messaging

• HTTP, TFTP, SFTP and MMS file transfer

Direct I/O allows for the sharing of high-speed digital information between multiple UR relays via direct back-to-back connections or multiplexed through a standard DS0 multiplexer channel bank. Regardless of the connection method, direct I/O provides continuous real-time channel monitoring that supplies diagnostics information on channel health.

• SNTP and IEEE 1588 for time synchronization • PRP as per IEC 62439-3

Interoperability with Embedded IEC 61850 Edition 2 The new IEC 61850 implementation in the UR Family positions GE as an industry leader in this standard. • Implements Edition 2 of the standard across the entire family of UR devices • Provides full relay setting management via standard SCL files (ICD, CID and IID) • Enables automated relay setting management using 3rd party tools through standard file transfer services (MMS and SFTP) • Increases the number of Logical Devices and data mapped to them, GOOSE messages, and reports to support different organizational needs for data transfer and reduce dependency on generic logical nodes

Direct I/O provides superior relay-to-relay communications that can be used in advanced interlocking, generation rejection and other special protection schemes. • Communication with up to 16 UR relays in single or redundant rings rather than strictly limited to simplistic point-to-point configurations between two devices • Connect to standard DS0 channel banks through standard RS422, G.703 or IEEE C37.94 interfaces or via direct fiber optic connections

Substation LAN redundancy has been traditionally accomplished by reconfiguring the active network topology in case of failure. Regardless of the type of LAN architecture (tree, mesh, etc), reconfiguring the active LAN requires time to switchover, during which the LAN is unavailable. UR devices deliver redundancy as specified by PRP-IEC 62439-3, which eliminates the dependency on LAN reconfiguration and the associated switchover time. The UR becomes a dual attached node that transmits data packets over both main and redundant networks simultaneously, so in case of failure, one of the data packets will reach the receiving device with no time delay.

Multi-Language UR devices support multiple languages: English, French, Russian, Chinese, Turkish and German. These language options are available on the front panel, in the EnerVista setup software, and in the product manuals. Easily switch between English and an additional language on the local displays without uploading new firmware.

Power System Troubleshooting The G60 contains many tools and reports that simplify and reduce the amount of time required for troubleshooting power system events.

Record the operation of the internal G60 elements and external connected devices with 1ms time-stamped accuracy to identify the Sequence of Operation of station devices during generator faults and disturbances.

Analyze generator faults using both analog and digital power system quantities that are measured and recorded up to a rate of 64 samples per cycle. Log generator operating parameters to allow for analyzing generator loading and performance over weeks and months.

GEDigitalEnergy.com

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Generator Protection

• IEC 61850 Ed. 2 with 61850-9-2 and 6185090-5 support

Generator Protection

G60 Generator Protection System

EnerVista Software

• Brochures

Viewpoint Maintenance

The EnerVista suite is an industry-leading set of software programs that simplifies every aspect of using the G60 relay. The EnerVista suite provides all the tools to monitor the status of the protected asset, maintain the relay, and integrate information measured by the G60 into DCS or SCADA monitoring systems. Convenient COMTRADE and SOE viewers are an integral part of the UR setup software included with every UR relay, to carry out postmortem event analysis and ensure proper protection system operation.

• Wiring Diagrams

Viewpoint Maintenance provides tools that will create reports on the operating status of the relay, simplify the steps to download fault and event data, and reduce the work required for cyber security compliance audits. Tools

• FAQs • Service Bulletins

Viewpoint Monitoring Viewpoint Monitoring is a simple-to-use and full-featured monitoring and data recording software package for small systems. Viewpoint Monitoring provides a complete HMI package with the following functionality:

available in Viewpoint Maintenance include: • Settings Security Audit Report • Device Health Report • Single-Click Fault Data Retrieval

• Plug & Play Device Monitoring

EnerVista Integrator

EnerVista Launchpad

• System Single-Line Monitoring & Control

EnerVista Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining Multilin products. The setup software within Launchpad allows for the configuration of devices in real-time by communicating using serial, Ethernet , or modem connections, or offline by creating setting files to be sent to devices at a later time.

• Annunciator Alarm Screens

EnerVista Integrator is a toolkit that allows seamless integration of Multilin devices into new or existing automation systems. Included

Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed. Documents made available include: • Manuals • Application Notes • Guideform Specifications

• Trending Reports • Automatic Event Retrieval • Automatic Waveform Retrieval

Viewpoint UR Engineer Viewpoint UR Engineer is a set of powerful tools that allows the configuration and testing of GE relays at a system level in an easy-touse graphical drag-and-drop environment . Viewpoint UR Engineer provides the following configuration and commissioning utilities:

in EnerVista Integrator is: • OPC/DDE Server • Multilin Drivers • Automatic Event Retrieval • Automatic Waveform Retrieval

• Graphical Logic Designer • Graphical System Designer • Graphical Logic Monitor • Graphical System Monitor

Simplifying Commissioning and Testing

Simplifying G60 Configuration

The internal operation of the G60 elements, logic, and outputs can be monitored in real-time to simplify commissioning and troubleshooting procedures.

Create G60 setting file templates to ensure critical settings are not altered.

44

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G60 Generator Protection System

User Interface

48 Configurable LED indicators

Multi-Language Display • English • Russian • French • Chinese • Turkish • German User-Programmable Pushbuttons

Typical Wiring

A B C

Tx1

10BaseFL 10BaseFL

CRITICAL FAILURE

V

F4c

TC 1

H1a H1b H1c H2a H2b H2c H3a H3b H3c H4a H4b H4c

TC 2

1

SURGE

IG1

F4a

F4b IG

F3c

IG5

V I

H4

Rx1

G60 GENERATOR MANAGEMENT RELAY

OUTPUT CONTROL POWER

RS-232 (front)

SURGE FILTER

DB-9

NORMAL ALTERNATE

COM 1

10BaseT RS485 com

X

GROUND BUS

W

V

U

T

S

R

P

N

M 8

PROVIDED

L

K

J

H 6

G

F 8

Inputs/ VT/CT outputs

D

B

9

1

CPU

Power Supply

TXD RXD

UR

G60-H00-HCH-F8F-H6G-M8H-PXX-UXX-WXX

CT

GEDigitalEnergy.com

CONNECTOR

IRIG-B Output

CONNECTOR

BNC

SGND

Co-axial

IRIG-B Input

8 3 RXD 2 TXD 20 7 SGND 6 4 5 22

BNC

1 2 3 4 5 6 7 8 9

Co-axial

COMPUTER

D1a D2a D3a D4b D4a

1 2 3 4 5 6 7 8 9

Remote Device

minimum

V I

H3

Rx2

Shielded

V I

H2

B1b B1a B2b B3a B3b B5b HI B6b LO B6a B8a B8b

Tx2

IC1

F2c IB1

IC5

H1

H8b

Fibre * Optic

I

6G

H7a H7c H8a H8c H7b

DC

F3b

F2b

F3a

IB

H5a H5c H6a H6c H5b

IC

F1c

F2a

IA1

IA

IB5

F1a

F1b

IA5

F8a

VC

F8c

F7c

VC

VX

F7a

VB

VX

F6a

F6c

VB

F5a

F5c VA

F 7c VC

VA

F 6c

F 7a

VB

VC

F 5c

VA

F 6a

F 5a

IG1

VB

M4c

IG

VA

M4a

M4b

IG5

M3b

M3c

IC

IC1

IB

M2c

M2a

M2b

IB5

M3a

M1c IA1

IB1

M1b IA

IC5

M1a IA5

R

45

Generator Protection

The G60 front panel provides extensive local HMI capabilities. The local display is used for monitoring, status messaging, fault diagnosis, and device configuration. User-configurable messages that combine text with live data can be displayed when user-defined conditions are met.

Ordering G60 - * 00 - H * * - F ** - H ** - M ** - P ** - U ** - W/X ** For full sized horizontal mount Base Unit G60 Base Unit CPU E RS485 + RS485 (IEC 61850 option not available) J RS485 + multimode ST 100BaseFX K RS485 + multimode ST Redundant 100BaseFX N RS485 + 10/100 BaseT T RS485 + three multimode SFP LC 100BaseFX. Req FW v7xx or higher U RS485 + two multimode SFP LC 100BaseFX + one SFP RJ45 100BaseT. Req FW v7xx or higher V RS485 + three SFP RJ45 100BaseT. Req FW v7xx or higher Software Options 00 No Software Options (see note 1 below) 01 Ethernet Global Data (EGD) 03 IEC 61850 04 Ethernet Global Data (EGD) + IEC 61850 05 Phasor Measurement Unit (PMU) 06 IEC 61850 + Phasor Measurement Unit (PMU) A0 CyberSentry UR Lvl 1. Req UR FW 7.xx or higher B0 IEEE 1588. Req UR FW 7.xx or higher C0 PRP D0 IEEE 1588 + CyberSentry UR. Req UR FW 7.xx or higher M0 IEC 61850 + PMU + 61850-90-5 Mount / Coating H Horizontal (19” rack) - Standard A Horizontal (19” rack) - Harsh Environment Coating V Vertical (3/4 size) - Standard B Vertical (3/4 size) - Harsh Environment Coating User Interface F Vertical Front Panel with English Display I Enhanced German Front Panel J Enhanced German Front Panel with User-Programmable Pushbuttons K Enhanced English Front Panel L Enhanced English Front Panel with User-Programmable Pushbuttons M Enhanced French Front Panel N Enhanced French Front Panel with User-Programmable Pushbuttons Q Enhanced Russian Front Panel T Enhanced Russian Front Panel with User-Programmable Pushbuttons U Enhanced Chinese Front Panel V Enhanced Chinese Front Panel with User-Programmable Pushbuttons W Enhanced Turkish Front Panel Y Enhanced Turkish Front Panel with User-Programmable Pushbuttons Power Supply H 125 / 250 V AC/DC (see note 2 below) H RH 125/250 V AC/DC with redundant 125/250 V AC/DC L 24 - 48 V (DC only) CT/VT DSP 8L 8L Standard 4CT/4VT w/ enhanced diagnostics 8M 8M Sensitive Ground 4CT/4VT w/ enhanced diagnostics 8N 8N Standard 8CT w/ enhanced diagnostics 8R 8R Sensitive Ground 8CT w/ enhanced diagnostics IEC 61850 Process Bus 81 8 Port IEC 61850 Process Bus Module Digital I/O XX XX XX XX XX No module 4A 4A 4A 4A 4A 4 Solid State (No Monitoring) MOSFET Outputs 4C 4C 4C 4C 4C 4 Solid State (Current w/opt Voltage) MOSFET Outputs 4D 4D 4D 4D 4D 16 Digital Inputs with Auto-Burnish 4L 4L 4L 4L 4L 14 Form-A (No Monitoring) Latchable Outputs 67 67 67 67 67 8 Form-A (No Monitoring) Outputs 6C 6C 6C 6C 6C 8 Form-C Outputs 6D 6D 6D 6D 6D 16 Digital Inputs 6E 6E 6E 6E 6E 4 Form-C Outputs, 8 Digital Inputs 6F 6F 6F 6F 6F 8 Fast Form-C Outputs 6K 6K 6K 6K 6K 4 Form-C & 4 Fast Form-C Outputs 6L 6L 6L 6L 6L 2 Form-A (Current w/ opt Voltage) & 2 Form-C Outputs, 8 Digital Inputs 6M 6M 6M 6M 6M 2 Form-A (Current w/ opt Voltage) & 4 Form-C Outputs, 4 Digital Inputs 6N 6N 6N 6N 6N 4 Form-A (Current w/ opt Voltage) Outputs, 8 Digital Inputs 6P 6P 6P 6P 6P 6 Form-A (Current w/ opt Voltage) Outputs, 4 Digital Inputs 6R 6R 6R 6R 6R 2 Form-A (No Monitoring) & 2 Form-C Outputs, 8 Digital Inputs 6S 6S 6S 6S 6S 2 Form-A (No Monitoring) & 4 Form-C Outputs, 4 Digital Inputs 6T 6T 6T 6T 6T 4 Form-A (No Monitoring) Outputs, 8 Digital Inputs 6U 6U 6U 6U 6U 6 Form-A (No Monitoring) Outputs, 4 Digital Inputs 6V 6V 6V 6V 6V 2 Form-A (Cur w/ opt Volt) 1 Form-C Output, 2 Latching Outputs, 8 Digital Inputs Transducer I/O 5A 5A 5A 5A 5A 4 dcmA Inputs, 4 dcmA Outputs 5C 5C 5C 5C 5C 8 RTD Inputs 5D 5D 5D 5D 5D 4 RTD Inputs, 4 dcmA Outputs 5E 5E 5E 5E 5E 4 dcmA Inputs, 4 RTD Inputs 5F 5F 5F 5F 5F 8 dcmA Inputs Inter-Relay Communications 7A 820 nm, multimode, LED, 1 Channel 7B 1300 nm, multimode, LED, 1 Channel 7C 1300 nm, singlemode, ELED, 1 Channel 7H 820 nm, multimode, LED, 2 Channels 7I 1300 nm, multimode, LED, 2 Channels 7J 1300 nm, singlemode, ELED, 2 Channels 7S G.703, 2 Channels 7W RS422, 2 Channels 76 IEEE C37.94, 820 nm, multimode, LED, 1 Channel 77 IEEE C37.94, 820 nm, multimode, LED, 2 Channel

Ordering Notes: 1. To view all available model order codes, options for G60 or to order the UR Classic Front Panel, please visit GE’s On-Line Store at http://store.gedigitalenergy.com/viewprod.asp?model=G60 2. Redundant power supply only available in horizontal unit. If redundant is chosen, must be same type. Maximum 2 per chassis

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12587H(E) English 150121

Multilin™ G30 Protection for Small to Medium Generators Combined Generators and Transformers The Multilin G30 generator protection system provides comprehensive protection for small to mediumsized steam, hydraulic and combustion-turbine generators as well as applications that have both the generator and transformer in the same zone of protection. The G30 is ideal for protecting single and multi-pole generators with single or split-phase winding configurations of generators. The G30 includes advanced automation and communication capabilities, extensive I/O options, and powerful fault recording features that can simplify fault and disturbance troubleshooting and minimize generator downtime.

Key Benefits • Advanced automation capabilities for providing customized protection and control solutions • Combined generator and transformer protection solution extending asset life • Advanced IEC 61850 Ed. 2 implementation, complete settings via SCL files and IEC 61850-9-2 process bus solution enable resource and platform managing optimization and reduce cost of ownership • Increased network availability via failover time reduced to zero through IEC 62439-3 “PRP” support ®

• CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog) • Advanced fault and disturbance recording, including internal relay operating signals, eliminating the need for external recording devices

Applications • Small to medium-sized generators typically driven by steam, gas or hydraulic turbines • Pumped storage generators • Combined generator and transformer in the zone of protection • Distributed Generator (DG) interconnect protection as per IEEE 1547 ®

Protection and Control • Generator differential protection including transformer • Restricted ground fault, thermal overload protection, directional, time, instantaneous, phase, neutral, negative sequence and ground overcurrent protection • Loss of excitation, overexcitation • 3rd Harmonic neutral undervoltage • Generator unbalance, reverse and low forward power • Accidental energization

Communications • 3 independent Ethernet ports for simultaneous & dedicated network connections with IEEE 1588 support • Supported industry protocols: IEC 61850 Ed. 2, SFTP, MMS File Transfer Service, DNP 3.0, Modbus Serial/TCP, IEEE 1588, IEC 60870-5-104 and 103, PRP, SNTP, HTTP, TFTP • Direct I/O: secure, high-speed exchange of data between UR relays for Direct Transfer Trip and I/O extension applications

Cyber Security • CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog) • Setting for security audit trails, tracking changes to device configurations

Monitoring & Metering • Advanced recording capabilities with highcapacity event recorder, configurable and extended waveform capture and data logger • Metering: current, voltage, power, energy, frequency, and harmonics

G30 Generator Protection System

Generator Protection

Protection and Control As part of the UR family of Protection & Control devices, the Multilin G30 offers a high degree of modularity in its design and functionality, providing superior performance while meeting the toughest requirements of the marketplace. Advanced protection and control features of this relay includes:

Generator/Transformer Differential High-speed percent differential protection is provided for detecting and clearing both generator stator and transformer winding faults that occur in the zone of protection of a single generator. The differential protection element has built-in phase compensation and magnitude compensation characteristics that allow for dealing with the inherent offset that occurs with CTs located on different windings of the transformer. These compensation characteristics eliminate the need for installing additional interposing CTs to account for the

difference in parameters measured by the relay. Advanced CT saturation and failure detection algorithms maintain immunity to high current AC and low current DC saturation conditions that may occur due to external disturbances, such as transformer inrush or near generator faults, without sacrificing speed or sensitivity.

2nd Harmonic Inrush Inhibit The G30 utilizes a 2nd harmonic inrush inhibit function to block the G30 from tripping under transformer inrush conditions that can otherwise cause the differential element to maloperate. This element can be configured to include the energization of different types of transformers by using either a traditional or adaptive mode of 2nd harmonic restraint. The adaptive 2nd harmonic restraint maintains protection dependability and speed on internal faults while ensuring security during inrush conditions even with weak second harmonics.

Overexcitation Inhibit An increase in transformer voltage or decrease in system frequency may result in overexcitation of the transformer. It is often desirable to prevent operation of the percent differential element in these cases. Therefore a fifth harmonic inhibit is integrated into a percent differential function to protect for overexcitation conditions resulting from an increased V/Hz ratio. The overexcitation inhibit works on a per-phase basis and is user-definable.

Functional Block Diagram PTs Located on Transformer HV Side

CLOSE TRIP

254 242 27P3 59P3 59_23 59N3 81O4 81U6 81R4

322

40 50/27

492

50N 51PV 51N 46 67P

50P2

67_22 67N2

87G2

METERING

87GT

50G 51G 27TN 27X2

59X2

G30 Generator Protection System ANSI® Device Numbers & Functions DEVICE NUMBER

FUNCTION

DEVICE NUMBER

FUNCTION

24 25 27P 27TN 27X 32 40 46 49 50G

Volts Per Hertz Synchronism Check Phase Undervoltage Third Harmonic Neutral Undervoltage Auxiliary Undervoltage Directional Power Loss of Excitation Generator Unbalance Thermal Overload Ground Instantaneous Overcurrent

50N 50P 50SP 50/27 51G 51N 51PV 59N 59P 59X

Neutral Instantaneous Overcurrent Phase Instantaneous Overcurrent Split Phase Instantaneous Overcurrent Accidental Energization Ground Time Overcurrent Neutral Time Overcurrent Phase Time Overcurrent with Voltage Restraint Neutral Overvoltage Phase Overvoltage Auxiliary Overvoltage

48

GEDigitalEnergy.com

DEVICE NUMBER

FUNCTION

59_2 67_2 67N 67P 81O 81R 81U 87GT 87G

Negative Sequence Overvoltage Negative Sequence Directional Overcurrent Neutral Directional Overcurrent Phase Directional Overcurrent Overfrequency Rate of Change of Frequency Underfrequency Generator/Transformer Differential Restricted Ground Fault

G30 Generator Protection System

2nd Harmonic Blocking Characteristic

can be used to provide independent alarm and trip settings.

Generator loss of excitation protection is provided via two negative offset mho characteristics as per IEEE C37.102. Independent pickup time delay settings and blocking input provide security for blown VT fuses and power swing conditions.

Frequency Rate of Change

The adaptive 2nd harmonic inhibit function will stop blocking the differential element as soon as the 2nd harmonic level drops below the pickup level if the angle of the 2nd harmonic to fundamental ratio is close to 0° or 180° (Point A). If the angle of the 2nd harmonic to fundamental ratio is close to 90°or 270°, this is an indication that the transformer is an inrush condition, even if the magnitude drops below the pickup level. The adaptive 2nd harmonic inhibit function will continue to block the differential element for an extended period of time (Point B).

The four available frequency rate of change (df/dt) elements can be used to provide protection against system disturbances through load shedding and to provide antiislanding protection. These elements monitor the speed by which the frequency changes in any direction, through voltage, current , and frequency supervision.

Pump Storage Generator Split-Phase Protection

below the pickup of the main stator differential element. The low-impedance RGF protection provided by the G30 uses an optimized adaptive restraint signal that provides security for external fault conditions that may cause CT saturation while still maintaining sensitivity for internal faults.

Split-phase protection is provided for sensitive detection for inter-turn faults and can be run in conjunction with the primary stator differential protection. Independent settings are provided on a per-phase basis and a single-slope bias characteristic is used to allow operation on machines with a section of winding bypassed.

Synchronism Check

Sensitive Directional Power

Restricted Ground Fault (RGF)

Two separate directional power elements are provided to detect reverse and low forward power conditions that are often needed for ensuring power only flows in one direction through the breaker. Each element responds to either reverse or low forward power flow and

Restricted ground fault protection (also known as zero-sequence differential) extends protection coverage to the neutral point of the stator winding, where fault currents may be

The G30 can be used for protecting generators that are also run as pump storage motors without the need for switching the CT secondary circuitry. The G30 is able to automatically compensate for the phase reversal that occurs when the generator is being run as a motor.

The G30 provides four elements to monitor differences in voltage magnitudes, phase angles, and frequencies to perform synchronism checks across breakers (up to four). The G30 can be used in conjunction with an external synchronizer as an independent check of the synchronizer prior to closing the generator breaker.

IEC 61850 Process Bus No Transformer CLOSE TRIP 242

254 27P3 59P3 59_23 59N3 81O4 81U6 81R4

322

40 50/27

492

50P2

50N 51P 51N 46 67P

67_22 67N2

The IEC 61850 Process Bus module is designed to interface with the Multilin HardFiber System, allowing bi-directional IEC 61850 fiber optic communications. The HardFiber System is designed to integrate seamlessly with existing UR applications, including protection functions, FlexLogic™, metering and communications. The Multilin HardFiber System offers the following benefits: • Communicates using open standard IEC 61850 messaging

METERING

87S

87G2

50G 51G

27TN

27X2

• Drastically reduces P&C design, installation and testing labor by eliminating individual copper terminations • Integrates with existing G30’s by replacing traditional CT/VT inputs with the IEC 61850 Process Bus module

59X2

G30 Generator Protection System

• Does not introduce new cyber security concerns

GEDigitalEnergy.com

49

Generator Protection

Loss of Excitation

G30 Generator Protection System

Generator Protection

Visit the HardFiber System product page on the GE Digital Energy web site for more details.

Advanced Automation The G30 incorporates advanced automation features including powerful FlexLogic programmable logic, communication, and SCADA capabilities that far surpass what is found in the average generator relay. The G30 integrates seamlessly with other UR relays for complete system protection, including the unit and auxiliary transformers, and balance of plant protection.

FlexLogic FlexLogic is the powerful UR-platform programming logic engine that provides the ability to create customized protection and control schemes, minimizing the need and associated costs of auxiliary components and wiring. Using FlexLogic, the G30 can be programmed to provide the required tripping logic along with custom scheme logic for generator breaker control (including interlocking with external synchronizers), transfer tripping schemes for remote breakers and dynamic setting group changes.

Scalable Hardware The G30 is available with a multitude of I/O configurations to suit the most demanding application needs. The expandable modular design allows for easy configuration and future upgrades. • Multiple CT/VT configurations allow for the implementation of many differential schemes, including concurrent split-phase and differential protection • Up to 80 digital inputs and up to 56 digital outputs are available • Types of digital outputs include trip-rated Form-A and Solid State Relay (SSR) mechanically latching, and Form-C outputs • RTDs and DCmA inputs are available to monitor equipment parameters such as temperature and pressure

Monitoring and Metering The G30 includes high accuracy metering and recording for all AC signals. Voltage, current , and power metering are built into the relay as a standard feature. Current and voltage parameters are available as total RMS magnitude, and as fundamental frequency magnitude and angle.

50

Fault and Disturbance Recording

Role Based Access Control (RBAC)

The advanced disturbance and event recording features within the G30 can significantly reduce the time needed for postmortem analysis of power system events and the creation of regulatory reports. Recording functions include:

Efficiently administrate users and roles within UR devices. The new and advanced access functions allow users to configure up to five roles for up to eight configurable users with independent passwords. The standard “Remote Authentication Dial In User Service” (Radius) is used for authentication.

• Sequence of Event (SOE) - 1024 time stamped events • Oscillography - 64 digital & up to 40 analog channels - Events up to 45s in length • Data Logger and Disturbance Recording - 16 channels up to 1 sample/cycle/channel • Fault Reports - Powerful summary report of pre-fault and fault values The very high sampling rates and large amounts of storage space available for data recording in the G30 can eliminate the need for installing costly stand-alone recording equipment.

Advanced Device Health Diagnostics The G30 performs comprehensive device health diagnostic tests at startup and continuously during run-time to test its own major functions and critical hardware. These diagnostic tests monitor for conditions that could impact security and availability of protection, and present device status via SCADA communications and front panel display. Providing continuous monitoring and early detection of possible issues help improve system uptime. • Comprehensive device health diagnostic performed at startup • Monitors the CT/VT input circuitry to validate the integrity of all signals • Input, outputs, trip circuits and analog channels are continuously monitored for accuracy and performance

Event Recorder (Syslog for SEM) Capture all cyber security related events within a SOE element (login, logout, invalid password attempts, remote/local access, user in session, settings change, FW update, etc), and then serve and classify data by security level using standard Syslog data format. This will enable integration with established SEM (Security Event Management) systems.

Communications The G30 provides advanced commun-ications technologies for remote data and engineering access, making it the easiest and most flexible generator protection relay to use and integrate into new and existing infrastructures. Direct support for fiber optic Ethernet provides high-bandwidth communications allowing for low-latency controls and high-speed file transfers of relay fault and event record information. The available three independent Ethernet ports, redundant Ethernet option and the embedded managed Ethernet switch provide the means to create fault tolerant communication architectures in an easy, cost-effective manner without the need for intermediary communication hardware. The G30 supports the most popular industry standard protocols enabling easy, direct integration into DCS and SCADA systems. • IEC 61850 Ed. 2 with 61850-9-2 support • DNP 3.0 (serial & TCP/IP)

Cyber Security - CyberSentry UR

• Ethernet Global Data (EGD)

CyberSentry UR enabled UR devices deliver full cyber security features that help customers to comply with NERC CIP and NIST® IR 7628 cyber security requirements. This software option delivers the following core features:

• IEC 60870-5-103 and IEC 60870-5-104

AAA Server Support (Radius/LDAP) Enables integration with centrally managed authentication and accounting of all user activities and uses modern industry best practices and standards that meet and exceed NERC CIP requirements for authentication and password management.

GEDigitalEnergy.com

• Modbus RTU, Modbus TCP/IP • HTTP, TFTP, SFTP and MMS file transfer • SNTP and IEEE 1588 for time synchronization • PRP as per IEC 62439-3

Interoperability with Embedded IEC 61850 Edition 2 The new IEC 61850 implementation in the UR Family positions GE as an industry leader in this standard.

G30 Generator Protection System

• Implements Edition 2 of the standard across the entire family of UR devices

• Enables automated relay setting management using 3rd party tools through standard file transfer services (MMS and SFTP) • Increases the number of Logical Devices and data mapped to them, GOOSE messages, and reports to support different organizational needs for data transfer and reduce dependency on generic logical nodes • Configures GE Systems based on IEC 61850 using universal 3rd party tools

Direct I/O Messaging Direct I/O allows for the sharing of high-speed digital information between multiple UR relays via direct back-to-back connections or multiplexed through a standard DS0 multiplexer channel bank. Regardless of the connection method, direct I/O provides continuous real-time channel monitoring that supplies diagnostics information on channel health. Direct I/O provides superior relay-to-relay communications that can be used in advanced interlocking, generation rejection and other special protection schemes.

• Connect to standard DS0 channel banks through standard RS422, G.703 or IEEE C37.94 interfaces or via direct fiber optic connections • Built-in continuous loop and channel monitoring provides real-time diagnostics of your communication channels with no external or handheld tester required

LAN Redundancy Substation LAN redundancy has been traditionally accomplished by reconfiguring the active network topology in case of failure. Regardless of the type of LAN architecture (tree, mesh, etc), reconfiguring the active LAN requires time to switchover, during which the LAN is unavailable. UR devices deliver redundancy as specified by PRP-IEC 62439-3, which eliminates the dependency on LAN reconfiguration and the associated switchover time. The UR becomes a dual attached node that transmits data packets over both main and redundant networks simultaneously, so in case of failure, one of the data packets will reach the receiving device with no time delay.

Multi-Language UR devices support multiple languages: English, French, Russian, Chinese, Turkish and German. These language options are available on the front panel, in the EnerVista setup software, and in the product manuals. Easily switch between English and an additional language on the local displays without uploading new firmware.

EnerVista Software The EnerVista suite is an industry-leading set of software programs that simplifies every aspect of using the G30 relay. The EnerVista suite provides all the tools to monitor the status of your generator, maintain your relay, and integrate information measured by the G30 into DCS or SCADA monitoring systems. Convenient COMTRADE and SOE viewers are an integral part of the UR setup software included with every UR relay, to carry out postmortem event analysis to ensure proper protection system operation.

EnerVista Launchpad EnerVista Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining Multilin products. The setup software within Launchpad allows for the configuration of devices in real-time by

Power System Troubleshooting

The G30 contains many tools and reports that simplify and reduce the amount of time required for troubleshooting power system events.

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51

Generator Protection

• Provides full relay setting management via standard SCL files (ICD, CID and IID)

• Communication with up to 16 UR relays in single or redundant rings rather than simplistic point-to-point configurations

G30 Generator Protection System

Generator Protection

communicating using serial, Ethernet , or modem connections, or offline by creating setting files to be sent to devices at a later time. Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed. Documents made available include:

Viwpoint Monitoring

Viewpoint Maintenance

Viewpoint Monitoring is a simple-to-use and full-featured monitoring and data recording software package for small systems. Viewpoint Monitoring provides a complete HMI package with the following functionality:

Viewpoint Maintenance provides tools that will create reports on the operating status of the relay, simplify the steps to download fault and event data, and reduce the work required for cyber security compliance audits. Tools available in Viewpoint Maintenance include:

• Plug & Play Device Monitoring

• Manuals

• System Single-Line Monitoring & Control

• Settings Security Audit Report

• Application Notes

• Annunciator Alarm Screens

• Device Health Report

• Guideform Specifications

• Trending Reports

• Single-Click Fault Data Retrieval

• Brochures

• Automatic Event Retrieval

EnerVista Integrator

• Wiring Diagrams

• Automatic Waveform Retrieval

EnerVista Integrator is a toolkit that allows seamless integration of Multilin devices into new or existing automation systems. Included in EnerVista Integrator is:

• FAQs • Service Bulletins

Viewpoint UR Engineer Viewpoint UR Engineer is a set of powerful tools that allows you to configure and test GE relays at a system level in an easy-to-use graphical drag-and-drop environment . Viewpoint UR Engineer provides the following configuration and commissioning utilities:

• OPC/DDE Server • Multilin Drivers • Automatic Event Retrieval • Automatic Waveform Retrieval

• Graphical Logic Designer • Graphical System Designer • Graphical Logic Monitor • Graphical System Monitor

Providing Traceability and Regulatory Audit Tracking The G30 tracks and records information about configuration changes that have been made to the relay, providing a method to audit system security and engineering processes.

52

GEDigitalEnergy.com

G30 Generator Protection System

User Interface

48 Configurable LED Indicators

The G30 front panel provides extensive local HMI capabilities. The local display is used for monitoring, status messaging, fault diagnosis, and device configuration. User-configurable messages that combine text with live data can be displayed when user-defined conditions are met.

Generator Protection

Multi-Language Display • English • Russian • French • Chinese • Turkish • German User-Programmable Pushbuttons

Typical Wiring ALTERNATE

A

A

B

B

C

C

52

NOTE:

I

H4

10BaseFL Rx2

CRITICAL FAILURE

V

F7c VC

F6c

F7a

H1a H1b H1c H2a H2b H2c H3a H3b H3c H4a H4b H4c

D1a D2a D3a D4b D4a

G30 GENERATOR MANAGEMENT RELAY

OUTPUT

RS-232 (front)

SURGE FILTER

DB-9

NORMAL ALTERNATE

UR

COM 1

TXD RXD RS485

BNC

Co-axial

SGND

com

BNC

Co-axial

TC 2

CONTROL POWER

10BaseT

Remote Device

TC 1

1

SURGE

VB

F6a V

VC

VB V I

H3

10BaseFL

Shielded

F5a

VX

H2

Rx1 Tx2

V I

B1b B1a B2b B3a B3b B5b HI B6b LO B6a B8a B8b

Tx1

F5c

VX

H1

H8b

Fibre * Optic

I

6G

H7a H7c H8a H8c H7b

DC

VA

F8a

F8c

VC

H5a H5c H6a H6c H5b

VA

F6c

F7a

F7c

VB

VC

F5a

F5c

F6a VB

F4c

VA

IG1

VA

F4a

F3c

F4b IG

IC1

IG5

F3a

F3b IC

IB

IB1

IC5

F2a

F2b

F2c

IB5

F1a

F1b

F1c

IA

IA1

M4c IG1

IA5

M3c

M4a

M4b IG

M3b IC

IC1

IG5

M2c

M3a

IB1

IB

IC5

M1c

M2a

M2b

IA1

IA

IB5

M1a

M1b

IA5

R

IRIG-B Input IRIG-B Output

1 2 3 4 5 6 7 8 9

CONNECTOR

COMPUTER

1 2 3 4 5 6 7 8 9

8 3 RXD 2 TXD 20 7 SGND 6 4 5 22

CONNECTOR

830744A2.CDR

minimum GROUND BUS

X PROVIDED

W

V

U

T

S

R

P

N

M 8 CT

L

K

J

H 6

G

F 8

Inputs/ VT/CT outputs

D

B

9

1

CPU

Power Supply

G30-H00-HCH-F8F-H6G-M8H-PXX-UXX-WXX

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53

Ordering G30 - * 00 - H * * - F ** - H ** - M ** - P ** - U ** - W/X ** For Full Sized Horizontal Mount Base Unit G30 Base Unit CPU E RS485 + RS485 (IEC 61850 option not available) J RS485 + multimode ST 100BaseFX K RS485 + multimode ST Redundant 100BaseFX N RS485 + 10/100 BaseT T RS485 + three multimode SFP LC 100BaseFX. Req FW v7xx or higher U RS485 + two multimode SFP LC 100BaseFX + one SFP RJ45 100BaseT. Req FW v7xx or higher V RS485 + three SFP RJ45 100BaseT. Req FW v7xx or higher Software Options 00 No Software Options (see note 1 below) 01 Ethernet Global Data (EGD) 03 IEC 61850 04 Ethernet Global Data (EGD) + IEC 61850 A0 CyberSentry UR Lvl 1. Req UR FW 7.xx or higher B0 IEEE 1588. Req UR FW 7.xx or higher C0 PRP D0 IEEE 1588 + CyberSentry. Req UR FW 7.xx or higher Mount / Coating H Horizontal (19" rack) - Standard A Horizontal (19" rack) - Harsh Environment Coating V Vertical (3/4 size) - Standard B Vertical (3/4 size) - Harsh Environment Coating User Interface F Vertical Front Panel with English Display I Enhanced German Front Panel J Enhanced German Front Panel with User-Programmable Pushbuttons K Enhanced English Front Panel L Enhanced English Front Panel with User-Programmable Pushbuttons M Enhanced French Front Panel N Enhanced French Front Panel with User-Programmable Pushbuttons Q Enhanced Russian Front Panel T Enhanced Russian Front Panel with User-Programmable Pushbuttons U Enhanced Chinese Front Panel V Enhanced Chinese Front Panel with User-Programmable Pushbuttons W Enhanced Turkish Front Panel Y Enhanced Turkish Front Panel with User-Programmable Pushbuttons Power Supply H 125 / 250 V AC/DC (see note 2 below) H RH 125/250 V AC/DC with redundant 125/250 V AC/DC L 24 - 48 V (DC only) CT/VT DSP 8L 8L Standard 4CT/4VT w/ enhanced diagnostics 8M 8M Sensitive Ground 4CT/4VT w/ enhanced diagnostics 8N 8N Standard 8CT w/ enhanced diagnostics 8R 8R Sensitive ground 8CT w/ enhanced diagnostic IEC 61850 Process Bus 81 8 Port IEC 61850 Process Bus Module Digital I/O XX XX XX XX XX XX No Module 4A 4A 4A 4A 4A 4A 4 Solid State (No Monitoring) MOSFET Outputs 4C 4C 4C 4C 4C 4C 4 Solid State (Current w/opt Voltage) MOSFET Outputs 4D 4D 4D 4D 4D 4D 16 Digital Inputs with Auto-Burnish 4L 4L 4L 4L 4L 4L 14 Form-A (No Monitoring) Latchable Outputs 67 67 67 67 67 67 8 Form-A (No Monitoring) Outputs 6C 6C 6C 6C 6C 6C 8 Form-C Outputs 6D 6D 6D 6D 6D 6D 16 Digital Inputs 6E 6E 6E 6E 6E 6E 4 Form-C Outputs, 8 Digital Inputs 6F 6F 6F 6F 6F 6F 8 Fast Form-C Outputs 6K 6K 6K 6K 6K 6K 4 Form-C & 4 Fast Form-C Outputs 6L 6L 6L 6L 6L 6L 2 Form-A (Current w/ opt Voltage) & 2 Form-C Outputs, 8 Digital Inputs 6M 6M 6M 6M 6M 6M 2 Form-A (Current w/ opt Voltage) & 4 Form-C Outputs, 4 Digital Inputs 6N 6N 6N 6N 6N 6N 4 Form-A (Current w/ opt Voltage) Outputs, 8 Digital Inputs 6P 6P 6P 6P 6P 6P 6 Form-A (Current w/ opt Voltage) Outputs, 4 Digital Inputs 6R 6R 6R 6R 6R 6R 2 Form-A (No Monitoring) & 2 Form-C Outputs, 8 Digital Inputs 6S 6S 6S 6S 6S 6S 2 Form-A (No Monitoring) & 4 Form-C Outputs, 4 Digital Inputs 6T 6T 6T 6T 6T 6T 4 Form-A (No Monitoring) Outputs, 8 Digital Inputs 6U 6U 6U 6U 6U 6U 6 Form-A (No Monitoring) Outputs, 4 Digital Inputs 6V 6V 6V 6V 6V 6V 2 Form-A (Cur w/ opt Volt) 1 Form-C Output, 2 Latching Outputs, 8 Digital Inputs Transducer I/O 5C 5C 5C 5C 5C 5C 8 RTD Inputs 5E 5E 5E 5E 5E 5E 4 dcmA Inputs, 4 RTD Inputs 5F 5F 5F 5F 5F 5F 8 dcmA Inputs Inter-Relay Communications 7A 820 nm, multimode, LED, 1 Channel 7B 1300 nm, multimode, LED, 1 Channel 7C 1300 nm, singlemode, ELED, 1 Channel 7H 820 nm, multimode, LED, 2 Channels 7I 1300 nm, multimode, LED, 2 Channels 7J 1300 nm, singlemode, ELED, 2 Channels 7R G.703, 1 Channels 7S G.703, 2 Channels 7T RS422, 1 Channels 7W RS422, 2 Channels 76 IEEE C37.94, 820 nm, multimode, LED, 1 Channel 77 IEEE C37.94, 820 nm, multimode, LED, 2 Channel 2A C37.94SM, 1300nm singlemode, ELED, 1 Channel singlemode 2B C37.94SM, 1300nm singlemode, ELED, 2 Channel singlemode

Ordering Note:

 .To view all the options available for G30, please visit GE’s On-Line Store at http://store.gedigitalenergy.com/viewprod.asp?model=G30 1 2. Redundant power supply only available in horizontal unit. If redundant is chosen, must be same type. Maximum 2 per chassis

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Passport.GEDigitalEnergy.com 12757G(E) English 150121

Multilin™ GPM-F Field Ground Protection Module The Multilin GPM-F field ground protection module works in combination with the Multilin G60 Generator Protection System to detect ground faults in the field winding of the generator. Providing application flexibility, the field ground protection module can be configured for either single point injection or double point injection based on application requirements. The solution includes two stage field ground detection, injected voltage and current supervision, brush lift-off detection, field over and under current elements and field ground fault location. 

Key Benefits • Providing advanced field ground fault protection for generator applications • Allowing both single point and double point injection methods provides optimal application flexibility depending on system configuration

Protection • Two stage field ground resistance based element - 64F • Wide range fault resistance coverage (1- 500Kohms) • Injection frequency range 0.1 – 3Hz based on field winding capacitance • Fault location feature while using single point injection • Brush-lift off detection

• Reduce generator down-time by locating the fault within the field winding when connected in single point injection method

• Injection blocking input for field flashing condition

• Designed to operate with GE’s Multilin industry leading G60 Generator Protection System

• Supports redundant G60 configurations

• Continuously monitors and protects the generator during stopped, starting and running conditions for increased asset life

• Field over current and field under current elements using dcmA input of G60

• Reduce system configuration time by configuring the Field Ground Protection Module through the G60 Generator Protection System and the easy-to-use EnerVista Setup Software • Increase generator lifespan by easily upgrading your current G60 generator protection relay with the Field Ground Protection Module • Simplified setup and configuration using EnerVista setup software

Applications • Medium to large generator applications • Deployable with redundant generator protection systems • Suitable for use with generator field voltages up to 800VDC

Diagnostics • Power swing blocking and out-of-step tripping • Backup distance • Reverse / low forward power • Restricted ground fault • Overexcitation • Generator unbalance

GPM-F Field Ground Protection Module

Generator Protection

Protection & Control The G60 Generator Protection System provides comprehensive protection for medium and large generators, including large steam and combustion turbines, combined-cycle generators and multi-circuit hydro units. The G60 includes advanced automation and communication capabilities, extensive I/O options, and powerful fault recording features that can simplify postmortem disturbance analysis and help minimize generator downtime. As part of the UR Family, the G60 provides superior protection and control that includes:

Field Ground Protection: Field ground protection identifies occurrence of ground fault in a generator field winding and helps to prevent serious damage to the generator, maximizing operational lifespan. The field ground protection module, GPM-F works in combination with the Multilin G60 to detect ground faults in the field winding of the generator. Providing application flexibility, the field ground protection module can be configured for either single point injection or double point injection based on application

requirements. The solution includes: two stage field ground detection, injected voltage and current supervision, brush lift-off detection, field over and under current elements and field ground fault location.

G60 Generator Protection Integration

If the rated field voltage of the generator is less than or equal to 600 Vdc, then a single box solution is provided. However if the rated field voltage of the generator is between 600800Vdc, then an external resistor box is provided to facilitate safer installation and operational practices.

• The G60, GPM-S, and GPM-F modules provide complete generator protection

Single point Injection

• GPM-S & GPM-F Protection units are connected directly to the G60 relay

Providing application flexibility and diagnostic information, single point injection provides the ability to quickly identify the fault location in the field winding, thus reducing damaging the generator and reducing down-time. Single point injection can’t be used on generators with brushless excitation unless both poles of the field winding is directly connected to a brush.

Double point Injection In addition to single point injection, the GPM-F module allows for ground fault detection via

• All configuration and monitoring is performed through the G60

double point injection. Double point injection has typically been used on applications where generators are equipped with static excitation. When the GPM-F is connected for double point injection the fault location feature is not available. It is recommended that is fault location is required that the GPM-F be configured for single point injection.

Field Ground Fault Detection

Excitation Cabinet

Slip Rings

Injection Unit Resistor Box

Field ground units are used to protect the field windings in the generator. This assists with preventing serious damage to the generator. The field ground units come with two options: • Single box solution for field voltages up to 600 VDC • An additional resistor box for field voltages between 600-800 VDC

56

GEDigitalEnergy.com

Rotor

Stator

GPM-F Field Ground Protection Module

Functional Block Diagram

ANSI Device Numbers & Functions ®

Trip

25 24

27P

59P 59_2 59N 81O 81U 81R

32

40

50/27 21P

50P 50N

46

51P 51N

6 7 P 6 7 _2 6 7 N

68

78

49

G

EX

64F

GPM-F

Metering 87S

1.000 1.000 87G 50G 51G 27TN 27X

59X 64TN 10.072

R

7.574 10.072 7.574

64S

FUNCTION

21P 24 25 27P 27TN 27X 32 40 46 49 50G 50N 50P 50SP 50/27 51G 51P 59N 59P 59X 59_2 64F 64S 64TN 67_2 67N 67P 68 78 81O 81R 81U 87G 87S

Phase Distance Backup Volts Per Hertz Synchronism Check Phase Undervoltage Third Harmonic Neutral Undervoltage Auxiliary Undervoltage Sensitive Directional Power Loss of Field Relay Generator Unbalance Thermal Overload RTD Ground Instantaneous Overcurrent Neutral Instantaneous Overcurrent Phase Instantaneous Overcurrent Split Phase Instantaneous Overcurrent Accidental Energization Ground Time Overcurrent Phase Time Overcurrent Neutral Overvoltage Phase Overvoltage Auxiliary Overvoltage Negative Sequence Overvoltage Field ground protection Sub-harmonic stator ground protection 100% stator ground Negative Sequence Directional Overcurrent Neutral Directional Overcurrent Phase Directional Overcurrent Power Swing Blocking Out-of-Step Protection Overfrequency Rate of Change of Frequency Underfrequency Restricted ground fault Generator Stator Differential

Generator Protection

Close

52

DEVICE NUMBER

G60 Generator Protection System

Dimensional Data

11.770 11.770

Field Ground Module (Up to 600 VDC Field Voltages) Top

Front 1.000

2.306 2.306 12.270 7.000

10.072

12.270

Side

7.574

10.142 10.142 6.500 5.875

5.000

11.770

9.090 9.090

High Voltage Resister Box Module (Field Voltages 600 VDC - 800 VDC) 3.500

Top

2.306

7.000

Side

12.270

7.000

6.500 5.875

5.000

2.500

10.142

2.750

8.600

3.500

9.090

7.000

GEDigitalEnergy.com 2.500

2.750

57

Protection Specifications Field Ground

Measured Field Ground Resistance Range: Ground Resistance Accuracy: Field winding Capacitance: Maximum Field Voltage:

Field voltage measurement range: Field voltage measurement accuracy - low Field voltage measurement accuracy - high Field ground RMS current accuracy: Fault location accuracy: Field ground resistance elements typical operating time: Field ground element dropout level accuracy: Time delay accuracy:

Field Current

Field current measurement (dcmA) accuracy: Field over and under current elements operating time: Field current element dropout level accuracy: Time delay accuracy:

Tests

1 kΩ–20 MΩ +/- 5% of reading +/- 250 Ω over the range 1 kΩ-500 kΩ 1–10 µF 600Vdc rated field voltage / 1000V ripple peak for single box option 800 Vdc rated field voltage / 2000V ripple peak for external resistor box option 15-800 Volts +/- 1V or +/- 3% of reading

Dielectric voltage withstand Impulse voltage withstand Insulation resistance Damped oscillatory Electrostatic discharge RF immunity Fast transient disturbance Surge immunity Conducted RF immunity

+/- 1V or +/-5% of reading +/- 5% of reading +/- 5% of reading 1.1s + (1/Injection frequency) 102-103% of pickup +/- 3% of time delay setting or +/- 4ms whichever is greater +/- 0.2% of full scale 1 power system cycle 102-103% of pickup for UC and 97-98% for OC +/- 3% of time delay setting or +/- 4ms whichever is greater

Voltage interruption and ripple DC Radiated and conducted emissions Sinusoidal vibration Shock and bump Seismic Power magnetic immunity Pulse magnetic immunity Damped magnetic immunity Voltage dip and interruption Voltage ripple Ingress protection Environment (Cold) Environment (Hot) Humidity SWC oscillatory SWC transients RF immunity ESD Safety Safety

EN60255-5

Approvals

CE compliance

EN60255-5 EN60255-5 IEC 61000-4-18 / IEC 60255-22-1 EN61000-4-2 / IEC 60255-22-2 EN61000-4-3 / IEC 60255-22-3 EN61000-4-4 / IEC 60255-22-4 EN61000-4-5 / IEC 60255-22-5 EN61000-4-6 / IEC 60255-22-6 IEC 60255-11

North America ISO

Environmentals Temperature: Humidity: Altitude: Pollution Degree: Overvoltage Category: Ingress Protection:

EN60255-5 EN60255-27 EN60255-26 EN50263 UL508 UL1053 C22.2 No. 14 ISO9001 Storage: -40C to +85C Operating: -40C to +70C Up to 95% (non condensing) @ 55C (as per IEC60068-2-30 Variant 1, 6 days) 2000m (maximum) II II IP10

CISPR11/CISPR22/ IEC 60255-25 IEC 60255-21-1 IEC 60255-21-2 IEC 60255-21-3 IEC 61000-4-8 IEC 61000-4-9 IEC 61000-4-10 IEC 61000-4-11 IEC 61000-4-17 IEC 60529 IEC 60068-2-1 IEC 60068-2-2 IEC 60068-2-30 IEEE/ANSI C37.90.1 IEEE/ANSI C37.90.1 IEEE/ANSI C37.90.2 IEEE/ANSIC37.90.3 UL508 ULC22.2-14

Ordering GPM-F Generator Field Voltage

-

* L H

-

Description Field Low Voltage (up to 600VDC field voltage) Field High Voltage (up to 800VDC field voltage)

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Multilin™ GPM-S 100% Stator Ground Protection Module The Multilin GPM-S stator ground protection module works in combination with the Multilin G60 Generator Protection System to provide 100% stator ground fault protection that is operational during generator start-up, running and stopped conditions. In the 100% stator ground fault protection based on sub-harmonic injection, a 20Hz voltage is injected to detect ground faults at any point across 100% of the winding thereby protecting the complete stator winding and allowing early detection of stator ground fault conditions. 

Protection • Two stage stator ground resistance based element – 64S • Wide range fault resistance coverage (1-20Kohms) • Over current element for low resistance faults

Key Benefits • Detect ground faults through 100% of the stator winding including neutral point • Sub-harmonic injection based stator ground protection provides early detection of ground fault conditions • Designed to operate with GE’s Multilin industry leading G60 Generator Protection System • Active protection of the generator even under machine shutdown conditions for increased asset life • Providing a wide range of fault resistance coverage which allows for superior generator protection • Increase generator lifespan by easily upgrading your current G60 generator protection relay with the 100% Stator Ground Protection Module • Simplified setup and configuration using EnerVista setup software

Applications • Medium to large generator applications • Generators with high impedance grounding • Deployable with redundant generator protection systems • Suitable for unit transformer connected systems

• CT phase angle error compensation

Diagnostics • Sub-harmonic voltage supervision • Sub-harmonic current supervision • Extensive internal diagnostics with critical-fail relay

GPM-S 100% Stator Ground Protection Module

Protection & Control

G60 Generator Protection System

Generator Protection

Stator Ground Protection Module: Stator ground module works in combination with UR G60 to provide a 100% stator ground fault protection that is operational during generator start-up, running and stopped conditions. In the 100% stator ground fault protection based on sub-harmonic injection, a 20Hz voltage is injected to detect ground faults at any point across 100% of the winding thereby protecting the complete stator winding and allowing early detection of stator ground fault conditions. Key components of the ground protection scheme: • G60 Generator Protection System • 20Hz Injection Module: GPM-S-G • Coupling Filter: GPM-S-B • CT: ITI Part # 204-SD-43737 • Sensitive ground CT/VT module in G60

G60 Generator Protection Integration

The G60 Generator Protection System provides comprehensive protection for medium and large generators, including large steam and combustion turbines, combined-cycle generators and multi-circuit hydro units. The G60 includes advanced automation and communication capabilities, extensive I/O options, and powerful fault recording features that can simplify postmortem disturbance analysis and help minimize generator downtime.

20Hz Injection Module Using sub-harmonic injection provides early detection of stator ground fault conditions. This is accomplished by the injection module generating a square wave pulse of 20Hz with a magnitude of +/-26V into the stator winding. The injection module monitors the frequency and magnitude of the signal it generates, which allows for the Stator module to determine if a ground fault has occurred in the stator winding. In addition, the stator module is also equipped with a critical-fail relay that can be wired to alarm failure.

• The G60, GPM-S, and GPM-F modules provide complete generator protection • GPM-S & GPM-F Protection units are connected directly to the G60 relay • All configuration and monitoring is performed through the G60

Coupling filter The coupling filter is used to meet two functions: to smooth the square wave and convert it into a sine wave and to protect the injection module from AC voltage impressed from the secondary of neutral grounding transformer. Coupling filter contains only passive components. It also contains voltage divider circuits to be used on applications with NGT secondary voltage greater than 500V.

100% Stator Ground Fault Detection Stator Module Bus Duct

Stator

Band Pass Filter

R CT

• • • •

60

Neutral Grounding Transformer

The 100% stator ground fault protection is based on sub-harmonic injection 20Hz voltage is injected to detect ground faults at any point across 100% of the winding The stator ground module works in combination with the G60 to provide 100% stator ground fault protection Operational during generator start-up, running and stopped conditions

GEDigitalEnergy.com

Rotor

Slip Rings

GPM-S 100% Stator Ground Protection Module

100% Stator Ground Fault Detection ANSI Device Numbers & Functions ®

52

Trip

25 24

27P

59P 59_2 59N 81O 81U 81R

32

40

50/27 21P

50P 50N

51P 51N

46

67P 67_2 67N

68

78

49

G

EX

64F

GPM-F

Metering 87S

87G 50G 51G 27TN 27X

59X 64TN

R

64S

G60 Generator Protection System

FUNCTION

21P 24 25 27P 27TN 27X 32 40 46 49 50G 50N 50P 50SP 50/27 51G 51P 59N 59P 59X 59_2 64F 64S 64TN 67_2 67N 67P 68 78 81O 81R 81U 87G 87S

Phase Distance Backup Volts Per Hertz Synchronism Check Phase Undervoltage Third Harmonic Neutral Undervoltage Auxiliary Undervoltage Sensitive Directional Power Loss of Field Relay Generator Unbalance Thermal Overload RTD Ground Instantaneous Overcurrent Neutral Instantaneous Overcurrent Phase Instantaneous Overcurrent Split Phase Instantaneous Overcurrent Accidental Energization Ground Time Overcurrent Phase Time Overcurrent Neutral Overvoltage Phase Overvoltage Auxiliary Overvoltage Negative Sequence Overvoltage Field ground protection Sub-harmonic stator ground protection 100% stator ground Negative Sequence Directional Overcurrent Neutral Directional Overcurrent Phase Directional Overcurrent Power Swing Blocking Out-of-Step Protection Overfrequency Rate of Change of Frequency Underfrequency Restricted ground fault Generator Stator Differential

Generator Protection

Close

DEVICE NUMBER

Dimensional Data Stator Module

Band Pass Filter Module

Top

Top 17.760

17.760 8.451

7.500

7.500

8.451

11.870

11.870

Front

Front 7.310

5.250

7.869 7.310

5.250

19.160 9.370

7.869

8.300

19.160

9.370

8.300

GEDigitalEnergy.com 7.250

61

Ordering Sub-Harmonic 100% Stator Ground (64S) Stator ground resistance pickup accuracy:

Total Stator Capacitance to Ground: Sub-harmonic voltage metering accuracy: Sub-harmonic current metering accuracy: Sub-harmonic element operating time: Sub-harmonic element dropout level accuracy: Time delay accuracy:

+/-5% of reading over the range from 1 kΩ-10 kΩ and +/-10% of reading over the range of 10-20 kΩ 200nF–2 µF

+/-2% of reading or 0.2V over the range 0.5V to 25Vac +/-2% of reading or 5mA over the range 5mA to 200mA 0.6 – 1.2 sec 102-103% of pickup +/- 3% of time delay setting or +/- 4ms whichever is greater

Tests

Dielectric voltage withstand Impulse voltage withstand Insulation resistance Damped oscillatory Electrostatic discharge RF immunity Fast transient disturbance Surge immunity Conducted RF immunity Voltage interruption and ripple DC Radiated and conducted emissions Sinusoidal vibration Shock and bump Seismic Power magnetic immunity Pulse magnetic immunity Damped magnetic immunity Voltage dip and interruption Voltage ripple Ingress protection Environment (Cold) Environment (Hot) Humidity SWC oscillatory SWC transients RF immunity ESD Safety Safety Safety

EN60255-5 EN60255-5 EN60255-5 IEC 61000-4-18 / IEC 60255-22-1 EN61000-4-2 / IEC 60255-22-2 EN61000-4-3 / IEC 60255-22-3 EN61000-4-4 / IEC 60255-22-4 EN61000-4-5 / IEC 60255-22-5 EN61000-4-6 / IEC 60255-22-6 IEC 60255-11 CISPR11/CISPR22/IEC 60255-25 IEC 60255-21-1 IEC 60255-21-2 IEC 60255-21-3 IEC 61000-4-8

Environmentals Temperature: Humidity: Altitude: Pollution Degree: Overvoltage Category: Ingress Protection:

Approvals

CE compliance

North America ISO CE compliance

North America ISO

Storage: -40C to +85C Operating: -40C to +70C Up to 95% (non condensing) @ 55C (as per IEC60068-2-30 Variant 1, 6 days) 2000m (maximum) II II IP10 EN60255-5 EN60255-27 EN60255-26 EN50263 UL508 UL1053 C22.2 No. 14 ISO9001 EN60255-5 EN60255-27 EN60255-26 EN50263 UL508 UL1053 C22.2 No. 14 ISO9001

IEC 61000-4-9 IEC 61000-4-10 IEC 61000-4-11 IEC 61000-4-17 IEC 60529 IEC 60068-2-1 IEC 60068-2-2 IEC 60068-2-30 IEEE/ANSI C37.90.1 IEEE/ANSI C37.90.1 IEEE/ANSI C37.90.2 IEEE/ANSIC37.90.3 UL508 ULC22.2-14 UL1053

Ordering GPM-S Included Components:

Description 20Hz Generator Band Pass Filter Current Transformer

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12878(E) English 150121

Transformer Protection Transformer Principles & Protection

64

A brief overview of typical transformer construction as well as transformer characteristics and a description of nameplate data. A brief overview of transformer protection theory, protection elements, and GE’s Multilin transformer protection products which provide enhanced reliability through special techniques and methods.

Typical Applications

70

Typical transformer protection applications for different transformer constructions and sizes and GE’s Multilin transformer protection products for each application.

Spotlight Application

74

Highlighting featured transformer applications and the advanced protection, diagnostics and asset monitoring benefits GE’s Multilin transformer protection products can provide. This application example explores the importance of asset health diagnostics and monitoring to improve asset and system reliability and reduce total cost of ownership.

Technical Resources

75

Access an extensive library of interactive tools and videos showcasing innovative solutions, as well as online publications, technical resources, how-to videos and transformer protection configurators.

Selector Guide

76

A reference table providing the feature set for each Multilin Transformer Protection Relay.

Featured Products Detailed product information for each Multilin Transformer Protection Relay.

77

Transformer Principles

Transformer Principles Transformer Protection

Introduction

Typical Step-Down Distribution Transformer

The purpose of a transformer in the power system is to step-up, step-down transmission or distribution voltages to the desired levels, reduce power system losses, and provide isolation for the two power system circuits ending at magnetically coupled windings. These windings work on the principle of induction, where the primary winding induces the secondary winding(s) with voltage and current. The windings are placed in close proximity, but are electronically isolated from each other. The power induced into the coils can either be stepped-down, meaning an increase in current and a decrease in voltage, usually required for distribution, or stepped-up meaning a decrease in current and an increase in voltage, usually required for transmission. Transformers can range in size from very small coupling transformers hidden within a device, to large units that are used to interconnect power grids. Transformers have become an essential component for high voltage power transmission as they ensure long distance transmission is economically practical.

Steel Laminations Oil-Cooling Radiators Primary Winding Secondary Winding Oil Coolant

Transformer locations in a power system:

Medium - High Voltage Step-Up Transformer 100 MVA +

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High Voltage Step-Down Transformer 7500 kVA - 100 MVA

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Medium - High Voltage Step-Down Transformer 500 kVA - 7500 kVA

Medium - Low Voltage Step-Down Transformer 75 kVA - 500 kVA

Transformer Principles

Three-Phase Transformers

The windings within a three-phase transformer may be connected in several ways. The primaries may be connected in a “delta“ configuration and the secondaries in a “wye” configuration or visa versa.

• Easy system to keep balanced electrical loads with the transformer being electrically grounded or ungrounded, making it more versatile Since a 3-phase transformer can have its primary and secondary windings connected the same (delta-delta or wye-wye), or differently (delta-wye or wye-delta). It is important to note that the secondary voltage waveforms will be in phase with the primary waveforms when the primary and secondary windings are connected the same way. When the transformer primary and secondary windings are connected differently, the voltages and currents from of the transformer secondary winding will not be in-phase with the voltages and currents from the corresponding primary winding. This is called a 30∞ phase shift.

Delta vs. Wye transformers

Special Purpose Transformers Various non-standard transformers are used in power system at transmission and distribution levels to achieve the special purposes such as: • Voltage regulation using Voltage Regulating Transformers • Three to two phase conversion using Scott Transformers Most distribution systems utilize a “wye” connected system as they offer greater advantages to the over-all system performance. As such, most power and distribution transformers are connected the same way.

• Non-standard phase shift between source and load side voltages using converters, phase shifters etc. Employing differential protection for such transformers is not straight forward, and requires special considerations such as

In a wye connection, one wire from each winding is connected together to form the neutral. In most power systems, the neutral is grounded, providing a low resistance connection to earth and an electrical reference point at zero points. By having this reference point, safety, voltage stability and protection system design are improved.

• non-standard phase shift

When determining and comparing which connection type is most suitable for a specific application, the following criteria could be used:

• special CTs - relay terminals connections

• on-load voltage regulation • zone of protection and locations of current transformers • winding currents

• Ratio of kVA output to the kVA internal rating of the bank • Degree of voltage symmetry with unbalanced phase loads • Voltage and current harmonics • Transformer ground availability • System fault-current level • Switching and system fault and transient voltages

Advantages of a grounded-wye connected transformer • Lower operating voltage as equipment is connected Line-to-Neutral (L-N) as opposed to the higher voltage required by Line-to-Line connections (L-L)

Sizing and Selecting a Transformer

• Smaller transformer size required as equipment is connected at a lower voltage

Transformer size is determined by the kVA of the load. The following information is essential to know:

• Easier to detect line-to-ground faults as any fault current generated, either as an overcurrent or a short-circuit would result in a significant of current on the neutral

• Load Voltage

Advantages of a Delta connected transformer

Equation (three-phase transformers): (volts x amps x 1.732) / 1000 = kVA

• Polarity end of one winding is connected to the non-polarity end of the next, allowing for an isolated ground

The kVA rating of your transformer should be greater than or equal to the kVA resulting from the above equation.

• Load Current/Amps • Line Voltage

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Transformer Protection

As most power is distributed in the form of three-phase AC, there are various types of three-phase transformers that support the three-phase power system. The three phase transformers are designed with three primary windings - one per phase and three secondary windings mounted on a three-legged core.

• One transformer can be removed (when connected in a bank) while the remaining units deliver three-phase power at 58% of the original output

Transformer Principles

Transformer Protection

Typical Nameplate Data

Transformer Nameplate Data: Correct transformer protection setup and configuration is essential to ensure not only proper transformer protection, but also optimized transformer operation (in terms of both performance and efficiency). The key pieces of data required to maximize transformer operation can be found on the transformer nameplate, supplied by the transformer manufacturer. Defined by codes and standards, depending on the kVA rating of a transformer, there is a minimum amount of data that must be shown on a nameplate. For transformers rated above 500 kVA the following information is required: • Name of manufacturer

• Approximate mass of the entire unit. Individual weights are provided for the core and coils, as well as the tank and fittings

• Serial number

• Connection diagram showing all winding terminations with a schematic plan view showing all fixed accessories

• Month/year of manufacture • Cooling class

• Installation operating instructions references

• Number of phases

• Suitability for step-up operation

• Frequency

• Maximum positive and negative operating pressures of the oil preservation system

• KVA or MVA rating • Voltage Ratings • Tap Voltages

• Liquid level below the top surface of the highest point of the highest manhole flange at 25 degrees C

• Rated Temperature Rise (degree C)

• Change in liquid level per 10 degree C change

• Phase or vector diagram (for polyphase transformers)

• Oil volume of each transformer compartment

• Percent impedance

• Type of insulating liquid

• Basic lightning impulse insulation levels (BIL ratings). Note: The BIL rating for each winding and each bushing are indicated

• Conductor material of each winding

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Transformer Protection

Transformer Protection Introduction

Transformer Protection Overview The type of protection for a transformer varies depending on the application and the importance of the transformer. Transformers are protected primarily against faults and overloads. The type of protection used should quickly isolate the transformer for internal faults to reduce the risk of catastrophic failure, and to simplify eventual repair. Any extended operation of the transformer under abnormal condition such as overexcitation or overloads compromises the life of the transformer, which means adequate protection should be provided for such conditions.

Innovative Multilin Solutions to Transformer Protection Applications Differential Characteristic The major operating challenge to transformer differential protection is maintaining security during CT saturation for external faults while maintaining sensitivity to detect low magnitude internal faults. CT saturation reduces the secondary output current from the CT, and causes a false differential current to appear to the relay. GE Multilin differential relays meet this challenge in the following ways: • the restraint current is based on the maximum measured winding current, as opposed to the traditional magnitude sum of the currents. This ensures ideal restraint for the actual fault condition, balancing sensitivity and security. • the differential element uses a dual slope-dual breakpoint characteristic. The differential element is set to account for both DC and AC saturation of the CTs, ensuring security, while maintaining sensitivity. CONDITIONS

PROTECTION PHILOSOPHY

INTERNAL

Transformer Failures Failures in transformers can be classified into: • winding failures due to short circuits (turn-turn faults, phase-phase faults, phase-ground, open winding) • core faults (core insulation failure, shorted laminations) • terminal failures (open leads, loose connections, short circuits) • on-load tap changer failures (mechanical, electrical, short circuit, overheating)

Differential (87T), overcurrent (51, 51N)

Winding inter-turn faults

Differential (87T), Buchholz relay

Core insulation failure, shorted laminations

Differential (87T), Buchholz relay, sudden pressure relay

Tank faults

Differential (87T), Buchholz relay and tankground protection

Overfluxing

Volts/Hz (24)

Restricted ground fault protection (87RGF)

EXTERNAL

• abnormal operating conditions (overfluxing, overloading, overvoltage) • external faults

Winding Phase-Phase, Phase-Ground faults

Overloads

Thermal (49)

Overvoltage

Overvoltage (59)

Overfluxing

Volts/Hz (24)

External system short circuits

Time overcurrent (51, 51G), Instantaneous overcurrent (50, 50G)

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Transformer Protection

Transformers are a critical and expensive component of the power system. Due to the long lead time for repair of and replacement of transformers, a major goal of transformer protection is limiting the damage to a faulted transformer. Some protection functions, such as overexcitation protection and temperature-based protection, may aid this goal by identifying operating conditions that may cause transformer failure. The comprehensive transformer protection provided by multiple function protective relays is appropriate for critical transformers of all applications.

Transformer Protection

Transformer Protection

Inrush Inhibit during Transformer Energization The differential current present during transformer energization resembles the condition of an internal fault. If no inhibiting mechanism is provided, the differential element will trip. Since the magnetizing inrush current has significant 2nd harmonic content, the level of 2nd harmonic current can be used to differentiate between inrush and a fault condition. The UR T60 and T35 GE Multilin transformer relays use two different 2nd harmonic modes to inhibit the differential element for inrush.

Power transformers may be connected to provide phase shift, such as the common Wye connection with its 30° phase shift. Protection relays perform this phase angle compensation and zero sequence removal automatically, based on the settings entered for the transformer. All CTs are connected Wye (polarity markings pointing away from the transformer). All currents are phase and zero sequence compensated internally before the calculation of differential and restraint quantities.

Traditional 2nd harmonic blocking – The traditional 2nd harmonic restraint responds to the ratio of the magnitudes of the 2nd harmonic and the fundamental frequency currents.

Compensation of non-standard phase shift is only available in T60 and T35.

Adaptive 2nd harmonic blocking– The adaptive 2nd harmonic blocking responds to both magnitudes and phase angles of the 2nd harmonic and the fundamental frequency currents. The differential element correctly distinguishes between faults and transformer energization, when the 2nd harmonic current is less than the entered 2nd harmonic setting. While levels of 2nd harmonic during inrush often do not go below 20%, many transformers are susceptible of generating lower 2nd harmonic current during energization. Setting the 2nd harmonic restraint below 20% may result in incorrect inhibit of the differential element during some internal fault events. The adaptive 2nd harmonic blocking allows settings in the traditional 20% range, while maintaining the security of the differential element against inrush. Modern transformers may produce small 2nd harmonic ratios during inrush conditions. This may result undesired tripping of the protected transformer. Reducing the 2nd harmonic inhibit threshold may jeopardize dependability and speed of protection. The 2nd harmonic ratio, if low, causes problems in one phase only. This may be utilized as a mean to ensure security by applying cross-phase blocking rather than lowering the inrush inhibit threshold. The UR T60 and T35 relays provides three inrush inhibit modes of operation based on per-phase. 2-out-of-3 phases and average of three phases. Available in the T60, T35. An alternative method for inrush inhibit is also available, where current, voltage, or breaker status is used to indicate a de-energized transformer. The threshold can be lowered during energization of the transformer as indicated either by breaker contact, current or voltage sensing, and will last for a settable time delay. This allows settings of less than 20% for inrush inhibit during transformer energization.

Sensitive Ground Fault Protection to limit Transformer Damage Differential protection and overcurrent protection are not sensitive enough to detect faults close to the neutral of wye-connected transformers with grounded neutrals. Such faults produce less fault current as shown by the current distribution curve. The restricted ground fault function (RGF) can be used to provide differential protection for such ground faults, down to faults at 5% of the transformer winding. Restricted ground fault protection can be a low impedance differential function or a high impedance differential function. The low impedance function can precisely set the sensitivity to meet the application requirement. This sensitive protection limits the damage to the transformer for faults close to the neutral. The restricted ground fault element uses adaptive restraint based on symmetrical components to provide security during external phase faults with significant CT error. This permits the function to maximize sensitivity without any time delay.

Overflux Protection Transformer overfluxing can be a result of system overvoltages, or low system frequency. A transformer is designed to operate at or below a maximum magnetic flux density in the transformer core. Above this design limit the eddy currents in the core and nearby conductive components cause overheating which within a very short time may cause severe damage. The magnetic flux in the core is proportional to the voltage applied to the winding divided by the frequency of the winding. The flux in the core increases with either increasing voltage or decreasing frequency. During startup or shutdown of generator-connected transformers, or following a load rejection, the transformer may experience an excessive ratio of volts to hertz, that is, become overexcited. When a transformer core is overexcited, the core is operating in a non-linear magnetic region, and creates harmonic components in the exciting current. A significant amount of current at the 5th harmonic is characteristic of overexcitation.

Available in the 745.

Phase, Magnitude and Zero-Sequence Compensation Transformer protection presents problems in the application of current transformers, standard and non-standard phase shift . CTs should be matched to the current rating of each transformer winding, so that normal current through the power transformer is equal on the secondary side of the CT on different windings. However, because only standard CT ratios are available, this matching may not be exact. All GE transformer protection relays automatically corrects for CT mismatch errors. All currents are magnitude compensated to be in units of the CTs of one winding before the calculation of differential and restraint quantities.

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Transformer Protection

Application Capabilities

Differential vs. Restraint Characteristic (ld vs.lr) Differential Current (Id)

Break Point 2

In addition, these relays are designed for both new and retrofit installations. New installations typically use wye-connected CTs, and internally compensate the measured currents for the phase shift of the protected transformer. Traditional installations may use delta-connected or wyeconnected CTs that externally compensate the measured currents for the phase shift of the protected transformer. GE Multilin accommodates both methods as simple configuration settings.

Transition Region

Break 1 Slope 1

Beyond these typical applications, GE Multilin transformer protection relays can be applied on more advanced applications.

Acquiring transformer measurements Restraint Current (Ir) The settings for the dual-slope, dual-breakpoint characteristic provides higher flexibility for shaping up the characteristic and achieve better sensitivity and security.

Winding hot-spot temperature protection The transformer winding hot-spot temperature is another quantity that should be used for protection of transformers. Protection based on winding hot-spot temperature can potentially prevent short circuits and catastrophic transformer failure, as excessive winding hot-spot temperatures cause degradation and eventual failure of the winding insulation. The ambient temperature, transformer loading, and transformer design determine the winding temperature. Temperature based protection functions alarm or trip when certain temperature conditions are met. GE Multilin relays use IEEE C57.91 compliant thermal models to calculate the winding hot-spot temperature and the loss of life of the winding insulation. The top-oil temperature may be directly measured, or calculated from the ambient temperature, load current, and transformer characteristics. In addition, the calculations may use a monthly model of ambient temperature, eliminating the need for external connections to the transformer and relay. This winding hot-spot temperature and transformer loss of life information is used in thermal overload protection to provide alarming or tripping when unacceptable degradation of the transformer winding insulation is occurring.

Transformer protection requires the use of currents measured from each winding, and possibly system voltages and transformer top-oil temperatures. Current measurements are normally taken from bushing CTs mounted at the transformer, voltages from nearby VTs, and top-oil temperatures via RTDs from the transformer cooling controls. Each measurement must be brought back individually by copper wiring to the transformer protection relay. Top-oil temperatures, for example, are rarely brought back to the transformer protection relay because of the need to run RTD wires across the switchyard. Each copper wire requires numerous terminations that are designed, documented, field installed, and tested one at a time. The HardFiber IEC 61850 Process Bus Solution simplifies the acquisition of measurement signals for transformer protection. The Brick interface device is mounted at the transformer. Winding currents (for 2 windings), ground current, top-oil temperatures, and sudden pressure relays / Bucholtz relay trips are wired to the Brick. One fiber optic cable, transmitting sampled values from all transformer measurements, and digital status information, is pulled across the switchyard to connect to the transformer protection relay. The copper wiring and fiber optic cabling uses simple connectors to attach to the Brick.

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Transformer Protection

GE Multilin transformer protection relays are suitable for different transformer protection applications, including medium voltage and high voltage transformers of any size, dual secondary transformers, autotransformers, three-winding transformers, non-standard phase shifters and transformers with dual-breaker terminals.

Slope 2

Typical Applications

Transformer Protection – Typical Applications Transformer Protection

Transformers 2 Winding (No Voltage)

Typical Functions

Additional Functions

87T

Differential

87RGF

Restricted Ground Fault

86

Lockout auxiliary

49

Thermal overload protection

50/51

Overcurrent and short circuit

50G

Ground fault

Functions

Typical Product Order Code

Typical Functions

345-E-P5-G5-H-E-S-SN-D-N 745-W2-P5-G5-HI-T 845-E-NN-M5-G5-H-N-N-A-N-N-G-S-P-B-B-SE-N-N-B-N T35-U00-HKH-F8N-H6L-Mxx-Pxx-Uxx-Wxx (19” rack)

+ Harsh Environment Option

345-E-P5-G5-H-E-S-SN-D-H 745-W2-P5-G5-HI-R-T-H 845-E-NN-M5-G5-H-N-N-A-N-N-G-S-P-B-B-SE-N-N-B-N T35-U00-AKH-F8N-H6L-Mxx-Pxx-Uxx-Wxx (19” rack)

+ Additional Functions

345-E-P5-G5-H-E-E-SN-D-N 845-E-NN-M5-G5-H-N-N-A-N-N-G-M-P-B-B-SE-N-N-B-N T60-U00-AKH-F8N-H6L-Mxx-Pxx-Uxx-Wxx (19” rack)

Transformers 2 Winding

70

Typical Functions

Additional Functions

87T

Differential

87RGF

Restricted Ground Fault

86

Lockout auxiliary

67

Directional overcurrent

50/51

Overcurrent and short circuit

24

Volts per Hertz

50G

Ground fault

59

Overvoltage

V, S

Voltage and Power metering

49

Thermal overload protection

Functions

Typical Product Order Code

Typical Functions

345-E-P5-G5-H-E-S-SN-D-N 745-W2-P5-G5-HI-T T35-U00-HKH-F8N-H6L-MXX-PXX-UXX-WXX (19” rack) T60-U00-HKH-F8N-H6L-MXX-PXX-UXX-WXX (19” rack) 845-E-P5-H5-G5-H-N-N-A-N-N-G-S-P-B-B-SE-N-N-B-N

+ Harsh Environment Option

345-E-P5-G5-H-E-S-SN-D-H 745-W2-P5-G5-HI-T-H T35-U00-AKH-F8N-H6L-MXX-PXX-UXX-WXX (19” rack) T60-U00-AKH-F8N-H6L-MXX-PXX-UXX-WXX (19” rack) 845-E-P5-H5-G5-H-N-N-A-N-N-G-S-P-B-B-SE-N-N-B-N

+ Voltage and Power metering

745-W2-P5-G5-HI-T T35-U00-AKH-F8N-H6L-M8L-PXX-UXX-WXX (19” rack) T60-U00-AKH-F8N-H6L-M8L-PXX-UXX-WXX (19” rack) 845-E-P5-H5-G5-H-N-N-A-N-N-G-S-P-B-B-SE-N-N-B-N

+ Directional overcurrent

T60-U00-AKH-F8N-H6L-M8L-PXX-UXX-WXX (19” rack) 845-E-P5-H5-G5-H-N-N-A-N-N-G-A-P-B-B-SE-N-N-B-N

Lockout

HEA61-A-RU-220-X2 T35-U00-AKH-F8N-H6L-M8L-P4L-UXX-WXX (19” rack) T60-U00-AKH-F8N-H6L-M8L-P4L-UXX-WXX (19” rack)

Standalone Integrated

GEDigitalEnergy.com

Typical Applications

Transformers, 3 Windings Additional Functions

87T

Differential

67

Directional overcurrent

86

Lockout auxiliary

V, S

Voltage and Power metering

50/51

Overcurrent and short circuit (three windings)

50N

Neutral ground fault (three windings)

Functions

Typical Product Order Code

Typical Functions

745-W3-P5-G5-HI-T T35-U00-HKH-F8N-H6L-M8L-PXX-UXX-WXX T60-U00-HKH-F8N-H6L-M8L-PXX-UXX-WXX 845-E-P5-M5-G5-H-N-N-A-N-N-G-S-P-B-B-SE-N-N-B-N

+ Harsh Environment Option

745-W3-P5-G5-HI-T-H T35-U00-AKH-F8N-H6L-M8L-PXX-UXX-WXX (19” rack) T60-U00-AKH-F8N-H6L-M8L-PXX-UXX-WXX (19” rack) 845-E-P5-M5-G5-H-N-N-A-N-N-G-S-P-B-B-SE-N-N-B-N

+ Voltage and Power metering

745-W3-P5-G5-HI-T T35-U00-AKH-F8N-H6L-M8L-PXX-UXX-WXX (19” rack) T60-U00-AKH-F8N-H6L-M8L-PXX-UXX-WXX (19” rack) 845-E-P5-M5-G5-H-N-N-A-N-N-G-S-P-B-B-SE-N-N-B-N

+ Directional overcurrent

T60-U00-AKH-F8N-H6L-M8L-PXX-UXX-WXX (19” rack) 845-E-P5-M5-G5-H-N-N-A-N-N-G-A-P-B-B-SE-N-N-B-N

Lockout

HEA61-A-RU-220-X2 T35-U00-AKH-F8N-H6L-M8L-P4L-UXX-WXX (19” rack) T60-U00-AKH-F8N-H6L-M8L-P4L-UXX-WXX (19” rack)

Standalone Integrated

Transformer Protection

Typical Functions

Transformers, 2 Winding, Dual-Breaker Source Typical Functions

Additional Functions

87T

Differential

87RGF

Restricted Ground Fault

86

Lockout auxiliary

67

Directional overcurrent

50/51

Overcurrent and short circuit (two windings)

24

Volts per Hertz

59

Overvoltage

V, S

Voltage and Power metering

50G

Ground fault

Functions

Typical Product Order Code

Typical Functions

T35-U00-HKH-F8N-H6L-M8L-PXX-UXX-WXX (19” rack) T60-U00-HKH-F8N-H6L-M8L-PXX-UXX-WXX (19” rack) T35-U00-VKH-F8N-H6L-M8L-PXX (Vertical/compact) T60-U00-VKH-F8N-H6L-M8L-PXX (Vertical/compact)

+ Voltage and Power metering

T35-U00-HKH-F8N-H6L-M8L-PXX-UXX-WXX (19” rack) T60-U00-HKH-F8N-H6L-M8L-PXX-UXX-WXX (19” rack) T35-U00-VKH-F8N-H6L-M8L-PXX (Vertical/compact) T60-U00-VKH-F8N-H6L-M8L-PXX (Vertical/compact)

+ Additional Functions

T60-U00-HKH-F8N-H6L-M8L-PXX-UXX-WXX (19” rack) T60-U00-VKH-F8N-H6L-M8L-PXX (Vertical/compact)

Lockout

HEA61-A-RU-220-X2 T35-U00-HKH-F8N-H6L-M8L-P4L-UXX-WXX (19” rack) T60-U00-HKH-F8N-H6L-M8L-P4L-UXX-WXX (19” rack) T35-U00-VKH-F8N-H6L-M8L-P4L (Vertical/compact) T60-U00-VKH-F8N-H6L-M8L-P4L (Vertical/compact)

Standalone Integrated

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Typical Applications

Transformer Protection

Auto-Transformer Typical Functions

Additional Functions

87T

Differential

87RGF

Restricted Ground Fault

86

Lockout auxiliary

67

Directional overcurrent

50/51

Overcurrent and short circuit (both sources)

24

Volts per Hertz

59

Overvoltage

V, S

Voltage and Power metering

50G

Ground fault

Functions

Typical Product Order Code

Typical Functions

T35-U00-HKH-F8N-H6L-MXX-PXX-UXX-WXX (19” rack) T60-U00-HKH-F8N-H6L-MXX-PXX-UXX-WXX (19” rack) T35-U00-VKH-F8N-H6L-MXX-PXX (Vertical/compact) T60-U00-VKH-F8N-H6L-MXX-PXX (Vertical/compact)

+ Voltage and Power metering

T35-U00-HKH-F8N-H6L-M8L-PXX-UXX-WXX (19” rack) T60-U00-HKH-F8N-H6L-M8L-PXX-UXX-WXX (19” rack) 845-E-P5-M5-H-N-N-A-N-N-G-S-P-B-B-SE-N-N-B-N

+ Additional Functions

T60-U00-HKH-F8N-H6L-M8L-PXX-UXX-WXX (19” rack) 845-E-P5-M5-G5-H-N-N-A-N-N-G-A-P-B-B-SE-N-N-B-N

Lockout

HEA61-A-RU-220-X2 T35-U00-HKH-F8N-H6L-M8L-P4L-UXX-WXX (19” rack) T60-U00-HKH-F8N-H6L-M8L-P4L-UXX-WXX (19” rack) T35-U00-VKH-F8N-H6L-M8L-P4L (Vertical/compact) T60-U00-VKH-F8N-H6L-M8L-P4L (Vertical/compact)

Standalone Integrated

Auto-Transformer, Dual-Breaker Terminals Typical Functions

Additional Functions

87T

Differential

87RGF

Restricted Ground Fault

86

Lockout auxiliary

67

Directional overcurrent

50/51

Overcurrent and short circuit (two windings)

24

Volts per Hertz

59

Overvoltage

V, S

Voltage and Power metering

50G

72

Ground fault

Functions

Typical Product Order Code

Typical Functions

T35-U00-HKH-F8N-H6L-M8L-PXX-UXX-WXX (19” rack) T60-U00-HKH-F8N-H6L-M8L-PXX-UXX-WXX (19” rack) T35-U00-VKH-F8N-H6L-M8L-PXX (Vertical/compact) T60-U00-VKH-F8N-H6L-M8L-PXX (Vertical/compact)

+ Voltage and Power metering

T35-U00-HKH-F8N-H6L-M8L-PXX-UXX-WXX (19” rack) T60-U00-HKH-F8N-H6L-M8L-PXX-UXX-WXX (19” rack) T35-U00-VKH-F8N-H6L-M8L-PXX (Vertical/compact) T60-U00-VKH-F8N-H6L-M8L-PXX (Vertical/compact)

+ Additional Functions

T60-U00-HKH-F8N-H6L-M8L-PXX-UXX-WXX (19” rack) T60-U00-VKH-F8N-H6L-M8L-PXX (Vertical/compact)

Lockout

HEA61-A-RU-220-X2 T35-U00-HKH-F8N-H6L-M8L-P4L-UXX-WXX (19” rack) T60-U00-HKH-F8N-H6L-M8L-P4L-UXX-WXX (19” rack) T35-U00-VKH-F8N-H6L-M8L-P4L (Vertical/compact) T60-U00-VKH-F8N-H6L-M8L-P4L (Vertical/compact)

Standalone Integrated

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Typical Applications

Auto with Dual-Breaker on both sides and loaded tertiary Typical Functions

Additional Functions

87T

Differential

V, S

86

Lockout auxiliary

50/51

Overcurrent and short circuit (three windings)

50G

Ground fault

Voltage and Power metering

Typical Product Order Code

Typical Functions

T35-U00-HKH-F8N-H6L-M8N-P6L-U8L-WXX (19” rack) T60-U20-HKH-F8N-H6L-M8N-P6L-U8L-WXX (19” rack)

+ Voltage and Power metering

T35-U00-HKH-F8N-H6L-M8N-P6L-U8L-WXX (19” rack) T60-U20-HKH-F8N-H6L-M8N-P6L-U8L-WXX (19” rack)

Lockout

HEA61-A-RU-220-X2 T35-U00-HKH-F8N-H6L-M8N-P6L-U8L-W4L (19” rack) T60-U20-HKH-F8N-H6L-M8N-P6L-U8L-W4L (19” rack)

Standalone Integrated

Transformer Protection

Functions

Generator Step Up Transformer Typical Functions

Additional Functions

87T

Differential

51G

Ground Fault

86

Lockout auxiliary

24

Volts per Hertz

51

Overcurrent and short circuit (three windings)

59

Overvoltage

V, S

Voltage and Power metering

Functions

Typical Product Order Code

Typical Functions

T60-U00-HKH-F8N-H6L-M8L-PXX-UXX-WXX (19” rack) 845-E-P5-M5-G5-H-N-N-A-N-N-G-S-P-B-B-SE-N-N-B-N

Lockout

HEA61-A-RU-220-X2 T60-U00-HKH-F8N-H6L-M8L-P4L-UXX-WXX (19” rack)

Standalone Integrated

Distributed Transformer with no load-side Circuit Breaker Typical Functions 87T

Differential

86

Lockout auxiliary

51

Overcurrent and short circuit (two windings)

50G

Ground fault

Functions

Typical Product Order Code

Typical Functions

T35-U00-HKH-F8N-H6L-M8N-P6L-U8N-WXX (19” rack) T60-U20-HKH-F8N-H6L-M8N-P6L-U8N-WXX (19” rack)

Lockout

HEA61-A-RU-220-X2 T35-U00-HKH-F8N-H6L-M8N-P6L-U8N-W4L (19” rack) T60-U20-HKH-F8N-H6L-M8N-P6L-U8N-W4L (19” rack)

Standalone Integrated

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73

Application Spotlight

Transformer Protection

Essential Transformer Diagnostics Increased equipment use, deferred capital expenditures and reduced maintenance expenses are challenges faced by most capital asset owners today. Therefore, managing critical electrical system assets such as large power transformers require a preventative maintenance plan that can screen device degradation and make intelligent device protection decisions.

The transformer top-oil temperature can be directly measured, or calculated from the ambient temperature, load current , and other transformer characteristics. The protective relays can be set to alarm or trip in cases where the computed hottest-spot temperature is above the pickup threshold for a user specified time (considered as transformer overheating).

Excessive heat and mechanical stress are major reasons for transformer damage. These factors can cause hot spots, breakdown of winding insulation, short circuits, and catastrophic failures. The good news, however, is that transformer failures are attributable to manageable problems and new technology in transformer protective relays enable Engineers to implement a diagnostic approach to assess the health of power transformers.

Multilin relays use IEEE C57.91 compliant thermal models to calculate the winding hot-spot temperature, detect abnormal temperatures inside the transformer, and prevent loss of life of the winding insulation. The loss of life element detects the accumulated total consumed transformer life. This element can be set to issue an alarm or trip when the actual accumulated transformer life becomes larger than the user-specified loss of life pick up value.

Measurable indicators of transformer health include electrical load, hottest-spot, ambient temperature, loss of life etc. Users who use protective relays to monitor these indicators, plan optimal transformer loading and maintenance, and thereby increase life of their asset and improve quality of their service.

The protective relay aging element detects the transformer aging in per unit normal insulation aging. This element can be set for alarm or trip whenever the computed aging factor is greater than the maximum permissible userdefined pickup setting under emergency loading conditions and maximum ambient temperature.

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Application Spotlight

T60, T35, 845 Transformer Protection Systems

Internal Short Circuit

Winding Hot Spots

Top Oil Temperature

• Fast tripping with unrestrained differential element

• Advanced algorithm based on IEEE C57.91-1995 and C57.96-1989

• Improve maintenance through oil temperature monitoring

• Enhanced selectivity with double break point transition characteristic

• Constant, value-based monitoring of winding temperatures

• Detection of oil aging to avoid isolation faults

• Sensitive ground current differential element

• Flexlogic for control of cooling fans

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Transformer Protection

Delivering fast, adaptive, sensitive and secure protection for small, medium and large power transformer applications. Multilin protection relays include advanced Health Diagnostics capabilities, coupled with advanced communications including IEC 61850 for remote data and engineering access to increase asset life and improve quality of service.

• Monitoring and alarming easily integrated with substation SCADA systems

75

WATCH. INTERACT. LEARN. Transformer Protection

OVER 10,000 interactive tools and technical resources t hat showcase our Grid Modernization Solutions

Extensive library of interactive tools & videos 

Broad range of publications & technical resources

SOLUTIONS

SELECTOR GUIDES

for transformer protection

Discover innovative solutions for transformer fleet management including protection, monitoring and diagnostics.

“How To” videos &

for transformer products

Compare, filter and select your product by protection, control, automation, and communications features to fit your application needs.

online product

TRAINING

CONFIGURATORS

Access over 60 step-by-step product videos and technical training to help you get the most out of your products.

Configure, price and easily order your transformer protection products on the Digital Energy online store.

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Product Selector Guide

Transformer Protection – Selector Guide Features

Device

345

745

845

T35

T60

•

•

• • •

• •

• •

•

•

• 6 • • • • 32/1

• 6 • • • • 32/1 • • • G/N/P G/N/P • N/P/X • P/N • • • • • • • • • • • • •

•

87T

87G (RGF) 24 27P 50G/N/P 51G/N/P

• 2 • •

• 3 • •

• 3 • •

• 16/1 •

• 16/1 • •

G/N/P G/N/P

G/N/P G/N/P •

•

• 20/1 • • • G/N/P G/N/P • N/P/X • P/N • •

•

•

•

• • •

• • •

•

•

•

4 16 8

59N/P/X 59N 67 N/P VTFF 81U/O 25 49 68 78 21

86 2 10 7 •

•

6 14 10 • •

32/0

16/16

32/32

Trip

Trip

1 1 •

• • • • • • • • • 21 • •

6 96 64 • • • 64/96 32/32 12 Trip/Close 48 • • • • 24/12 24

• • • •

• • •

• • • •

• • • • • •

• •

• • • • • •

3 • 15 • • • • 16 12

25 • • • 1024 128 • •

40 12

•

• •

•

• •

•

• •

•

•

• •

• •

• • • • • • • • •

•

• •

• 6 96 64 • • • 64/96 32/32 12 Trip/Close 48 • • • • 24/12 24

256 32

• •

G/P •

• • • • • • 1024 64 • •

25 • • • 1024 64 • •

• • • • •

• • • • •

• • • • • • • • • •

• • • • • • • • • •

Transformer Protection

APPLICATIONS & FUNCTIONALITY Low to Medium size LV and MV Transformers Medium to Large size MV-HV Transformers Auto-transformers Non-Standard Transformers (Converter transformer, Scott and LeBlanc Transformers, Phase shifters, zig-zag transformers) PROTECTION & CONTROL Transformer Differential Maximum Number of Windings/Restraint Inputs Harmonic Restraint Internal Winding Standard Phase Shift Compensation Internal Winding Standard and Non-Standard Phase Shift Compensation Dynamic CT Ratio-Matching CT Mismatch Range Restricted Ground Fault Over-excitation (Voltz Per Hertz) Phase Undervoltage IOC, Ground/Neutral/Phase TOC, Ground/Neutral/Phase Custom programmable overcurrent curves Overvoltage, Neutral/Phase/Auxiliary Overvoltage, Symmetrical Component Current Directional, Neutral/Phase. Voltage Transformer Fuse Failure Under/Overfrequency Synchrocheck Synchrophasor Transformer Overload Power Swing Blocking Out of Step Backup Distance Protection Transformer Hottest-spot Temperature Transformer Aging factor Transformer Loss of Life Lockout Tap Changer Monitoring AUTOMATION Settings Groups Contact Inputs (Up to) Contact Outputs (Up to) Non-volatile latches Programmable Logic FlexElements™ Virtual Inputs/Outputs Direct Inputs/Outputs Programmable Pushbuttons Trip/Close Coil Supervision User-Programmable LEDs User-Programmable Self Test Selector Switch Digital Counters Digital Elements Analog Inputs/Outputs (Up to) RTD Inputs (Up to) MONITORING & METERING Power Factor Current – RMS Current – Phasor Current – Demand Current - Unbalance Voltage Power - Apparent, Real, Reactive MW, MVA, Mvar Demand Breaker Arc Current Energy Frequency Temperature Current Harmonics (Up to) Loss of Life Calculations Fault Report User Programmable Trip Reports Event Recorder - Number of Events Oscillography - Sampling Rate Trip Counters Data Logger Simulation Mode COMMUNICATIONS INTERFACES RS232 Port RS485 Port RS422, G.703, C37.94 Ethernet Fiber (800nm, 1300nm, 1550nm) PROTOCOLS ModBus (RTU & TCP/IP) DNP3 EGD Protocol IEC61850 IEC 60870-5-104 Simple Network Time Protocol TCP/IP HTTP IRIG-B Input Process Bus (IEC 61850-9-2)

For the most up-to-date selector guides, please visit

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77

Featured Products

Transformer Protection – Featured Products T60

Comprehensive multi-winding transformer protection system

79

Transformer Protection

The T60 Transformer Protection System is designed for various power transformer applications, including autotransformers, generator step up transformers, split-phase, angle regulating transformers and reactors. Uses multiple current and voltage inputs to provide primary protection and back-up protection of transformers, including differential, ground differential, phase, neutral, and ground overcurrent, under- and over-voltage, under- and overfrequency, over-fluxing, and breaker failure protection. Also provides protection of transformer based on winding temperature and loss-of-life calculations.

T35

Cost effective protection for transformers with up to 6 restraints

87

The T35 Transformer Protection System is designed to provide basic transformer protection functions for variety of transformer applications. Uses multiple current inputs to provide primary protection and backup protection of transformers, including differential, phase and ground overcurrent, protection. The relay can be configured to accept up to 6 sets of current inputs to provide proper differential restraint for applications with three winding transformers with windings configured in dual breaker arrangements.

845

Comprehensive Protection Solution

95

The 845 Transformer Protection System is a complete protection and control solution for small and medium power transformers. The 845 can be applied on two-winding and three-winding transformers. Uses multiple current and voltage inputs to provide primary protection and back-up protection of transformers, including differential, ground differential phase, neutral, and ground overcurrent, over fluxing, on-load tap changer monitoring and monitoring and protection of transformer insulation ageing. The 845 is also equipped with serial (RS485), USB, and Ethernet ports, as well as a wide selection of protocols such as Modbus, DNP3.0, IEC60870- 5-103, 60870-5-104, IEC 61850 GOOSE also offers complete support for communications.

345

Complete Protection Solution for 2 Winding Transformer The 345 Transformer Protection System is used for primary and backup protection of small to medium size distribution transformers. It can be applied to 2 winding transformer. The relay provides advanced algorithms for automatic magnitude and phase compensation for more than twenty types of two winding transformers, good sensitivity for the detection of winding ground faults, and the flexibility to set any of the phase, ground, neutral and negative sequence currents overcurrent elements.

Go online for the full listing of Multilin Protection & Control products

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113

Multilin™ T60 Full-Featured, Multiple-Winding Transformer Protection

Protection & Control

The Multilin T60 transformer protection system is a comprehensive three-phase transformer relay designed to protect medium and large power transformers. The T60 provides automatic or userdefinable magnitude reference winding selections for CT ratio matching, and performs automatic phase shift compensation for all types of transformer winding connections. The T60 algorithm allows the user to enable removal of the zero-sequence current even for delta connected transformer windings, accommodating transformers with a variety of grounding configurations.

Key Benefits • Secure, high-speed protection for transformers, compliant with IEEE® C37.91 for maximum asset life • Improved security for transformer energization and inrush provided through an adaptive 2nd harmonic restraint algorithm

• Transformer overexcitation overload and inhibit, thermal overload protection, 2nd Harmonic inrush • Restricted ground fault, loss-of-life, aging factor, hottest spot • Five-zone backup distance protection with power swing detection and load encroachment function • 3 phase undervoltage and 3 phase overvoltage elements • Synchrocheck, ROCOF, over and under frequency

• Sensitive ground fault protection provides low-impedence differential protection down to 5% of the winding to limit transformer damage • Integrated transformer thermal monitoring for asset management and maintenance optimization • Embedded Synchrophasor measurement capabilities (per IEEE® C37.118), eliminating the need for dedicated PMUs and support for synchrophasor multi-cast (per IEC® 61850-90-5) reducing bandwidth and communications infrastructure costs • Advanced IEC 61850 Ed. 2 implementation, complete settings via SCL files and IEC 61850-9-2 process bus solution enable resource and platform managing optimization and reduce cost of ownership • Increased network availability via failover time reduced to zero through IEC® 62439-3 “PRP” support • CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC CIP, AAA, Radius, RBAC, Syslog) ®

• Advanced fault and disturbance recording, including internal relay operating signals, eliminating the need for external recording devices

Applications • Transformer asset monitoring using hottest spot, loss-of-life and aging factor • Applicable for transformers with up to six windings in a ring bus or breaker-and-a-half configuration • Reliable and secure protection for three-phase transformers, autotransformers, reactors, split phase and phase angle regulating transformers • Stand-alone or component in automated substation control system

• Dual-slope, dual-breakpoint differential restraint characteristic, restrained and unrestrained differential

• CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog)

Communications • 3 independent Ethernet ports for simultaneous & dedicated network connections with IEEE 1588 support • Supported industry protocols: IEC 61850 Ed. 2, SFTP, MMS File Transfer Service, DNP 3.0, Modbus Serial/TCP, IEEE 1588, IEC 60870-5-104 and 103, PRP, SNTP, HTTP, TFTP • Direct I/O for secure, high-speed exchange URs for DTT & pilot-aided schemes

Monitoring & Metering • P&M class synchrophasors of voltage, current, and sequence components • Advanced recording capabilities with highcapacity event recorder, configurable and extended waveform capture and data logger • Metering: current, voltage, power, energy, frequency, and harmonics

T60 Transformer Protection System

Protection and Control

T60 - Protection, Metering, Monitoring and Control

Transformer Protection

The T60 transformer protection system is a comprehensive three-phase transformer relay designed to protect medium and large power transformers. As part of the Universal Relay (UR) Family, the T60 provides superior protection and control that includes:

Percent Differential Protection The T60 provides enhanced security by including both restrained and unrestrained (instantaneous) differential protection. The percent differential element is based on a configurable dual-breakpoint/dual-slope differential restraint characteristic with inrush and overexcitation inhibits. The maximum winding current is used as a restraining signal for better through fault stability under CT saturation conditions. The T60 is the single point for protection, control, metering, and monitoring in one integrated device that can easily be connected directly into DCS or SCADA monitoring and control systems like Viewpoint Monitoring as shown.

The percent characteristic allows the element to account for both DC and AC saturation of the current transformers.

Functional Block Diagram 3V_0

78

Amps

67N

67P

51P-1

50P-1

50N-1

51N-1

Amps

87G-1

51G-1

50G-1

Calculate 3I_0

50N-2

51N-2

Amps

87G-2

51G-2

50G-2

51P-2

50P-2

Calculate Harmonics 2&5

Winding 2

Block

Calculate 3I_0

Winding 1

Amps

Metering

T60

50/87

Harmonic Restraint

68

3

Amps

49

TM

27X2

59X2

FlexElement

81 O4

87T

21G5

3

Calculate Operate Amps

27P3 81 U6

21P5

Calculate Restraint Amps

Transformer Protection System

ANSI Device Numbers & Functions ®

DEVICE FUNCTION NUMBER

DEVICE FUNCTION NUMBER

DEVICE FUNCTION NUMBER

21P 21G 24 25 27P 27X 49 50BF 50G

50N 50P 50/87 51G 51N 51P 59N 59P 59X

67N 67P 68 78 81O 81U 81R 87G 87T

80

Phase Distance Ground Distance Volts Per Hertz Synchrocheck Phase Undervoltage Auxiliary Undervoltage Thermal Overload Breaker Failure Ground Instantaneous Overcurrent

Neutral Instantaneous Overcurrent Phase Instantaneous Overcurrent Instantaneous Differential Overcurrent Ground Time Overcurrent Neutral Time Overcurrent Phase Time Overcurrent Neutral Overvoltage Phase Overvoltage Auxiliary Overvoltage

GEDigitalEnergy.com

Neutral Directional Overcurrent Phase Directional Overcurrent Power Swing Blocking Out-of-Step Tripping Overfrequency Underfrequency Rate of Change of Frequency (ROCOF) Restricted Ground Fault Transformer Differential

THE AC SIGNAL PATH IS CONFIGURABLE

242

49 Amps

TYPICAL CONFIGURATION (UP TO 6 WINDINGS)

59N3

Transducer Input

59P3

T60 Transformer Protection System

Differential vs. Restraint Characteristic (ld vs.lr) Differential Current (Id)

signal that provides security for external fault conditions that may cause CT saturation while still maintaining sensitivity for internal faults.

Slope 2

Distance Protection Break Point 2

Slope 1

Break 1

Restraint Current (Ir)

The settings for the dual-slope, dual-breakpoint characteristic provides higher flexibility for shaping up the characteristic and achieving better sensitivity and security.

Inrush Inhibit The 2nd harmonic inhibit function is selectable in order to cover the energization of different types of transformers and can be set to either traditional or adaptive mode. The adaptive mode maximizes dependability on internal faults and ensures security during inrush conditions even with weak second harmonics. It reduces the sensitivity of magnitude comparison by biasing towards security, based on an angular relationship. Dependability is maintained by applying the restraint signal only for a period of time, dependent on the magnitude ratio.

Overexcitation Inhibit An increase in transformer voltage or decrease in system frequency may result in overexcitation of the transformer. It is often desirable to prevent operation of the percent differential element in these cases, therefore a fifth harmonic inhibit is integrated into the percent differential element to cater to overexcitation conditions, resulting from an increased V/Hz ratio.

Separate high-speed phase and ground distance elements are provided in T60 as a backup protection. T60 comes with five phase and ground distance quad and mho distance elements. The phase distance elements come with built-in in-zone transformer compensation. The T60 also provides a load encroachment element , which supervises the distance elements under heavy resistive loading conditions.

Overcurrent Functions T60 provides thermal overload, time and instantaneous overcurrent elements for phase, neutral, ground, phase and neutral directional. The neutral directional overcurrent element supports enhanced dual polarization modes which can be configured to prioritize on voltage or current polarization. All of them can run in parallel with primary differential protection or can be programmed to provide primary protection under conditions when other protection elements are blocked.

User-Definable Protection Functions Sixteen user-definable protection functions (FlexElements) can be programmed to respond to any quantity measured or computed by the relay (phase, ground and sequence current and voltage power, frequency, power factor, etc.) These elements respond to variations in its input signal. Applications could include: overvoltage, overpower, low power factor, temperature differential, and more.

The IEC 61850 Process Bus module is designed to interface with the Multilin HardFiber System, allowing bi-directional IEC 61850 fiber optic communications. The HardFiber System is designed to integrate seamlessly with existing UR applications, including protection functions, FlexLogic™ metering and communications. The Multilin HardFiber System offers the following benefits: • Communicates using open standard IEC 61850 messaging • Drastically reduces P&C design, installation and testing labor by eliminating individual copper terminations • Integrates with existing T60’s by replacing traditional CT/VT inputs with the IEC 61850 Process Bus module • Does not introduce new cyber security concerns Visit the HardFiber System product page on the GE Digital Energy web site for more details.

Advanced Automation The T60 incorporates advanced automation features including powerful FlexLogic programmable logic, communication, and SCADA capabilities that far surpass what is found in the average transformer relay. The T60 integrates seamlessly with other UR relays for complete system protection.

FlexLogic FlexLogic is the powerful UR-platform programming logic engine that provides the ability to create customized protection and control schemes, minimizing the need and associated costs of auxiliary components

Unrestrained Differential An unrestrained differential element is provided for fast tripping on heavy internal faults to limit catastrophic damage to the transformer and minimize risks to the remainder of the power system.

Restricted Ground Fault (RGF) RGF (also known as zero-sequence differential) extends protection coverage to the neutral point of wye-connected windings where fault currents may be below the pickup of the main transformer differential elements. The low-impedance RGF protection provided in the T60 uses an optimized adaptive restraint

Faults close to the neutral point of a wye-connected winding does not generate adequate fault current for elements to detect. Restricted ground fault protection provides sensitive ground fault detection for lowmagnitude fault currents.

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81

Transformer Protection

Transition Region

IEC 61850 Process Bus

Transformer Protection

T60 Transformer Protection System

and wiring. Using FlexLogic, the T60 can be programmed to provide the required tripping logic along with custom scheme logic for line phase comparison (including interlocking with external synchronizers), transfer tripping schemes for remote breakers and dynamic setting group changes.

Scalable Hardware The T60 is available with a multitude of I/O configurations to suit the most demanding application needs. The expandable modular design allows for easy configuration and future upgrades. • Multiple CT/VT configurations allow for the implementation of many differential schemes, including concurrent split-phase and differential protection • Types of digital outputs include triprated Form-A and Solid State Relay (SSR) mechanically latching, and Form-C outputs • RTDs and DCmA inputs are available to monitor equipment parameters such as temperature and pressure

Monitoring and Metering The T60 includes high accuracy metering and recording for all AC signals. Voltage, current , and power metering are built into the relay as a standard feature. Current and voltage parameters are available as total RMS magnitude, and as fundamental frequency magnitude and angle. For power quality applcations, harmonic measurements (up to the 25th) for voltage and current are available. T60 can monitor, calculate and log hottestspot temperature, aging factor and loss-of-life data over a long period. This data, combined

with economic analysis, allows criteria to be developed regarding the best time at which to replace a power transformer due to load growth, i.e. to minimize the cost without significantly increasing the risk.

Fault and Disturbance Recording The advanced disturbance and event recording features within the T60 can significantly reduce the time needed for postmortem analysis of power system events and the creation of regulatory reports. Recording functions include: • Sequence of Event (SOE) 1024 time stamped events • Oscillography - 64 digital & up to 40 analog channels - Events with up to 45s length

can also be used with the T60 for temperature monitoring. The RRTD provides cost savings when compared with traditional RTD wiring.

Advanced Device Health Diagnostics The T60 performs comprehensive device health diagnostic at startup and continuously during run-time to test its own major functions and critical hardware. These diagnostic tests monitor for conditions that could impact security and availability of protection, and present device status via SCADA communications and front panel display. Providing continuous monitoring and early detection of possible issues help improve system uptime. • Comprehensive device health diagnostic performed at startup

• Data Logger and Disturbance Recording - 16 channels up to 1 sample/cycle/channel

• Monitors the CT/VT input circuitry to validate the integrity of all signals

• Fault Reports - Powerful summary report of pre-fault and fault values

• Inputs, outputs, trip circuits and analog channels are continuously monitored for accuracy and performance

• Extensive breaker info (continuous coil monitor, arcing current, operating time, operation counter for asset management)

Advanced Asset Monitoring

The very high sampling rates and large amount of storage space available for data recording in the T60 can eliminate the need for installing costly stand-alone recording equipment.

Temperature Monitoring – RTD Module Option 5C The T60 RTD option provides 8 programmable RTD inputs per module that are used for temperature monitoring. Each RTD input has 2 operational levels: alarm and trip. The T60 supports RTD trip voting and provides open RTD failure alarming. Alternatively, a remote RTD module “RRTD”, which supports 12 RTD inputs,

The T60 has advanced functions that raise an alarm or trip the scheme when an internal condition in the power transformer or breaker could lead to a fault . These functions are conditions of: • Hottest-spot temperature: element provides a mechanism for detecting abnormal winding hottest-spot temperatures inside the transformer. • Aging factor: the aging factor element detects transformer aging in per-unit normal insulation aging. • Loss of Life: The Loss of Life element detects the accumulated total consumed transformer life. • Breaker arcing current: This element calculates an estimate of the per-phase deterioration on the breaker contacts by measuring and integrating the current (squared) passing through the breaker contacts as an arc. These elements allow the user to optimize maintenance routines on the power transformer and breakers.

Cyber Security – CyberSentry UR CyberSentry UR enabled UR devices deliver full cyber security features that help customers to comply with NERC CIP and NIST® IR 7628 cyber security requirements. This software option delivers the following core features:

Multi-breaker application example.

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T60 Transformer Protection System

AAA Server Support (Radius/LDAP)

Role Based Access Control (RBAC) Efficiently administrate users and roles within UR devices. The new and advanced access functions allow users to configure up to five roles for up to eight configurable users with independent passwords. The standard “Remote Authentication Dial In User Service” (Radius) is used for authentication.

Event Recorder (Syslog for SEM) Capture all cyber security related events within a SOE element (login, logout, invalid password attempts, remote/local access, user in session, settings change, FW update, etc), and then serve and classify data by security level using standard Syslog data format. This will enable integration with established SEM (Security Event Management) systems.

Communications The T60 provides advanced commun-ications technologies for remote data and engineering access, making it the most advanced and flexible transformer protection relay to use and integrate into new and existing infrastructures. Direct support for fiber optic Ethernet provides

• IEC 61850 Ed. 2 with 61850-9-2 and 61850‑90-5 support • DNP 3.0 (serial & TCP/IP) • Ethernet Global Data (EGD) • IEC 60870-5-103 and IEC 60870-5-104 • Modbus RTU, Modbus TCP/IP • HTTP, TFTP, SFTP and MMS file transfer • SNTP and IEEE 1588 for time synchronization • PRP as per IEC 62439-3

Interoperability with Embedded IEC 61850 Edition 2 The new IEC 61850 implementation in the UR Family positions GE as an industry leader in this standard. • Implements Edition 2 of the standard across the entire family of UR devices • Provides full relay setting management via standard SCL files (ICD, CID and IID)

• Enables automated relay setting management using 3rd party tools through standard file transfer services (MMS and SFTP) • Increases the number of Logical Devices and data mapped to them, GOOSE messages, and reports to support different organizational needs for data transfer and reduce dependency on generic logical nodes • Configures GE Systems based on IEC 61850 using universal 3rd party tools • Multicast IEEE C37.118 synchrophasor data between PMU and PDC devices using IEC 91850-90-5

Direct I/O Messaging Direct I/O allows for the sharing of high-speed digital information between multiple UR relays via direct back-to-back connections or multiplexed through a standard DS0 multiplexer channel bank. Regardless of the connection method, direct I/O provides continuous real-time channel monitoring that supplies diagnostics information on channel health. Direct I/O provides superior relay-to-relay communications that can be used in advanced interlocking, generation rejection and other special protection schemes. • Communication with up to 16 UR relays in single or redundant rings rather than simplistic point-to-point configurations • Connect to standard DS0 channel banks through standard RS422, G.703 or IEEE C37.94 interfaces or via direct fiber optic connections

Power System Troubleshooting

Record the operation of the internal T60 elements and external connected devices with 1ms time-stamped accuracy to identify the Sequence of Operation of station devices during transformer faults and disturbances.

Analyze transformer faults using both analog and digital power system quantities that are measured and recorded up to a rate of 64 samples per cycle.

GEDigitalEnergy.com

Visualization of differential characteristics allows for setting verification and operation troubleshooting.

83

Transformer Protection

Enables integration with centrally managed authentication and accounting of all user activities and uses modern industry best practices and standards that meet and exceed NERC CIP requirements for authentication and password management.

high-bandwidth communications allowing for low-latency controls and high-speed file transfers of relay fault and event record information. The available three independent Ethernet ports, redundant Ethernet option and the embedded managed Ethernet switch provide the means to create fault tolerant communication architectures in an easy, cost-effective manner without the need for intermediary communication hardware. The T60 supports the most popular industry standard protocols enabling easy, direct integration into DCS and SCADA systems.

T60 Transformer Protection System

• Built-in continuous loop and channel monitoring provides real-time diagnostics of your communication channels with no external or handheld tester required

Transformer Protection

LAN Redundancy Substation LAN redundancy has been traditionally accomplished by reconfiguring the active network topology in case of failure. Regardless of the type of LAN architecture (tree, mesh, etc), reconfiguring the active LAN requires time to switchover, during which the LAN is unavailable. UR devices deliver redundancy as specified by PRP-IEC 62439-3, which eliminates the dependency on LAN reconfiguration and the associated switchover time. The UR becomes a dual attached node that transmits data packets over both main and redundant networks simultaneously, so in case of failure, one of the data packets will reach the receiving device with no time delay.

Multi-Language UR devices support multiple languages: English, French, Russian, Chinese, Turkish and German. These language options are available on the front panel, in the EnerVista setup software, and in the product manuals. Easily switch between English and an additional language on the local displays without uploading new firmware.

EnerVista Software The EnerVista suite is an industry-leading set of software programs that simplifies every aspect of using the T60 relay. The EnerVista suite provides all the tools to monitor the status of the transformer, maintain the relay, and integrate information measured by the T60 into DCS or SCADA monitoring systems. Convenient COMTRADE and SOE viewers are an integral part of the UR setup software included with every UR relay, to carry out postmortem event analysis and ensure proper protection system operation.

User Interface

EnerVista Launchpad

Viewpoint UR Engineer

EnerVista Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining Multilin products. The setup software within Launchpad allows for the configuration of devices in real-time by communicating using serial, Ethernet, or modem connections, or offline by creating setting files to be sent to devices at a later time. Included in Launchpad is a document archiving and management system that ensures critical documentation is up-todate and available when needed. Documents made available include:

Viewpoint UR Engineer is a set of powerful tools that allows you to configure and test GE relays at a system level in an easy-to-use graphical drag-and-drop environment . Viewpoint UR Engineer provides the following configuration and commissioning utilities:

• Manuals

Viewpoint Maintenance

• Application Notes & Support Documents

• FAQ’s

Viewpoint Maintenance provides tools that will create reports on the operating status of the relay, simplify the steps to download fault and event data, and reduce the work required for cyber security compliance audits. Tools available in Viewpoint Maintenance include:

• Service Bulletins

• Settings Security Audit Report

• Guideform Specifications • Brochures • Wiring Diagrams

Viewpoint Monitoring Viewpoint Monitoring is a simple-to-use and full-featured monitoring and data recording software package for small systems. Viewpoint Monitoring provides a complete HMI package with the following functionality:

• Graphical Logic Designer • Graphical System Designer • Graphical Logic Monitor • Graphical System Monitor • IEC 61850 Configurator

• Device Health Report • Single-Click Fault Data Retrieval

EnerVista Integrator

• Plug-&-Play Device Monitoring

EnerVista Integrator is a toolkit that allows seamless integration of Multilin devices into new or existing automation systems. Included in EnerVista Integrator:

• System Single-Line Monitoring & Control

• OPC/DDE Server

• Annunciator Alarm Screens

• Multilin Drivers

• Trending Reports

• Automatic Event Retrieval

• Automatic Event Retrieval

• Automatic Waveform Retrieval

• Automatic Waveform Retrieval

48 Configurable LED Indicators

The T60 front panel provides extensive local HMI capabilities. The local display is used for monitoring, status messaging, fault diagnosis, and device configuration. User-configurable messages that combine text with live data can be displayed when user-defined conditions are met.

MultiLanguage Display • English • Russian • French • Chinese • Turkish • German

User-Programmable Pushbuttons

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T60 Transformer Protection System

Fibre * Optic

Remote Device

Typical Wiring

DC

Shielded

Co-axial

Co-axial

Transformer Protection

A B C

minimum

PROVIDED

H7a H7c H8a H8c H7b

H8b

10BaseFL

Rx1

10BaseFL

B1b B1a B2b B3a B3b B5a MED B5b HI B6b LO B6a B8a B8b

Tx1

Tx2

com

10BaseT

Rx2

D1a D2a D3a D4b D4a BNC

BNC

SURGE

CRITICAL FAILURE

OUTPUT

CONTROL POWER

SURGE FILTER

NORMAL

ALTERNATE

RS485

IRIG-B Input

IRIG-B Output

1

COM 1

X W V U

6 Inputs/ outputs *

U1a U1c U2a U2c U1b

F5a

VA

F5c

VB

F6a

VB

F6c

VC

F7a

VC

F7c

VA

F5a

VA

F5c

VB

F6a

VB

F6c

VC

F7a

VC

F7c

VX

F8a

VX

F8c

IA5

T S

U3a U3c U4a U4c U3b

R P

6 Inputs/ outputs *

N 6

M L K

CT/VT

8

H

6D

6

J

Inputs/ outputs

SURGE

F1a

IA

F1b

IA1

F1c

IB5

F2a

IB

F2b

IB1

F2c

IC5

F3a

IC

F3b

IC1

F3c

IG5

F4a

IG

F4b

IG1

F4c

G F D

9

B 1

T60-H03-HLH-F8L-H6H-M8N-P6C-U6D P1

P2

P3

P4

P5

P6

P7

6H 1

2

V

V

V

V

V

V

I

IA5

M 1a

IA

M 1b

IA1

M 1c

IB5

M 2a

IB

M 2b

IB1

M 2c

IC5

M 3a

IC

M 3b

IC1

M 3c

IG5

M 4a

IG

M 4b

IG1

M 4c

IA5

M 5a

IA

M 5b

IA1

M 5c

IB5

M 6a

IB

M 6b

IB1

M 6c

IC5

M 7a

IC

M 7b

IC1

M 7c

IG5

M 8a

IG

M 8b

IG1

M 8c

I

3

4

5

6

RS-232

DB-9

(front)

I

P8

6C

P1a P1b P1c P2a P2b P2c P3a P3b P3c P4a P4b P4c P5a P5b P5c P6a P6b P6c P7a P7b P7c P8a P8b P8c

I

Power supply

T60

I

CPU

GE Digital Energy Multilin

I

CT

U5a U5c U6a U6c U5b U7a U7c U8a U8c U7b U8b

VA

H1a H1b H1c H2a H2b H2c H3a H3b H3c H4a H4b H4c H5a H5b H5c H6a H6b H6c

TC 2

A B C

A B C

TC 1

TXD RXD

SGND

T60

1 2 3 4 5 6 7 8 9

CONNECTOR

CONNECTOR

8 3 RXD 2 TXD 20 7 SGND 6 4 5 22

COMPUTER

1 2 3 4 5 6 7 8 9

PERSONAL COMPUTER

GEDigitalEnergy.com

This diagram is based on the following order code: T60-H03-HLH-F8L-H6H-M8N-P6C-U6D This diagram provides an example of how the device is wired, not specifically how to wire the device. Please refer to the Instruction Manual for additional details

85

Ordering

T60 - * 00 - H * * - F ** - H ** - M ** -P ** - U ** - W/X ** For Full Sized Horizontal Mount

Base Unit T60 Base Unit CPU E RS485 + RS485 (IEC 61850 option not available) J RS485 + multimode ST 100BaseFX K RS485 + multimode ST Redundant 100BaseFX N RS485 + 10/100 BaseT T RS485 + three multimode SFP LC 100BaseFX. Req FW v7xx or higher U RS485 + two multimode SFP LC 100BaseFX + one SFP RJ45 100BaseT. Req FW v7xx or higher V RS485 + three SFP RJ45 100BaseT. Req FW v7xx or higher Software Options 00 No Software Options (see notes 1 & 3 below) 01 Ethernet Global Data (EGD) 03 IEC 61850 04 Ethernet Global Data (EGD) + IEC 61850 06 PMU 07 IEC 61850 + PMU 10 Synchrocheck 11 Synchrocheck + IEC 61850 23 5 windings (No Breaker Failure) + EGD + IEC 61850 33 PMU + Synchrocheck 34 PMU + IEC 61850 + Synchrocheck A0 CyberSentry UR Lvl 1. Req UR FW 7.xx or higher B0 IEEE 1588. Req UR FW 7.xx or higher C0 PRP D0 IEEE 1588 + CyberSentry. Req UR FW 7.xx or higher M0 IEC 61850 + PMU + 61850-90-5 Mount / Coating H Horizontal (19" rack) - Standard A Horizontal (19" rack) - Harsh Chemical Environment Option V Vertical (3/4 size) - Standard B Vertical (3/4 size) - Harsh Chemical Environment Option User Interface F Vertical Front Panel with English Display I Enhanced German Front Panel J Enhanced German Front Panel with User-Programmable Pushbuttons K Enhanced English Front Panel L Enhanced English Front Panel with User-Programmable Pushbuttons M Enhanced French Front Panel N Enhanced French Front Panel with User-Programmable Pushbuttons Q Enhanced Russian Front Panel T Enhanced Russian Front Panel with User-Programmable Pushbuttons U Enhanced Chinese Front Panel V Enhanced Chinese Front Panel with User-Programmable Pushbuttons W Enhanced Turkish Front Panel Y Enhanced Turkish Front Panel with User-Programmable Pushbuttons Power Supply H 125 / 250 V AC/DC (see note 2 below) H RH 125/250 V AC/DC with redundant 125/250 V AC/DC L 24 - 48 V (DC only) CT/VT DSP 8L 8L Standard 4CT/4VT w/ enhanced diagnostics 8M 8M Sensitive Ground 4CT/4VT w/ enhanced diagnostics 8N 8N Standard 8CT w/ enhanced diagnostics 8R 8R Sensitive Ground 8CT w/ enhanced diagnostics IEC 61850 Process Bus 81 8 Port IEC 61850 Process Bus Module Digital I/O XX XX XX XX XX XX No Module 4A 4A 4A 4A 4A 4A 4 Solid State (No Monitoring) MOSFET Outputs 4C 4C 4C 4C 4C 4C 4 Solid State (Current w/opt Voltage) MOSFET Outputs 4D 4D 4D 4D 4D 4D 16 Digital Inputs with Auto-Burnish 4L 4L 4L 4L 4L 4L 14 Form-A (No Monitoring) Latchable Outputs 67 67 67 67 67 67 8 Form-A (No Monitoring) Outputs 6C 6C 6C 6C 6C 6C 8 Form-C Outputs 6D 6D 6D 6D 6D 6D 16 Digital Inputs 6E 6E 6E 6E 6E 6E 4 Form-C Outputs, 8 Digital Inputs 6F 6F 6F 6F 6F 6F 8 Fast Form-C Outputs 6K 6K 6K 6K 6K 6K 4 Form-C & 4 Fast Form-C Outputs 6L 6L 6L 6L 6L 6L 2 Form-A (Current w/ opt Voltage) & 2 Form-C Outputs, 8 Digital Inputs 6M 6M 6M 6M 6M 6M 2 Form-A (Current w/ opt Voltage) & 4 Form-C Outputs, 4 Digital Inputs 6N 6N 6N 6N 6N 6N 4 Form-A (Current w/ opt Voltage) Outputs, 8 Digital Inputs 6P 6P 6P 6P 6P 6P 6 Form-A (Current w/ opt Voltage) Outputs, 4 Digital Inputs 6R 6R 6R 6R 6R 6R 2 Form-A (No Monitoring) & 2 Form-C Outputs, 8 Digital Inputs 6S 6S 6S 6S 6S 6S 2 Form-A (No Monitoring) & 4 Form-C Outputs, 4 Digital Inputs 6T 6T 6T 6T 6T 6T 4 Form-A (No Monitoring) Outputs, 8 Digital Inputs 6U 6U 6U 6U 6U 6U 6 Form-A (No Monitoring) Outputs, 4 Digital Inputs 6V 6V 6V 6V 6V 6V 2 Form-A (Cur w/ opt Volt) 1 Form-C Output, 2 Latching Outputs, 8 Digital Inputs Transducer I/O 5A 5A 5A 5A 5A 5A 4 dcmA Inputs, 4 dcmA Outputs 5C 5C 5C 5C 5C 5C 8 RTD Inputs 5E 5E 5E 5E 5E 5E 4 dcmA Inputs, 4 RTD Inputs 5F 5F 5F 5F 5F 5F 8 dcmA Inputs Inter-Relay Communications 7A 820 nm, multimode, LED, 1 Channel 7B 1300 nm, multimode, LED, 1 Channel 7C 1300 nm, singlemode, ELED, 1 Channel 7H 820 nm, multimode, LED, 2 Channels 7I 1300 nm, multimode, LED, 2 Channels 7J 1300 nm, singlemode, ELED, 2 Channels 7S G.703, 2 Channels 7W RS422, 2 Channels 77 IEEE C37.94, 820 nm, multimode, LED, 2 Channel 2B C37.94SM, 1300nm singlemode, ELED, 2 Channel singlemode

Ordering Notes: 1. To view all the options available for T60, please visit GE’s On-Line Store http://store.gedigitalenergy.com/viewprod.asp?model=T60 2. Redundant power supply only available in horizontal unit. If redundant is chosen, must be same type. Maximum 2 per chassis. 3. All “5 windings (No breaker Failure)” options become “6 windings w/breaker failure” when FW v7xx is chosen.

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12650I(E) English 150122

Multilin™ T35 Cost-Effective Differential Protection for Transformers With Up To 6 Sets of CTs The Multilin T35 transformer protection system is a three-phase transformer relay designed to protect power transformers with up to six windings/restraints. The T35 provides for automatic or user-definable magnitude reference winding selection for CT ratio matching. The T35 performs automatic phase shift compensation for all types of transformer winding connections. The T35 algorithm allows the user to enable the removal of the zero-sequence current even for delta connected transformer windings, accommodating transformers with a variety of grounding configurations.

Protection & Control • Percent restrained and unrestrained differential protection • 2nd Harmonic inrush inhibit and overexcitation inhibit • Thermal overload and time overcurrent elements for backup protection • Transducer I/Os (RTD & dcmA) • FlexElements & FlexCurves

Key Benefits

Communications

• Secure, high-speed protection for transformers, compliant with IEEE® C37.91 for maximum asset life

• 3 independent Ethernet ports for simultaneous & dedicated network connections with IEEE 1588 support

• Improved security for transformer energization and inrush provided through an adaptive 2nd harmonic restraint algorithm • Application flexibility for transformers with up to 6 sets of CTs, with independent magnitude/phase angle compensation and grounding settings • Advanced automation capabilities to enable customized protection & control solutions • Advanced IEC 61850 Ed. 2 implementation, complete settings via SCL files and IEC 61850-9-2 process bus solution enable resource and platform managing optimization and reduce cost of ownership • Increased network availability via failover time reduced to zero through IEC® 62439-3 “PRP” support • CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog) • Advanced fault and disturbance recording, including internal relay operating signals, eliminating the need for external recording devices and optimization of asset management & maintenance activities

Applications • Combined protection for transformers and small bus zone, including breaker-and-a-half and ring bus diameters • Stand-alone or component in automated substation control systems • Primary & backup protection of power transformers, autotransformers, reactors, split-phase and angle regulating transformers

• Supported industry protocols: IEC 61850 Ed. 2, SFTP, MMS File Transfer Service, DNP 3.0, Modbus Serial/TCP, IEEE 1588, IEC 60870-5-104 and 103, PRP, SNTP, HTTP, TFTP • Direct I/O for secure, high-speed exchange of data between URs for DTT & pilot-aided schemes

Cyber Security • CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog) • Setting for security audit trails, tracking changes to device configurations

Monitoring & Metering • Advanced recording capabilities with highcapacity event recorder, configurable and extended waveform capture and data logger • Metering: current, voltage, power, energy, frequency, and harmonics

T35 Transformer Protection System

Protection and Control

T35 - Protection, Metering, Monitoring and Control

Transformer Protection

The T35 transformer protection system is a three-phase transformer relay designed to protect power transformers with up to six windings/restraints. As part of the Universal Relay (UR) Family, the T35 provides cost-effective solutions and superior protection and control.

Multi-CT Configurations The T35 can be used to protect transformer differential zones with up to 6 three-phase current inputs (six restraints), making it possible to include multiple breakers or small buses in the differential zone.

Percent Differential Protection The percent differential element is based on a configurable dual-breakpoint/dual-slope differential restraint characteristic with inrush and overexcitation inhibits. The maximum winding current is used as a restraint signal for better through-fault stability under CT saturation conditions. The percent differential protection characteristic allows the element to account for both DC and AC saturation of the current transformers.

Inrush Inhibit The 2nd harmonic inhibit function is selectable in order to cover the energization of different types of transformers, and can be set to either traditional or adaptive mode. The adaptive mode maximizes dependability on internal faults and ensures security during inrush conditions even with weak second harmonics. It reduces the sensitivity of magnitude comparison, by biasing towards security, based on an angular relationship. Dependability is maintained by applying the restraint signal only for a period of time, dependent on the magnitude ratio.

The T35 is the single point for protection, control, metering, and monitoring in one integrated device that can easily be connected directly into DCS or SCADA monitoring and control systems like Viewpoint Monitoring as shown.

Overexcitation Inhibit An increase in transformer voltage or decrease in system frequency may result in the transformer becoming overexcited. It is often desirable to prevent differential element operation in these cases, therefore, a fifth harmonic inhibit is integrated into the percent differential element to cater to overexcitation conditions resulting from an increased V/Hz ratio.

Unrestrained Differential An unrestrained differential element is provided for fast tripping on heavy internal faults to limit catastrophic damage to the transformer and minimize risks to the rest of the power system.

Differential vs. Restraint Characteristic (ld vs.lr) Differential Current (Id)

Slope 2

Break Point 2 Transition Region

Slope 1

Break 1

Restraint Current (Ir)

The settings for the dual-slope, dual-breakpoint characteristic provides higher flexibility for shaping up the characteristic and achieving better sensitivity and security.

Multi-CT Configurations

5 CT inputs 1 VT input

6 CT inputs

6 CT inputs

Examples of T35 applications for transformers and autotransformers connected to more than two breakers.

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GEDigitalEnergy.com

5 CT inputs 1 VT input

T35 Transformer Protection System

Overcurrent Functions

FlexLogic™ Designer

Transformer Protection

T35 provides thermal overload, time overcurrent elements for phase, neutral, and ground, which can run in parallel with primary differential protection or can be programmed to provide primary protection under conditions when other protection elements are unavailable.

User-Definable Protection Functions Sixteen user-definable protection functions (FlexElements) can be programmed to respond to any quantity measured or computed by the relay (phase, ground and sequence currents and voltages, power, frequency, power factor, etc.). Applications could include overvoltage, overpower, low power factor, temperature differential, and more.

IEC 61850 Process Bus The IEC 61850 Process Bus module is designed to interface with the Multilin HardFiber System, allowing bi-directional IEC 61850 fiber optic communications. The HardFiber System is designed to integrate seamlessly with existing UR applications, including protection functions, FlexLogic, metering and communications. The Multilin HardFiber System offers the following benefits: • Communicates using open standard IEC 61850 messaging

FlexLogic allows for customizing the T35 to operate and control the breakers and other auxiliary devices needed to fit most transformer protection schemes and applications.

• Integrates with existing T35’s by replacing traditional CT/VT inputs with the IEC 61850 Process Bus module • Does not introduce new cyber security concerns Visit the HardFiber System product page on the GE Digital Energy web site for more details.

• Drastically reduces P&C design, installation and testing labor by eliminating individual copper terminations

Advanced Automation The T35 incorporates advanced automation features including powerful FlexLogic programmable logic, communication, and SCADA capabilities that far surpass what is found in the average transformer relay. The T35 integrates seamlessly with other UR relays for complete system protection.

Functional Block Diagram ANSI Device Numbers & Functions ®

Measure 3I_0

Calculate Restraint Amps 51P-1

DEVICE FUNCTION NUMBER

Measure 3I_0

49 50/87 51G 51P 87T

Calculate Operate Amps 50/87

87T

49-1

Thermal Overload Instanataneous Differential Overcurrent Ground Time Overcurrent Phase Time Overcurrent Transformer Differential

Calculate 2nd, 5th harmonics 51P-2

49-2

Metering

Transducer Input

FlexElement

TM

T35 Transformer Protection System

GEDigitalEnergy.com

89

T35 Transformer Protection System

Transformer Protection

FlexLogic FlexLogic is the powerful UR-platform programming logic engine that provides the ability to create customized protection and control schemes, minimizing the need and associated costs of, auxiliary components and wiring. Using FlexLogic, the T35 can be programmed to provide the required tripping logic along with custom scheme logic for transformer breaker control (including interlocking with external synchronizers), transfer tripping schemes for remote breakers and dynamic setting group changes.

Scalable Hardware The T35 is available with a multitude of I/O configurations to suit the most demanding application needs. The expandable modular design allows for easy configuration and future upgrades. • Multiple CT/VT configurations allow for the implementation of many different schemes, including multi-winding transformer differential protection • Flexible, modular I/O covering a broad range of input signals and tripping schemes • Types of digital outputs include triprated Form-A and Solid State Relay (SSR) mechanically latching, and Form-C outputs

• Form-A and SSR outputs available with optional circuit continuity monitoring and current detection to verify continuity and health of the associated circuitry • Mechanically latching outputs can be used to develop secure interlocking applications and replace electromechanical lockout relays • RTDs and DCmA inputs are available to monitor equipment parameters such as temperature and pressure

• Data Logger and Disturbance Recording - 16 channels up to 1 sample/cycle/channel • Fault Reports - Powerful summary report of pre-fault and fault values The very high sampling rate and large amount of storage space available for data recording in the T35 can eliminate the need for installing costly stand-alone recording equipment.

Advanced Device Health Diagnostics

Monitoring and Metering The T35 includes high accuracy metering and recording for all AC signals. Voltage, current , and power metering are built into the relay as a standard feature. Current and voltage parameters are available as total RMS magnitude, and as fundamental frequency magnitude and angle.

Fault and Disturbance Recording

The T35 performs comprehensive device health diagnostic tests at startup and continuously during run-time to test its own major functions and critical hardware. These diagnostic tests monitor for conditions that could impact security and availability of protection, and present device status via SCADA communications and front panel display. Providing continuous monitoring and early detection of possible issues help improve system uptime.

The advanced disturbance and event recording features within the T35 can significantly reduce the time needed for postmortem analysis of power system events and the creation of regulatory reports. Recording functions include:

• Comprehensive device health diagnostic performed at startup

• Sequence of Event (SOE) - 1024 time stamped events

Cyber Security – CyberSentry UR

• Oscillography - 64 digital & up to 40 analog channels - Events with up to 45s length

• Monitors the CT/VT input circuitry to validate the integrity of all signals

CyberSentry UR enabled UR devices deliver full cyber security features that help customers to comply with NERC CIP and NIST® IR 7628 cyber security requirements. This software option delivers the following core features:

Power System Troubleshooting The T35 contains many tools and reports that simplify and reduce the amount of time required for troubleshooting power system events.

Record the operation of the internal T35 elements and external connected devices with 1ms time-stamped accuracy to identify the Sequence of Operation of station devices during transformer faults and disturbances.

90

Visualization of differential characteristics allows for setting verification and operation troubleshooting.

GEDigitalEnergy.com

Analyze transformer faults using both analog and digital power system quantities that are measured and recorded up to a rate of 64 samples per cycle.

T35 Transformer Protection System

AAA Server Support (Radius/LDAP)

Role Based Access Control (RBAC) Efficiently administrate users and roles within UR devices. The new and advanced access functions allow users to configure up to five roles for up to eight configurable users with independent passwords. The standard “Remote Authentication Dial In User Service” (Radius) is used for authentication.

Event Recorder (Syslog for SEM)

• IEC 61850 Ed. 2 with 61850-9-2 • DNP 3.0 (serial & TCP/IP) • Ethernet Global Data (EGD) • IEC 60870-5-103 and IEC 60870-5-104 • Modbus RTU, Modbus TCP/IP • HTTP, TFTP, SFTP and MMS file transfer

• Increases the number of Logical Devices and data mapped to them, GOOSE messages, and reports to support different organizational needs for data transfer and reduce dependency on generic logical nodes • Configures GE Systems based on IEC 61850 using universal 3rd party tools

Direct I/O Messaging Direct I/O allows for the sharing of high-speed digital information between multiple UR relays via direct back-to-back connections or multiplexed through a standard DS0 multiplexer channel bank. Regardless of the connection method, direct I/O provides continuous real-time channel monitoring that supplies diagnostics information on channel health. Direct I/O provides superior relay-to-relay communications that can be used in advanced interlocking, generation rejection and other special protection schemes.

Capture all cyber security related events within a SOE element (login, logout, invalid password attempts, remote/local access, user in session, settings change, FW update, etc), and then serve and classify data by security level using standard Syslog data format. This will enable integration with established SEM (Security Event Management) systems.

• SNTP and IEEE 1588 for time synchronization

Communications

• Implements Edition 2 of the standard across the entire family of UR devices

• Connect to standard DS0 channel banks through standard RS422, G.703 or IEEE C37.94 interfaces or via direct fiber optic connections

• Provides full relay setting management via standard SCL files (ICD, CID and IID)

• No external or handheld tester required to provide channel diagnostic information

• Enables automated relay setting management using 3rd party tools through standard file transfer services (MMS and SFTP)

LAN Redundancy

The T35 provides advanced communications technologies for remote data and engineering access, making it easy and flexible to use and integrate into new and existing infrastructures. Direct support for fiber optic Ethernet provides highbandwidth communications allowing for lowlatency controls and high-speed file transfers

• PRP as per IEC 62439-3

Interoperability with Embedded IEC 61850 Edition 2 The new IEC 61850 implementation in the UR Family positions GE as an industry leader in this standard.

Cost Effective Solution

• Communication with up to 16 UR relays in single or redundant rings rather than strictly limited to simplistic point-to-point configurations between two devices

Substation LAN redundancy has been traditionally accomplished by reconfiguring the active network topology in case of failure. Regardless of the type of LAN architecture (tree, mesh, etc), reconfiguring the active LAN requires time to switchover, during which the LAN is unavailable. UR devices deliver redundancy as specified by PRP-IEC 62439-3, which eliminates the dependency on LAN reconfiguration and the associated switchover time. The UR becomes a dual attached node that transmits data packets over both main and redundant networks simultaneously, so in case of failure, one of the data packets will reach the receiving device with no time delay.

Multi-Language

Auto-transformer with breaker-and-a-half on both sides and loaded tertiary.

GEDigitalEnergy.com

UR devices support multiple languages: English, French, Russian, Chinese, Turkish and German. These language options are available on the front panel, in the EnerVista setup software, and in the product manuals. Easily switch between English and an additional language on the local displays without uploading new firmware.

91

Transformer Protection

Enables integration with centrally managed authentication and accounting of all user activities and uses modern industry best practices and standards that meet and exceed NERC CIP requirements for authentication and password management.

of relay fault and event record information. The available three independent Ethernet ports, redundant Ethernet option and the embedded managed Ethernet switch provide the means to create fault tolerant communication architectures in an easy, cost-effective manner without the need for intermediary communication hardware. The T35 supports the most popular industry standard protocols enabling easy, direct integration into DCS and SCADA systems.

Transformer Protection

T35 Transformer Protection System

EnerVista Software

• Manuals

• Graphical Logic Designer

The EnerVista suite is an industry-leading set of software programs that simplifies every aspect of using the T35 relay. The EnerVista suite provides all the tools to monitor the status of the protected asset, maintain the relay, and integrate information measured by the T35 into DCS or SCADA monitoring systems. Convenient COMTRADE and SOE viewers are an integral part of the UR setup software included with every UR relay, to carry out postmortem event analysis and ensure proper protection system operation.

• Application Notes

• Graphical System Designer

• Guideform Specifications

• Graphical Logic Monitor

• Brochures & Presentations

• Graphical System Monitor

• Wiring Diagrams

• IEC 61850 Configurator

• FAQ’s

Viewpoint Maintenance

EnerVista Launchpad EnerVista Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining Multilin products. The setup software within Launchpad allows for the configuration of devices in real-time by communicating using serial, Ethernet , or modem connections, or offline by creating setting files to be sent to devices at a later time. Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed. Documents made available include:

• Service Bulletins

Viewpoint Monitoring Viewpoint Monitoring is a simple-to-use and full-featured monitoring and data recording software package for small systems. Viewpoint Monitoring provides a complete HMI package with the following functionality:

Viewpoint Maintenance provides tools that will create reports on the operating status of the relay, simplify the steps to download fault and event data, and reduce the work required for cyber security compliance audits. Tools available in Viewpoint Maintenance include: • Settings Security Audit Report

• Plug-&-Play Device Monitoring

• Device Health Report

• System Single-Line Monitoring & Control

• Single-Click Fault Data Retrieval

• Annunciator Alarm Screens

EnerVista Integrator

• Trending Reports

EnerVista Integrator is a toolkit that allows seamless integration of Multilin devices into new or existing automation systems. Included in EnerVista Integrator is:

• Automatic Event Retrieval • Automatic Waveform Retrieval

Viewpoint UR Engineer Viewpoint UR Engineer is a set of powerful tools that will allow the configuration and testing of UR relays at a system level in an easy-touse graphical drag-and-drop environment . Viewpoint UR Engineer provides the following configuration and commissioning utilities:

• OPC/DDE Server • Multilin Drivers • Automatic Event Retrieval • Automatic Waveform Retrieval

User Interface The T35 front panel provides extensive local HMI capabilities. The local display is used for monitoring, status messaging, fault diagnosis, and device configuration. User-configurable messages that combine text with live data can be displayed when user-defined conditions are met. 48 Configurable LED Indicators

Multi-Language Display • English • Russian • French • Chinese • Turkish • German

User-Programmable Pushbuttons

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F3b

P

N

M

6D

F4b F4c

F3c IG5

F4a

L

K

J 6

H Inputs/ outputs

9

D CPU

F 8

G

CT/VT

B 1 Power supply

M5a

IA

M5b 6C

IC5

M7a

IC

M7b DB-9

V

V

V

V

V

V

RS-232

H6

H5

H4

H3

H2

H1

M6b

M6c

6H

IB

IB1

(front)

I

IC

6

H1a H1b H1c H2a H2b H2c H3a H3b H3c H4a H4b H4c H5a H5b H5c H6a H6b H6c

M8c I

IRIG-B Input

RS485

ALTERNATE

NORMAL

SURGE FILTER

CONTROL POWER

OUTPUT

CRITICAL FAILURE

SURGE

F7c COM 1

F7a VC

IRIG-B Output

F3a CT

IG

IG1 I

Rx1

10BaseFL

com

BNC

F2c IC5

6 Inputs/ outputs *

M8a

M8b I

H8b

F6c

10BaseFL

B1b B1a B2b B3a B3b B5a MED B5b HI B6b LO B6a B8a B8b

Tx1

F6a VB

10BaseT

Rx2

D1a D2a D3a D4b D4a

Tx2

VB

VA

F5a VA

F5c

F6c VC

VC

F7a

F7c VX

F8a

M1a

IA

M1b

M1c

M2a

M2b

M2c

M3a

IC

M3b

M4a

M4b

M4c

IA1

M5c

IB5

M6a

Transformer Protection

A B C

F5c

H7a H7c H8a H8c H7b

F5a VA

BNC

F2b

R

IB

S

F1c

F2a

T

IA1 IB5

U

U3a U3c U4a U4c U3b

V

F1b

W

F1a IA

X

IA5

VX

M7c IC1

F8c

U1a U1c U2a U2c U1b

6 Inputs/ outputs *

IG5 I

DC

Shielded

Co-axial Co-axial

minimum

PROVIDED

VA

TC 2

A B C

A B C

TC 1

TXD RXD

SGND

UR

1 2 3 4 5 6 7 8 9

CONNECTOR

CONNECTOR

8 3 RXD 2 TXD 20 7 SGND 6 4 5 22

COMPUTER

1 2 3 4 5 6 7 8 9

PERSONAL COMPUTER

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IA5

P8

IG

IG1

P7

M3c

IG5

P6

IC1

P5

IC5

P4

IB

IB1

P3

IA1

IB5

P2

IA5

P1

P1a P1b P1c P2a P2b P2c P3a P3b P3c P4a P4b P4c P5a P5b P5c P6a P6b P6c P7a P7b P7c P8a P8b P8c

IG

IG1

SURGE

IB1

U5a U5c U6a U6c U5b

F6a VB

T35

VB

Multilin

VC 1

IC1

U7a U7c U8a U8c U7b U8b

Fibre * Optic

Remote Device

Typical Wiring

I

T35 Transformer Protection System

Ordering

T35 - * ** - H * * - F ** - H ** - M ** - P ** - U ** - W ** For full sized horizontal mount

Base Unit T35 Base Unit CPU E RS485 & RS485 (IEC 61850 option not available) J RS485 + multimode ST 100BaseFX K RS485 + multimode ST Redundant 100BaseFX N RS485 + 10/100 100BaseT T RS485 + three multimode SFP LC 100BaseFX. Req FW v7xx or higher U RS485 + two multimode SFP LC 100BaseFX + one SFP RJ45 100BaseT. Req FW v7xx or higher V RS485 + three SFP RJ45 100BaseT. Req FW v7xx or higher Software Options 00 No Software Options (See note 1 below) 01 Ethernet Global Data (EGD) 03 IEC 61850 04 Ethernet Global Data (EGD) + IEC 61850 A0 CyberSentry UR Lvl 1. Req UR FW 7.xx or higher B0 IEEE 1588. Req UR FW 7.xx or higher C0 PRP D0 IEEE 1588 + CyberSentry. Req UR FW 7.xx or higher Mount H Horizontal (19" rack) - Standard A Horizontal (19” rack) - Harsh Chemical Environment Option V Vertical (3/4 size) - Standard B Vertical (3/4 size) - Harsh Chemical Environment Option User Interface F Vertical Front Panel with English Display I Enhanced German Front Panel J Enhanced German Front Panel with User-Programmable Pushbuttons K Enhanced English Front Panel L Enhanced English Front Panel with User-Programmable Pushbuttons M Enhanced French Front Panel N Enhanced French Front Panel with User-Programmable Pushbuttons Q Enhanced Russian Front Panel T Enhanced Russian Front Panel with User-Programmable Pushbuttons U Enhanced Chinese Front Panel V Enhanced Chinese Front Panel with User-Programmable Pushbuttons W Enhanced Turkish Front Panel Y Enhanced Turkish Front Panel with User-Programmable Pushbuttons Power Supply H 125 / 250 V AC/DC (see note 2 below) H RH 125/250 V AC/DC with redundant 125/250 V AC/DC power supply L 24 - 48 V (DC only) CT/VT DSP 8L 8L 8L Standard 4CT/4VT w/ enhanced diagnostics 8M 8M 8M Sensitive Ground 4CT/4VT w/ enhanced diagnostics 8N 8N 8N Standard 8CT w/ enhanced diagnostics 8R 8R 8R Sensitive Ground 2CT/6VT w/ enhanced diagnostics IEC 61850 Process Bus 81 8 Port IEC 61850 Process Bus Module Digital I/O XX XX XX XX XX No module 4A 4A 4A 4A 4A 4 Solid State (No Monitoring) MOSFET Outputs 4C 4C 4C 4C 4C 4 Solid State (Current w/opt Voltage) MOSFET Outputs 4L 4L 4L 4L 4L 14 Form-A (No Monitoring) Latchable Outputs 67 67 67 67 67 8 Form-A (No Monitoring) Outputs 6C 6C 6C 6C 6C 8 Form-C Outputs 6D 6D 6D 6D 6D 16 Digital Inputs 6E 6E 6E 6E 6E 4 Form-C Outputs, 8 Digital Inputs 6F 6F 6F 6F 6F 8 Fast Form-C Outputs 6K 6K 6K 6K 6K 4 Form-C & 4 Fast Form-C Outputs 6L 6L 6L 6L 6L 2 Form-A (Current w/ opt Voltage) & 2 Form-C Outputs, 8 Digital Inputs 6M 6M 6M 6M 6M 2 Form-A (Current w/ opt Voltage) & 4 Form-C Outputs, 4 Digital Inputs 6N 6N 6N 6N 6N 4 Form-A (Current w/ opt Voltage) Outputs, 8 Digital Inputs 6P 6P 6P 6P 6P 6 Form-A (Current w/ opt Voltage) Outputs, 4 Digital Inputs 6R 6R 6R 6R 6R 2 Form-A (No Monitoring) & 2 Form-C Outputs, 8 Digital Inputs 6S 6S 6S 6S 6S 2 Form-A (No Monitoring) & 4 Form-C Outputs, 4 Digital Inputs 6T 6T 6T 6T 6T 4 Form-A (No Monitoring) Outputs, 8 Digital Inputs 6U 6U 6U 6U 6U 6 Form-A (No Monitoring) Outputs, 4 Digital Inputs 6V 6V 6V 6V 6V 2 Form-A (Cur w/ opt Volt) 1 Form-C Output, 2 Latching Outputs, 8 Digital Inputs Transducer I/O 5A 5A 5A 5A 5A 4 dcmA inputs, 4 dcmA outputs 5C 5C 5C 5C 5C 8 RTD Inputs 5E 5E 5E 5E 5E 4 dcmA Inputs, 4 RTD Inputs 5F 5F 5F 5F 5F 8 dcmA Inputs Inter-Relay Communications 7A 820 nm, multimode, LED, 1 Channel 7B 1300 nm, multimode, LED, 1 Channel 7C 1300 nm, singlemode, ELED, 1 Channel 7H 820 nm, multimode, LED, 2 Channels 7I 1300 nm, multimode, LED, 2 Channels 7J 1300 nm, singlemode, ELED, 2 Channels 7S G.703, 2 Channels 7W RS422, 2 Channels 77 IEEE C37.94, 820 nm, multimode, LED, 2 Channel

Notes: 1 . To view all the options available for T35, please visit GE’s On-Line Store http://store.gedigitalenergy.com/viewprod.asp?model=T35 2. Redundant power supply only available in horizontal unit. If redundant is chosen, must be same type. Maximum 2 per chassis.

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

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10 YEAR WORLDWIDE

Multilin 845 ™

Comprehensive Transformer Protection and Management for Small, Medium and Large Power Transformers The Multilin 845 relay is a member of the Multilin 8 Series protective relay platform and has been designed for the protection, control and management of small, medium and large power transformers used for Industrial or Utilities applications. The Multilin 845 provides advanced functionality for various types of applications such as high-speed protection, extensively customizable programmable logic, advanced transformer monitoring and diagnostics, and flexible configuration capabilities. Advanced communications of the 8 Series platform allows easy integration into process and electrical control systems for smoother asset monitoring and control.

Key Benefits

WARRANTY

Innovative Technology & Design • Advanced transformer protection, control and diagnostics capability • Patented environmental monitoring and diagnostics • Advanced, flexible and embedded communications: IEC® 61850 Ed2, IEC 62439/PRP, Modbus® RTU & TCP/IP, DNP3.0, IEC 60870-5-104 • Single setup and configuration across the platform • Elimination of electrolytic capacitors

• Comprehensive transformer protection for small, medium and large power transformers

• Field swappable power supply

• Advanced transformer diagnostics and disturbance recording extending asset life

• Enhanced relay draw-out construction

• High-end cyber security such as AAA, Radius, RBAC, and Syslog helps enable NERC® CIP requirements • Wi-Fi connectivity minimizes system configuration and facilitates safe relay programming and diagnostic retrieval

Exceptional Quality & Reliability

• Monitored environmental conditions helps reduce system downtime

• IPC A-610-E Class 3 manufacturing standards

• High flexibility for customized protection and control logic

• Highest reliability standards for electronics testing

Applications

• 100% Environmental Stress Screening and full functional testing

• Draw-out design simplifies testing, commissioning and maintenance, thereby increasing process uptime

• Primary and back-up protection and management of small, medium and larger power transformers, autotransformers and reactors • Transformer asset monitoring using hottest spots, loss of life & aging factors • Integrated transformer protection, diagnostics and transformer health visualization

• Rated for IP54 (front) applications • Standard Harsh Environment Conformal Coating

Uncompromising Service & Support • Covered under GE’s 10 year warranty plan • Designed, tested and manufactured by GE

845 Transformer Protection System

Transformer Protection

Multilin 8 Series Platform Overview From oil pumping and refining facilities, to open pit or underground mining and processing operations, to large or small utilities, customers demand solutions that ensure maximum process uptime, minimum operational and maintenance efforts, and have the durability to withstand harsh environmental conditions. The Multilin 8 Series is GE’s next-generation protection and control relay platform provides comprehensive protection and asset monitoring for critical feeders, motors, generators, and transformers.

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The 8 Series is designed to solve the challenges that customers face in running their day-to-day operations including maximizing system and process uptime, simplifying system integration and maintenance, and extending the life of critical assets. Utilizing advanced design practices, superior technology (elimination of all electrolytic capacitors), and state-ofthe art test and manufacturing facilities, GE is raising the bar on system performance and reliability. With advanced communications the 8 Series integrates easily and seamlessly into new or existing DCS/SCADA system, along with other Multilin protection devices, providing a comprehensive solution for the end-to-end electrical system within the operations.

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845 Transformer Protection System

Pioneering Technology & Design

Industry-leading quality, reliability and design processes are at the core of GE’s next generation protective relay platform. With significant investments in state-of-the-art type test facilities that simulate a complete range of operating environments and manufactured to the IPC A-610 Class 3 standard, adhering to the highest reliability standards and ensuring rugged performance, each device completes Environmental Stress Screening prior to shipping from GE’s facility.

The Multilin 845 is part of the 8 Series platform that provides comprehensive, high performance protection and control for critical assets in Industrial and utility environment.

The Multilin 8 Series Protection Relays are manufactured in an ISO® 9001:2008 certified manufacturing facility.

The Multilin 845 Transformer Protection System offers a powerful solution for protecting & monitoring small, medium or large power transformers. Utilizing decades of experience in transformer protection, GE has implemented ease-of-use features, such as single screen setup and condition-based health reports delivering faster configuration and enabling quicker identification of potential transformer issues.

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Transformer Protection

Exceptional Quality & Reliability

845 Transformer Protection System

Multilin 845 Overview

The Mutilin 8 Series products have an integrated protection integrity engine that utilizes customized algorithms, providing advanced diagnostics to ensure asset protection is not compromised.

Transformers are an essential component in the distribution of power. Process & consumers depend on the transformers performance to meet uninterrupted power supply.

Transformer Protection

Maintaining and safeguarding the electrical supply of an operation is critical to ensuring maximum process availability and performance.

Transformers are constantly under thermal & electrodynamic stress. The goal of the protective relay is to minimize the trip time in event of a fault within the transformer.

The 8 Series incorporates the latest cyber security features, including password complexity, RADIUS authentication and role-based access control (RBAC), enabling customers to comply with NERC CIP and NISTIR 7628 requirements.

The Multilin 845 Transformer Protection System is a protection device designed for the management, protection and control of small, medium or large Distribution & Power Transformers. The 845 provides comprehensive protection, control & monitoring of various types of transformers.

Understanding that customers need protection and control devices that must reliably operate in harsh and challenging environments, GE delivers the Multilin 8 Series with harsh conformal coating on all printed circuit boards and a patented environmental awareness module that provides real-time detection of environmental factors that affect product life, as part of its standard offering, delivering higher reliability and extended relay life.

The 845 relay offers the ideal solution for protecting, monitoring and controlling transformers during disturbances or faults. With a fast protection pass, running every 1/8th of a cycle, the 845 relay provides fast operating current, voltage, power and frequency protection elements. Supporting the latest in industry standard communication protocols, including IEC 62439/ PRP and IEC 61850 Ed2, the Multilin 845 relay easily integrates into new or existing networks.

Uncompromised Reliability & Service Designed, manufactured and tested to industry standards at our state-ofthe-art facilities, the Multilin 8 Series delivers maximum performance for today’s most demanding environments.

The 845 is an advanced transformer protection relay that provides high performance protection, extensive programmable logic and flexible configuration capabilities. With protection and control logic, the 845 allows for simplified coordination with upstream and downstream disconnect devices. The 845 also offers enhanced features, such as diagnostics, preventative maintenance, condition monitoring, security, and advanced communications options. The 845’s asset monitoring features fore warns operators on signs of degradations in the transformers, thus mitigating the risks of expensive outages due to failures.

In addition to the superior technology and innovative design advancements that enable delivery of uncompromised performance and reliability, the Multilin 8 Series is also backed by GE’s 10 year warranty plan.

1

2

4

3

1

Field Swappable Power Supply Extends the usable life of the protection relay and minimizes costly, time consuming replacement and re-configuration.

2

Harsh Environment Conformal Coating

3

No Electrolytic Capacitors

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Standard on all printed circuit boards delivering higher reliability and extended relay life

Increasing quality and reliability for continuous plant operations

5

4

IPC A-610 Class 3 Manufacturing

5

Robust Extruded Aluminum Chassis

6

Draw-Out

GEDigitalEnergy.com

6

Drives to the highest level of reliability standards delivering rugged performance

Custom-designed extruded aluminum chassis delivering optimal thermal management to extend component life

Providing simplified device fleet management

845 Transformer Protection System

Protection & Control Percent Differential Protection

Transformer Protection

The 845 provides enhanced security by including both restrained and unrestrained (instantaneous) differential protection. The percent differential element is based on a configurable dual-breakpoint/dual-slope differential restraint characteristic with inrush and overexcitation inhibits based on 2nd & 5th harmonics. The restraint current is calculated as a maximum of the internally compensated currents for better through-fault stability under CT saturation conditions. The percent characteristic allows the element to account for both DC and AC saturation of the current transformers. The “cubic spline” curve characteristics enables the relay to perform accurately for restraint current in range between the two slope breakpoints.

Harmonic Inrush /Overexcitation Inhibit The 845 offers great performance in dealing with magnetizing current inrush during transformer energization, by providing four programmable restraint methods(Per Phase, Average, 2-out-of-3, 1-out-of-3), each of which can be enabled or disabled by the user.

Differential vs. Restraint Characteristic (ld vs.lr) Differential Current (Id)

Slope 2

Break Point 2

Restricted Ground Fault Conventional overcurrent protection fails to provide adequate protection for star connected windings whose neutral is impedance earthed. Faults close to the neutral do not generate adequate fault current. RGF (also known as zero sequence differential) provides sensitive ground fault detection for lowmagnitude fault currents.

Transition Region

Slope 1

Break 1

Overcurrent Elements

Restraint Current (Ir)

The settings for the dual-slope, dual-breakpoint characteristic provides higher flexibility for shaping up the characteristic and achieving better sensitivity and security. An increase in transformer voltage or decrease in system frequency may result in overexcitation of the transformer. It is often desirable to prevent operation of the percent differential element in these cases therefore a fifth harmonic inhibit is integrated into the percent differential element to cater for overexcitation conditions resulting from an increased V/Hz ratio. An independent fifth harmonic inhibit allows restraint for systems permitting intentional overexcitation (overfluxing) during energization

Unrestrained Differential An unrestrained differential element current magnitude is provided for fast tripping on heavy internal faults to limit catastrophic damage to the transformer and minimize risks to the remainder of the power system.

The 845 can be used to provide backup protection for transformer and adjacent power system equipment. Instantaneous overcurrent (IOC) elements can be used for fast clearing of severe internal and external (through) faults. Up to six time overcurrent protection (TOC) elements per winding allow to coordinate with the adjacent protection zones and act as backup protection. • IOC protection functions are provided for phase, neutral & ground currents • TOC protection functions are provided for phase, neutral and ground currents. A variety of standard time curves including IEEE, IEC, GE IAC, I2t, definite time are provided • FlexCurves to coordinate with adjacent protections (including fuses) as well as transformer damage curves and thermal/damage curves for downstream equipment Directional protection functions are provided for phase, neutral and ground currents. The voltage memory function enables a more reliable relay operation, especially for faults close to the VTs.

Negative Sequence Overcurrent For Delta/Wye impedance grounded transformers, overcurrent protection is particularly difficult to set. A negative sequence based overcurrent element provides the required sensitivity phase during faults.

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845 Transformer Protection System

Functional Block Diagram

Directional Power The multilin 845 Directional Power element responds to three-phase directional power and is designed for reverse power (32REV) and low forward power (32FWD) applications for interconnections involving co-generation.

Winding 3 Winding 1 3

Transformer Protection

3VTs

Breaker Failure Protection

3 T.C.

50P-1

The breaker failure protection element monitors for timely operation of the connected breaker. If a trip command is not successful in operating the breaker and clearing the fault, the breaker failure element can be used to send trip signals to upstream breakers to clear the fault.

51P-1

50G-1

50G-2

50P-2

50P-3

51G-1

51G-2

51P-2

51P-3

Tap Position

49

OLTC Failure

RTD Protection The Multilin 845 supports up to 13 programmable RTD inputs that can be configured for an Alarm or Trip.

3

Winding 2

3V_0

The RTDs can be assigned to a group for monitoring winding and ambient temperatures. The RTD voting option gives additional reliability to ignore any RTD failures.

50_2

67G-1

67G-2

50BF-2

50BF-3

51_2

51N-1

51N-2

Amps

Amps

50BF-1

50N-1

50N-2

67P

87G-1

87G-2

Harmonics

Harmonics

Amps

Amps

67N

Amps Harmonics Calculate 3I_0

Calculate 3I_0

Undervoltage and Overvoltage Protection The 845 provides phase Over & Under voltage functions and in addition also includes neutral Overvoltage, negative sequence overvoltage.

Synchronism Check

Calculate Restraint Amps

Calculate Operate Amps

Amps

Amps

Eight user-definable protection functions (FlexElements) can be programmed torespond to any quantity measured or computed by the relay (phase, ground and sequence current and voltage power, frequency, power factor, etc.) These elements respond to variations in its input signal. Applications could include: overvoltage, overpower, low power factor, temperature differential, and more.

Tap Position, Ambient Temperature, Analog Inputs, Analog Outputs The 845 monitors and displays tap position and ambient temperature. The 845 supports Tap position based on BCD, mA or resistance input. The 845 provides for 7 Analog Outputs (dc mA), 4 Analog Inputs (dc mA), 1 RTD input & resistance input for tap changer. An optional general purpose transducer input allows a user-defined quantity to be monitored and used as part of the protection as defined by FlexLogic™.

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Block

87T Metering Transient Recorder Event Recorder Fault Report Data Logger

Over/Under Frequency Protection

User-Definable Protection Functions

Harmonic restraint

50/87

The 845 provides synchrocheck elements that monitor voltage difference, phase angle difference and slip frequency to ensure proper breaker closure for parallel operation.

The 845 calculates and maintains a running average of the system frequency and the frequency rate-of-change (df/dt). Two underfrequency and four rate-of-change elements are provided to implement traditional and advanced load shedding schemes. Additionally, an overfrequency element can be used to trigger a generator rampdown.

Calculate 2nd and 5th harmonics

RTD input 59N

845

59P

24

DcmA I/O 27P

81U

81O

81R

27X

59X

Тransformer Protection System

894014C1.CDR

845 Transformer Protection System

Additional Features

Advanced Asset Monitoring

The 845 offers additional features designed for ease of use:

The 845 has advanced functions that raise an alarm or trip the scheme when an internal condition in the power transformer or breaker could lead to a fault. These functions are conditions of:

Auto CT Configuration

Advanced Automation The Multilin 845 incorporates advanced automation capabilities that exceeds what is found in most transformer protection relays. This reduces the need for additional programmable controllers or discrete control relays including programmable logic, communication, and SCADA devices. Advanced automation also facilitates the Multilin 845 to integrate seamlessly with other protection/process systems.

FlexLogic™ FlexLogic is the powerful programming logic engine that provides the ability to create customized protection and control schemes, minimizing the need and associated costs of auxiliary components and wiring. Using FlexLogic, the 845 can be programmed to provide the required tripping logic along with custom scheme logic for transformer breaker control (including external inputs for interlocking), interlocking schemes with adjacent protections (for example, preventing sympathetic tripping of healthy feeders), and dynamic setting group changes.

Hottest-spot temperature: element provides a mechanism for detecting abnormal winding hottest-spot temperatures inside the transformer. Aging factor: the aging factor element detects transformer aging in per-unit normal insulation aging Loss of Life: This feature provides an estimate of how much of the transformer’s total insulation life has elapsed. Harmonic Derating: This derating factor is used to evaluate the load capability of the installed transformer under the non-sinusoidal load currents Tap Changer Failure: This element picks up when the actual tap changer position exceeds the maximum number of taps or the actual tap changer position lowers below the minimum number of taps. Breaker arcing current: This element calculates an estimate of the perphase deterioration on the breaker contacts by measuring and integrating the current (squared) passing through the breaker contacts as an arc

Breaker Health Monitoring The breaker is monitored by the relay not only for detection of breaker failure, but also for the overall “breaker health” which includes: • Breaker close and breaker open times • Trip circuit monitoring • Spring charging time • Per-phase arcing current • Trip counters All algorithms provide the user with the flexibility to set up initial breaker trip counter conditions and define the criteria for breaker wear throughout a number of setpoints.

FlexLogic allows the Multilin 845 to operate and control breakers and other auxiliary devices needed to fit most transformer protection schemes and applications

Monitoring & Diagnostics The Multilin 845 includes high accuracy metering and recording for all AC signals. Voltage, current, and power metering are built into the relay as a standard feature. Current and voltage parameters are available as total RMS magnitude, and as fundamental frequency magnitude and angle.

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Transformer Protection

All CTs are connected in a wye configuration for simplicity. All phase and magnitude corrections as well as zero-sequence current compensation are performed automatically based on a choice of over 100 transformer types.

Transformer Protection

845 Transformer Protection System

Multilin 8 Series Breaker Health Report available on the display or via the setup software

Environmental Monitoring The 869 implements a patented environmental monitoring system that measures and provides operating condition information. Reliable and secure operation of the 869 relay and other electronic devices in the vicinity may be affected by environmental factors. The 869 relay has been designed to meet or exceed required industry standards. Some operating conditions may be beyond those standards and reduce total lifespan of the device. Typical environmental conditions that may affect electronic device reliability include voltage, current , temperature, humidity, dust , contaminants, mechanical stress, shock, radiation and intensity of electrical and magnetic fields. These environmental factors are different from natural weather conditions at particular installation conditions and are beneficial to monitor. The 869 relay’s built-in environmental awareness feature (patent “Systems and methods for predicting maintenance of intelligent electronic devices”) collects the histograms of operating conditions from the point the device is put into service. Monitored environmental conditions include temperature, humidity and transient voltage. The histogram of each environmental factor may be retrieved from the diagnostic page accessed through a PC running the EnerVista Multilin 8 Series Setup program.

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Environmental health report is available via Multilin PC Software

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845 Transformer Protection System

Metering The Multilin 845 offers high accuracy power quality monitoring for fault and system disturbance analysis. The Multilin 8 Series delivers unmatched power system analytics through the following advanced features and monitoring and recording tools:

• The length of the transient recorder record ranges from 31 cycles to 1549 cycles, depending on the user specified configuration. This gives the user the ability to capture long disturbance records which is critical for some applications.

• Comprehensive data logger provides the recording of 16 analog values selected from any analog values calculated by the relay. Capture rates range from 16 ms, 20ms, 1 second, 30 seconds, 1 minute, 30 minutes, or 1 hour rate. This data capture flexibility allows the operator to measure power factor or reactive power flow (for example), for several hours or even days, enabling detailed analysis and corrective action to be taken, if required. • Detailed Fault Report allows the user to identify the fault location, fault type and element(s) that triggered the 845 to trip. It carries other useful information, such as pre-fault and fault phasors, relay name and model, firmware revision and other details. The 845 stores fault reports for the last 16 events. • 1024 Event Recorder chronologically lists all triggered elements with an accurate time stamp over a long period of time. The 845 stores the last 1024 events locally in the relay.

Multilin 845 Phasor viewer

Multilin 845 Event Recorder

The 845 monitoring system performance with oscillography and event records

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Transformer Protection

• Harmonics measurement up to 25th harmonic for both currents and voltages including THD.

• 32 digital points and 16 analog values, assigned by the user, can be captured in the COMTRADE format by the transient recorder.

Transformer Protection

845 Transformer Protection System

Communications

AAA Server Support (Radius/LDAP)

The 845 provides advanced communications technologies for remote data and engineering access, making it easy and flexible to use and integrate into new and existing infrastructures. Direct support for fiber optic Ethernet provides high-bandwidth communications, allowing for low-latency controls and high-speed file transfers of relay fault and event record information. The 845 also supports two independent IP addresses, providing high flexibility for the most challenging of communication networks.

Enables integration with centrally managed authentication and accounting of all user activities and uses modern industry best practices and standards that meet and exceed NERC CIP requirements for authentication and password management.

Providing several Ethernet and serial port options and supporting a wide range of industry standard protocols, the 845 enables easy, direct integration into DCS and SCADA systems. The 845 supports the following protocols:

Role Based Access Control (RBAC) Efficiently administrate users and roles within UR devices. The new and advanced access functions allow users to configure up to five roles for up to eight configurable users with independent passwords. The standard “Remote Authentication Dial In User Service” (Radius) is used for authentication.

• IEC 61850 Ed2, IEC 62439 / PRP

Event Recorder (Syslog for SEM)

• DNP 3.0 serial, DNP 3.0 TCP/IP, IEC 60870-5-103, IEC 60870-5-104

Capture all cyber security related events within a SOE element (login, logout, invalid password attempts, remote/local access, user in session, settings change, FW update, etc), and then serve and classify data by security level using standard Syslog data format. This will enable integration with established SEM (Security Event Management) systems.

• Modbus RTU, Modbus TCP/IP The 845 has USB front port and Wi-Fi interfaces for ease of access to the relay. Wi-Fi Connectivity:

RBAC (Role Based Access Control), which provides efficient administration of users and roles within devices, efficiently administrates users and roles. In addition, Event Recorder (Syslog for SEM) captures all cyber security related events within a SOE element (login, logout, invalid password attempts, remote/local access, user in session, settings change, FW update, etc.), and then serves and classifies data by security level using standard Syslog data format. This will enable integration with established SEM (Security Event Management) systems.

• Simplify set-up and configuration • Simplify diagnostic retrieval • Eliminate personnel in front of switchgear • WPA-2 security

Local HMI / Single Line

SCADA

EMS

Data Historian

DMS

Security Server

Access Request: Role, User, Password

D400

Authentication Request: Role, User, Password Encrypted (SSH)

D400

0 00C H ML3 SWIT

000 ML3 ITCH SW

LOCAL AREA NETWORK

LOCAL AREA NETWORK

A

B

000 ML3 ITCH SW

000 ML3 ITCH SW

000 ML3 ITCH SW

000 ML3 ITCH SW

Authentication Request: Role, User, Password Encrypted (SSH)

Cyber Security with Radius Authentication F650

350

469

850

869

889

845

UR

Cyber Security The 845 cyber security enables the device to deliver full cyber security features that help operators to comply with NERC CIP guidelines and regulations.

104

Software & Configuration The EnerVista™ suite is an industry-leading set of software programs that simplifies every aspect of using the Multilin 845. EnerVista provides all the tools to monitor the status of the protected asset, maintain the device and integrate the information measured by the Multilin 8 Series into SCADA or DCS process control systems. The ability to easily view sequence of events is an integral part of the setup software, as postmortem event analysis is critical to proper system management.

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845 Transformer Protection System

Single Click Device Communications Transformer Protection

Quick Link Diagnostic Information

Online Device Configuration and Monitoring Menu Driven Device Configuration

Offline Device Setting File Configuration

EnerVista Launchpad

Simplified Setup & On-Going Maintenance

EnerVista Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining Multilin products.

The robust 845 streamlines user workflow processes and simplifies engineering tasks, such as configuration, wiring, testing, commissioning, and maintenance. Building on the history of simplified setup and configuration, the 845 relay has implemented simplified setup screens to assist in minimizing relay setup time. In addition, for local programming, the 845 comes with a fully functional Graphical Control Panel (GCP), which allows

The setup tools within Launchpad allow for the configuration of devices in real-time, by communicating via serial, Ethernet or modem connections, or offline by creating device setting files to be sent to devices at a later time. Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed.

8 Series Setup Software 8 Series Setup Software is a single setup and configuration tool across the platform and can reduce device setup and configuration time.

1

Easy to Use - Draw-out case

2

users to locally monitor the asset.

Ease-of-Use Continuing its legacy in providing easy-to-use protective relay solutions, the 845 is designed to minimize product and system configurability requirements for quicker physical installation and for easier and simplified setup and configuration.

Easy to Configure - 1 simple step

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3

Detailed Diagnostics

105

Transformer Protection

845 Transformer Protection System

Full Color Graphical HMI Front Display

G = Green: General Condition

A large, full color Graphic Control Panel (GCP) ensures clear representation of critical status and measurements. When the keypad and display are not being used, the GCP will automatically revert to screen saver mode, which will turn off the display until one of the local pushbuttons is pushed.

A = Amber: Alert Condition

The GCP can be used to view device and system status, alarms and event logs, and metering information. The GCP and navigation keys simplify relay configuration and setup, allowing users to make setting changes directly through the front panel.

LED Indicators for Quick Status Indication The front panel includes user configurable LED’s. Each LED can be completely configured and named based on the application and user requirements. The color of each indicator conveys its importance.

R = Red: Serious Alarm or Important Status The 845 front panel provides 14 LED indicators and 3 LED pushbutton indicators. 10 LED’s are user- programmable, while “In service” and “Pickup” LED’s are non-programmable. “Trip” and “Alarm” LED’s are not color programmable but can be assigned with selected operands. User-programmable LED’s can be turned on by a selection of FlexLogic operands representing protection, control or monitoring elements. Each LED can be configured to be self-reset or latched and labeled based on the application and user requirements. User-programmable LED’s can be selected to be either Red, Green or Amber to give the distinctive indication of selected operations.

Front View Menu path display indicating location within menu structure Graphic Control Panel (GCP) Soft key navigation menu

Soft menu navigation keys LED status indicators

Navigation keys

User-programmable pushbuttons

Front USB port Self-captive screw on draw-out handle

Rear View

Grounding screw

Standard serial and RJ45 Ethernet module

Power supply Analog I/O

Advanced communications module (fiber optic port)

Digital I/O CT, VT inputs

106

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845 Transformer Protection System

Dimensions & Mounting

7.15”

Transformer Protection

9.90”

8.84”

5”

8.42”

5”

7.5

1.5

Typical Wiring

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107

845 Transformer Protection System

Technical Specifications POWER SUPPLY

Continuous current draw

Transformer Protection

Power Supply Nominal DC Voltage

125 to 250 V

Minimum DC Voltage

88 V

Maximum DC Voltage

300 V

Nominal AC Voltage

100 to 240 V at 50/60 Hz

Minimum AC Voltage

88 V at 50/60 Hz

Maximum AC Voltage

265 V at 50 to 60 Hz

ANALOG INPUTS AC Currents

2 mA

2

Minimum pickup

0.05 to 1.00 pu in steps of 0.001

Slope 1 range

15 to 100% in steps of 1%

Slope 2 range

50 to 100% in steps of 1%

Kneepoint 1

1.0 to 2.0 pu in steps of 0.0001

Kneepoint 2

2.0 to 30.0 pu in steps of 0.0001

2nd harmonic inhibit level

1.0 to 40.0% in steps of 0.1

Curve Timing Accuracy Currents > 1.1 x pickup: ± 3% of operate time or ± ½ cycle (whichever is greater) from pickup to operate Voltage Restrained Phase Time Overcurrent (51V)

Nominal Frequency

50 and 60 Hz

2nd harmonic inhibit function

Adaptive, Traditional, Disabled

VT Range

10 to 260 V

Per-phase, 2-out-of-3, Average

Nominal Frequency

20 to 65 Hz

2nd harmonic inhibit mode

Burden

<0.25 VA at 120 V

1.0 to 40.0% in steps of 0.1

Conversion Range.

1 to 275 V

5th harmonic inhibit range

Voltage Withstand

Continuous at 260 V to neutral; 1 min/hr at 420 V to neutral

Operate times: Harmonic inhibits selected

20 to 30 ms at 60 Hz; 20 to 35 ms at 50 Hz 5 to 20 ms

Types (3-wire)

100 Ω Platinum

No harmonic inhibits selected

Sensing current

5 mA

Dropout level

97 to 98% of pickup

Range

–40 to +250°C

Level accuracy

Accuracy

±2°C

±0.5% of reading or ±1% of rated (whichever is greater)

Instantaneous Differential Pickup level

2.00 to 30.00 pu in steps of 0.01

Dropout level

97 to 98% of pickup

Level accuracy

±0.5% of reading or ±1% of rated (whichever is greater) <20 ms at 3´ pickup at 60 Hz

Configuration

2 (two) electromechanical

Operate time

<8 ms

Operate time

Continuous current

10 A

Restricted Ground Fault

Make and carry for 0.2s 30 A per ANSI C37.90

Pickup

0.005 to 30.000 pu in steps of 0.001

Form-A Voltage Monitor

Dropout

97 to 98% of pickup

Applicable voltage

20 to 250 VDC

Slope

0 to 100% in steps of 1%

Trickle current

1 to 2.5 mA

Pickup delay

0 to 600.00 s in steps of 0.01

Form-C Relays

Dropout delay

0 to 600.00 s in steps of 0.01

Configuration

Electromechanical

Operate time

<1 power system cycle

Operate time

<8 ms

Volts Per Herts

Continuous current

10 A

Voltage

Phasor only

Make and carry for 0.2s 30 A per ANSI C37.90

Pickup level

0.80 to 4.00 in steps of 0.01 pu V/Hz

ANALOG INPUTS

Dropout level

97 to 98% of pickup

General purpose input

Level accuracy

±0.02 pu

Timing curves

Definite Time; Inverse A, B, and C, FlexCurves™ A, B, C, and D

TD Multiplier

0.05 to 600.00 s in steps of 0.01

Reset delay

0.0 to 1000.0 s in steps of 0.1

Timer accuracy

±3% of operate time or ±15 cycles (whichever is greater) for values greater than 1.1 × pickup

Type

dcmA

Ranges

4–20 mA

Input impedance

375 ± 10%

Conversion range

0–21 mA

Accuracy

±1% of full scale (based on input range)

RTD Input Type: 3-wire

100 Platinum (DIN.43760) 100 and 120 Nickel

Sensing current

5 mA

Range

-50 to +250°C

Accuracy

RTD Protection Pickup

1 to 250°C in steps of 1°C

Pickup Hysteresis

2°C

Timer accuracy

<2 s

±2°C

Elements

Trip and Alarm

Amplitude modulated

1.0 – 10 Vpp

Current

Phasor or RMS

DC shift

TTL

Pickup Level

0.050 to 30.000 x CT in steps of 0.001 x CT

Dropout Level

97 to 98% of Pickup

Level Accuracy

For 0.1 to 2 x CT: ±0.5% of reading or ±0.4% of rated, whichever is greater; For > 2.0 x CT: ±1.5% of reading

IRIG-B Input

CONTACT INPUTS Number of Inputs:

Based on relay ordering

Type

Wet or Dry

Wet Contacts

300 V DC maximum

Selectable thresholds

17, 33, 84, 166 VDC

Tolerance

±10%

Recognition time

1ms (typical)

Debounce time

0.0 to 16.0 ms in steps of 0.5 ms

108

Instantaneous, Timed

Differential Restraint pre-set

Number of zones

1 A or 5 A based on relay ordering

Form-A Relays

0.05 to 600.00 in steps of 0.01

Reset Time

Characteristic

CT Rated Secondary

CONTACT OUTPUTS

Curve Multiplier

Percent Differential

1 to 12000 A

RTD Inputs

IEEE Extremely/Very/Moderately Inverse ANSI Extremely/Very/Normally/ Moderately Inverse IEC Curve A/B/C and Short Inverse IAC Extremely/Very/Inverse/Short Inverse FlexCurve™ A, FlexCurve™ B, FlexCurve™ C, FlexCurve™ DI2t, I4t, Definite Time

PROTECTION

CT Rated Primary:

AC Voltage

Curve Shape

Phase/Neutral/Ground Time Overcurrent (51)

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Voltage Restraint

Modifies Pickup from 0.1 < V < 0.9 VT Nominal in a fixed linear relationship

Phase/Neutral/Ground Instantaneous Overcurrent (50P/N/G) Current (for Phase IOC only)

Phasor or RMS

Current (for Neutral/ Ground IOC only)

Fundamental Phasor Magnitude

Pickup Level

0.050 to 30.000 x CT in steps of 0.001 x CT

Dropout Level

97 to 98% of Pickup

Level Accuracy

For 0.1 to 2 x CT: ±0.5% of reading or ±0.4% of rated, whichever is greater For > 2.0 x CT: ±1.5% of reading

Operate Time

<12 ms typical at 3 × Pickup at 60 Hz (Phase/Ground IOC) <16 ms typical at 3 × Pickup at 60 Hz (Neutral IOC) <15 ms typical at 3 × Pickup at 50 Hz (Phase/Ground IOC) <20 ms typical at 3 × Pickup at 50 Hz (Neutral IOC)

Timer Accuracy

±3% of delay setting or ± ¼ cycle (whichever is greater) from pickup to operate

Negative Sequence Instantaneous Overcurrent (50_2) Current

I_2 Fundamental Phasor Magnitude

Pickup Level

0.050 to 30.000 x CT in steps of 0.001 x CT

Dropout Level

97 to 98% of Pickup

Level Accuracy

For 0.1 to 2.0 x CT: ±0.5% of reading or ±0.4% of rated, whichever is greater For > 2.0 x CT: ±1.5% of reading

Overreach

< 2%

Operate Time

< 12 ms typical at 3 x Pickup at 60 Hz < 15 ms typical at 3 x Pickup at 50 Hz

Timer Accuracy

±3% of delay setting or ± ¼ cycle (whichever is greater) from pickup to operate

Phase Directional Overcurrent (67P) Relay Connection

90º(Quadrature)

Quadrature Voltage

ABC phase seq.: phase A (Vbc), phase B (Vca), phase C (Vab); ACB phase seq.: phase A (Vcb), phase B (Vac), phase C (Vba)

Polarizing Voltage Threshold

0.05 to 3.000 x VT in steps of 0.001 x VT

Current Sensitivity Threshold

0.05 x CT

Characteristic Angle

0º to 359º in steps of 1°

Angle Accuracy

± 2º

Operation Time Reverse to Forward transition : < 12 (FlexLogic™ operands) ms, typically; Forward to Reverse transition: <8 ms, typically Neutral Directional Overcurrent (67N) Directionality

Co-existing forward and reverse

Polarizing

Voltage, Current, Dual

Polarizing Voltage

V_0 or VX

Polarizing Current

Ig

845 Transformer Protection System

Operating Current

I_0

Dropout Time Delay

0.000 to 6000.000 s in steps of 0.001 s

Applicable Voltage

20 to 250 VDC

Level Sensing

3 x (|I_0| – K x |I_1|), Ig

Operate Time

Trickle Current

1 to 2.5 mA

Restraint, K

0.000 to 0.500 in steps of 0.001

< 25 ms at 1.1 x pickup at 60 Hz < 30 ms at 1.1 x pickup at 50 Hz

Timing Accuracy

± 3 % or ± 4 ms, whichever is greater

Characteristic Angle

-90º to 90º in steps of 1°

Close Circuit Monitor (Ccm)

Limit Angle

40º to 90º in steps of 1°, independent for forward and reverse

± 3% of delay setting or ± ¼ cycle (whichever is greater) from pickup to operate

±2º

Pickup Level

0.050 to 30.000 x CT in steps of 0.001 x CT

Dropout Level Operate Time (no direction transition)

Directional Power (32) Measured Power

3-phase

Number of Stages

2

97 to 98% of Pickup

Characteristic Angle

0º to 359º in steps of 1°

< 16 ms at 3 x Pickup at 60 Hz < 20 ms at 3 x Pickup at 50 Hz

Calibration Angle

0.00º to 0.95º in steps of 0.05°

Power Pickup Range

–1.200 to 1.200 in units of (Rated Power) in steps of 0.001

Pickup Level Accuracy

± 1% or ± 0.001 (Rated Power), whichever is greater

Hysteresis

2% or 0.001 (Rated Power), whichever is greater

Phase Undervoltage (27P) Voltage

Fundamental Phasor Magnitude

Minimum Voltage

0.00 to 1.50 x VT in steps of 0.01 x VT

Pickup Level

0.00 to 1.50 x VT in steps of 0.01 x VT

Dropout Level

102 to 103% of Pickup

Pickup Time Delay

0.000 to 6000.000 s in steps of 0.001 s

Phases Required for Operation

Any one, Any two, All three

Operate Time

Undervoltage Curves

Definite Time or Inverse Time

< 55 ms at 1.1 x pickup at 60 Hz < 65 ms at 1.1 x pickup at 50 Hz

Pickup Time Delay

0.000 to 6000.000 s in steps of 0.001s

Timer Accuracy

Operate Time

< 20 ms at 0.90 x pickup at 60 Hz < 25 ms at 0.90 x pickup at 50 Hz

± 3% of delay setting or ± ¼ cycle (whichever is greater)from pickup to operate

Curve Timing Accuracy at < 0.90 x pickup ± 3.5% of curve delay or ± ½ cycle(whichever is greater) from pickup to operate Phase Overvoltage (59P)

Underfrequency (81U)

Applicable Voltage

20 to 250 VDC

Trickle Current

1 to 2.5 mA

Timing Accuracy

± 3 % or ± 4 ms, whichever is greater

RECORDING Learned Data Recorder Number of records

250

Content

Learned/last acceleration time; Learned/last starting current; Learned/last start TCU; Learned average load, Learned average real power, Learned average reactive power, Learned average power factor, Average run time (days/hours/ minutes); RTD maximum temperature

TRANSFORMER HOTTEST-SPOT TEMPERATURE Operating quantity

computed temperature in °C

Pickup level

50 to 300°C in steps of 1

Dropout level

1°C below pickup

Pickup delay

0 to 30000 min. in steps of 1

Pickup Level

20.00 to 65.00 Hz in steps of 0.01

Dropout Level

Pickup + 0.03 Hz

Pickup Time Delay

0.000 to 6000.000 s in steps of 0.001s

TRANSFORMER AGING FACTOR

Dropout Time Delay

0.000 to 6000.000 s in steps of 0.001s

Operating quantity

Minimum Operating Voltage

0.000 to 1.250 x VT in steps of 0.001 x VT

computed aging acceleration factor (pu)

Pickup level

1 to 10 pu in steps of 0.1

0.000 to 30.000 x CT in steps of 0.001 x CT

Pickup delay

0 to 30000 min. in steps of 1

Votage

Fundamental Phasor Magnitude

Pickup Level

0.02 to 3.00 x VT in steps of 0.01 x VT

Dropout Level

97 to 98% of Pickup

Minimum Operating Current

Level Accuracy

±0.5% of reading from 15 to 208 V

Level Accuracy

± 0.001 Hz

Phases Required for Operation

Any one, Any two, All three

Timer Accuracy

Pickup Time Delay

0.000 to 6000.000 s in steps of 0.001s (Definite Time)

± 3% of delay setting or ± ¼ cycle (whichever is greater)from pickup to operate

Dropout Time Delay

0.000 to 6000.000 s in steps of 0.001s (Definite Time)

Operate Time

< 25 ms at 1.1 x pickup at 60Hz < 30 ms at 1.1 x pickup at 50Hz

Overfrequency (81O) Pickup Level

20.00 to 65.00 Hz in steps of 0.01

Event Recorder

± 3% of delay setting or ± ¼ cycle (whichever is greater)from pickup to operate

Dropout Level

Pickup - 0.03 Hz

Number of events

1024

Pickup Time Delay

0.000 to 6000.000 s in steps of 0.001 s

Time-tag Accuracy

to one microsecond

Dropout Time Delay

0.000 to 6000.000 s in steps of 0.001 s

Digital counters

Timer Accuracy

Auxiliary Overvoltage (59X)

Operate Time

Typically 7.5 cycles at 0.1 Hz/s change Typically 7 cycles at 0.3 Hz/s change Typically 6.5 cycles at 0.5 Hz/s change

TRANSFORMER LOSS OF LIFE Operating quantity

computed accumulated transformer loss of life, in hours

Pickup level

0 to 500000 hours in steps of 1

Transient Recorder Default AC Channels

5 currents + 4 voltages

Configurable Channels 16 analog and 32 digital channels Sampling rate

128 /c, 64/c, 32/c, 16/c, 8/c

Pickup Level

0.00 to 3.00 x VT in steps of 0.01 x VT

Minimum Operating Voltage

0.000 to 1.250 x VT in steps of 0.001 x VT

Number of Counters

16

Dropout Level

97 to 98% of Pickup

Counting

preset, compare

Level Accuracy

± 0.001 Hz

Pickup Time Delay

0.000 to 6000.000 s in steps of 0.001s

Programmability

Timer Accuracy

reset, up/down, set to pre-set, freeze/ reset, freeze/count

Dropout Time Delay

0.000 to 6000.000 s in steps of 0.001s

METERING

Operate Time

< 25 ms at 1.1 x pickup at 60Hz < 30 ms at 1.1 x pickup at 50Hz

± 3% of delay setting or ± ¼ cycle (whichever is greater)from pickup to operate

Operate Time

Timer Accuracy

± 3% of delay setting or ± ¼ cycle (whichever is greater)from pickup to operate

CONTROL

Typically 7.5 cycles at 0.1 Hz/s change Typically 7 cycles at 0.3 Hz/s change Typically 6.5 cycles at 0.5 Hz/s change

RMS PARAMETERS Currents Parameters

Phase A, B, C, Neutral, Ground and Sensitive Ground

Accuracy

± 0.25% of reading or ± 0.2% of rated (whichever is greater) from 0.1 to 2.0 x CT ± 1% of reading > 2.0 x CT

Neutral Overvoltage (59N)

Trip Bus

Pickup Level

0.02 to 3.00 x VT in steps of 0.01 x VT

Number of Elements

6

Dropout Level

97 to 98% of Pickup

Number of Inputs

16

Level Accuracy

±0.5% of reading from 15 to 208 V

Pickup Time Delay

0.000 to 6000.000 s in steps of 0.001 s

Voltages

Neutral Overvoltage Curves

Definite time, Flex Curve A,B,C,D

Dropout Time Delay

0.000 to 6000.000 s in steps of 0.001 s

0.000 to 6000.000 s in steps of 0.001 s (Definite Time)

< 2 ms at 60 Hz

Parameters and Residual

Pickup Time Delay

Operate Time Timer Accuracy

Dropout Time Delay

0.000 to 6000.000 s in steps of 0.001 s (Definite Time)

± 3% of delay setting or ± ¼ cycle (whichever is greater)from pickup to operate

Wye VTs: A-n, B-n, C-n, A-B, B-C, C-A, Average Phase, Neutral and Residual Delta VTs: A-B, B-C, C-A, Neutral and Residual

Accuracy

± 0.5% of reading from 15 to 208 V± 1% for open Delta connections

Operate Time

< 25 ms at 1.1 x pickup at 60Hz < 30 ms at 1.1 x pickup at 50Hz

Curve Timing Accuracy at > 1.1 x Pickup ± 3% of curve delay or ± 1 cycle (whichever is greater) from pickup to operate Negative Sequence Overvoltage (59_2)

SYNCHROCHECK Max voltage difference 0 to 400000 V in steps of 1 Max angle difference

0 to 100° in steps of 1

Max freq. difference

0.00 to 2.00 Hz in steps of 0.01

Hysteresis for max. freq. diff.

0.00 to 0.10 Hz in steps of 0.01

Dead source function

None, LV1 & DV2, DV1 & LV2, DV1 or DV2, DV1 xor DV2, DV1 & DV2 (L = Live, D = Dead)

Pickup Level

0.00 to 3.00 x VT in steps of 0.01 x VT

Dropout Level

97 to 98% of Pickup

MONITORING

Pickup Time Delay

0.000 to 6000.000 s in steps of 0.001 s

Trip Circuit Monitor (Tcm)

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Real Power (Watts) Range

-214748364.8 kW to 214748364.7 kW

Parameters

3-phase; per phase if VT is Wye

Accuracy

± 1.0% of reading or 0.1 kW (whichever is greater) at -0.8
Reactive Power (Vars) Range

-214748364.8 kvar to 214748364.7 kvar

Parameters

3-phase; per phase if VT is Wye

109

Transformer Protection

Angle Accuracy

Timer Accuracy

845 Transformer Protection System

Technical Specifications Accuracy

± 1.0% of reading or 0.1 kvar (whichever is greater) at -0.2
Transformer Protection

Apparent Power (VA)

Delta VTs

A-B, B-C, C-A, Neutral and Residual

Serial

Magnitude Accuracy

± 0.5% of reading from 15 to 208 V ± 1% for open Delta connections

RS485 port

Isolated

Baud rates

up to 115 kbps

0.5° (15 V
Response time:

10 ms typical

Parity

None, Odd, Even

Protocol

Modbus RTU, DNP 3.0, IEC 608705-103

Maximum distance

1200 m (4000 feet)

Isolation

2 kV

Range

0 kVA to 214748364.7 kVA

Angle Accuracy

Parameters

3-phase; per phase if VT is Wye

Frequency

Accuracy

± 1.0% of reading or 0.1 kVA (whichever is greater)

Range

3 to 72 Hz

Accuracy at

V = 15 to 208 V I = 0.1 to 0.25 x CT ± 0.02 Hz (input frequency 15 to 70 Hz); I > 0.25 x CT to 0.4 x CT ± 0.005 Hz (input frequency 15 to 70 Hz) I > 0.4 x CT ± 0.001 Hz (input frequency 15 to 70 Hz)

Power Factor Parameters

3-phase; per phase if VT is Wye

Range

0.01 Lag to 1.00 to 0.01 Lead

Accuracy

± 0.02

Watt-Hours (Positive And Negative) Range

- 2147483.648 MWh to 2147483.647 MWh

Parameters

3-phase only

Update Rate

50 ms

Accuracy

± 2.0% of reading

Magnitude of each harmonic and THD

Size

Range

2nd to 25th harmonic: per-phase displayed as % of f1 fundamental frequency

Refer to Dimensions & Mounting (Pg. 15)

Weight

9 kg [20.0 lbs]

COMMUNICATIONS Ethernet – Base Offering Modes:

10/100 Mbps

Parameters

3-phase only

One Port

RJ45

Update Rate

50 ms

Protocol

Modbus TCP

Accuracy

± 2.0% of reading

Ethernet – Card Option

PHASORS

Modes

100 MB

Current

Two Ports

ST (with this option both enabled ports are on the communications card; the Ethernet port located on the base CPU is disabled)

Protocols

Modbus TCP, DNP3.0, IEC60870-5-104, IEC 61850 Ed2, IEC 61850 GOOSE, IEEE 1588, SNTP, IEC 62439-3 clause 4 (PRP)

± 0.5% of reading or ± 0.2% of rated (whichever is greater) from 0.1 to 2.0 x CT ± 1.0% of reading > 2.0 x CT

Angle Accuracy

2° USB

Voltages Parameters and Residual

110

Wye VTs

30 ft (direct line of sight)

Parameters

- 2147483.648 Mvarh to 2147483.647 Mvarh

Magnitude Accuracy

Range PHYSICAL DIMENSIONS

Range

Phase A, B, C, Neutral and Ground

Standard specification IEEE802.11bgn

Current And Voltage Harmonics

Var-Hours (Positive And Negative)

Parameters

WIFI

Standard specification Compliant with USB 2.0 Protocols

Modbus TCP, TFTP

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845 Transformer Protection System

Testing and Certification TEST

REFERENCE STANDARD

TEST LEVEL

Dielectric voltage withstand

EN60255-5/IEC 60255-27

2.3 kV

Impulse voltage withstand

EN60255-5/IEC 60255-27

5kV

Damped Oscillatory

IEC61000-4-18IEC60255-22-1

2.5 kV CM, 1 kV DM

EN61000-4-2/IEC60255-22-2

Level 4

EN61000-4-3/IEC60255-22-3

Level 3

Fast Transient Disturbance

EN61000-4-4/IEC60255-22-4

Class A and B

Surge Immunity

EN61000-4-5/IEC60255-22-5

Level 3 & 4

Conducted RF Immunity

EN61000-4-6/IEC60255-22-6

Level 3

Power Frequency Immunity

EN61000-4-7/IEC60255-22-7

Class A & B

Voltage interruption and Ripple DC

IEC60255-11

PQT levels based on IEC61000-4-29, IEC61000-4-11 and IEC61000-4-17

Radiated & Conducted Emissions

CISPR11 /CISPR22/ IEC60255-25

Class A

Sinusoidal Vibration

IEC60255-21-1

Class 1

Shock & Bump

IEC60255-21-2

Class 1

Seismic

IEC60255-21-3

Class 2

Power magnetic Immunity

IEC61000-4-8

Class 5

Pulse Magnetic Immunity

IEC61000-4-9

Class 4

Damped Magnetic Immunity

IEC61000-4-10

Class 4

Voltage Dip & interruption

IEC61000-4-11

0, 40, 70, 80% dips, 250/300 cycle interrupts

Conducted RF Immunity 0-150khz

IEC61000-4-16

Level 4

Ingress Protection

IEC60529

IP54 front

Environmental (Cold)

IEC60068-2-1

-40C 16 hrs

Environmental (Dry heat)

IEC60068-2-2

85C 16hrs

Relative Humidity Cyclic

IEC60068-2-30

6day variant 2

EFT

IEEE/ANSI C37.90.1

4kV, 2.5 kHz

Damped Oscillatory

IEEE/ANSI C37.90.1

2.5kV, 1 MHz

RF Immunity

IEEE/ANSIC37.90.2

20V/m, 80 MhZ to 1GHz

ESD

IEEE/ANSIC37.90.3

8kV CD/ 15 kV AD

Safety

UL508

e57838 NKCR

UL C22.2-14

e57838 NKCR7

ENVIRONMENTAL

APPROVALS APPLICABLE COUNCIL DIRECTIVE

ACCORDING TO

Ambient temperatures:

CE compliance

Low voltage directive EMC Directive

North America

cULus

EN60255-5 / EN60255-27 EN60255-26 / EN50263 EN61000-6-2 / EN61000-6-4 UL508 UL1053 C22.2.No 14 ISO9001

Storage/Shipping: Operating: Humidity:

ISO

Transformer Protection

Electrostatic Discharge RF immunity

Manufactured under a registered quality program

Altitude: Pollution Degree: Overvoltage Category: Ingress Protection:

GEDigitalEnergy.com

-40°C to 85°C -40°C to 60°C (continuous) Operating up to 95% (non condensing) @ 55°C (As per IEC60068-2-30 Variant 2, 6days) 2000m (max) II III IP54 Front

111

Ordering 845 -E Base Unit Language PHASE CURRENTS SLOT J Bank 1/2:

**

**

**

*

*

*

*

*

*

*

*

*

*

*

*

*

*

*

*

N

845 E

English NN

Two windings, no voltage

P1

1A three-phase currents (J1) with voltage (J2)

P5 PHASE CURRENTS SLOT K Bank 1/2:

5A three-phase currents (J1) with voltage (J2)

MX

1A three-phase inputs (K1), 1A three-phase inputs (K2) two windings without voltage 5A three-phase inputs (K1), 5A three-phase inputs (K2) two windings without voltage 5A three-phase inputs (K1), 1A three-phase inputs (K2) two windings without voltage

H1

1A three-phase inputs (K1) - two windings with voltage

M1 M5

H5 Ground Currents

5A three-phase inputs (K1) - two windings with voltage G1

1A ground inputs

G5 Power Supply Slot B - LV I/O

5A ground inputs H

110 - 250 V dc/110 - 230 Vac N

None

R Slot C - LV I/O

6 X RTDs N

None

R Slot F - HV I/O Slot G - HV I/O

Slot H - HV I/O

6 X RTDs A

2 Form A (Vmon), 3 Form C, 7 Digital Inputs (Low / High voltage, Int/Ext supply) N

None

A

2 Form A (Vmon), 3 Form C, 7 Digital Inputs (Low / High voltage, Int/Ext supply) N

None

L Faceplate Current Protection

Voltage Metering & Protection: Control

7 mA O/P + 4 mA I/P + RTD + Ohm Input G

Color Graphical Display S M A

Basic = 87T, 50/87, 50P(3), 50N(2), 50G(3), 51P(3), 51N(2), 51G(3) Standard = Basic + 50_2(2), 51_2(2), RGF(2) Advanced = Standard + 67P, 67G, 67N, (requires voltage selection) S

Basic = 27P, 27X, 59P, 59N, 59X, 81O/U

P

Standard = Basic + 24(2), 32, 55, 81R B

Basic = Setpoint Group Control, Virtual Inputs, Trip Bus, 50BF

F Monitoring

Standard = Basic + Flexlogic, VTFF B

Standard = Breakers Trip Coil, Harmonics, THD, Demand, Trip Counters, Transformer Overload, Harmonic Derating Factor Advanced = Standard + Breaker Arcing, Breaker Health, Winding Hottest Spot, Aging Factor, Loss of Life, Tap Changer M&D = Standard + Breaker Arcing, Breaker Health, Winding Hottest Spot, Aging Factor, Loss of Life, Tap Changer+ M&D Standard = Front USB, 1 x Rear RS485 : Modbus RTU, DNP3.0, IEC60870-5-103 + 1 x Ethernet (Modbus TCP) Advanced = Front USB, 1 x Rear RS485 + 2 x Ethernet Fiber, MODBUS RTU / TCP, DNP3.0, IEC 60870-5-103/104, 1588, SNTP

C D Communications

Fiber Optic Connector

S

E

1

E

1

P

2

E

Advanced + PRP Advanced + PRP + IEC 61850 N

None

S

ST, Multi-mode 850nm

M

MTRJ Mutli-mode 1310nm

F Wireless Communication Security Future Option

Transformer Protection Relay (Standard : English Language; High Voltage PS, Graphical Control Panel)

SFP, Multi-mode 1310nm N

None

W

WiFi 802.11 B A

Basic Advanced - CyberSentry Level 1 N

Not available

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12875(E) English 150122

Multilin 345 ™

Transformer Protection System Intuitive Transformer Protection

Protection and Control

The Multilin 345 is a member of the Multilin 3 Series protective relay platform and has been designed for the protection, control and management of power transformers as primary or backup protection device. The 345 provides advanced transformer protection, control and monitoring in one economical draw-out or non draw-out design. The 345 contains a full range of self-contained protection and control elements as well as advanced communications, metering, monitoring and diagnostics.

• Dual slope, dual breakpoint differential protection

Key Benefits • Cost-effective proven and secure high-speed transformer protection • Integrated transformer thermal monitoring for asset management maintenance optimization • Improved transformer energization inhibiting • Ground current supervised sensitive ground fault protection for detection of ground faults down to 5% of the winding • Assignable CT inputs providing flexibility • Seamless integration into most communication architectures • Multiple communication networks including USB, Serial, Fiber or copper Ethernet supporting the most popular industry standard protocols • Unique draw-out construction to reduce the use of test switches • Small footprint easy on new installations or retrofits • Simplified transformer and protection setup right from the main menu

• Second harmonic inrush and fifth harmonic over-excitation inhibits • Unrestrained differential • Restricted Ground Fault (RGF) • Thermal model • Comprehensive overcurrent elements

Metering & Monitoring • Comprehensive current metering • Event Recorder: 256 events with 1ms time stamping • 32 samples per cycle oscillography • IRIG-B clock synchronization • Security audit trail and password control

Communications

• Draw out or non draw out options available

• Front USB and rear serial, Ethernet and Fiber ports

Applications

• Multiple Communication Protocols including IEC 61850, IEC 61850 GOOSE, MODBUS TCP/ IP, MODBUS RTU, DNP 3.0, IEC60870-5-104, IEC60870-5-103

• Primary or backup protection of two winding power transformers • Protection of reactors and autotransformers • Applications requiring fast and secure communications • Harsh environments requiring protection against corrosion and humidity

EnerVista™ Softwares • Simplify setup and configuration • Strong document archive and management system • Simplify full featured monitoring and data recording • Strong maintenance and troubleshooting tool • Seamless integration toolkit

Transformer Protection

345 Transformer Protection System

Overview

Easy to Use

Easy to Configure

The 345 is a microprocessor-based system for primary and backup protection of small and medium size distribution transformers. The 345 offers advanced algorithms for automatic magnitude and phase compensations for more than twenty types of two winding transformers, fast and secure biased differential protection with dual slope, and dual breakpoint characteristic. The 345 is equipped with restricted ground fault elements to detect ground faults down to 5% of the transformer winding, basic thermal protection and a full set of phase, ground, neutral and negative sequence over-current protection. The two identical groups with protection elements aim to satisfy these applications, where an automatic change of the settings is required.

Drawout Construction

Fast & Simple Configuration

The 345 offers a complete drawout feature eliminating the need for rewiring after testing has been concluded. The withdrawable feature also eradicates the need to disconnect communication cables, and helps retain communication status even after the relay has been withdrawn from its case.

Providing ease-of-use functionality, the 345 allows for transformer configuration in a simple one page setup screen. Therefore complete transformer protection setup can be completed in one easy step.

Effortless Retrofit

Easy integration into new or existing infrastructure

The 345 provides excellent accessibility and transparency with regard to the power system conditions and events, through its target messaging and the four lines of 20 characters display, the Transient and Event Recorders, and the powerful EnerVista PC program.

The compact and withdrawable feature of the 345 relay minimizes mounting requirements, enables easy retrofit to existing cases, and allows multiple relays to be mounted side by side on a panel. The 345 also provides a pluggable RS485 & IRIG-B connection for easy trouble shooting.

Advanced Communications

With several Ethernet and serial port options, and a variety of communication protocols, the 345 provides advanced and flexible communication selections for new and existing applications.

345 Relay Features

114

Easy to Configure - 1 simple step

Advanced & Flexible Communication Options

Easy to Use - Draw out case

Diagnostic Alarms

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345 Transformer Protection System

Enhanced Diagnostics

Multiple Options Several options for protection and communications are provided to match basic to high end application requirements.

Preventative Maintenance

Inrush Inhibit

Protection & Control The 345 transformer protection system is designed to protect and control small to medium size power transformers. Flexible and powerful, the 345 provides advanced transformer protection, control and monitoring in one economical draw-out design. The 345 contains a full range of self-contained protection and control elements as detailed in the Functional Block Diagram and in the Features table.

Failure Alarm The 345 detects and alarms on communication port and IRIG-B failures. The 345 also enables users to analyze system performance via diagnostics information such as event records and oscillography. It issues detailed transformer health reports and alarms when thresholds are exceeded.

Percent Differential Protection The Percent Differential protection is based on a proven algorithm that provides good sensitivity on detecting internal faults and better stability during through-fault conditions. The protection is characterized with the following key elements:

Cost Effective Robust Design The 345 is subjected to Accelerated Life Testing (ALT) to validate accurate relay functions under specified normal conditions. The device is further tested for durability through High Accelerated Life Testing (HALT), undergoing stress testing for extreme operating conditions.

The 2nd harmonic inrush inhibit function is selectable in order to cover energization of different types of transformers, and can be set to either per-phase, 2-out-of-3, or average mode.

Overexcitation inhibit An increase in transformer voltage, or decrease in system frequency may result in transformer overexcitation condition. In some cases the transformer overexcitation may result in undesirable operation of the percent differential element. Fifth harmonic inhibiting is integrated into the percent differential element to cater such overexcitation conditions. Differential Current (Id)

• Configurable dual slope, dual breakpoint differential/restraint characteristic

Slope 2

Break Point 2

Transition Region

• Inrush inhibiting • Overexcitation inhibits

Reduced Life Cycle Cost

Dual Slope, Dual Breakpoint Differential / Restraint Characterisitc

The 345 is designed to reduce total installation and life cycle cost for transformer protection. The draw out construction of the device reduces downtime during maintenance and decreases extra wiring needed for relay testing and commissioning.

This characteristic defines the area of percent differential protection operation versus no-operation, constructed through the setting of the minimum pickup differential current, the settings of slope 1 and slope 2 connected by a cubic spline curve, as well as the settings of

Break 1 Slope 1

Restraint Current (Ir)

The settings for the dual-slope, dual-breakpoint characteristic provides higher flexibility for shaping up the characteristic and achieve better sensitivity and security.

Functional Block Diagram ANSI Device Numbers & Functions ®

51P

50BF 51_2

50N

51N

Winding 2

87G 50G

Calculate Differential Currents

50/87

Calculate Harmonics 2nd and 5th

51G 51G

Winding 1

BLOCK

50G

51G 51G 87G

50P

87T

51P

50BF 51_2

50N

51N

Calculate Restraint Current

49P

345 RELAY

GEDigitalEnergy.com

Metering

50P

DEVICE NUMBER

FUNCTION

49

Thermal Model

50/87

Instantaneous Differential

50G

Ground/Sensitive Ground Instantaneous Overcurrent

50N

Neutral Instantaneous Overcurrent

50P

Phase Instantaneous Overcurrent

50BF

Breaker Failure

51_2

Negative Sequence Timed Overcurrent

51G

Ground/Sensitive Ground Timed Overcurrent

51N

Neutral Timed Overcurrent

51P

Phase Timed Overcurrent

87G

Restricted Ground Fault

87T

Percent Differential

115

Transformer Protection

The 345 allows users to track relay exposure to extreme environmental conditions by monitoring and alarming at high or low temperatures. This data allows users to proactively schedule regular maintenance work and upgrade activities.

breakpoint 1 and breakpoint 2. The maximum winding current is used as a restraining signal for better through-fault stability under CT saturation conditions.

345 Transformer Protection System

Unrestrained differential

Transformer Protection

An unrestrained differential element is provided for fast tripping on heavy internal faults to limit further damage to the transformer and minimize the risk to the rest of the system.

Restricted Ground Fault (RGF) The Restricted Ground Fault (RGF) elements extend the protection coverage to the neutral point of wye-connected windings where fault currents may be below the pickup of the main transformer differential element . The RGF elements use maximum phase winding currents as a restraining signal to provide stability during through fault conditions. Configurable ground current supervision is integrated into the element to add more stability during nonground out of zone faults with CT saturation, resulting in excessive neutral current, that may be enough to cause RGF operation.

Thermal protection The 345 relay provides basic thermal protection based on winding heating and cooling constants. The protection monitors the winding loading, and is settable to produce alarm or trip, based on the selected overloading criteria.

Overcurrent Elements The 345 relay provides phase, neutral, ground and negative sequence over-current functions that are configurable with respect to either winding currents. They can run in parallel with the main differential protection, and can be set to provide either primary or backup transformer protection for all types of transformer faults. When ordered with sensitive ground CTs, the 345 relay can be set to provide 10 times more sensitivity on detection of ground fault currents through the transformer winding neutrals grounded via current limiting resistor.

Inputs/Outputs The 345 features the following inputs and outputs for monitoring and control of typical transformer applications: • 10 contact Inputs with programmable thresholds • 2 Form A output relays for breaker trip with coil monitoring • 5 Form C output relays

Faults close to the neutral point of a wye-connected winding do not generate adequate fault current for differential element to pick up. Restricted Ground Fault protection provides sensitive ground fault detection for low-magnitude fault currents.

Advanced Automation

Monitoring & Diagnostics

Logic Elements

Event Recording

The 345 relay has sixteen Logic Elements available for the user to build simple logic using the state of any programmed contact, virtual, or remote input, or an output operand from protection, or control elements.

Events consist of a broad range of change of state occurrences, including pickups, trips, contact operations, alarms and self test status. The 345 stores up to 256 events time tagged to the nearest millisecond. This provides the information required to determine sequence of events which facilitates diagnosis of relay operation. Each event is individually maskable in order to avoid the generation of undesired events, and includes the values of currents and status of all the protection elements at the moment of the event.

The logic provides for assigning up to three triggering inputs in an “AND/OR” gate for the logic element operation and up to three blocking inputs in an “AND/OR” gate for defining the block signal. Pickup and dropout timers are available for delaying the logic element operation and reset respectively.

Virtual Inputs Virtual inputs allow communication devices the ability to write digital commands to the 345 relay. These commands could be changing setting groups or blocking protection elements.

IEC61850 The 345 supports IEC 61850 Logical Nodes which allows for digital communications to DCS, SCADA and higher level control systems. In addition, the 345 also supports IEC 61850 GOOSE communication, providing a means of sharing digital point state information between 345’s or other IEC61850 compliant IED’s. • Eliminates the need for hardwiring contact inputs to contact outputs via communication messaging. • Transmits information from one relay to the next in as fast as 8 ms. • Enables sequence coordination with upstream and downstream devices. • When Breaker Open operation malfunctions, GOOSE messaging sends a signal to the upstream breaker to trip and clear the fault.

116

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Oscillography The 345 captures current waveforms and digital channels at 32 samples per cycle. The oscillography record captures 8 individual analog channels allowing for detailed analysis. The oscillography is triggered either by internal signals or an external contact.

IRIG-B IRIG-B is a standard time code format that allows time stamping of events to be synchronized among connected devices within 1 milliseconds. An IRIG-B input is provided in the 345 to allow time synchronization using a GPS clock over a wide area. The 345 IRIG-B supports both AM and DC time synchronization with an auto detect feature that removes the requirement for manual selection.

345 Transformer Protection System

Security

Advanced Communications

The 345 continuously measures and computes the following AC signals indicating the health of the protected transformer:

Security Audit Trail

The 345 utilizes the most advanced communication technologies today making it the easiest and most flexible transformer protection relay to use and integrate into new and existing infrastructures. Multiple communication ports and protocols allow control and easy access to information from the 345.

• Phase winding currents • Winding ground current • Winding neutral current • Winding negative sequence current • Differential and restraint currents per-phase • Winding ground differential current • Percent 2nd and 5th harmonics differential currents per phase • Percent thermal capacity per-phase The states of all digital inputs/outputs are provided through the actual values either from the summary pages or individually. This includes: • States of contact inputs • States of virtual inputs • States of remote inputs • States of relay outputs • States of logic elements

The Security Audit Trail feature provides complete traceability of relay setting changes at any given time and is NERC CIP compliant. The 345 maintains a history of the last changes made to the 345 configuration, including modifications to settings and firmware upgrades. Security Setting Reports include the following information:

• MAC address of user making setting changes

The 345 supports the most popular industry standard protocols enabling easy, direct integration into electrical SCADA and HMI systems. Modbus RTU is provided as standard with a RS485 networking port.

• Listing of modified changes

The following optional protocols are available:

• Method of setting changes - Keypad, Front serial port, Ethernet, etc.    

• IEC 61850

Password Control

• DNP 3.0,

• If Password was required to change settings

With the implementation of the Password Security feature in the 345 relay, extra measures have been taken to ensure unauthorized changes are not made to the relay. When password security is enabled, changing of setpoints or issuing of commands will require passwords to be entered. Separate passwords are supported for remote and local operators, and separate access levels support changing of setpoints or sending commands.

• IEC 61850 GOOSE • Modbus RTU, • Modbus TCP/IP, • IEC 60870-5-104, • IEC 60870-5-103

Eight logic elements available for simple logic for applications such as manual control, interlocking, and peer to peer tripping.

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117

Transformer Protection

Metering

345 Transformer Protection System

Easy to Use

Transformer Protection

Simplified Transformer Setting Included with every 345 Transformer Protection System is the Multilin Simplified Transformer Setup. The Simplified Transformer Setup provides users with a quick and easy method to setup and start the transformer and process in applications that require fast commissioning. The Simplified Transformer Setup will generate a complete 345 setting file based on the transformer nameplate and system information entered by the user. Once all the information is entered, the Simplified Transformer Setup will generate the settings file, as well as provide the documentation indicating which settings were enabled, along with an explanation of the specific parameters entered. The Simplified Transformer Setup will provide a detailed setting file in PDF format that can be saved or printed for future reference.

Enervista Software The Enervista suite is an industry leading set of software programs that simplifies every aspect of using the 345 relay. The Enervista suite provides all the tools to monitor the status of the protected asset, maintain the relay, and integrate the information measured into DCS or SCADA monitoring systems. Convenient COMTRADE and sequence of event viewers are an integral part of the 345 set up software and are included to ensure proper protection and system operation.

Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed. Documents made available include: • Manuals • Application Notes • Guideform Specifications • Brochures

Viewpoint Maintenance provides tools that will increase the security of the 345 Transformer Protection System. Viewpoint Maintenance will create reports on the operating status of the relay, and simplify the steps to troubleshoot protected transformers. The tools available in Viewpoint Maintenance include:

• Wiring Diagrams

• Settings Security Audit Trail

• FAQs

• Device Health Report

• Service Bulletins

• Comprehensive Fault Diagnostics

Viewpoint Monitoring

EnerVista Integrator

Viewpoint Monitoring is a simple to use and full featured monitoring and data recording software package for small systems. Viewpoint monitoring provides a complete HMI package with the following functionality:

EnerVista Integrator is a toolkit that allows seamless integration of Multilin devices into new or existing automation systems.

• Plug and play device monitoring • System single line monitoring and control • Annunciator alarm screens • Trending reports • Automatic event retrieval • Automatic waveform retrieval

Launchpad Enervista Launchpad is a powerful software package that provides users with all of the set up and support tools needed for configuring and maintaining GE products. The setup software within Launchpad allows configuring devices in real time by communicating using serial, Ethernet or modem connections, or offline by creating setting files to be sent to devices at a later time.

Trace any setting changes with security audit trail

118

Viewpoint Maintenance

GEDigitalEnergy.com

Included in the EnerVista Integrator is: • OPC/DDE Server • Multilin Devices • Automatic Event Retrieval • Automatic Waveform Retrieval

345 Transformer Protection System

Power System Troubleshooting Analyze power system disturbances with transient fault recorder and event records

Transformer Protection

User Interface IN SERVICE: This indicator will be on continuously lit if the relay is functioning normally and no major self-test errors have been detected. TROUBLE: Trouble indicator LED will be AMBER if there is a problem with the relay or the relay is not configured. TRIP: Indicates that the relay has tripped the transformer offline based on predefined programmed conditions. ALARM: Indicates that the transformer is currently operating in an alarm condition and may proceed to a trip condition if not addressed. MAINTENANCE: Environmental alarms such as ambient temperature alarm or coil monitor alarms.

The display messages are organized into Main Menus, Pages, and Sub-pages. There are four main menus labeled Actual Values, Quick Setup, Setpoints, and Maintenance. Pressing the MENU key followed by the MESSAGE key scrolls through the four Main Menu Headers.

The ten button keypad allows users easy access to relay configuration and information.

USER INTERFACE OPTIONS: Draw out and non draw out options available

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119

345 Transformer Protection System

Dimensions

Front

Transformer Protection

DRAW-OUT DESIGN

Top

NON DRAW-OUT DESIGN

in

mm

in

mm

H

7.93

201.5

7.98

202.7

W

6.62

168.2

6.23

158.2

D

9.62

244.2

9.35

237.5

W1

3.96

100.6

3.96

100.6

D1

7.89

200.4

7.88

200.2

D2

1.73

43.8

1.47

37.3

H1

6.82

173.2

6.82

173.2

H

H

H

H

Rear

W

W

W

W

D2

D2

D2

D2

Side

D1 D D

D1

W1

W1

W1

W1

D1 D

D1

D

H1

H1

H1

H1

Technical Specifications PASSWORD SECURITY Master Reset 8 to 10 alpha-numeric characters Password: Settings Password: 3 to 10 alpha-numeric characters for local or remote access Control Password: 3 to 10 alpha-numeric characters for local or remote access PHASE/NEUTRAL/GROUND/NEGATIVE SEQUENCE TIMED OVERCURRENT (51P/51N/51G/51_2) Ground Current: Fundamental Pickup Level: 0.04 to 20.00 x CT in steps of 0.01 x CT Dropout Level: 97 to 99% of Pickup @ I > 1 x CT pickup - 0.02 x CT @ I > 1 x CT Curve Shape: ANSI Extremely/Ver y/Moderately/ Normally Inverse Definite Time (1 s base curve) IEC Curve A/B/C/Short IAC Extremely/Very/Inverse/Short Curve Multiplier: 0.05 to 20.00 in steps of 0.01 Reset Time: Instantaneous, Linear Time Delay ±3% of expected inverse time or 1 cycle, Accuracy: whichever is greater Level Accuracy: per CT input SENSITIVE GROUND TIMED OVERCURRENT (51SG) Ground Current: Fundamental Pickup Level: 0.005 to 3.000 x CT in steps of 0.001 x CT Dropout Level: 97 to 99% of Pickup @ I > 0.1 x CT pickup - 0.02 x CT @ I > 0.1 x CT Curve Shape: ANSI Extremely/Very/Moderately/ Normally Inverse Definite Time (1 s base curve) IEC Curve A/B/C/Short IAC Extremely/Very/Inverse/Short Curve Multiplier: 0.5 to 20.0 in steps of 0.1 Reset Time: Instantaneous, Linear Time Delay ±3% of expected inverse time or 1 cycle, Accuracy: whichever is greater Level Accuracy: per CT input

120

PHASE/NEUTRAL/GROUND/NEGATIVE SEQUENCE INSTANTANEOUS OVERCURRENT (50P/50N/50G/50_2) Current: Fundamental Pickup Level 0.05 to 20.00 x CT in steps of 0.01 x CT Dropout Level: 97 to 99% of Pickup I > 0.1 x CT Pickup - 0.02 x CT at I < 0.1 x CT Time delay: 0.00 to 300.00 sec in steps of 0.01 Operate Time: <30 ms @ 60Hz (I > 2.0 x PKP, No time delay) <35 ms @ 50Hz (I > 2.0 x PKP, No time delay) Time Delay 0 to 1 cycle (time delay selected) Accuracy: Level Accuracy: per CT input TRANSFORMER PERCENT DIFFERENTIAL PROTECTION (87T) Differential/ Dual Slope, Dual Breakpoint Restraint Characteristic: Minimum Pickup 0.05 to 1.00 x CT in steps of 0.01 Level: Slope 1 Range: 15 to 100% in steps of 1% Slope 2 Range: 50 to 100% in steps of 1% Kneepoint 1: 0.50 to 4.00 x CT in steps of 0.01 Kneepoint 2: 1.00 to 10.00 x CT in steps of 0.01 2nd Harmonic 1.0 to 40.0% insteps of 0.1% Inhibit Level: 2nd Harmonic Per-phase, 2-out-of-three, Average Inhibit Mode: 5th Harmonic 1.0 to 40.0% insteps of 0.1% Inhibit Level: Dropout Level: 97 to 98% of Pickup Operate Time: < 20 ms (no harmonics inhibits selected) < 30 ms (harmonics inhibits selected) Level Accuracy: per current inputs TRANSFORMER THERMAL PROTECTION (49) Current: Fundamental Pickup Accuracy: per current inputs Timing Accuracy: ±3% of expected time, or 30 ms (whichever is greater) @ I > 1.5 x PKP

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SENSITIVE GROUND INSTANTANEOUS OVERCURRENT (50SG) Pickup Level (Gnd 0.005 to 3.000 x CT in steps of 0.001 x CT IOC): Dropout Level: 97 to 99% of Pickup @ I > 0.1 x CT Pickup - 0.002 x CT @ I < 0.1 x CT Time delay: 0.00 to 300.00 sec in steps of 0.01 Operate Time: <30 ms @ 60Hz (I > 2.0 x PKP, No time delay) <35 ms @ 50Hz (I > 2.0 x PKP, No time delay) Time Delay 0 to 1 cycle (time delay selected) Accuracy: Level Accuracy: per CT input TRANSFORMER INSTANTANEOUS DIFFERENTIAL PROTECTION (50/87) Pickup Level: 3.00 to 20.00xCT in steps of 0.01xCT Dropout Level: 97 to 98% of Pickup Operate Time: <30 ms Level Accuracy: per current inputs RESTRICTED GROUND FAULT (87G) Number of 2 Elements: Pickup Level: 0.02 to 20.00 xCT in steps of 0.01 0.002 to 2.000 xCT (with sensitive CTs) GND Supervision 0.02 to 20.00 xCT in steps of 0.01 Level: 0.002 to 2.000 xCT (with sensitive CTs) Dropout Level: 97 to 98% of Pickup Slope Range: 0 to 100% in steps of 1 Pickup Delay: 0.00 to 600.0 s in steps of 0.01 Operate Time: < 30 ms @ 0 ms time delay Level Accuracy: per current inputs

345 Transformer Protection System

Technical Specifications

SENSITIVE GROUND CURRENT INPUT CT Primary: 1 to 600 A Range: 0.002 to 3 × CT Input type: 1 A or 5 A (must be specified with order P1S1 or P5S5) Nominal 50/60 Hz frequency: Accuracy: ±1% of reading at 1× CT ±3% of reading from 0.01 to 3 × CT ±20% of reading from 0.002 to 0.009 × CT CT withstand: 1 second at 100 × rated current 2 seconds at 40 × rated current continuous at 3 × rated current TRANSIENT RECORDER Buffer size: 3s No. of buffers: 1x192, 3x64, 6x32 No. of channels: 14 Sampling rate: 32 samples per cycle Triggers: Manual Command Contact Input Virtual Input Logic Element Element Pickup/Trip/Dropout/Alarm Data: AC input channels Contact input state Contact output state Virtual input state Logic element state Data storage: RAM - battery backed-up; retained for 3 days EVENT RECORDER Number of events: Header: Content:

Data Storage:

256 relay name, order code, firmware revision event number, date of event, cause of event, per-phase current, ground current, sensitive ground current, neutral current , ground differential current , negative sequence current , restraint current , per-phase differential current, per-phase differential second harmonic current, thermal capacity RAM - battery backed up; retained for 3 days

CLOCK Setup: IRIG-B:

LOGIC ELEMENTS Number of logic elements: Trigger source inputs per element: Block inputs per element: Supported operations: Pickup timer: Dropout timer:

Date and time (Daylight Savings Time) Auto-detect (DC shift or Amplitude Modulated) Amplitude modulated: 1 to 10 V pk-pk DC shift: 1 to 10 V DC Input impedance: 40 kOhm ± 10% RTC Accuracy: ± 1 min / month at 25°C 16 3 3 AND, OR, NOT, Pickup / Dropout timers 0 to 6000 ms in steps of 1 ms 0 to 6000 ms in steps of 1 ms

BREAKER FAILURE (50BF) Pickup Level: 0.05 to 20.00 x CT in steps of 0.01 Dropout Level: 97 to 98% of pickup Timer 1 Delay: 0.03 to 1.00 s in steps of 0.01 s Timer 2 Delay: 0.00 to 1.00 s in steps of 0.01 s Time Delay 0 to 1 cycle (Timer 1, Timer 2) Accuracy: Level Accuracy: per CT input

AMBIENT TEMPERATURE High Temperature 20°C to 80°C in steps of 1°C Pickup: Low Temperature -40°C to 20°C in steps of 1°C Pickup: Time Delay: 1 to 60 min in steps of 1 min Temperature Configurable 90 to 98% of pickup Dropout: Temperature ±10°C Accuracy: Timing Accuracy: ±1 second CONTACT INPUTS Inputs: Selectable thresholds: Recognition time: Continuous current draw: Debounce time: Type: External switch: Maximum input voltage: FORM-A RELAYS Configuration: Contact material: Operate time: Continuous current: Make and carry for 0.2s: Break (DC inductive, L/R=40 ms): Break (DC resistive): Break (AC inductive): Break (AC resistive):

10 17, 33, 84, 166 VDC 1/2 cycle 2 mA (to be confirmed) 1 to 64 ms, selectable, in steps of 1 ms opto-isolated inputs wet contact 300 VDC

2 (two) electromechanical silver-alloy <8 ms 10 A 30 A per ANSI C37.90 24 V / 1 A 48 V / 0.5 A 125 V / 0.3 A 250 V / 0.2 A 24 V / 10 A 48 V / 6 A 125 V / 0.5 A 250 V / 0.3 A 720 VA @ 250 VAC Pilot duty A300 277 VAC / 10 A

FORM-A VOLTAGE MONITOR Applicable voltage: 20 to 250 VDC Trickle current: 1 to 2.5 mA FORM-C RELAYS Configuration: Contact material: Operate time: Continuous current: Make and carry for 0.2s: Break (DC inductive, L/R=40 ms): Break (DC resistive): Break (AC inductive): Break (AC resistive):

5 (five) electromechanical silver-alloy <8 ms 10 A 30 A per ANSI C37.90 24 V / 1 A 48 V / 0.5 A 125 V / 0.3 A 250 V / 0.2 A 24 V / 10 A 48 V / 6 A 125 V / 0.5 A 250 V / 0.3 A 720 VA @ 250 VAC Pilot duty A300 277 VAC / 10 A

TRIP SEAL-IN Relay 1 trip seal-in: 0.00 to 9.99 s in steps of 0.01 Relay 2 trip seal-in: 0.00 to 9.99 s in steps of 0.01 HIGH-RANGE POWER SUPPLY Nominal: 120 to 240 VAC 125 to 250 VDC Range: 60 to 300 VAC (50 and 60 Hz) 84 to 250 VDC Ride-through time: 35 ms LOW-RANGE POWER SUPPLY Nominal: 24 to 48 VDC Range: 20 to 60 VDC ALL POWER SUPPLY RANGES Voltage withstand: 2 × highest nominal voltage for 10 ms Power 15 W nominal, 20 W maximum consumption: 20 VA nominal, 28 VA maximum

ETHERNET (FIBER) Fiber type: Wavelength: Connector: Transmit power: Receiver sensitivity: Power budget: Maximum input power: Typical distance: Duplex: Protocol: SERIAL RS485 port: Baud rates: Response time: Parity: Protocol: Maximum distance: Isolation: USB Standard specification: Connector: TYPE TESTS Dielectric voltage withstand: Impulse voltage withstand: Damped Oscillatory: Electrostatic Discharge: RF immunity: Fast Transient Disturbance: Surge Immunity: Conducted RF Immunity: Power Frequency Immunity: Voltage interruptionand Ripple DC: Radiated & Conducted: Emissions Sinusoidal Vibration: Shock & Bump: Siesmic: Power magnetic Immunity: Pulse Magnetic Immunity: Damped Magnetic Immunity: Voltage Dip & interruption:

100 MB Multi-mode 1300 nm MTRJ -20 dBm -31 dBm 9 dB -11.8 dBm 2 km (1.25 miles) half/full Modbus TCP/IP, DNP 3.0, IEC 60870-5104, IEC 61850 GOOSE Opto-coupled up to 115 kbps 1 ms typical None, Odd, Even Modbus RTU, DNP 3.0, IEC 60870-5-103 1200 m (4000 ft) 2 kV Compliant with USB 2.0 115 kbps 2.3KV EN60255-5

5KV

IEC61000-418IEC60255-22-1 EN61000-4-2/ IEC60255-22-2 EN61000-4-3/ IEC60255-22-3 EN61000-4-4/ IEC60255-22-4 EN61000-4-5/ IEC60255-22-5 EN61000-4-6/ IEC60255-22-6 EN61000-4-7/ IEC60255-22-7 IEC60255-11

2.5KV CM, 1KV DM

CISPR11 /CISPR22/ IEC60255-25

Class A

IEC60255-21-1

Class 1

IEC60255-21-2 IEC60255-21-3 IEC61000-4-8

Class 1 Class 2 Level 5

IEC61000-4-9

Level 4

IEC61000-4-10

Level 4

IEC61000-4-11

Level 4 Level 3 Class A and B Level 3 & 4 Level 3 Class A & B 15% ripple, 200ms interupts

Damped Oscillatory: Conducted RF Immunity 0-150khz: Voltage Ripple: Ingress Protection:

IEC61000-4-12

0, 40, 70, 80% dips, 250/300 cycle interrupts 2.5KV CM, 1KV DM

IEC61000-4-16

Level 4

IEC61000-4-17 IEC60529

Environmental (Cold): Environmental (Dry heat): Relative Humidity Cyclic: EFT: Damped Oscillatrory: RF Immunity:

IEC60068-2-1

15% ripple IP40 front , IP10 Back -40C 16 hrs

IEC60068-2-2

85C 16hrs

IEC60068-2-30

6day variant 2

IEEE /ANSI C37.90.1 4KV, 2.5Khz IEEE/ANSI C37.90.1 2.5KV,1Mhz ®

IEEE/ANSIC37.90.2

20V/m 80-1Ghz

ESD:

IEEE/ANSIC37.90.3

8KV CD/ 15KV AD e83849 NKCR

Safety:

UL508 UL C22.2-14 UL1053

e83849 NKCR7 e83849 NKCR

ETHERNET (COPPER) Modes: 10/100 MB (auto-detect) Connector: RJ-45 Protocol: Modbus TCP/IP, DNP 3.0, IEC 60870-5-104, IEC 61850

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121

Transformer Protection

PHASE & GROUND CURRENT INPUTS CT Primary: 1 to 6000 A Range: 0.02 to 20 × CT Input type: 1 A or 5 A (must be specified with order P1G1 or P5G5) Configurable 1 A or 5 A (must be specified with order P0G0) Nominal 50/60 Hz frequency: Burden: <0.1 VA at rated load Accuracy: ±1% of reading at 1× CT ±3% of reading from 0.1 to 20 × CT ±20% of reading from 0.02 to 0.09 × CT CT withstand: 1 second at 100 × rated current 2 seconds at 40 × rated current continuous at 3 × rated current

Technical Specifications CERTIFICATION CE: North America: ISO:

OPERATING ENVIRONMENT Ambient operating –40°C to +60°C [-40°F to +140°F] temperature: Ambient storage / –40°C to +85°C [-40°F to +185°F] shipping temperature: Humidity: Operating up to 95% (non condensing) @ 55C (As per IEC60068-2-30 Variant 2, 6days) Altitude: 2000m (max) Pollution degree: II Overvoltage III category: Ingress Protection: IP40 Front , IP10 back

Low voltage directive EN60255-5 / EN60255-27 / EN61010-1 EMC Directive EN60255-26/EN50263, EN61000-6-2, UL508 cULus UL1053, C22.2.No 14 Manufactured under a registered quality program ISO9001

DIMENSIONS Size: Weight:

Refer to Dimensions Chapter 4.1 kg [9.0 lb]

Ordering Multilin 345 Base Unit Language Phase Currents

345 Ground Currents*

Power Supply Faceplate 345 Current Protection

345

E

**

**

**

E

*

N

N **

*

*

E P1 P5 G1 G5 S1 S5 L H E S E M

Communications

Extended configuration - 87T, 87T-50, 51P(2), 51G(2), 50P(2), 50G(2), 51N(2), 50(2), 50BF(1), RGF(1), 49P Advanced configuration - 87T, 87T-50, 51P(2), 51G(2), 50P(2), 50G(2), 50BF(2), 49P, 51N(2), 50N(2), 51_2 (2), RGF(2) Standard :Front USB, Rear RS485 : Modbus RTU, DNP3.0, IEC60870-5-103 Standard + Ethernet (Copper & Fiber - MTRJ) MODBUS TCP/IP, DNP3.0, IEC 60870-5-104 Standard + Ethernet (Copper & Fiber - MTRJ) MODBUS TCP/IP, DNP3.0, IEC 60870-5-104, IEC 61850 GOOSE Standard + Ethernet (Copper & Fiber - MTRJ) MODBUS TCP/IP, DNP3.0, IEC 60870-5-104, IEC 61850

SN 1E 2E 3E

Case Design

Description

Base Unit English 1A three phase current inputs 5A three phase current inputs 1A ground current input 5A ground current input 1A sensitive ground current input 5A sensitive ground current input 24 - 48 Vdc 110 - 250 V dc/110 - 230 Vac Standard faceplate (LCD, full menu, actual values and setpoints) with 10 Inputs, 7 Outputs (2 Form A, 5 Form C) Standard configuration - 87T, 87T-50, 51P(1), 51G(1), 50P(1), 50G(1), 51N(1), 50N(1)

D N

Harsh Environment

N H

Draw-out design Non Draw-out design None Harsh Environment Conformal Coating

Ordering Notes: * 1) G1/G5 and S1/S5 must match corresponding P1/P5 - there cannot be 5A and 1A mixing

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12778K(E) English 150121

Transmission Line Protection Transmission Line Principles & Protection

124

An overview of transmission line principles, outlining typical construction of three phase overhead and underground transmission lines, and the common causes of abnormal operating conditions.

Typical Applications

132

Typical transmission line protection schemes showing small to large applications and how different Multilin protection and control products can be applied.

Spotlight Application

136

Highlighting unique transmission line applications and the benefits of deploying GE Multilin transmission line protection products in such applications. This applications details the importance of double ended fault location capabilities of Multilin protection and control systems.

Technical Resources

138

Access an extensive library of interactive tools and videos showcasing innovative solutions, as well as online publications, technical resources, how-to videos and transmission line protection configurators.

Selector Guide

139

Reference table highlighting the feature set for each Multilin transmission line protection system.

Featured Products Detailed product information for transmission line protection products offered by GE.

140

Transmission Line Principles

Transmission Line Principles Transmission Protection

The Purpose of Transmission Lines Transmission lines act like the arteries in the human circulatory system, moving electrical power from where it is produced by generators to where it is consumed at load centers. And like arteries in the human body, the loss or damage to transmission infrastructure can have disastrous effects on the overall power system and the customers it serves.

Types of Transmission Lines Overhead Lines The most common type of transmission circuit is overhead lines, where the energized conductors are suspended from tower structures using porcelain, glass or polymer insulators. The spacing between conductors is dependent on the voltage level the line is operated at, and typically the conductors are located dozens of meters above the ground for isolation and safety reasons. Due to the weight of the suspended conductors and the distances needed, the tower structures to support overhead lines are very large and have a large geographic footprint (commonly referred to as Right-of-Way or ROW). One of the advantages of overhead construction, beyond the easier ability to maintain it, is the ability to use ambient air to cool the conductors and therefore dynamically change the rating of transmission circuits based on ambient air temperature and wind speed. This method of construction is typically the most common, and usually meets the most public opposition when new construction or upgrading of transmission infrastructure is discussed.

Underground Cables As opposed to overhead lines, underground cables use a solid dielectric material to isolate the energized phase conductors and ground. Older cables made use of many layers of paper saturated in mineral oil to insulate the phase conductors, while newer cable technology makes use of polymer dielectric materials such as cross linked polyethylene (XLPE). Due to the high insulation value of polymer dielectric materials like XLPE, the conductors within an underground cable may be placed much closer together when compared to the air insulated overhead line. For lower voltages, all three phases may be built into a single cable; for higher voltages each phase conductor is in a separate cable. While the geographic footprint of underground cables is generally less than that of overhead lines, the overall power capacity of underground cables tends to be significantly less than overhead construction. For underground cables where large power transfers are required, cables are often installed into conduits that are filled with mineral oil that is continuously circulated in order to provide additional cooling. This incurs additional capital and maintenance costs and presents additional risks for environmental incidents should the oil leak. Underground cables tend to meet less public opposition for aesthetic reasons, however the costs associated for fixing underground cables is far greater. Repairing faults on underground cables require expensive excavation, and therefore, providing highly accurate fault location is critical.

124

Figure 1. Overhead transmission lines

Power Transfer Through Transmission Lines The ability to move power from generators to loads is determined by a number of factors, including the voltage level expected and produced at both ends of the system, and the equivalent impedance of the transmission system as viewed from a generation source to a load. The voltages at each end of the transmission system are typically controlled either by a required voltage magnitude (for loads) or by the maximum safe operating voltage of the source (for generators). The impedance is determined by such factors as the individual impedances of the transmission lines – ultimately determined by the size and type of conductors used and the geometry of the transmission line.

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Transmission Line Principles

The power transfer across a simple transmission system like the one shown in Figure 3 is determined by the formula:

P=

Vs Vr

Transmission Protection

sin d X where Vs and Vr are the voltages at the sending and receiving ends, d is the angle difference between Vs and Vr, and X is the equivalent impedance (neglecting resistance) between sending and receiving terminals. Real-time knowledge of the various voltage magnitudes, angles and power flows from generation to load centers across the system are essential to the reliable operation of the bulk electric system, especially when determining steadystate and transient stability limits.

Loadability Limits & Thermal Effects One of the limiting factors in the ability for a given transmission line is the heating effect caused by power lost due to I2R losses in the resistance of the conductors themselves. The I2R losses in the transmission line resistance heat the conductors and cause them to lengthen and sag. The additional sagging of the conductors reduces the distances between phase conductors and ground – if the sag becomes too great then the transmission line may flashover and cause a fault. The heating effect is directly related to the resistance of the conductors that make up the transmission line and the cooling provided by the environment. For example, an overhead line will be able to carry more current on colder windier days than on hot days with no wind. For underground cables, circulating oil around the cables provides additional cooling. Besides the steady-state thermal limits, there are also short term considerations that determine the amount of load that a given transmission line can carry for a limited period of time. Essentially a transmission line may be overloaded for a short period of time to allow the system to ride through disturbances. For example, one transmission line may be overloaded temporarily when a nearby transmission line is tripped and is waiting to be automatically reclosed. The loadability limits and requirements on transmission lines can introduce additional constraints for protective relaying, as protection must be able to allow the transmission line to be temporarily overloaded while still retaining the ability to correctly detect and clear faults.

Figure 2. Underground cables

X Vs

Generation

Vr

Transmission

Distribution

Figure 3. Power transfer across a simple transmission system

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Transmission Line Principles

Abnormal Conditions Faults

Transmission Protection

Transmission line faults are generally caused by a loss of insulation, either between the conductors of two or three of the phases or between one or more phase conductors and ground. For overhead lines, the insulation between phases is dependent on the dielectric value provided by the air surrounding the conductors according to the distance between each of the phases and ground. There are a number of ways in which the insulation level for overhead lines can be degraded to the point where a fault can occur: • Loss of the dielectric value of air due to contaminants suspended in the air. A prime example of this is the presence of soot particles suspended in the air, coming from nearby fires or from the combustion exhaust from industrial facilities.

For underground cables, faults occur due to the degradation of the dielectric material used as the insulator in the cable. This is often caused by thermal stress from repeated overloading of the cable line, electrical stress from steady-state and transient overvoltages but is most commonly caused by water penetration into the cable insulation itself. Water penetration is very common at junctions in the cable, where two separate pieces of cable are spliced together as the splice loses its watertight properties with age. Faults on underground cables can present an additional risk of public injury, as the cables are often run in populated areas and faults in underground cable vaults can result in explosions that may result in personal injury or property damage.

• Reduced spacing between conductors and/or grounded objects. This can be caused by high winds causing the conductors to sway, or conductor sagging from overheating or being loaded with ice. • Contamination of suspension insulators. The isolation between the phase conductors and the grounded transmission towers is provided by insulators that if contaminated or “fouled” lose their insulating value and can lead to flashovers between a phase conductor and ground. Common causes of insulator fouling include salt residue near coastal areas, air pollution and ice in colder climates. • The distance between the conductors is determined by the insulation required for a given voltage level. If the voltage on the line increases beyond the normal operating value, the extra voltage may cause insulation breakdown and flashover.

Figure 4. St Clair diagram showing transmission line capability in terms of surge impedance loading (SIL). The table shows loadability of various transmission solutions. (ACSR - aluminium conductor steel reinforced).

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Transmission Line Protection

Transmission Line Protection Introduction Transmission lines are a vital part of the electrical distribution system, as they provide the path to transfer power between generation and load. Transmission lines operate at voltage levels of 69kV and above, and are ideally tightly interconnected for reliable operation. Transmission Protection

Factors like de-regulated market environment, economics, right-of-way clearance and environmental requirements have pushed utilities to operate transmission lines close to their operating limits. Any fault, if not detected and isolated quickly will cascade into a system wide disturbance causing widespread outages for a tightly interconnected system operating close to its limits. Transmission protection systems are designed to identify the location of faults and isolate only the faulted section. The key challenge to the transmission line protection lies in reliably detecting and isolating the faults compromising the security of the system.

Factors Influencing Line Protection The high level factors influencing line protection include the criticality of the line (in terms of load transfer and system stability), fault clearing time requirements for system stability, line length, the system feeding the line, the configuration of the line (the number of terminals, the physical construction of the line, the presence of parallel lines), the line loading, the types of communications available, and failure modes of various protection equipment. The more detailed factors for transmission line protection directly address dependability and security for a specific application. The protection system selected should provide redundancy to limit the impact of device failure, and backup protection to ensure dependability. Reclosing may be applied to keep the line in service for transient faults, such as lightning strikes. The maximum load current level will impact the sensitivity of protection functions, and may require adjustment to protection functions settings during certain system operating conditions. Single-pole tripping applications impact the performance requirements of distance elements, differential elements, and some communications schemes. The physical construction of the transmission line is also a factor in protection system application. The type of conductor, the size of conductor, and spacing of conductors determines the impedance of the line, and the physical response to short circuit conditions, as well as line charging current. In addition, the number of line terminals determines load and fault current flow, which must be accounted for by the protection system. Parallel lines also impact relaying, as mutual coupling influences the ground current measured by protective relays. The presence of tapped transformers on a line, or reactive compensation devices such as series capacitor banks or shunt reactors, also influences the choice of protection system, and the actual protection device settings.

GE’s Multilin Application Advantages Before considering using a Multilin relay for a specific transmission line protection application, it is important to understand how the relay meets some more general application requirements for simplicity, security, and dependability. Multilin relays provide simplicity and security for single pole tripping, dependability for protection communications between line terminals, security for dual-breaker line terminals, and simplicity and dependability of redundant protection schemes.

Single pole tripping Single pole tripping using distance protection is a challenging application. A distance relay must correctly identify a single-phase fault, and trip only the circuit breaker pole for the faulted phase. The relay also must initiate the recloser and breaker failure elements correctly on the fault event. The distance elements protecting the unfaulted phases must maintain security during the open-pole condition and any reclosing attempts.

Reset

Open Pole

V, I

Open Pole(s)

Phase Selector

21P

Trip Output

Init BF

AR

21G Dir. Supv.

Open Pole Detector

Single pole trip logic

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127

Transmission Line Protection

Transmission Protection

The D90Plus Line Distance System, L90 Line Differential System, L60 Line Phase Comparison System and D60 Line Distance System use simple, dedicated control logic for a single pole tripping applications. This control logic uses a Phase Selector, Trip Output and Open Pole Detector in conjunction with other elements as shown in the simplified block diagram. The Trip Output is the central logic of single pole tripping. The Trip Output combines information from the Open Pole Detector, Phase Selector, and protection elements to issue a single pole or three pole trip, and also to initiate automatic reclosing and breaker failure. The Phase Selector is the key element for maintaining the security of single pole tripping applications, quickly and accurately identifying the faulted phase or phases based on measured currents and voltages, by looking at the phase angles between the positive sequence, negative-sequence, and zero-sequence components. The Open Pole Detector ensures the relay operates correctly during a single pole trip, placing the relay in an open pole condition when a single pole trip command is issued, or one pole of the circuit breaker is open. The Open Pole Detector may assert on a single pole trip command, even before the circuit breaker pole actually opens, to block protection elements that may misoperate under an open pole condition, such as negative sequence elements, undervoltage protection, and phase distance elements associated with the faulted phase (for example, AB and CA elements for an AG fault). The Open Pole Detector also resets and blocks the Phase Selector so the other distance elements may operate for evolving faults. The Open Pole Detector also accounts for line charging current and for weak infeed conditions. Once the Open Pole Detector operates, a further trip will cause the Trip Output to declare a three pole fault, indicating either an evolving fault condition or a reclose onto a permanent phase-to-ground fault. This total logic simplifies the setting of the D60 for single pole tripping, and ensures dependable and secure operation when faced with single line-to-ground faults. In spite of L90 Line Differential System is the only inherently phasesegregated relay, however all relays indicated above will provide correct single-pole tripping. Single pole tripping on these relays is user-friendly to program and does not present any unusual challenges, as each phase of the protection element operates independently of the other unfaulted phases.

Communications Often transmission lines are protected by using schemes that require communications with relays located at other line terminals. The reliability of the communications obviously impacts the reliability of the protection system. Multilin relays include features that maintain reliable operation of the protection communications during power line faults, communications channel delays, communications channel switching, and communications channel dropout. Pilot protection: Pilot protection schemes, such as directional comparison blocking and permissive over-reaching transfer trip, use simple on/off communications between relays. There are many methods to send this signal. The most common method is to use contact closure to an external communication circuit, such as power line carrier, microwave, radio, or fiber optic communications. Multilin relays simplify fiber optic communications method by using internal fiber optic communications via Teleprotection I/O, eliminating the need for external communications devices. Teleprotection I/O is a reliable mechanism that is simple to configure, securely transmits digital status points such as tripping or blocking commands between relays via directly-connected or multiplexed fiber optic channels. Teleprotection I/O operates within ¼ cycles plus channel delay for high speed communications to the remote line end.

128

Teleprotection I/O is available in any of the transmission line relays by adding an internal communications card. The output of the card can be IEEE C37.94, RS422 or G.703 communications to interface with fiber optic multiplexers, or may be a direct fiber connection to other relays. The communications card can be single-channel or dual-channel, to support point-to-point communications, dual point-to-point communications, Line Current Differential: Communications is an integral piece of a line differential relay, as the current phasors from one line terminal must be sent to relays at other line terminals to perform the differential calculation. This requires the use of a 64 kbps digital communications channel, which is commonly a multiplexed channel where channel switching may occur. The analog information must be precisely time synchronized between the line ends for the differential calculation to be correct. Synchronization errors show up as phase angle offset, where identical currents produce phasors with different phase angles, and transient errors, where changes in current are seen at different times at different measurement points. For example, on a 60 Hz system, every 1ms of time shift between terminals introduces a 21.6° phase shift into the measured currents. There are two methods to account for the phase shift between line terminals due to the communications channel delay. One method is to measure the round-trip channel delay, and shift the local current phase by an angle equal to ½ of the round-trip delay time. This method is simple to implement, but creates a transient error when the communications channel is switched. In addition, the differential element will be temporarily blocked when the communications channel switches, or noise in the communications channel causes communications packet loss. The L90 Line Differential Relay employs a different method, using synchronous sampling by internally synchronizing the clocks on each L90. This method achieves high reliability, as the round-trip channel delay is not virtally important. The differential element flawlessly operates during channel switching right after packet loss, because the communications packets are precisely synchronized. In the L90, synchronization is accomplished by synchronizing the clocks to each other rather than to a master clock. Each relay compares the phase of its clock to the phase of the other clocks and compares the frequency of its clock to the power system frequency and makes appropriate adjustments. The frequency and phase tracking algorithm keeps the measurements at all relays within a plus or minus 25 microsecond error during normal conditions for a 2 or 3 terminal system. In all cases, an estimate of phase error is computed and used to automatically adapt the restraint region of the differential element. The time synchronization algorithm can also use a GPS satellite clock to compensate for channel asymmetry. The use of a GPS clock is not normally required, except in applications such as a SONET ring where the communications channel delay may be asymmetric. This method produces synchronization accurate to within 125 microseconds between the relays on each end of the protected line. By using internally synchronized sampling, the L90 can accommodate 4 consecutive cycles of communications channel loss before needing to block the differential element. If the communications channel is restored within 5 seconds of channel loss, the L90 differential element will restart on the first received valid packet, without any time synchronization delay, due to the inertia of the internal clocks of the relays.

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Transmission Line Protection

Line Phase Comparison: Similar to line differential, communications is an integral part of phase comparison relaying. Simple binary communications, such as power line carrier or microwave, is used to send a pulse to the remote end when during positive half of the sinewave. Proper time alignment between the pulses from the remote end, and local end pulses, must be maintained.

The other common issue is pulse asymmetry of the carrier signal. Carrier sets may extend, either the mark (on) or space (off) signals at the receiving end compared with the originally sent signal. This difference is measured during commissioning by using oscillography data, and simply entered as a setting in the phase comparison element. In addition, the L60 supports some other methods to improve the reliability of protection communications.. The L60 also supports automated checkback of the carrier system. Under normal conditions, the relay can initiate transmission of and modulate the analog signal to exchange small amounts of information. This automatic loop-back can replace the carrier guard signal, and more importantly, verifies the entire communications path, including the relays on both ends.

Security for Dual-Breaker Terminals Dual-breaker terminal line terminals, such as breaker-and-a-half and ring bus terminals, are a common design for transmission lines. The standard practice is to sum up the currents from each circuit breaker externally by paralleling the CTs, and using this external sum as the line current for protection relays. This practice works well during actual line faults. However, for some external fault events, poor CT performance may lead to improper operation of line protection relays. When current flows through a dual-breaker line terminal, the line current measured by a relay using external summation matches the actual line current only if the two CTs are accurate. The most significant relaying problem is CT saturation in either CT. The current measured by the relay may contain a large error current, which can result in the relay operating due to an incorrect magnitude or direction decision. This incorrect operation may also occur if the linear error current of the CTs due to accuracy class is close to the through current level. These errors appear in the measured phase currents. As a result, relays that calculate the negative sequence and zero sequence currents from the measured phase currents may also see errors. Distance: Distance relays applied at dual-breaker line terminals are vulnerable to mis-operation on external faults. During a close-in reverse external fault, the voltage is depressed to a very low level, and the security of the relay is maintained by directional supervision. If one of the line CTs saturates, the current measured by the relay may increase in magnitude, and be in the opposite direction of the actual fault current, leading to an incorrect operation of the forward distance element for an external fault. The D90Plus Line Distance System and the D60 Line Distance System handles the challenge of dual-breaker line terminals by supporting two threephase current inputs to support breaker failure, overcurrent protection, and metering for each circuit breaker. The relays then mathematically add these currents together to form the total line current used for distance and directional overcurrent relaying.

The dual-breaker line terminal supervisory logic may essentially determine if the current flow through each breaker is either forward or reverse. Both currents should be forward for an internal fault, and one current should be forward and one reverse for an external line fault. Tripping is permitted during all forward faults, even with weak infeed at the dual-breaker terminal. Tripping is blocked for all reverse faults when one breaker sees forward current and one breaker sees reverse current. During an evolving external-to-internal fault, tripping is initially blocked, but when the second fault appears in the forward direction, the block is lifted to permit tripping. Line Differential: Line differential protection is prone to tripping due to poor CT performance on dual-breaker terminals, as the error current from the CTs is directly translated into a differential current. The only possible solution for traditional line differential relays is to decrease the sensitivity of the differential element, which limits the ability of the differential element to detect low magnitude faults, such as highly resistive faults. The L90 Line Differential System supports up to four three-phase current inputs for breaker failure, overcurrent protection, and metering for each circuit breaker. The relay then uses these individual currents to form the differential and restraint currents for the differential protection element. The L90 differential element design explicitly accounts for the performance of the CTs for dual-breaker line terminals. Each L90 protecting a transmission line calculates differential and restraint quantities based on local information directly measured by the relay, and information received from relays located at the remote line ends. Tripping decisions are made locally be each relay.

Relay 2

Relay 1 f

System Frequency

+

f - f1

Compute Frequency Deviation

f +

-

f1

f2

Compute Frequency Deviation

f - f2

Phase Frequency Loop Filter

Phase Frequency Loop Filter

2

1 ( 2 - 1)/2 Ping-Pong Phase Deviation

time stamps

Ping-Pong ( 2 - 1)/2 Phase Deviation

GPS Phase Deviation

time stamps

GPS Phase Deviation

( 2 - 1)/2

GPS Clock

( 2 - 1)/2

GPS Clock

Clock synchronization block diagram for a two terminal system using L90 current differential system

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129

Transmission Protection

The L60 Line Phase Comparison Relay directly solves two common challenges with the carrier signal. The first issue is channel delay. The channel delay is measured during commissioning and is entered as a setting in the phase comparison element.. The L60 has two communications channels, and two independent channel time delays, to support three-terminal lines.

Directly measuring the currents from both circuit breakers independently allows the use of supervisory logic to prevent the distance element and directional overcurrent elements from operating incorrectly for reverse faults due to CT error. This supervisory logic does not impact the speed or sensitivity of the protection elements, operates during all load conditions, and correctly allows tripping during an evolving external-to-internal fault condition.

Transmission Line Protection

The information sent by one L90 to the other L90s on the line is the local differential and restraint currents. The local differential current is the sum of all the local currents on a per-phase basis. One L90 can accept up to 4 current measurements, but only 2 currents are used for a dual-breaker application.

Transmission Protection

I LOC = I 1 + I 2 + I 3 + I 4 The local restraint current is defined by the following equation for each phase.

I LOC _ RESTRAINT =

(I

) + MULT • (I 2

LOC _ REST _ TRAD

LOC _ ADA

)

2

The starting point for the restraint is the locally measured current with the largest magnitude. This ensures the restraint is based on one of the measured currents for all fault events, and increases the level of restraint as the fault magnitude increases. ILOC_REST_TRAD is this maximum current magnitude applied against the actual differential characteristic settings. ILOC_ADA is the sum of the squares estimate of the measurement error in the current, and is used to increase the restraint as the uncertainty of actual measurement increases, such as during high magnitude fault events and CT saturation. MULT is an additional factor that increases the error adjustment of the restraint current based on the severity of the fault event and the likelihood the fault is an external fault, when CT saturation is most likely to cause an incorrect operation. The values of ILOC and ILOC_RESTRAINT are transmitted to the L90 relays located at the other line ends. The differential and restraint values used in the actual tripping decision combine both the local differential and restraint current, and the differential and restraint currents from the remote line ends. These calculations are performed individually on each phase.

I DIFF = I LOC + I REMOTE 1 + I REMOTE 2

(I REST ) 2 = (I LOC _ RESTRAINT ) 2 + (I REM 1 _ RESTRAINT ) 2+ (I REM 2 _ RESTRAINT ) 2

Considering the worst case external fault with CT saturation, the differential current IDIFF will increase due to the CT error that appears in ILOC. However, the restraint current IREST will increase more significantly, as the ILOC_RESTRAINT uses the maximum of the local currents, that is increased based on the estimation of CT errors and presence of CT saturation. The end result is a correct restraining of the differential element. Phase Comparison: The L60 Line Phase Comparison System supports two three-phase current inputs for breaker failure, overcurrent protection, and metering for each circuit breaker. The relay then uses these individual currents to form the local phase angle information for use in the phase comparison scheme. A phase comparison relay operates by comparing the relative phase angles of the current from each end of the transmission line. When the measured current exceeds the level of a fault detector, and the phase angles from each end of the line are in phase, the phase comparison relay operates. For a dual-breaker application using an external sum, the saturation of one CT may cause the relay current to increase high enough to operate the fault detector. Because the current from the unsaturated CT predominates in this waveform, the phase angle of the relay current may change. If the phase angle of the relay current is in phase with the relay current at the remote end of the line, the relay will trip. The L60 in dual-breaker applications selects the appropriate phase angle, based on the information measured from the current flow through both circuit breakers. The relay uses fault detectors on each current input, and develops the phase angle for each current input, and then special dual breaker logic consolidates the fault detector flags and the phase angle pulses for the line terminal. The fault detector flag is set for a line terminal if either fault detector from the two breakers is picked up. The type of phase comparison protection scheme, tripping or blocking, controls the pulse combination logic. For a tripping scheme, a positive polarity is declared for the terminal if one breaker displays positive polarity with its respective fault detector picked up, while the other breaker either does not show negative polarity or its fault detector is not picked up.

Redundancy Requirements - Alternate Main Protection Possibilities from GE

i2

IF + ILine

CT 1 saturates i2 is reduced i

IF + ILine

CT 1 iLine

52

ILine

IF

iLine shows incorret magnitude, direction iLine

CT 1 52

Relay

ILine

IF

52

CT 2

10 - 15 pu

L90

10 - 15 pu

52

52

Id > 0.2 pu Ir = 10 - 15 pu NO TRIP

52

Relay

Relay

503

Id > 0.2 pu Ir > 0.2 pu TRIP

52

503

10 - 15 pu with > 0.1 pu error

>0.1 pu error

i1

Impact of CT saturation on two-breaker line applications.

Sensitivity of Line Differential system for Dual-Breaker applications

(a) Accurate CTs preserve the reverse line current direction under weak remote feed. (b) Saturation of the CT carries the reverse current may invert the line current as measured from the externally summated CTs

130

>0.2 pu error

52

CT 2 i1

10 - 15 pu with > 0.1 pu error

>0.1 pu error

2

GEDigitalEnergy.com

Transmission Line Protection

Redundancy Considerations to Enhance Reliability

Multiple sets of protection using the same protection scheme involve using multiple relays and communications channels. This is a method to overcome individual element failure. The simplest method is to use two protection relays of the same type, using the same scheme and communications channel. This only protects against the failure of one relay. In some instances, relays of different manufacturers are used, to protect against common mode failures. It is also common to use redundant communications channels, in case of failure on one communications channel. Often, the communications channels use different methods, such as power line carrier and fiber optic. This is especially true due to the concerns of power line carrier operation during internal fault events.

GE simplifies solutions when multiple protection schemes are used by providing both protective relays that only use current and protective relays that use both current and voltage. The L60 Line Phase Comparison System and the L90/L30 Line Differential Systems are both current-only protection relays with a different operating principles. The D90Plus, D60 and D30 Line distance protection systems are full-featured distance relays. These relays are on a common hardware and software platform, simplifying engineering, design, installation, and operations issues. All of these relays support multiple communications options, including power line carrier, microwave, and fiber optic communications. The relays are also designed to communicate with each other, to implement voting schemes, reclosing control, and other applications.

An alternative way to increase reliability through redundancy is to use multiple protection methods on the same line such as phase comparison and permissive over-reaching transfer trip, using different communications channels. This method protects against individual element failure of both relays and communications channels. More importantly, it protects against the failure of one of the protection methods. For example, a VT circuit fuse failure blocks a distance relay from operating, while a line differential system or phase comparison system will continue to operate. For this reason, often at least one current-only scheme, such as phase comparison or line differential, and then one pilot protection scheme based on distance relays are employed.

CT 1

CT 1 52

52

52

52

CT 2

CT 2 L90 Line Differential

D90Plus Distance Protection

D60 Distance Protection

D60 Distance Protection

Example with 2 protection relays - same protection method

L60 Phase Comparison

Example with 2 or 3 protection relays - multiple protection method

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131

Transmission Protection

The reliability of transmission system protection is dependent on the reliability of the protection scheme used and the individual components of the protection scheme. Transmission protection systems typically use redundancy to increase the dependability of the system. There are two general methods of implementing redundancy. One method is to use multiple sets of protection using the same protection scheme. The other method is to use multiple sets of protection using different protection principles. Depending on the voltage class, either method of redundancy may involve using 2 or 3 sets of protection. In both cases, the goal is to increase dependability, by ensuring the protection operates for a fault event. Security may be improved through the use of so-called voting schemes (e.g. 2-out-of-3), potentially at the expense of dependability.

A second advantage of using multiple protection methods to protect one line is the ability to increase the security of the line. It is possible to implement a “voting” scheme, where at least 2 protection methods must operate before the line can be actually tripped. Such a voting scheme may be applied permanently on lines where security is an issue, such as major inter-tie lines. A voting scheme may also be applied only when the system is at risk, such as during wide-area disturbances, either automatically based on system conditions, or by command from system operators.

Typical Applications

Transmission Protection

Transmission Line Protection – Typical Applications Stepped-Distance Protection

3Y

52

Typical Functions

Additional Functions

21P

Phase distance

67P/N/_2 Directional overcurrent

21G

Ground distance

50BF

Breaker Failure

25

Synchrocheck

79

Reclosing

V, W, VAR

Voltage and Power metering

V, S

Voltage and Power metering

Synchrophasors Phasor Measurement Unit

3Y

21P 21G 67P 67N 3

V

50BF

3

S

25

79

Functions

Typical Product Order Code

Base Configuration

D30-U00-HKH-F8L-H6P-MXX-PXX-UXX-WXX

Alternative

D60-U00-HKH-F8L-H6P-MXX-PXX-UXX-WXX

+ Ethernet (Copper and Fiber)

D60-U00-HKH-F8L-H6P-MXX-PXX-UXX-WXX

+ Advanced Comms (IEC61850, IEEE1588-PTP, PRP)

D60-UE3-HKH-F8L-H6P-MXX-PXX-UXX-WXX

+ Synchrophasors (PMU)

D60-UE7-HKH-F8L-H6P-MXX-PXX-UXX-WXX

+ Advanced Comms and CyberSentry

D60-UG7-HKH-F8L-H6P-MXX-PXX-UXX-WXX

+HardFiber IEC 61850 Process Bus

D60-U03-HKH-FXX-H81-MXX-PXX-UXX-WXX

Note:

For single pole trip-logic replace D30 with D60

Note 2: For other options and languages, please visit GE’s OLS at www.GEDigitalEnergy.com/Onlinestore

Stepped-Distance Protection - Dual Breaker

1

3Y

Typical Functions

Additional Functions

21P

Phase distance

67P/N/_2 Directional overcurrent

21G

Ground distance

50BF

Breaker Failure

25

Synchrocheck

79

Reclosing

V, W, VAR

Voltage and Power metering

V, S

Voltage and Power metering

Synchrophasors Phasor Measurement Unit

52

3Y

52 3Y

21P 21G 67P 67N 3

V

3

S

25

79

Functions

Typical Product Order Code

Base Configuration

D30-U00-HKH-F8L-H6P-MXX-PXX-UXX-WXX

Alternative

D60-U00-HKH-F8L-H6P-MXX-PXX-UXX-WXX

+ Ethernet (Copper and Fiber)

D60-U00-HKH-F8L-H6P-MXX-PXX-UXX-WXX

+ Advanced Comms (IEC61850, IEEE1588-PTP, PRP)

D60-UE3-HKH-F8L-H6P-MXX-PXX-UXX-WXX

+ Synchrophasors (PMU)

D60-UE7-HKH-F8L-H6P-MXX-PXX-UXX-WXX

+ Advanced Comms and CyberSentry

D60-UG7-HKH-F8L-H6P-MXX-PXX-UXX-WXX

+HardFiber IEC 61850 Process Bus

D60-U03-HKH-FXX-H81-MXX-PXX-UXX-WXX

Note:

50BF 2

For single pole trip-logic replace D30 with D60

Note 2: For other options and languages, please visit GE’s OLS at www.GEDigitalEnergy.com/Onlinestore

2

1

132

GEDigitalEnergy.com

Typical Applications

Pilot Protection Schemes

3Y

52

Additional Functions

21P

Phase distance

67P/N/_2

Directional overcurrent

21G

Ground distance

50BF

Breaker Failure

85

Power line carrier / microwave transmitter & receiver / fiber or digital channel

25

Synchrocheck

79

Reclosing

V, W, VAR

Voltage and Power metering

V, S

Voltage and Power metering

85

3Y

Other Communications Options

21P 21G 67P 67N 3

V

50BF

3

S

25

79

85

Inter-Relay Communications

85

Sonet Multiplexer

Transmission Protection

Typical Functions

Synchrophasors Phasor Measurement Unit

85

Functions Typical Product Order Code External Teleprotection interface

Functions Typical Product Order Code Embedded Digital Teleprotection Interfaces

Base Configuration

D60-U00-HKH-F8L-H6P-M6F-P6D-UXX-WXX D30-U00-HKH-F8L-H6P-M6F-P6D-UXX-WXX

IEEE C37.94, 820 nm, multimode, LED, 2 Channels

D60-UE7-HKH-F8L-H6P-MXX-PXX-UXX-W77

Alternative (Pilot Schemes based on Flex-Logic)

D60-U00-HKH-F8L-H6P-M6F-P6D-UXX-WXX

1550 nm, single-mode, LASER, 2 Channels

D60-UE7-HKH-F8L-H6P-MXX-PXX-UXX-W7K

+ Ethernet (Copper and Fiber) + Advanced Comms (IEC61850, IEEE1588-PTP, PRP)

D60-UE3-HKH-F8L-H6P-M6F-P6D-UXX-WXX

G.703, 2 Channels

D60-UE7-HKH-F8L-H6P-MXX-PXX-UXX-W7S

RS422, 2 Channels

+ Synchrophasors (PMU)

D60-UE7-HKH-F8L-H6P-M6F-P6D-UXX-WXX

D60-UE7-HKH-F8L-H6P-MXX-PXX-UXXW7W

+ Advanced Comms and CyberSentry

D60-UG7-HKH-F8L-H6P-M6F-P6D-UXX-WXX

D60-UE7-HKH-F8L-H6P-MXX-PXX-UXX-W2J

+HardFiber IEC 61850 Process Bus

D60-U03-HKH-FXX-H81-M6F-P6D-UXX-WXX

Hybrid: Channel 1 - IEEE C37.94, MM, 64kbps; Channel 2 - 1550 nm, single-mode, LASER

Pilot Protection Schemes - Dual Breakers 1

Typical Functions

Additional Functions

21P

Phase distance

67P/N/_2

Directional overcurrent

21G

Ground distance

50BF

Breaker Failure

85

Power line carrier / microwave transmitter & receiver

25

Synchrocheck

79

Reclosing

V, S

Voltage and Power metering

3Y

Other Communications Options

52

85

Inter-Relay Communications

85

Sonet Multiplexer

Synchrophasors Phasor Measurement Unit

Functions Typical Product Order Code External Teleprotection interface

3Y

85

Base Configuration

D60-U02-HKH-F8L-H6P-M8L-P6F-U6D-WXX

Alternative (External sum of currents) D60-U00-HKH-F8L-H6P-MXX-P6F-U6D-WXX

52 21P 21G 67P 67N

3Y

3

V

S

2

25

79 2

1

50BF

3 85

+ Ethernet (Copper and Fiber)

D60-U02-HKH-F8L-H6P-M8L-P6F-U6D-WXX

+ Advanced Comms (IEC61850, IEEE1588-PTP, PRP)

D60-UE5-HKH-F8L-H6P-M8L-P6F-U6D-WXX

+ Synchrophasors (PMU)

D60-UE9-HKH-F8L-H6P-M8L-P6F-U6D-WXX

+ Advanced Comms and CyberSentry

D60-UG9-HKH-F8L-H6P-M8L-P6F-U6D-WXX

+HardFiber IEC 61850 Process Bus

D60-U03-HKH-FXX-H81-MXX-P6F-U6D-WXX

Embedded Digital Teleprotection Interfaces IEEE C37.94, 820 nm, multimode, LED, 2 Channels

D60-UE9-HKH-F8L-H6P-M8L-PXX-UXX-W77

1550 nm, single-mode, LASER, 2 Channels

D60-UE9-HKH-F8L-H6P-M8L-PXX-UXX-W7K

G.703, 2 Channels

D60-UE9-HKH-F8L-H6P-M8L-PXX-UXX-W7S

RS422, 2 Channels

D60-UE9-HKH-F8L-H6P-M8L-PXX-UXX-W7W

Hybrid: Channel 1 - IEEE C37.94, MM, 64kbps; Channel 2 - 1550 nm, single-mode, LASER

D60-UE9-HKH-F8L-H6P-M8L-PXX-UXX-W2J

GEDigitalEnergy.com

133

Typical Applications

Line Current Differential Protection

1

Additional Functions

87L

Line differential

21P

Phase distance

85

Sonet Multiplexer

21G

Ground distance

67P/N/_2 Directional overcurrent

3Y

52 3Y

Transmission Protection

Typical Functions

Other Communications Options

50BF

Breaker Failure

85

25

Synchrocheck

79

Reclosing

Inter-Relay Communications

85

V, W, VAR Voltage and Power metering

Synchrophasors

V, S

Phasor Measurement Unit

87L

67P 67N

21P 21G 25 3

50BF

79

Identical relay on other line terminals

85

Voltage and Power metering

Functions

Typical Product Order Code

Base Configuration

L90-U00-HKH-F8L-H6P-LXX-NXX-SXX-UXX-W77

Alternative (Pilot Schemes based on L30-U00-HKH-F8L-H6P-LXX-NXX-SXX-UXX-W77 Flex-Logic)

3

+ Ethernet (Copper and Fiber)

L90-U00-HKH-F8L-H6P-LXX-NXX-SXX-UXX-W77

+ Advanced Comms (IEC61850, IEEE1588-PTP, PRP)

L90-UE3-HKH-F8L-H6P-LXX-NXX-SXX-UXX-W77

+ Synchrophasors (PMU)

L90-UE7-HKH-F8L-H6P-LXX-NXX-SXX-UXX-W77

+ Advanced Comms and CyberSentry L90-UG7-HKH-F8L-H6P-LXX-NXX-SXX-UXX-W77 +HardFiber IEC 61850 Process Bus

L90-UG7-HKH-FXX-H81-LXX-NXX-SXX-UXX-W77

Optional Communicaiton Interfaces IEEE C37.94, 820 nm, multimode, LED, 2 Channels

L90-UE7-HKH-F8L-H6P-LXX-NXX-SXX-UXX-W77

1550 nm, single-mode, LASER, 2 Channels

L90-UE7-HKH-F8L-H6P-LXX-NXX-SXX-UXX-W7K

G.703, 2 Channels

L90-UE7-HKH-F8L-H6P-LXX-NXX-SXX-UXX-W7S

RS422, 2 Channels

L90-UE7-HKH-F8L-H6P-LXX-NXX-SXX-UXX-W7W

Hybrid: Channel 1 - IEEE C37.94, MM, 64kbps; Channel 2 - 1550 nm, single-mode, LASER

L90-UE7-HKH-F8L-H6P-LXX-NXX-SXX-UXX-W7J

Line Current Differential Protection – Dual Breaker 1

Typical Functions

Additional Functions

87L

Line differential

21P

Phase distance

85

Sonet Multiplexer

21G

Ground distance

67P/N/_2 Directional overcurrent 3Y

52

Other Communications Options

50BF

Breaker Failure

85

25

Synchrocheck

79

Reclosing

Inter-Relay Communications

Synchrophasors Phasor Measurement Unit

3Y

85

52 87L

3Y

67P 67N

3

1

3

79

V, S

Voltage and Power metering

Functions

Typical Product Order Code

Base Configuration

L90-U02-HKH-F8L-H6P-L8L-NXX-SXX-UXX-W77

Alternative (Pilot Schemes based on L90-U00-HKH-F8L-H6P-LXX-NXX-SXX-UXX-W77 Flex-Logic, external sum of current) + Ethernet (Copper and Fiber)

L90-U02-HKH-F8L-H6P-L8L-NXX-SXX-UXX-W77

+ Advanced Comms (IEC61850, IEEE1588-PTP, PRP)

L90-UE5-HKH-F8L-H6P-L8L-NXX-SXX-UXX-W77

+ Synchrophasors (PMU)

L90-UE9-HKH-F8L-H6P-L8L-NXX-SXX-UXX-W77

+ Advanced Comms and CyberSentry L90-UG9-HKH-F8L-H6P-L8L-NXX-SXX-UXX-W77 2

21P 21G 25

134

50BF

V, W, VAR Voltage and Power metering

85

2 Identical relay on other line terminals

+HardFiber IEC 61850 Process Bus

L90-UG7-HKH-FXX-H81-LXX-NXX-SXX-UXX-W77

Communication Options IEEE C37.94, 820 nm, multimode, LED, 2 Channels

L90-UE9-HKH-F8L-H6P-L8L-NXX-SXX-UXX-W77

1550 nm, single-mode, LASER, 2 Channels

L90-UE9-HKH-F8L-H6P-L8L-NXX-SXX-UXX-W7K

G.703, 2 Channels

L90-UE9-HKH-F8L-H6P-L8L-NXX-SXX-UXX-W7S

RS422, 2 Channels

L90-UE9-HKH-F8L-H6P-L8L-NXX-SXX-UXX-W7W

Hybrid: Channel 1 - IEEE C37.94, MM, 64kbps; Channel 2 - 1550 nm, single-mode, LASER

L90-UE9-HKH-F8L-H6P-L8L-NXX-SXX-UXX-W7J

GEDigitalEnergy.com

Typical Applications

Phase Comparison Protection

1

3Y

Typical Functions

Additional Functions

87PC

Phase Comparison

21P

Phase distance

85

Power Line Carrier / Microwave

21G

Ground distance

67P/N/_2 Directional overcurrent

52 85

Breaker Failure

25

Synchrocheck

79

Reclosing

Transmission Protection

3Y

50BF

V, W, VAR Voltage and Power metering

87 PC

67P 67N

21P 21G 25 3

50BF

79

Identical relay on other line terminals

85

Functions

Typical Product Order Code

Base Configuration

L60-U00-HKH-F8P-H6P-L8L-NXX-SXX-UXX-WXX

+ Ethernet (Copper and Fiber)

L60-U00-HKH-F8P-H6P-L8L-NXX-SXX-UXX-WXX

+ Advanced Comms (IEC61850, IEEE1588-PTP, PRP)

L60-UE3-HKH-F8P-H6P-L8L-NXX-SXX-UXX-WXX

+ Advanced Comms and CyberSentry L60-UG3-HKH-F8P-H6P-L8L-NXX-SXX-UXX-WXX

3

Phase Comparison Protection - Dual Breakers 1

Typical Functions

Additional Functions

87PC

Phase Comparison

21P

Phase distance

85

Power Line Carrier / Microwave

21G

Ground distance

67P/N/_2 Directional overcurrent

3Y

52

50BF

Breaker Failure

25

Synchrocheck

79

Reclosing

V, W, VAR Voltage and Power metering

3Y

85

Functions

Typical Product Order Code

Base Configuration

L60-U00-HKH-F8P-H6P-L8L-NXX-SXX-UXX-WXX

+ Ethernet (Copper and Fiber)

L60-U00-HKH-F8P-H6P-L8L-NXX-SXX-UXX-WXX

+ Advanced Comms (IEC61850, IEEE1588-PTP, PRP)

L60-UE3-HKH-F8P-H6P-L8L-NXX-SXX-UXX-WXX

+ Advanced Comms and CyberSentry L60-UG3-HKH-F8P-H6P-L8L-NXX-SXX-UXX-WXX

52 87 PC

3Y

67P 67N

50BF 2

21P 21G 25 3

79

85

Identical relay on other line terminals

3

Sub-Transmission – Multi-stage Overcurrent w/Directional Control

3Y

52 3Y or 2D

67P 67N 25 V

S

79

50

51

Typical Functions

Additional Functions

67P/N/_2

Directional overcurrent

25

Synchrocheck

50P/N/G/_2

Instantaneous overcurrent

79

Reclosing

51P/N/G/_2

Time delay overcurrent

V, W, VAR

21P/G

Distance (alternative)

Voltage and Power metering

Functions

Typical Product Order Code

Base Configuration

F60-U00-HKH-F8L-H6L-M8L-P6L-UXX-WXX

Alternative

D60-U02-HKH-F8L-H6L-M8L-P6L-UXX-WXX

+ Ethernet (Copper and Fiber)

F60-U02-HKH-F8L-H6L-M8L-P6L-UXX-WXX

+ Advanced Comms (IEC61850, IEEE1588-PTP, PRP)

F60-UE5-HKH-F8L-H6L-M8L-P6L-UXX-WXX

Advanced Comms and CyberSentry F60-UG5-HKH-F8L-H6L-M8L-P6L-UXX-WXX +HardFiber IEC 61850 Process Bus

GEDigitalEnergy.com

F60-U05-HKH-FXX-H81-MXX-PXX-UXX-WXX

135

Application Spotlight

Fast & Accurate Multi-Ended Fault Location Transmission Protection

The ability to accurately determine the location of faults on power systems lines are important as they facilitate faster inspection and shorter repair times, leading to faster restoration of the faulted lines. Maintenance crews rely on the advanced functions of the Multilin L90 Line Current Differential System. Transmission lines connect major generating stations with major urban centers where power is consumed, where fault can make a key piece of infrastructure unavailable and result in large outages within the city. Locating a fault quickly and accurately on an transmission lines allows for timely dispatch of maintenance crews to restore service as quickly as possible.

Traditional impedance-based single-ended fault locators accuracy is affected by many factors and uncertainties, including parallel lines mutual coupling, uncertainty in zero-sequence compensation factor, fault resistance and power flow, system homogeneity and weak-infeed applications. Multi‑ended fault locator in L90 eliminates all deficiencies of the single‑ended fault locators by utilizing inherently synchronized current and voltage measurements from all line terminals and eliminating fault location error due to mutual coupling, fault resistance, load, non‑homogeneity, non-synchronized measurements. It is designed to operate at both 2- and 3-terminal lines.

Fault Detected

Connection to Transmission Substation A

L90 Line Distance Protection System

L90

Connection to Transmission Substation B

136

Line Distance Protection System

GEDigitalEnergy.com

Application Spotlight

Accuracy of the multi-ended fault locator is further enhanced by compensating charging current and eliminating fault resistance from the equations and eliminating dependency on the phase selection ( fault type). During communications channel failures, relay is still providing fault location results by using UR platform single-ended impedance-based method.

Transmission Protection

Oscillography records obtained from protective relays at both ends of the cable can be post processed to calculate the fault distance fairly accurately. However, this post processing requires oscillography files to be collected and takes additional time following an event. In the contrast, L90’s multi-ended fault locator provides fault location results to the operator at all terminals immediately after fault over communications media available in the relay.

In addition to providing fast, sensitive and secure line current differential protection for MV, HV and EHV applications, the Multilin L90 features a multi-ended fault location algorithm that can provide system operators with extremely accurate fault type and location information immediately after a fault. Multi-ended method in L90 relay is coming at no cost to the customer.

Secure, High-Speed Communications GE’s JungleMUX multiplexers create the utility hardened communications backbone with a secure, high-speed network.

L90 Line Distance Protection System

Connection to Transmission Substation C

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137

WATCH. INTERACT. LEARN. Transmission Protection

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SOLUTIONS

SELECTOR GUIDES

to transmission challenges

From System Integrity Protection to Digitized Substations, explore advanced transmission solutions using our 3D power system.

“How To” videos &

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Compare, filter and select your product by protection, control, automation, and communications features to fit your application needs.

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CONFIGURATORS

Access over 60 step-by-step product videos and technical training to help you get the most out of your products.

Configure, price and easily submit your transmission protection and control product order on the Digital Energy online store.

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Product Selector Guide

Transmission Line Protection – Selector Guide Features

D30

D60

D90Plus

21

•

• •

• •

•

•

<1.5

<1.5

<1

5 5 G/N/P/_2 G/N/P/_2 N/P/_2

5 5 G/N/P/_2 G/N/P/_2 N/P/_2

5 5 G/N/P/_2 G/N/P/_2 N/P/_2

87L 87PC

87LP/G 21P/G 21P/G 50G/N/P/_2 51G/N/P/_2 67G/N/P/_2 87G 32N 32 59P/X/N/_2 27P/X 81U/O 81R 68/78 SOTF 50BF 86 25 79

P/X/N/_2 • • • • • • 4 3 6 •

• • P/X/N/_2 • • • • • • • • • 4 1&3 6 • • • •

VTFF

512

512

8 • 6 16 80 70 64 96 • 2 48

8 • 6 16 80 70 64 96 • 4 48

16 •

16 •

32 2 8 48 • 24 12 24

32 2 8 48 • 24 12 24

• • • • •

• • • • • •

• 15 1024 64/32/16/8

• 15 1024 64/32/16/8

•

•

• • • •

• • • • • • • •

•

•

• 3 • •

• 3 • •

• • • • • • • • • • •

• • • • • • • • • • •

L30

•

<1.5 •

• • • • • • 4 1&3 • • • • • 512 4096 16 • 6 16 115 60 64 96 • 2 288 30 • 32 10 8 •

• • • • • • • • 15 8192 256/128/64/32/16 1 • • • • • • • • 3 • • • • • • • • •

L90

•

• • •

• •

•

512

512

512

8 • 6 16 80 70 64 96 • 2 48

8 • 6 16 80 70 64 96 • 2 48

8 • 6 16 80 70 64 96 • 4 48

16 •

16 •

16 •

32 2 8 48 • 24 12 24

32 2 8 48 • 24 12 24

32 2 8 48 • 24 12 24

• • • • • •

• • • • • •

• 15 1024 64/32/16/8

• 15 1024 64/32/16/8

• • • • • • • • 15 1024 64/32/16/8

• •

• • •

G/N/P/_2 G/N/P/_2 N/P

<1

• <1.5 • 5 5 G/N/P/_2 G/N/P/_2 N/P/_2 • • • P/X/N • • • • • • • • • 4 1&3 6 • • • • •

• P/X/N/_2 • •

L60

3 3 G/N/P/_2 G/N/P/_2 N/P/_2 •

P/X/_2 • u

P/X/N/_2 •

• • • 4 3 6

• • • • • • 4 1& 3 6 • • •

• • • •

• •

• •

• • • • • • • • • •

•

•

•

• 3 • •

• 3 • •

• 3 • •

• • • • • • • • • • •

• • • • • • • • • •

• • • • • • • • • • •

• • •

• • •

For the most up-to-date selector guides, please visit

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139

Transmission Protection

FUNCTIONALITY Stepped Distance Pilot Protection Line Current Differential Line Phase Comparison Breaker-and-Half configurations PROTECTION & CONTROL Typical Operating Time (cycles) Phase & Ground Current Differential Mho Phase & Ground Distance (No. of Zones) Quad Phase & Ground Distance (No. of Zones) Instantaneous Overcurrent Time Overcurrent Directional overcurrent Restricted Ground Fault Wattmetric Ground Fault Sensitive Directional Power Overvoltage Undervoltage (Phase/Auxiliary) Under/Over frequency Frequecny Rate of Change Power Swing Blocking/Out-of-Step Tripping Switch onto Fault (Line Pickup) Load Encroachment Breaker Failure Lockout Functionality Synchronism Check or Synchronizing AC Reclosing (No. of Shots) Trip Modes: Three-Pole/Single-Pole Trip Bus (No. of Elements) Pilot Protection Logic Series Compensation Three terminal lines Lines with In-zone transformers Synchrophasors AUTOMATION Programmable Protection Logic (no of lines) Programmable Automation Logic (no of lines) FlexElements™ (number) User Programmable Self-Test Contact Settings Groups Non-volatile latches (up to) Contact Inputs Programmable - (up to) Contact Outputs Programmable - (up to) Virtual Inputs - (up to) Virtual Outputs - (up to) Direct Inputs/Outputs Breaker Control (up to) User-Programmable LEDs (up to) User - Programmable Annunciator Alarms (up to) User-Programmable Push Buttons (up to) User Definable Displays Large HMI (Graphical) Timers (number) Selector Switch (number) Digital Counters (number) Digital Elements (number) IRIG-B Input Analog Inputs (up to) Analog Outputs (up to) RTD Inputs (up to) MONITORING & METERING Current, voltage Symmetrical Components Power - Apparent, Real, Reactive Energy Power Factor Frequency Demand Fault Location Fault Report (number) Event Recorder - Number of Events Oscillography - Sampling Rate Disturbance Recorder - Sampling Rate (sample/cycle) Voltage Transformer Fuse Failure Current Transformer Supervision Open Pole Detector Broken Conductor Detection Thermal Overload Breaker Arcing Current Breaker Flashover Breaker Restrike Trip/Close Coil Supervision Data Logger COMMUNICATIONS INTERFACES RS232 Port USB Port RS485 Port Ethernet Port (Fiber and Copper, up to) Direct Fiber Communications (800nm, 1330nm, 1550nm) Communication Interface (RS422, G.703, C37.94) PROTOCOLS ModBus (RTU and TCP/IP) DNP3 IEC 60870-5-104 UCA2/MMS IEC61850 IEEE 1588 (PTP) IEC 62439 Parallel Redundancy Protocol Simple Network Time Protocol (SNTP) HTTP, TFTP, SFTP IEC 60870-5-103 Process Bus (IEC 61850-9-2)

Device

Featured Products

Transmission Line Protection – Featured Products

Transmission Protection

L90

Segregated Line Current Differential and Distance Protection

141

The L90 provides high-speed line current differential and distance protection intended for transmission lines and cables of various voltage levels. The L90 supports single and dual-breaker circuits requiring single or three-pole autoreclosing and independent synchrocheck supervision applications. The L90 offers advanced communications capabilities, supporting a wide range of industry standard protocols including IEC 61850 Edition 2, IEC 61850-90-2, and IEC 62439-3 PRP, ensuring resource and platform optimization and reliability.

L60

Sub-Cycle Phase Comparison and Distance Protection

149

The L60 provides fast and secure sub-cycle phase comparison and distance protection, for both two-terminal and three-terminal lines, lines with series compensation and for single-pole and three-pole tripping applications. The L60 can operate using existing Power Line Carrier or fiber optic communications, and employes advanced algorithms for channel noise immunity, to compensate for channel asymmetry and charging currents. The L60 can provide complete support of dual-breaker line terminals by using multiple current inputs. Supports both dual and single phase comparison, and can be configured for tripping or blocking applications.

L30

Cost-Effective Current Differential Protection

157

The L30 is a cost effective line current differential protection relay intended for sub-transmission and medium voltage lines and cables providing reliable and secure operation even under the worst case power system conditions. The L30 provides secure high-speed fault detection and clearance suitable for three-pole tripping applications. The L30 supports inter-relay protection communications via direct fiber as well as standard RS422, G.703 and C37.94 telecommunication interfaces. The L30 also provides Synchrophasor measurements over Ethernet per IEEE C37.118 and supports synchrophasor multi-cast per IEC(R) 61850-90-5.

D90Plus

Sub-Cycle Line Distance Protection & Advanced Automation Controller

165

The D90 is a sub-cycle line distance protection system and bay controller suitable for protecting transmission lines and cables including lines equipped with series compensation. The D90Plus is ideally suited for application on circuits where fast fault detection and small breaker failure margin are required. The D90Plus supports different teleprotection schemes, including DCB, DCU, POTT, Hybrid POTT, and PUTT. The D90Plus also provides Synchrophasor measurement over Ethernet per IEEE C37.118 and supports synchrophasor multi-cast per IEC® 61850-90-5. Plus

D60

High-Speed Transmission Line Protection With Three/Single Pole Tripping

175

The D60 is a high-end, cost-effective distance protection relay intended for protecting transmission lines and cables, providing reliable, secure operation even under severe power system conditions. The D60 supports dual-breaker applications and can be applied in single-pole or three-pole tripping applications. The D60 provides five zone quad or mho, phase and ground distance protection for greater system reliability. Advanced communications capabilities offers multiple, independent ports supporting a wide range of communication protocols and communications services.

D30

High-Speed Primary & Backup Distance Protection The D30 is a cost-effective distance protection system suitable for primary protection of sub-transmission lines and as a backup protection for HV & EHV lines, reactors and generators. The D30 provides three zones of phase and ground distance protection along with complete overcurrent and voltage protection functions intended for three-pole tripping applications.

Go online for the full listing of Multilin Protection & Control products

140

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183

Multilin™ L90 Line Protection System with Segregated Line Current Differential and Distance Protection The Multilin L90 is a high-end line current differential protection relay intended for transmission lines and cables of different voltages levels, providing reliable and secure operation even under the worst case power system conditions. The L90 provides high-speed phase-segregated fault clearance, suitable for single and three-pole tripping applications. Part of the Universal Relay (UR) family, the Multilin L90 comes with a variety of versatile features, truly integrating protection, monitoring, metering, communication and control in one easy-to-use device.

Key Benefits • Standardized and comprehensive line protection device with high-speed phase segregated differential protection, 5 zones for phase & ground distance protection with customizable pilot schemes ensuring high-speed single-pole tripping • In-zone power transformer enables savings on CTs and protection device requirements • Increased sensitivity through dynamic charging current compensation and communication channel asymmetry compensation • Embedded Synchrophasor measurement capabilities (per IEEE® C37.118), eliminating the need for dedicated PMUs and support for synchrophasor multi-cast (per IEC® 61850-90-5) reducing bandwidth and communications infrastructure costs • Advanced IEC 61850 Ed. 2 implementation, complete settings via SCL files and IEC 61850-9-2 process bus solution enable resource and platform managing optimization and reduce cost of ownership

Applications • Overhead lines including series compensated lines and underground cables of different voltage levels • Circuits with tapped transformer feeders • Suitable for three-terminal lines with channel redundancy and Direct Transfer Tripping (DTT) • Wide area system monitoring and control, using integrated protection and synchrophasor measurement • Single and dual-breaker circuits requiring single/three-pole autoreclosing and independent synchrocheck supervision • Secure application with Capacitively-Coupled Voltage Transformers (CCVTs)

Protection and Control • Phase segregated line current differential with adaptive restraint, ground differential, in-zone transformer and stub bus protection • Phase & ground distance (5 zones) with independent compensation settings • Thermal overload, phase, neutral & negative sequence directional overcurrent, broken conductor and reverse power

Advanced Communications • 3 independent Ethernet ports for simultaneous & dedicated network connections with IEEE 1588 support • Advanced IEC 61850 Edition 2 implementation with complete settings via SCL files and IEC 61850-9-2 process bus support • Wide range of supported protocols: IEC 61850 Ed. 2, SFTP, MMS File Transfer Service, DNP 3.0, Modbus Serial/TCP, IEEE 1588, IEC 60870‑5‑104 and 103, PRP, SNTP, HTTP, TFTP • Increased network availability by reducing failover time to zero through IEC 62439-3 PRP Support

Cyber Security • CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog)

Monitoring & Metering • Multi-ended fault location consistently providing 2% accuracy • Advanced recording with high capacity event recorder, waveform capture, and data logger

L90 Line Differential System

Protection and Control

L90 - Protection, Metering, Monitoring and Control

The Multilin L90 Line Protection System offers a high degree of modularity in its design and functionality, providing superior performance while meeting the toughest requirements of the marketplace.

Trasmission Protection

Advanced protection and control features of this relay includes:

Segregated Current Differential Protection The L90 is a phase-segregated current differential protection relay, which uses superior and patented algorithms to address the challenges of bandwidth, security, dependability and sensitivity in current differential relaying. Bandwidth requirements are effectively addressed by means of a patented new data consolidation technique called “phaselets”. This permits application within a communications bandwidth of 64 Kbps, and can detect faults within a half-cycle plus channel delay.

The L90 is the single point for protection, control, metering, and monitoring in one integrated device that can easily be connected directly into DCS or SCADA monitoring and control systems like Viewpoint Monitoring as shown.

Functional Block Diagram 52 79

Monitoring

50DD

CLOSE

50P 4

50_2 2

TRIP

51P 51_2 50BF 4

2

32

2

87L

2

49

2

Data From/To Remote End (via Dedicated Communications)

81U/O

21P

67P 5

68

78

50N

2

51N

4

Metering

TM

FlexElement

21G

67N/G 4

2

Transducer Inputs

5

59P 27P

50G

4

51G

4

59N 59X

27X

2

L90 Line Differential System

2

25

3 3

3

4

ANSI Device Numbers & Functions ®

DEVICE NUMBER

FUNCTION

DEVICE NUMBER

FUNCTION

21G 21P 25 27P 27X 32 49 50BF 50DD 50G 50N

Ground Distance Phase Distance Synchronism Check Phase Undervoltage Auxiliary Undervoltage Sensitive Reverse Power Thermal Overload Breaker Failure Current Disturbance Detector Ground Instantaneous Overcurrent Neutral Instantaneous Overcurrent

50P 50_2 51G 51N 51P 51_2 52 59N 59P 59X 67_2

Phase Instantaneous Overcurrent Negative Sequence Instantaneous Overcurrent Ground Time Overcurrent Neutral Time Overcurrent Phase Time Overcurrent Negative Sequence Time Overcurrent AC Circuit Breaker Neutral Overvoltage Phase Overvoltage Auxiliary Overvoltage Negative Sequence Directional Overcurrent

142

GEDigitalEnergy.com

DEVICE NUMBER

FUNCTION

67N 67P 68 78 79 81U/O 87L 81ROCOF 87LG

Neutral Directional Overcurrent Phase Directional Overcurrent Power Swing Blocking Out-of-Step Tripping Automatic Recloser Under/Over Frequency, df/dt Segregated Line Current Differential Rate of Change of Frequency Ground Line Current Differential

L90 Line Differential System

The L90 innovative dual-slope-adaptiverestraint characteristic, based on estimates of measurement errors, allows the relay to be secure on severe external faults while maintaining sensitivity for internal faults. The estimate of errors in the input currents permits more sensitive settings than those used in the traditional percent differential schemes.

The L90 approach to clock synchronization relies upon precise and distributed synchronization. Clocks are phase-synchronized to each other and frequency-synchronized to the power system frequency. Each relay compares its clock to the phase of the other clocks and makes appropriate adjustments. This allows for greater transient ride-through for power system and communications disturbances. Enhanced additional security is provided by a sensitive current disturbance detector, which can be used to supervise the current differential element.

Integrated channel monitoring provides realtime diagnostic data on the health of the L90. Communications channel deterioration or failure will activate an alarm, and can be used to enable backup protection. Channel propagation delay is monitored and adjusted according to variations in communication paths.

Communication Topologies Relays can communicate through direct fiber, RS422, G.703, and IEEE C37.94 interfaces at 64/128Kbps, with extensive channel monitoring and diagnostics. In a current differential scheme, the L90s exchange data via the communication link, acting either as master collecting data, making calculations and making all relevant trip and restraint decisions, or as slave only, transmitting current data to the one

acting as master. For two-terminal applications, use the redundant communications capability of the L90 for optimal reliability of the current differential line protection. For this scheme, data is continuously transmitted over both channels, so if a failure occurs, the L90 will continue to provide current differential protection. For three-terminal applications, advanced interrelay communication features eliminate the need for redundant communication channels due to the ability of the L90 to automatically switch between master and slave mode, maintaining a dependable system even with a failure of one of the communication channels.

Distance Protection The L90 shares the core of the D60 relay, which is the distance function, and provides a high degree of sensitivity and selectivity for all types of faults. The distance function in the L90 comes with five zones of phase distance and ground distance, providing the user maximum flexibility to cater to different applications, which include primary line protection and backup protection for busbars, generators, transformers and reactors. The L90 can be applied to power systems with

Ground Differential “87G” The ground differential function “87G” protects against low-current single line-to-ground faults. It has a single slope characteristic and uses the vectorial sum of all in-zone phase currents to calculate the neutral differential current, with the maximum value of phase current being used as restraint. This function, together with the phase differential, delivers enhanced sensibility and selectivity to the protection scheme.

Typical Applications

Charging Current Compensation For long transmission lines and underground cables, the charging current may be large and result in excessively high pickup settings. The L90 can dynamically compensate the charging current, thus increasing its sensitivity to the fault current on long transmission lines.

Enhanced Monitoring Features The L90 uses advanced error detection and supervising functions to secure itself against misoperation due to erroneous data. High bit errors are addressed by means of computing a 32-bit CRC checksum, effectively addressing the concerns of multiple bit errors due to high channel noise. Typical two and three-terminal applications of L90. L90 supports a variety of media cards for signaling between L90’s including direct multimode or singlemode fiber, RS422, G.703 and IEEE C37.94.

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143

Transmission Protection

The line differential element also has 2nd harmonic inrush-current inhibit for in-zone power transformer protection. This functionality enables the L30 to protect 2 or 3-terminal lines that have a power transformer in between ends.

On multiplexed channels, channel asymmetry may be expected due to path switching causing spurious differential currents, which can endanger the security of the differential system. By using GPS time synchronization, up to 10ms of channel asymmetry can be compensated. Extra security has been implemented in the L90 to ensure proper operation in the event of IRIG-B signal failure.

Trasmission Protection

L90 Line Differential System

different earthing conditions, lines with in-zone transformers or tapped transformer feeders, and overhead lines with series compensation. Each zone element for the phase and ground distance can be independently set as quad or mho characteristics with the flexibility of designing different characteristic shapes to suit different power system conditions. The advanced comparator-based distance elements provide the utmost security, sensitivity and selectivity for different types of faults. Superior digital filtering techniques provide secure and optimum reach accuracy even under worst-case CCVT transients. Secure directional discrimination is achieved by using positive sequence memory voltage polarization, providing reliable directionality for worst-case close-in faults. Dual distance algorithms deliver exceptional security and speed performance to ensure average operating times of 1.5 cycles for 75% line reach and SIR 30, and <2.5 cycles for 90% line reach and SIR 60. The L90 employs a well-proven algorithm for phase selection, which provides faster, secure and reliable faulted phase identification for single-pole tripping and proper fault-distance calculation for a variety of power system conditions. An additional voltage monitoring function provides extra security to the distance element , which can be used to block the distance elements under voltage source fusefailure conditions.

In-Zone Transformer Compensation Phase distance protection in the L90 can be used to detect faults through different types of three-phase wye/delta transformers, allowing application of the L90 for backup protection on generators. VTs and CTs can be installed independently of each other on either side of the power transformer. The relay automatically compensates for transformer connections, to guarantee accurate reach for any type of fault.

Line Pickup (Switch-on-to Fault)

Overcurrent Functions

The line pickup feature uses a combination of undercurrent and undervoltage to identify a line that has been de-energized (line end open). Three instantaneous overcurrent elements are used to identify a previously de-energized line that has been closed on to a fault.

The L90 provides thermal overload, and time and instantaneous overcurrent elements for phase, neutral, ground, negative sequence, phase and neutral directional. The neutral directional overcurrent element supports enhanced dual polarization modes which can be configured to prioritize on voltage or current polarization. Any of them can run in parallel with primary differential protection or can be programmed to run when the differential element is not available.

Power Swing Detection Dynamic transients in the power system, due to short-circuits, circuit switching, or load unbalance changes, can travel across the power network as power swings (characterized by fluctuating currents and voltages). This can result in unwanted tripping since distance elements can respond to these power swings as faults. The L90 power swing detection element provides both power swing blocking and out-of-step tripping functions. The element measures the positive sequence apparent impedance and traces its locus with respect to either a two or three-step userselectable mho or quad operating characteristic. Negative sequence current supervisors provide extended selectivity for detecting evolving faults that may appear as a power swing event (faults with slow moving impedance locus).

Series Compensated Lines The L90 provides enhanced stability and security by employing an adaptive distance reach control to cope with the overreaching and sub-synchronous oscillations when applied to, or in the vicinity of, series compensated lines. For directional integrity the relay uses memory voltage polarization and a multi-input comparator to deal with current inversion issues in series compensated lines.

Single-Pole Tripping The L90 relay uses a state-of-the-art dual phase selection algorithm that provides fast and accurate fault type identification even under weak infeed conditions.

Load Encroachment

Direct Transfer Trip (DTT)

The load encroachment feature offers discrimination between line loading conditions and fault conditions, especially for long lines under heavy loads by supervising the distance elements or any overcurrent element . This prevents unwanted tripping under heavy line load conditions and enables optimum operation of the line while meeting regulatory requirements for line loading.

Use the DTT feature of L90 to trip remote breakers. Both single and three-pole DTTs are supported. Up to eight signals can be sent over pilot communications channels, selectable through user-configurable logic.

144

Overvoltage and Undervoltage Protection Long lines under lightly loaded or no-load conditions may experience voltages exceeding rated per unit voltage level of the line. Use the three-phase overvoltage elements of the L90 to initiate a local trip as well as a remote trip using Direct Transfer Tripping DTT.

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Communication Aided (Pilot) Schemes L90 supports different teleprotection functions for fast fault clearance for any faults within the protected line. The following types of pilot-aided schemes are available in the L90: • Direct Underreach Transfer Trip (DUTT) • Permissive Underreach Transfer Trip for Distance and Current (PUTT) • Two Permissive Overreach Transfer Trip (POTT) • Hybrid Permissive Overreach Transfer Trip (HYB POTT), permissive echo and transient blocking logic incorporated • Directional Comparison Blocking Scheme (DCB) • Directional Comparison Unblocking Scheme (DCUB) • Customizable version of the POTT and DCB schemes (POTT1 and DCB1)

Autoreclosing The L90 provides multi-shot autoreclosing (up to 4 shots) for single or three-pole autoreclose on all types of faults with independent settings for each shot. Any of the autoreclose elements can be dynamically blocked or unblocked by other elements or user logic. This way they can be coordinated with the L90 protection setting groups. Four different autoreclose operation modes are available, enabling users to select the autoreclosing mode to suit specific applications.

Synchronism Check The L90 provides four synchrocheck elements that monitor voltage difference, phase angle difference and slip frequency, to ensure proper breaker closure as per user requirements. Any of the four synchrocheck elements can be dynamically blocked or unblocked by other elements or user logic. The L90 also provides additional enhancements in synchronizing by allowing synchrocheck verification between local and remote line terminal voltages.

L90 Line Differential System

Breaker Failure

HardFiber System benefits:

The L90 is able to provide fully independent breaker failure protection for the breakers associated to the line when connected to a substation with a breaker-and-a-half or ring bus arrangement. The L90 provides the required elements to perform two independent breaker failure functions.

• Communicates using open standard IEC 61850 messaging

• Flexible, modular I/O covering a broad range of input signals and tripping schemes • Mechanically latching outputs can be used to develop secure interlocking applications and replace electromechanical lockout relays

• Drastically reduces P&C design, installation and testing labor by eliminating individual copper terminations

Monitoring and Metering

Multiple Breaker Configurations

The L90 includes high accuracy metering and recording for all AC signals. Voltage, current , and power metering are built into the relay as a standard feature. Current and voltage parameters are available as total RMS magnitude, and as fundamental frequency magnitude and angle.

• Does not introduce new cyber security concerns

The L90 supports multi-breaker busbar configurations, such as breaker-and-a-half or ring bus arrangements, providing dual breaker autoreclose dual synchrocheck elements, and dual independent breaker failure elements. The design provides secure operation during external faults with possible CT saturation.

Advanced Automation The L90 incorporates advanced automation features including powerful FlexLogic™ programmable logic, communication, and SCADA capabilities that far surpass what is found in the average line relay. The L90 integrates seamlessly with other UR relays for complete system protection.

Special Applications - Distributed Busbar Use the L90’s capability of supporting up to 4 directly connected CTs for applications where the use of conventional bus differential relaying is not practical or economically feasible. The L90 can be used to protect both line and buses by measuring currents from the feeder CTs as shown. The L90 provides primary protection for both the buses and the circuit connecting them.

Fault and Disturbance Recording The advanced disturbance and event recording features within the L90 can significantly reduce the time needed for postmortem analysis of power system events and creation of regulatory reports. Recording functions include: • Sequence of Event (SOE) - 1024 time stamped events

FlexLogic FlexLogic is the powerful UR-platform programming logic engine that provides the ability to create customized protection and control schemes, minimizing the need and associated costs of auxiliary components and wiring.

IEC 61850 Process Bus

• Oscillography - 64 digital & up to 40 analog channels - Events with up to 45s length • Data Logger and Disturbance Recording - 16 channels up to 1 sample/cycle/channel

Using FlexLogic, the L90 can provide required tripping and custom scheme logic for line breaker control and interlocking and dynamic setting group changes.

The IEC 61850 Process Bus module is designed to interface with the Multilin HardFiber™ System, allowing bi-directional IEC 61850 fiber optic communications. The HardFiber System is designed to integrate seamlessly with existing UR applications, including protection functions, FlexLogic, metering and communications.

• Fault Reports - Powerful summary report of pre-fault and fault values • Multi-Ended Fault Location - Calculation of fault location on two or threeterminal lines with 2% accuracy

Scalable Hardware The L90 is available with a multitude of I/O configurations to suit the most demanding application needs. The expandable modular design allows for easy configuration and future upgrades.

CT1 L90-1

CB1

CB2

CT2

VT1 CT1

CT2

CT3

CT4

CB1

CB2

CB3

CB4

VT2 1PH

1PH

Communication channel

BUS1

L90

BUS2 CB5

CB6

CB7

CT5

CT6

CT7

VT3

L90-2

Example of Distributed Bus Differential Protection Application.

PROTECTED LINE 831783A1.CDR

L90 Breaker-and-a-Half Application Example.

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145

Transmission Protection

• Integrates with existing L90’s by replacing traditional CT/VT inputs with the IEC 61850 Process Bus module

L90 Line Differential System

The very high sampling rate and large amount of storage space available for data recording in the L90 can eliminate the need for installing costly stand-alone recording equipment.

Trasmission Protection

Advanced Device Health Diagnostics The L90 performs comprehensive device health diagnostic tests at startup and continuously during run-time to test its own major functions and critical hardware. These diagnostic tests monitor for conditions that could impact security and availability of protection, and present device status via SCADA communications and the front panel display. Providing continuous monitoring and early detection of possible issues help improve system uptime.

Communications The L90 provides for secure remote data and engineering access, making it easy and flexible to use and integrate into new and existing infrastructures. Fiber optic Ethernet provides high-bandwidth communications allowing for low-latency controls and high-speed file transfers of relay fault and event record information. The available redundant Ethernet option and the embedded managed Ethernet switch provide the means to create fault tolerant communication architectures in an easy, cost-effective manner. The L90 supports the most popular industry standard protocols enabling easy, direct integration into monitoring and SCADA systems.

• Comprehensive device health diagnostic performed at startup

• IEC 61850 Ed. 2 with 61850‑9‑2 and 61850‑90‑5 support

• Monitors the CT/VT input circuitry to validate the integrity of all signals

• DNP 3.0 (serial & TCP/IP)

Cyber Security – CyberSentry UR CyberSentry UR enabled UR devices deliver full cyber security features that help customers to comply with NERC CIP and NIST® IR 7628 cyber security requirements. This software option delivers the following core features:

AAA Server Support (Radius/LDAP) Enables integration with centrally managed authentication and accounting of all user activities and uses modern industry best practices and standards that meet and exceed NERC CIP requirements for authentication and password management.

Role Based Access Control (RBAC) Efficiently administrate users and roles within UR devices. The new and advanced access functions allow users to configure up to five roles for up to eight configurable users with independent passwords. The standard “Remote Authentication Dial In User Service” (Radius) is used for authentication.

Event Recorder (Syslog for SEM) Capture all cyber security related events within a SOE element (login, logout, invalid password attempts, remote/local access, user in session, settings change, FW update, etc), and then serve and classify data by security level using standard Syslog data format. This will enable integration with established SEM (Security Event Management) systems.

146

• Ethernet Global Data (EGD) • IEC 60870-5-103 and IEC 60870-5-104 • Modbus RTU, Modbus TCP/IP • HTTP, TFTP, SFTP and MMS file transfer • SNTP and IEEE 1588 for time synchronization • PRP as per IEC 62439-3

Interoperability with Embedded IEC 61850 Edition 2 The new IEC 61850 implementation in the UR Family positions GE as an industry leader in this standard. • Implements Edition 2 of the standard across the entire family of UR devices • Provides full relay setting management via standard SCL files (ICD, CID and IID) • Enables automated relay setting management using 3rd party tools through standard file transfer services (MMS and SFTP) • Increases the number of Logical Devices and data mapped to them, GOOSE messages, and reports to support different organizational needs for data transfer and reduce dependency on generic logical nodes • Configures GE Systems based on IEC 61850 using universal 3rd party tools • Multicast IEEE C37.118 synchrophasor data between PMU and PDC devices using IEC 91850-90-5

LAN Redundancy Substation LAN redundancy has been traditionally accomplished by reconfiguring the active network topology in case of failure. Regardless of the type of LAN architecture (tree, mesh, etc), reconfiguring the active LAN requires

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time to switchover, during which the LAN is unavailable. UR devices deliver redundancy as specified by PRP-IEC 62439-3, which eliminates the dependency on LAN reconfiguration and the associated switchover time. The UR becomes a dual attached node that transmits data packets over both main and redundant networks simultaneously, so in case of failure, one of the data packets will reach the receiving device with no time delay.

Multi-Language UR devices support multiple languages: English, French, Russian, Chinese, Turkish and German. These language options are available on the front panel, in the EnerVista setup software, and in the product manuals. Easily switch between English and an additional language on the local displays without uploading new firmware.

EnerVista Software The EnerVista suite is an industry-leading set of software programs that simplifies every aspect of using the L90 relay. The EnerVista suite provides all the tools to monitor the status of the protected asset, maintain the relay, and integrate information measured by the L90 into DCS or SCADA monitoring systems. Convenient COMTRADE and SOE viewers are an integral part of the UR setup software included with every UR relay, to carry out postmortem event analysis and ensure proper protection system operation.

EnerVista Launchpad EnerVista Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining Multilin products. The setup software within Launchpad allows for the configuration of devices in real-time by communicating via serial, Ethernet, or modem connections, or offline by creating setting files to be sent to devices at a later time. Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed. Documents made available include: • Manuals & Brochures • Application Notes • Guideform Specifications • Wiring Diagrams • FAQ’s • Service Bulletins

L90 Line Differential System

Viewpoint Monitoring

Typical Wiring

Viewpoint Monitoring is a simple-to-use and full-featured monitoring and data recording software package for small systems. Viewpoint Monitoring provides a complete HMI package with the following functionality:

A

B

C

52

• Plug-&-Play Device Monitoring • System Single-Line Monitoring & Control

N

Transmission Protection

• Annunciator Alarm Screens F8a

F8c VX

VX

F7a

F7c VC

VC

VB

F6a

VA

F6c

F5a

F5c

VA

VB

F4b

F4a

F4c

F3c

IG5

IG1

F3b IC

IC1

IG

F2c

F3a

F2a

F2b IB

IB1

F1c IA1

IB5

IC5

F1a

F1b IA

• Automatic Event Retrieval

IA5

OPTIONAL

• Trending Reports • Automatic Waveform Retrieval

8L

Viewpoint UR Engineer

H5a H5c H6a H6c H5b

Viewpoint UR Engineer is a set of powerful tools that will allow the configuration and testing of GE relays at a system level in an easy-touse graphical drag-and-drop environment . Viewpoint UR Engineer provides the following configuration and commissioning utilities:

H1

H3

SURGE

U7a U7c U8a U8c U7b

U1

I

U3

Multilin

U5

6K 6D

N3

N5

N6

L7a L7c L8a L8c L7b L8b

EnerVista Integrator

N7

SURGE

FIBER

CRITICAL FAILURE

6C

Rx1 Rx2

INTER-RELAY COMMS. W7A

Tx1 Tx2

FIBER

B1b B1a B2b B3a B3b B5b HI B6b LO B6a B8a B8b

DC

N8

RS-232

S1a S1b S1c S2a S2b S2c S3a S3b S3c S4a S4b S4c S5a S5b S5c S6a S6b S6c S7a S7b S7c S8a S8b S8c

S1

DB-9 (front)

1

TO REMOTE L90

N1a N1b N1c N2a N2b N2c N3a N3b N3c N4a N4b N4c N5a N5b N5c N6a N6b N6c N7a N7b N7c N8a N8b N8c

N1

N4

L5a L5c L6a L6c L5b

• Single-Click Fault Data Retrieval

V

N2

L3a L3c L4a L4c L3b

• Device Health Report

V I

U6

L1a L1c L2a L2c L1b

• Settings Security Audit Report

V I

L90

Viewpoint Maintenance provides tools that will create reports on the operating status of the relay, simplify the steps to download fault and event data, and reduce the work required for cyber security compliance audits. Tools available in Viewpoint Maintenance include:

S2

S3

OUTPUT CONTROL POWER

S4

SURGE FILTER

S5

S6 Fibre * Optic

Tx1

10BaseFL

NORMAL

Rx1

• OPC/DDE Server

Tx2

10BaseFL Rx2

Shielded

S7 COM 1

ALTERNATE

S8

10BaseT

Remote Device

D1a D2a D3a D4b D4a

• Automatic Event Retrieval

UR TXD RXD

SGND

1 2 3 4 5 6 7 8 9

CONNECTOR

COMPUTER

1 2 3 4 5 6 7 8 9

8 3 RXD 2 TXD 20 7 SGND 6 4 5 22

CONNECTOR

PERSONAL COMPUTER

RS485 com

IRIG-B Input

BNC

Co-axial

IRIG-B Output

BNC

Co-axial

The L90 front panel provides extensive local HMI capabilities. The local display is used for monitoring, status messaging, fault diagnosis, and device configuration. User-configurable messages that combine text with live data can be displayed when user-defined conditions are met.

V I

U4

Viewpoint Maintenance

User Interface

V

SURGE

TC 2

U1a U1b U1c U2a U2b U2c U3a U3b U3c U4a U4b U4c U5a U5b U5c U6a U6b U6c

V I

U2

U8b

• Graphical System Monitor

• Automatic Waveform Retrieval

V I

6H

• Graphical Logic Monitor

• Multilin Drivers

V I

H4

• Graphical System Designer

EnerVista Integrator is a toolkit that allows seamless integration of Multilin devices into new or existing automation systems. Included in EnerVista Integrator is:

V I

H8b

• Graphical Logic Designer

V I

H2

H7a H7c H8a H8c H7b

TC 1

H1a H1b H1c H2a H2b H2c H3a H3b H3c H4a H4b H4c

I

6G

minimum

X W PROVIDED

V

U

T

S

7 6 6 Inputs/ Inputs/ COM outputs outputs * *

R

P

N

M

L

6 6 Inputs/ Inputs/ outputs outputs * *

K

H G

J

F

D

B

6

8

9

1

Inputs/ outputs

CT/VT

CPU

Power supply

L90-H00-HCL-F8F-H6G-L6D-N6K-S6C-U6H-W7A

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147

Ordering L90 - * 00 - H * * - F ** - H ** - L ** - N ** - S ** - U ** - W/X ** For Horizontal Mount Base Unit L90 Base Unit CPU E RS485 + RS485 (IEC 61850 option not available) J RS485 + multimode ST 100BaseFX K RS485 + multimode ST Redundant 100BaseFX N RS485 + 10/100 BaseT T RS485 + three multimode SFP LC 100BaseFX. Requires FW v7xx or higher U RS485 + two multimode SFP LC 100BaseFX + one SFP RJ45 100BaseT. Requires FW v7xx or higher V RS485 + three SFP RJ45 100BaseT. Requires FW v7xx or higher Software Options 00 No Software Options (see note 2) 02 Breaker and Half software 03 IEC 61850 05 Breaker and Half + IEC 61850 06 Phasor Measurement Unit (PMU) 07 IEC 61850 + Phasor Measurement Unit (PMU) 08 Breaker & Half + Phasor Measurement Unit (PMU) 09 Breaker & Half + IEC 61850 + Phasor Measurement Unit (PMU) 24 In-zone TX protection 25 In-zone TX protection + IEC 61850 26 In-zone TX protection + PMU 27 In-zone TX protection + IEC 61850 + PMU A0 CyberSentry UR Lvl 1. Requires UR FW 7.xx or higher B0 IEEE 1588. Requires UR FW 7.xx or higher C0 PRP D0 IEEE 1588 + CyberSentry UR Lvl 1. Requires UR FW 7.xx or higher M0 IEC 61850 + PMU + 61850-90-5 Mount / Coating H Horizontal (19" rack) - Standard A Horizontal (19" rack) - Harsh Chemical Environment Option V Vertical (3/4 size) - Standard B Vertical (3/4 size) - Harsh Chemical Environment Option User Interface F Vertical Front Panel with English Display I Enhanced German Front Panel J Enhanced German Front Panel with User-Programmable Pushbuttons K Enhanced English Front Panel L Enhanced English Front Panel with User-Programmable Pushbuttons M Enhanced French Front Panel N Enhanced French Front Panel with User-Programmable Pushbuttons Q Enhanced Russian Front Panel T Enhanced Russian Front Panel with User-Programmable Pushbuttons U Enhanced Chinese Front Panel V Enhanced Chinese Front Panel with User-Programmable Pushbuttons W Enhanced Turkish Front Panel Y Enhanced Turkish Front Panel with User-Programmable Pushbuttons Power Supply H 125 / 250 V AC/DC (see note 3) H RH 125/250 V AC/DC with redundant 125/250 V AC/DC L 24 - 48 V (DC only) CT/VT DSP 8L 8L Standard 4CT/4VT w/ enhanced diagnostics 8N 8N Standard 8CT w/ enhanced diagnostics IEC 61850 Process Bus 81 8 Port IEC 61850 Process Bus Module Digital I/O XX XX XX XX XX No Module 4A 4A 4A 4A 4A 4 Solid State (No Monitoring) MOSFET Outputs 4C 4C 4C 4C 4C 4 Solid State (Current w/opt Voltage) MOSFET Outputs 4D 4D 4D 4D 4D 16 Digital Inputs with Auto-Burnish 4L 4L 4L 4L 4L 14 Form-A (No Monitoring) Latchable Outputs 67 67 67 67 67 8 Form-A (No Monitoring) Outputs 6C 6C 6C 6C 6C 8 Form-C Outputs 6D 6D 6D 6D 6D 16 Digital Inputs 6E 6E 6E 6E 6E 4 Form-C Outputs, 8 Digital Inputs 6F 6F 6F 6F 6F 8 Fast Form-C Outputs 6K 6K 6K 6K 6K 4 Form-C & 4 Fast Form-C Outputs 6L 6L 6L 6L 6L 2 Form-A (Current w/ opt Voltage) & 2 Form-C Outputs, 8 Digital Inputs 6M 6M 6M 6M 6M 2 Form-A (Current w/ opt Voltage) & 4 Form-C Outputs, 4 Digital Inputs 6N 6N 6N 6N 6N 4 Form-A (Current w/ opt Voltage) Outputs, 8 Digital Inputs 6P 6P 6P 6P 6P 6 Form-A (Current w/ opt Voltage) Outputs, 4 Digital Inputs 6R 6R 6R 6R 6R 2 Form-A (No Monitoring) & 2 Form-C Outputs, 8 Digital Inputs 6S 6S 6S 6S 6S 2 Form-A (No Monitoring) & 4 Form-C Outputs, 4 Digital Inputs 6T 6T 6T 6T 6T 4 Form-A (No Monitoring) Outputs, 8 Digital Inputs 6U 6U 6U 6U 6U 6 Form-A (No Monitoring) Outputs, 4 Digital Inputs 6V 6V 6V 6V 6V 2 Form-A (Cur w/ opt Volt) 1 Form-C Output, 2 Latching Outputs, 8 Digital Inputs Transducer I/O 5A 5A 5A 5A 5A 4 dcmA Inputs, 4 dcmA Outputs 5F 5F 5F 5F 5F 8 dcmA Inputs Inter-Relay Communications 2B C37.94SM, 1300nm singlemode, ELED, 2 Channel singlemode 2I Channel 1 - IEEE C37.94, 820nm, multimode fiber, 64/128 kbps; Channel 2 - 1300 nm, singlemode, LASER 2J Channel 1 - IEEE C37.94, 820nm, multimode fiber, 64/128 kbps; Channel 2 - 1550 nm, singlemode, LASER 7A 820 nm, multimode, LED, 1 Channel 7B 1300 nm, multimode, LED, 1 Channel 7C 1300 nm, singlemode, ELED, 1 Channel 7H 820 nm, multimode, LED, 2 Channels 7I 1300 nm, multimode, LED, 2 Channels 7J 1300 nm, singlemode, ELED, 2 Channels 7S G.703, 2 Channels 7V RS422, 2 Channels, Dual Clock 7W RS422, 2 Channels 73 1550 nm, singlemode, LASER, 2 Channel 76 IEEE C37.94, 820 nm, multimode, LED, 1 Channel 77 IEEE C37.94, 820 nm, multimode, LED, 2 Channel

Ordering Notes: 1. For vertical mounting order codes, please visit our online store 2. T o view all the options available for L90, please visit GE’s On-Line Store http://store.gedigitalenergy.com/viewprod.asp?model=L90 3. R  edundant power supply only available in horizontal unit. If redundant is chosen, must be same type. Maximum 2 per chassis.

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12589E(E) English 150121

Multilin™ L60 Sub-Cycle Phase Comparison and Distance Protection The Multilin L60 is an advanced sub-cycle phase comparison relay intended for application on overhead transmission lines, including series compensated lines, and underground cables of different voltage levels. Two and three-terminal lines can be protected easily by interfacing to new or existing power line carrier equipment. The Multilin L60 also has built-in interfaces to support communication channels of various types between line terminals. Part of the Universal Relay (UR) family, the Multilin L60 comes with a variety of versatile features, truly integrating protection, monitoring, metering, communication and control in one easy-to-use device. The UR family offers a high degree of modularity in its design and functionality, providing superior performance in protection and control, while meeting the toughest requirements of the marketplace.

Key Benefits • Fast and secure phase comparison protection with a typical tripping time of ¾ of a power cycle • End-to-end communication over power line carrier provides cost-effective solution • Advanced algorithms for channel noise immunity, accurate per-channel signal asymmetry, charging current compensation and channel delay compensation • Advanced IEC 61850 Ed. 2 implementation, and complete settings via SCL files enable resource and platform managing optimization and reduce cost of ownership • CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog) • Advanced fault and disturbance recording, including internal relay operating signals, eliminating the need for external recording devices

Applications • Short and long overhead lines and cables of different voltage levels • Suitable for two and three-terminal lines • Circuits with tapped transformer feeders • Implicit Direct Transfer Trip (DTT) for breaker failure applications

Protection and Control • Single or dual-phase comparison with permissive and blocking schemes • Multiple phase, ground, neutral and negative sequence instantaneous and timed overcurrent elements • 3-Zone phase and ground distance elements • Phase & negative sequence directional overcurrent, neutral directional with dual polarity criteria and thermal overload • Single-pole, dual breaker autoreclose with synchronism check

Advanced Communications • 3 independent Fiber or Copper Ethernet ports for simultaneous & dedicated network connections with IEEE 1588 support • Supported industry protocols: IEC 61850 Ed. 2, SFTP, MMS File Transfer Service, DNP 3.0, Modbus Serial/TCP, IEEE 1588, IEC 60870‑5‑104 and 103, PRP, SNTP, HTTP, TFTP

Cyber Security • CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog)

Monitoring & Metering • Breaker condition monitoring including breaker arcing current (I2t) and trip counter • Fault locator • Advanced recording capabilities with highcapacity event recorder, configurable and extended waveform capture and data logger

L60 Line Phase Comparison System

Protection and Control

L60 - Protection, Metering, Monitoring and Control

Trasmission Protection

As part of the UR family of Protection & Control devices, the Multilin L60 Line Phase Comparison System offers a high degree of modularity in its design and functionality, providing superior performance while meeting the toughest requirements of the marketplace. Advanced protection and control features of this relay includes:

Phase Comparison The phase comparison function can be used for protecting two or three-terminal lines including terminals with breaker-and-a-half configurations. The L60 can be configured for single or dual-phase comparison schemes according to the communication equipment employed, requirements of trip speed and reliability. The L60 combines the advantages of the modern digital relay with the traditional analog phase comparison principle. Pulses received are digitally sampled at 64 samples per cycle, providing excellent resolution. Channel asymmetry settings can adjust distorted received pulses, including those

The L60 is the single point for protection, control, metering, and monitoring in one integrated device that can easily be connected directly into DCS or SCADA monitoring and control systems.

Fault Detectors

that are not equal to half a sine wave. All phase comparison signals are captured and available in oscillography for commissioning, troubleshooting, and analysis purposes.

The L60 employs multiple fault detectors to initiate phase comparison and ensures that all fault types are detected quickly and reliably.

Functional Block Diagram 52

Monitoring

79

TRIP

CLOSE

50DD 50P(4) 50_2(2) 51P(4) 51_2(2) 50BF(2) 87PC

49(2)

21P(3)

67N/G(2)

Data From/To Remote End (via Communications)

67_2(2)

68

FlexElement

78

TM

51N(4)

50N(4)

Metering

67P(2)

Transducer Inputs

21G(3)

27P(3) 59P(3)

50G(4)

51G(4)

59X

27X

59N(3) 25(4)

L60 Line Phase Comparison System

ANSI Device Numbers & Functions ®

DEVICE NUMBER

FUNCTION

DEVICE NUMBER

FUNCTION

21G 21P 25 27P 27X 32N 49 50BF 50DD 50G

Phase Distance Ground Distance Synchrocheck Phase Undervoltage Auxiliary Undervoltage Wattmetric Zero-Sequence Directional Thermal Overload Breaker Failure Current Disturbance Detector Ground Instantaneous Overcurrent

50N 50P 50_2 51G 51N 51P 51_2 52 59N 59P

Neutral Instantaneous Overcurrent Phase Instantaneous Overcurrent Negative Sequence Instantaneous Overcurrent Ground Time Overcurrent Neutral Time Overcurrent Phase Time Overcurrent Negative Sequence Time Overcurrent AC Circuit Breaker Neutral Overvoltage Phase Overvoltage

150

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DEVICE NUMBER

FUNCTION

59X 67N 67P 67_2 68 78 79 87PC

Auxiliary Overvoltage Neutral Directional Overcurrent Phase Directional Overcurrent Negative Sequence Directional Overcurrent Power Swing Blocking Out-of-Step Tripping Autoreclose Phase Comparison

L60 Line Phase Comparison System

• Overcurrent starters based on low and high set overcurrent elements. • Negative-sequence overvoltage element starter meant to detect faults under weak system conditions.

• Rate of change of the positive-sequence current element to detect three-phase balance faults under high load conditions. All fault detectors operate independently from each other and each detector supports low and high setting levels to facilitate starting and supervise tripping.

Charging Current Compensation For long transmission lines and underground cables, the charging current may be large and result in excessively high pickup settings. The L60 can dynamically compensate for the line charging current thus increasing its sensitivity to the fault current on long transmission lines.

Open Breaker Echo The open breaker echo feature enables proper operation of the phase comparison scheme for an internal fault during a terminal open condition or weak infeed at one end of the faulted line.

Signaling Channel Typical channels used for the communications link between two or three L60s include AM and FSK Power Line Carrier (PLC), FSK microwave, and multiplexed fiber optic. The L60 features excellent stability during channel noise due to the high sampling rate of the received signal, and the unique integrator makes the digital phase-comparison relay fully equivalent to analog phase comparison relays.

Line Pickup (Switch-on-to-Fault) The line pickup feature uses a combination of undercurrent and undervoltage to identify a line that has been de-energized (line end open). Three instantaneous overcurrent elements are used to identify a previously de-energized line that has been closed on to a fault.

Distance Protection Separate high-speed phase and ground distance elements are provided for optimal supervision with tapped transformers and as

modes are available, enabling users to select the reclosing mode best-suited to specific applications.

Undervoltage and Overvoltage Protection

Multiple Breaker

Long lines under lightly loaded or no-load conditions may experience voltages exceeding rated per unit voltage level of the line. Use the three-phase overvoltage elements of the L60 to initiate a local trip as well as a remote trip. The L60 also provides additional voltage functions including neutral overvoltage, negative sequence overvoltage and phase undervoltage.

The L60 supports multi-breaker busbar configurations such as breaker-and-a-half or ring bus arrangements, providing dual breaker autoreclose, dual synchrocheck elements, and dual independent breaker failure elements. The design provides secure operation during external faults with possible CT saturation.

Overcurrent Functions The L60 provides thermal overload and overcurrent functions for phase, neutral and ground, which can run parallel with the primary phase compensation element or can be programmed to provide primary protection under conditions when the phase compensation element is not available. • Instantaneous and timed overcurrent elements for phase, neutral, ground and negative sequence protection • Directional supervision is available for phase neutral and negative sequence elements • Time O/C elements can individually be set to use IEEE, IEC or user-defined FlexCurvesTM for best coordination

Single-Pole Tripping The L60 relay uses a state-of- the-art dual phase selection algorithm that provides fast and accurate fault type identification even under weak infeed conditions.

Autoreclosing The L60 provides multi-shot autoreclosing (up to 4 shots) for single or three-pole autoreclose on all types of faults with independent settings for each shot. Any of the autoreclose elements can be dynamically blocked or unblocked by other elements or user logic. This way they can be coordinated with the L60 protection setting groups. Four different autoreclose operation

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Synchronism Check The L60 provides four synchrocheck elements that monitor voltage difference, phase angle difference and slip frequency to ensure proper breaker closure as per user requirements. The L60 provides additional enhancements in synchronizing by the detection of dead source conditions for synchronism bypass under these conditions.

Breaker Failure The L60 is able to provide fully independent breaker failure protection for the breakers associated with a line when connected to a substation that has a breaker-and-a-half or ring bus arrangement. The L60 provides the required elements to perform two independent breaker failure functions.

Advanced Automation The L60 incorporates advanced automation features including powerful FlexLogic programmable logic, communication, and SCADA capabilities that far surpass what is found in the average line differential relay. The L60 integrates seamlessly with other UR relays for complete system protection.

FlexLogic FlexLogic is the powerful UR-platform programming logic engine that provides the ability to create customized protection and control schemes, minimizing the need and associated costs of, auxiliary components and wiring. Using FlexLogic, the L60 can be programmed to provide the required tripping logic along with custom scheme logic for line breaker control and interlocking transfer tripping schemes for remote breakers and dynamic setting group changes.

151

Transmission Protection

• Rate of change of the negative-sequence current element to detect faults under load unbalance such as on un-transposed high voltage transmission lines or in a vicinity of electrical traction systems causing significant negative-sequence current unbalance.

backup during channel failures or unavailability. The backup distance functions in the L60 come with three zones of phase and ground distance (mho or quad). Dual distance algorithms deliver exceptional security and speed performance to ensure average operating times of 1.5 cycles for 75% line reach and SIR 30, and <2.5 cycles for 90% line reach and SIR 60. The phase distance elements come with built-in in-zone transformer compensation. The L60 also provides a load encroachment element, which supervises the distance elements under heavy line loading conditions.

L60 Line Phase Comparison System

Scalable Hardware The L60 is available with a multitude of I/O configurations to suit the most demanding application needs. The expandable modular design allows for easy configuration and future upgrades.

Trasmission Protection

• Flexible, modular I/O covering a broad range of input signals and tripping schemes • Types of digital outputs include triprated Form-A and Solid State Relay (SSR) mechanically latching, and Form-C outputs • Form-A and SSR outputs available with optional circuit continuity monitoring and current detection to verify continuity and health of the associated circuitry • Mechanically latching outputs can be used to develop secure interlocking applications and replace electromechanical lockout relays

the relay as a standard feature. Current and voltage parameters are available as total RMS magnitude, and as fundamental frequency magnitude and angle.

The advanced disturbance and event recording features within the L60 can significantly reduce the time needed for postmortem analysis of power system events and the creation of regulatory reports. Recording functions include:

The L60 performs comprehensive device health diagnostic tests at startup and continuously during run-time to test its own major functions and critical hardware. These diagnostic tests monitor for conditions that could impact security and availability of protection, and present device status via SCADA communications and front panel display. Providing continuous monitoring and early detection of possible issues help improve system uptime.

• Sequence of Event (SOE) - 1024 time stamped events

• Comprehensive device health diagnostic performed at startup

• Oscillography - 64 digital & up to 40 analog channels - Events with up to 45s length

• Monitors the CT/VT input circuitry to validate the integrity of all signals

• Data Logger and Disturbance Recording - 16 channels up to 1 sample/cycle/channel

Cyber Security – CyberSentry UR

Fault and Disturbance Recording

• Fault Reports - Powerful summary report of pre-fault and fault values

• DCmA inputs are available to monitor line temperature

Monitoring and Metering The L60 includes high accuracy metering and recording for all AC signals. Voltage, current , and power metering are built into

Advanced Device Health Diagnostics

The very high sampling rate and large amount of storage space available for data recording in the L60 can eliminate the need for installing costly stand-alone recording equipment.

CyberSentry UR enabled UR devices deliver full cyber security features that help customers to comply with NERC CIP and NIST® IR 7628 cyber security requirements. This software option delivers the following core features:

Power System Troubleshooting The L60 contains many tools and reports that simplify and reduce the amount of time required for troubleshooting power system events.

Record the operation of the internal L60 elements and external connected devices with 1ms time-stamped accuracy to identify the Sequence of Operation of station devices during line faults and disturbances.

152

Analyze line faults using both analog and digital power system quantities that are measured and recorded up to a rate of 64 samples per cycle.

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Graphically view zone settings for ground phase distance elements for the selected zones and the power swing detection element.

L60 Line Phase Comparison System

AAA Server Support (Radius/LDAP)

Transmission Line Status Monitoring

Enables integration with centrally managed authentication and accounting of all user activities and uses modern industry best practices and standards that meet and exceed NERC CIP requirements for authentication and password management.

Role Based Access Control (RBAC) Transmission Protection

Efficiently administrate users and roles within UR devices. The new and advanced access functions allow users to configure up to five roles for up to eight configurable users with independent passwords. The standard “Remote Authentication Dial In User Service” (Radius) is used for authentication.

Event Recorder (Syslog for SEM) Capture all cyber security related events within a SOE element (login, logout, invalid password attempts, remote/local access, user in session, settings change, FW update, etc), and then serve and classify data by security level using standard Syslog data format. This will enable integration with established SEM (Security Event Management) systems.

Communications The L60 provides for secure remote data and engineering access, making it easy and flexible to use and integrate into new and existing infrastructures. Fiber optic Ethernet provides high-bandwidth communications allowing for low-latency controls and high-speed file transfers of relay fault and event record information. The available three independent Ethernet ports, redundant Ethernet option and the embedded managed Ethernet switch provide the means to create fault tolerant communication architectures in an easy, costeffective manner. The L60 supports the most popular industry standard protocols enabling easy, direct integration into monitoring and SCADA systems.

Monitor each L60 individually using the easy-to-use Viewpoint Monitoring HMI.

Interoperability with Embedded IEC 61850 Edition 2 The new IEC 61850 implementation in the UR Family positions GE as an industry leader in this standard. • Implements Edition 2 of the standard across the entire family of UR devices • Provides full relay setting management via standard SCL files (ICD, CID and IID) • Enables automated relay setting management using 3rd party tools through standard file transfer services (MMS and SFTP) • Increases the number of Logical Devices and data mapped to them, GOOSE messages, and reports to support different organizational needs for data transfer and reduce dependency on generic logical nodes • Configures GE Systems based on IEC 61850 using universal 3rd party tools

• IEC 61850 Ed. 2 with 61850-9-2 support

Direct I/O Messaging

• DNP 3.0 (serial & TCP/IP)

Direct I/O allows for the sharing of high-speed digital information between multiple UR relays via direct back-to-back connections or multiplexed through a standard DS0 multiplexer channel bank. Regardless of the connection method, direct I/O provides continuous real-time channel monitoring that supplies diagnostics information on channel health.

• Ethernet Global Data (EGD) • IEC 60870-5-103 and IEC 60870-5-104 • Modbus RTU, Modbus TCP/IP • HTTP, TFTP, SFTP and MMS file transfer • SNTP and IEEE 1588 for time synchronization • PRP as per IEC 62439-3

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Direct I/O provides superior relay-to-relay communications that can be used in advanced interlocking, generation rejection and other special protection schemes. • Communication with up to 16 UR relays in single or redundant rings rather than strictly limited to simplistic point-to-point configurations between two devices • Connect to standard DS0 channel banks through standard RS422, G.703 or IEEE C37.94 interfaces or via direct fiber optic connections • No external or handheld tester required to provide channel diagnostic information

LAN Redundancy Substation LAN redundancy has been traditionally accomplished by reconfiguring the active network topology in case of failure. Regardless of the type of LAN architecture (tree, mesh, etc), reconfiguring the active LAN requires time to switchover, during which the LAN is unavailable. UR devices deliver redundancy as specified by PRP-IEC 62439-3, which eliminates the dependency on LAN reconfiguration and the associated switchover time. The UR becomes a dual attached node that transmits data packets over both main and redundant networks simultaneously, so in case of failure, one of the data packets will reach the receiving device with no time delay.

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L60 Line Phase Comparison System

Multi-Language

Trasmission Protection

UR devices support multiple languages: English, French, Russian, Chinese, Turkish and German. These language options are available on the front panel, in the EnerVista setup software, and in the product manuals. Easily switch between English and an additional language on the local displays without uploading new firmware.

EnerVista Software The EnerVista suite is an industry-leading set of software programs that simplifies every aspect of using the L60 relay. The EnerVista suite provides all the tools to monitor the status of the protected asset, maintain the relay, and integrate information measured by the L60 into DCS or SCADA monitoring systems. Convenient COMTRADE and SOE viewers are an integral part of the UR setup software included with every UR relay, to carry out postmortem event analysis and ensure proper protection system operation.

EnerVista Launchpad EnerVista Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining GE Multilin products. The

setup software within Launchpad allows for the configuration of devices in real-time by communicating using serial, Ethernet , or modem connections, or offline by creating setting files to be sent to devices at a later time. Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed. Documents made available include:

• Plug-&-Play Device Monitoring • System Single-Line Monitoring & Control • Annunciator Alarm Screens • Trending Reports • Automatic Event Retrieval • Automatic Waveform Retrieval

Viewpoint UR Engineer

• Brochures

Viewpoint UR Engineer is a set of powerful tools that allows the configuration and testing of GE relays at a system level in an easy-touse graphical drag-and-drop environment . Viewpoint UR Engineer provides the following configuration and commissioning utilities:

• Wiring Diagrams

• Graphical Logic Designer

• FAQ’s

• Graphical System Designer

• Service Bulletins

• Graphical Logic Monitor

Viewpoint Monitoring

• Graphical System Monitor

Viewpoint Monitoring is a simple-to-use and full-featured monitoring and data recording software package for small systems. Viewpoint Monitoring provides a complete HMI package with the following functionality:

Viewpoint Maintenance

• Manuals • Application Notes • Guideform Specifications

Viewpoint Maintenance provides tools that will create reports on the operating status of the relay, simplify the steps to download fault and event data, and reduce the work required for cyber security compliance audits. Tools available in Viewpoint Maintenance include: • Settings Security Audit Report • Device Health Report

Security Audit

• Single-Click Fault Data Retrieval

EnerVista Integrator EnerVista Integrator is a toolkit that allows seamless integration of GE Multilin devices into new or existing automation systems. Included in EnerVista Integrator is: • OPC/DDE Server • GE Multilin Drivers • Automatic Event Retrieval • Automatic Waveform Retrieval

User Interface The L60 front panel provides extensive local HMI capabilities. The local display is used for monitoring, status messaging, fault diagnosis, and device configuration. User-configurable messages that combine text with live data can be displayed when user-defined conditions are met.

Access the security report of L60 to audit the changes made to the settings or configurations.

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L60 Line Phase Comparison System

Typical Wiring A

Optional

B

52

52

C

8P

L7 c

L8a

VC

VX

8F

V I

H2

H7a H7c H8a H8c H7b

V I

H3

V I

H4 SURGE

U7a U7c U8a U8c U7b

V

6H V

I

U2

U8b

V

SURGE

I

U3

6D

S1a S1c S2a S2c S1b

V I

U4

V I

S3a S3c S4a S4c S3b

U5

V I

U6

S5a S5c S6a S6c S5b S7a S7c S8a S8c S7b S8b

N1a N1b N1c N2a N2b N2c N3a N3b N3c N4a N4b N4c N5a N5b N5c N6a N6b N6c N7a N7b N7c N8a N8b N8c

Multilin SURGE

B1b B1a B2b B3a B3b B5b B6b B6a B8a B8b

L60

CRITICAL FAILURE OUTPUT HI LO

CONTROL POWER SURGE FILTER

Fibre * Optic

TC 2

U1a U1b U1c U2a U2b U2c U3a U3b U3c U4a U4b U4c U5a U5b U5c U6a U6b U6c

I

U1

TC 1

H1a H1b H1c H2a H2b H2c H3a H3b H3c H4a H4b H4c

I

H1

V

N1

6C

6G

H8b

L8 c

L6c

L7a

VB

RECEIVE

H5a H5c H6a H6c H5b

DC

VC

L5c

L6a VB

L5a VA

VA

L4 c IG1

L4a

L4b

IG5

IG

L3b

L3 c

IC

IC1

L2c

L3a

IB1

IB

IC5

L2a

L2b

IB5

L1b

L1 c

IA

IA 1

F8 c

L1a IA5

F8b

Rx2P

F7 c

F8a Rx2N

BAT T-

F7b BAT T+

Tx2P

F6 c

F7a

Rx1N

Tx2N

F5 c

F6a

Tx1P

F6b

F5b BAT T+

BAT T-

F4c

F5a Tx1N

F4b IG

IG1

F3 c

F4a IG5

F3b IC

IC1

F2 c

F3 a IC5

F2b IB

IB1

F1 c

F2a

IA 1

IA

IB5

F1a

F1b

IA 5

Rx1P

TRANSMIT

C

Transmission Protection

RECEIVE

TRANSMIT

B

VX

A

CURRENT POLARIZATION SOURCE

N2

N3

N4 UR

N5

TXD RXD

N6 SGND

N7

1 2 3 4 5 6 7 8 9

10BaseFL Rx1

Tx2

10BaseFL Rx2

Shielded

D1a D2a D3a D4b D4a

ALTERNATE

COM 1

RS-232 DB-9

RS485

BNC

Co-axial

BNC

CONNECTOR

(front) PERSONAL COMPUTER

com

Co-axial

8 3 RXD 2 TXD 20 7 SGND 6 4 5 22

NORMAL

10BaseT

Remote Device

1 2 3 4 5 6 7 8 9

N8 CONNECTOR

Tx1

COMPUTER

IRIG-B Input IRIG-B Output

minimum

PROVIDED

X W

V

U

T

S

6 6 Inputs/ Inputs/ outputs outputs * *

R

P

N

M

L

6 6 Inputs/ Inputs/ outputs outputs * *

K

H G

J

F

D

L60-H00-HCL-F8P-H6G-L6D-N6K-S6C-U6H-W7Z

B

6

8

9

1

Inputs/ outputs

CT/VT

CPU

Power supply

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Ordering

L60 - * 00 - H * * - F ** - H ** - L ** - N ** - S ** - U ** - W/X ** For Full Sized Horizontal Mount

Base Unit L60 Base Unit CPU E RS485 + RS485 (IEC 61850 option not available) J RS485 + multimode ST 100BaseFX K RS485 + multimode ST Redundant 100BaseFX N RS485 + 10/100 BaseT T RS485 + three multimode SFP LC 100BaseFX. Req FW v7xx or higher U RS485 + two multimode SFP LC 100BaseFX + one SFP RJ45 100BaseT. Req FW v7xx or higher V RS485 + three SFP RJ45 100BaseT. Req FW v7xx or higher Software 00 No Software Options (see note 1 below) 03 IEC 61850 A0 CyberSentry UR Lvl 1. Req UR FW 7.xx or higher B0 IEEE 1588. Req UR FW 7.xx or higher C0 PRP D0 IEEE 1588 + CyberSentry. Req UR FW 7.xx or higher Mount / Coating H Horizontal (19" rack) - Standard A Horizontal (19" rack) - Harsh Chemical Environment Option V Vertical (3/4 size) - Standard B Vertical (3/4 size) - Harsh Chemical Environment Option User Interface F Vertical Front Panel with English Display I Enhanced German Front Panel J Enhanced German Front Panel with User-Programmable Pushbuttons K Enhanced English Front Panel L Enhanced English Front Panel with User-Programmable Pushbuttons M Enhanced French Front Panel N Enhanced French Front Panel with User-Programmable Pushbuttons Q Enhanced Russian Front Panel T Enhanced Russian Front Panel with User-Programmable Pushbuttons U Enhanced Chinese Front Panel V Enhanced Chinese Front Panel with User-Programmable Pushbuttons W Enhanced Turkish Front Panel Y Enhanced Turkish Front Panel with User-Programmable Pushbuttons Power Supply H 125 / 250 V AC/DC (see note 2 below) H RH 125/250 V AC/DC with redundant 125/250 V AC/DC L 24 - 48 V (DC only) CT/VT DSP 8P 8F L60 DSP 4CT & 2 Comms Channels + Standard 4CT/4VT (Breaker and Half) 8L Standard 4CT/4VT w/ enhanced diagnostics Digital I/O XX XX XX XX No Module 4A 4A 4A 4A 4 Solid State (No Monitoring) MOSFET Outputs 4C 4C 4C 4C 4 Solid State (Current w/opt Voltage) MOSFET Outputs 4D 4D 4D 4D 16 Digital Inputs with Auto-Burnish 4L 4L 4L 4L 14 Form-A (No Monitoring) Latchable Outputs 67 67 67 67 8 Form-A (No Monitoring) Outputs 6C 6C 6C 6C 8 Form-C Outputs 6D 6D 6D 6D 16 Digital Inputs 6E 6E 6E 6E 4 Form-C Outputs, 8 Digital Inputs 6F 6F 6F 6F 8 Fast Form-C Outputs 6K 6K 6K 6K 4 Form-C & 4 Fast Form-C Outputs 6L 6L 6L 6L 2 Form-A (Current w/ opt Voltage) & 2 Form-C Outputs, 8 Digital Inputs 6M 6M 6M 6M 2 Form-A (Current w/ opt Voltage) & 4 Form-C Outputs, 4 Digital Inputs 6N 6N 6N 6N 4 Form-A (Current w/ opt Voltage) Outputs, 8 Digital Inputs 6P 6P 6P 6P 6 Form-A (Current w/ opt Voltage) Outputs, 4 Digital Inputs 6R 6R 6R 6R 2 Form-A (No Monitoring) & 2 Form-C Outputs, 8 Digital Inputs 6S 6S 6S 6S 2 Form-A (No Monitoring) & 4 Form-C Outputs, 4 Digital Inputs 6T 6T 6T 6T 4 Form-A (No Monitoring) Outputs, 8 Digital Inputs 6U 6U 6U 6U 6 Form-A (No Monitoring) Outputs, 4 Digital Inputs Transducer I/O 5A 5A 5A 5A 4 dcmA Inputs, 4 dcmA Outputs 5F 5F 5F 5F 8 dcmA Inputs Inter-Relay Communications 2B 37.94SM, 1300nm singlemode, ELED, 2 Channel singlemode 2I Channel 1 - IEEE C37.94, 820nm, multimode fiber, 64/128 kbps; Channel 2 - 1300 nm, singlemode, LASER 2J Channel 1 - IEEE C37.94, 820nm, multimode fiber, 64/128 kbps; Channel 2 - 1550 nm, singlemode, LASER 7A 820 nm, multimode, LED, 1 Channel 7B 1300 nm, multimode, LED, 1 Channel 7C 1300 nm, singlemode, ELED, 1 Channel 7H 820 nm, multimode, LED, 2 Channels 7I 1300 nm, multimode, LED, 2 Channels 7J 1300 nm, singlemode, ELED, 2 Channels 7S G.703, 2 Channels 7W RS422, 2 Channels 73 1550 nm, singlemode, LASER, 2 Channels 77 IEEE C37.94, 820 nm, multimode, LED, 2 Channel

Ordering Note: 1 . To view all the options available for L60, please visit GE’s On-Line Store http://store.gedigitalenergy.com/viewprod.asp?model=L60 2. Redundant power supply only available in horizontal unit. If redundant is chosen, must be same type. Maximum 2 per chassis.

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12590P(E) English 150122

Multilin™ L30 Cost-Effective Current Differential System for Lines and Cables The Multilin L30 Line Differential System is a cost-effective line current differential protection relay intended for sub-transmission and medium voltage lines and cables, providing reliable and secure operation even under the worst-case power system conditions. The Multilin L30 provides secure highspeed fault detection and clearance suitable for three-pole tripping applications. Part of the Universal Relay (UR) family, the Multilin L30 comes with a variety of versatile features truly integrating protection, monitoring, metering, communication and control in one easy-to-use device.

Key Benefits • Proven current differential protection for secure, high-speed tripping • Increased sensitivity through dynamic charging current compensation and communication channel asymmetry compensation • Adaptive restraint characteristic provides security against measurement errors including CT saturation • Embedded Synchrophasor measurement capabilities (per IEEE® C37.118), eliminating the need for dedicated PMUs and support for synchrophasor multi-cast (per IEC® 61850-90-5) reducing bandwidth and communications infrastructure costs • Advanced IEC 61850 Ed. 2 implementation, complete settings via SCL files and IEC 61850-9-2 process bus solution enable resource and platform managing optimization and reduce cost of ownership • CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog) • Advanced fault and disturbance recording, including internal relay operating signals, eliminating the need for external recording devices

Applications • Overhead lines and underground cables of different voltage levels • Circuits with tapped transformer feeders • Suitable for three-terminal lines, with channel redundancy and Direct Transfer Tripping (DTT) • Wide area system monitoring and control using integrated protection and synchrophasor measurement • Applications requiring three-pole autoreclosing and independent synchrocheck supervision

Protection & Control • Line current differential with adaptive restraint. in-zone transformer & Stub bus protection • Breaker failure and three-pole autoreclose • Phase & negative sequence directional overcurrent, neutral directional with dual polarity criteria, broken conductor and thermal overload • Phase over/under voltage, negative sequence overvoltage and 4 independent synchronism check elements

Advanced Communications • 3 independent Ethernet ports with IEEE 1588 support • Advanced IEC 61850 Edition 2 implementation and IEC 61850-9-2 process bus support • Supported industry protocols: IEC 61850 Ed. 2, SFTP, MMS File Transfer Service, DNP 3.0, Modbus Serial/TCP, IEEE 1588, IEC 60870‑5‑104 and 103, PRP, SNTP, HTTP, TFTP • Direct I/O for secure, high-speed exchange of data between Multilin L30s for DTT applications

Cyber Security • CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog)

Monitoring & Metering • Advanced recording capabilities with highcapacity event recorder, configurable and extended waveform capture and data logger • P & M class synchrophasors of voltage, current, and sequence components

L30 Line Differential System

Protection and Control

L30 - Protection, Metering, Monitoring and Control

Trasmission Protection

The Multilin L30 offers a high degree of modularity in its design and functionality, providing superior performance while meeting the toughest requirements of the marketplace. Advanced protection and control features of this relay includes:

Current Differential Protection The L30 current differential protection relay uses superior and patented algorithms to address the challenges of bandwidth, security, dependability and sensitivity in current differential relaying. Bandwidth requirements are effectively addressed by means of a patented new data consolidation technique called “phaselets”. This permits application within a communications bandwidth of 64 Kbps, and can detect faults within a half cycle plus channel delay.

The L30 is the single point for protection, control, metering, and monitoring in one integrated device that can easily be connected directly into DCS or SCADA monitoring and control systems like Viewpoint Monitoring as shown.

Functional Block Diagram 52

79

Monitoring

CLOSE

TRIP

50DD 50P 50_2 51P 51_2 50BF 87L 50N 51N 2

2

2

2

2

2

Data From/To Remote End (via Dedicated Communications)

49 67P 67N 2

2

2

FlexElement

2

Metering

TM

Transducer Inputs

59_2 3

59P 3

50G

51G

2

2

27P 3

59X

27X

59N 25

L30 Line Differential System

4

ANSI Device Numbers & Functions ®

DEVICE NUMBER

FUNCTION

DEVICE NUMBER

FUNCTION

DEVICE NUMBER

FUNCTION

25 27P 27X 49 50BF 50DD 50G 59_2

Synchronism Check Phase Undervoltage Auxiliary Undervoltage Thermal Overload Breaker Failure Current Disturbance Detector Ground Instantaneous Overcurrent Negative Sequence Overvoltage

50P 50_2 51G 51N 51P 51_2 52 59_2

Phase Instantaneous Overcurrent Negative Sequence Instantaneous Overcurrent Ground Time Overcurrent Neutral Time Overcurrent Phase Time Overcurrent Negative Sequence Time Overcurrent AC Circuit Breaker Negative Sequence Overvoltage

59P 59X 67N 67P 79 81U 87L 87LG

Phase Overvoltage Auxiliary Overvoltage Neutral Directional Phase Directional Automatic Recloser Underfrequency Segregated Line Current Differential Line Ground Current Differential

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L30 Line Differential System

The L30 approach to clock synchronization relies upon precise distributed synchronization. Clocks are phase synchronized to each other and frequency synchronized to the power system frequency. Each relay compares its clock to the phase of the other clocks and makes appropriate adjustments. This allows for greater transient ride-through for power system and communications disturbances. Enhanced additional security is provided by a sensitive current disturbance detector, which can be used to supervise the current differential element.

Charging Current Compensation For long lines and especially for underground cables, the charging current may be large and result in excessively high pickup settings. The L30 can dynamically compensate the charging current, thus increasing its sensitivity to the fault current on long transmission lines.

Integrated channel monitoring provides realtime diagnostic data on the health of the L30. Communications channel deterioration or failure will activate an alarm, and can be used to enable backup protection. Channel propagation delay is monitored and adjusted according to variations in communication paths.

Communication Topologies Relays can communicate through direct fiber, RS422, G.703, and IEEE C37.94 interfaces at 64Kbps, with extensive channel monitoring and diagnostics. In a current differential scheme, the L30s exchange data via the communication link, acting either as master collecting data, making calculations and making all relevant trip and restraint decisions, or as slave only, transmitting current data to the one acting as master. For two-terminal applications, use the redundant communications capability of the L30 for optimal reliability of the current differential line protection. For this scheme, data is continuously transmitted over both channels, so if a failure occurs, the L30 will continue to provide current differential protection. For three-terminal applications, advanced interrelay communication features eliminate the need for redundant communication channels due to the ability of the L30 to automatically switch between master and slave mode, maintaining a dependable system even with a failure of one of the communication channels.

Enhanced Monitoring Features The L30 uses advanced error detection and supervising functions to secure the L30 against maloperation due to erroneous data. High bit error rates are addressed by means of computing a 32-bit CRC checksum, effectively addressing the concerns of multiple bit errors due to high channel noise.

Overvoltage and Undervoltage Protection Long lines under lightly loaded or no-load conditions may experience voltages exceeding rated per unit voltage level of the line. Use the three phase overvoltage elements of the L30 to initiate a local trip as well as a remote trip using Direct Transfer Tripping (DTT).

Overcurrent Functions The L30 provides thermal overload, and time and instantaneous overcurrent elements for phase, neutral, ground, negative sequence, phase and neutral directional. The neutral directional overcurrent element supports enhanced dual polarization modes which can be configured to prioritize on voltage or current polarization. Any of them can run in parallel with primary differential protection or can be programmed to run when the differential element is not available.

Direct Transfer Trip (DTT) Use the DTT feature of L30 to trip remote breakers. Both single and three-pole DTTs are supported. Up to eight signals can be sent over pilot communications channels, selectable through user-configurable logic.

Autoreclosing The L30 provides multi-shot autoreclosing for three-pole applications with independently programmable dead time for each shot . Autoreclose can be dynamically blocked by user-programmable logic.

Typical Applications

On multiplexed channels, channel asymmetry may be expected due to path switching causing spurious differential currents, which can endanger the security of the differential system. By using GPS time synchronization, up to 10ms of channel asymmetry can be compensated. Extra security has been implemented in the L30 to ensure proper operation in the event of IRIG-B signal failure.

Typical two-terminal application of L30. L30 supports a variety of media cards for signaling between L30’s including direct multimode or singlemode fiber, RS422, G.703 and IEEE C37.94.

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Transmission Protection

The L30 innovative dual slope adaptive restraint characteristic, based on estimates of measurement errors, allows the relay to be secure on severe external faults while maintaining sensitivity for internal faults. The estimate of errors in the input currents permits more sensitive settings than those used in the traditional percent differential schemes. The line differential element also has 2nd harmonic inrush-current inhibit for in-zone power transformer protection. This functionality enables the L30 to protect 2 or 3-terminal lines that have a power transformer in between ends.

L30 Line Differential System

FlexLogic Designer

Monitoring and Metering

Trasmission Protection

The L30 includes high accuracy metering and recording for all AC signals. Voltage, current , and power metering are built into the relay as a standard feature. Current and voltage parameters are available as total RMS magnitude, and as fundamental frequency magnitude and angle.

Fault and Disturbance Recording The advanced disturbance and event recording features within the L30 can significantly reduce the time needed for postmortem analysis of power system events and the creation of regulatory reports. Recording functions include: • Sequence of Event (SOE) - 1024 time stamped events FlexLogic allows for the customization of the L30 to operate and control the breakers and other auxiliary devices needed to fit most line protection schemes and applications.

• Oscillography - 64 digital & up to 40 analog channels - Events with up to 45s length

Synchronism Check

Visit the HardFiber System product page on the GE Multilin web site for more details.

• D  ata Logger and Disturbance Recording - 16 channels up to 1 sample/cycle/channel

Advanced Automation

• Fault Reports - Powerful summary report of pre-fault and fault values

The L30 provides four synchrocheck elements that monitor voltage difference, phase angle difference and slip frequency to ensure proper breaker closure as per user requirements. The L30 provides additional enhancements in synchronizing, by checking dead source conditions for synchronism bypass under these conditions.

Breaker Failure The L30 provides two fully independent breaker failure protection elements.

The L30 incorporates advanced automation features including powerful FlexLogic programmable logic, communication, and SCADA capabilities that far surpass what is found in the average line relay. The L30 integrates seamlessly with other UR relays for complete system protection.

FlexLogic

IEC 61850 Process Bus The IEC 61850 Process Bus module is designed to interface with the GE Multilin HardFiber System, allowing bi-directional IEC 61850 fiber optic communications. The HardFiber System is designed to integrate seamlessly with existing UR applications, including protection functions, FlexLogic™, metering and communications. The GE Multilin HardFiber System offers the following benefits: • Communicates using open standard IEC 61850 messaging • Drastically reduces P&C design, installation and testing labor by eliminating individual copper terminations • Integrates with existing L30’s by replacing traditional CT/VT inputs with the IEC 61850 Process Bus module • Does not introduce new cyber security concerns

160

FlexLogic is the powerful UR-platform programming logic engine that provides the ability to create customized protection and control schemes, minimizing the need and associated costs of, auxiliary components and wiring. Using FlexLogic, the L30 can be programmed to provide the required tripping logic along with custom scheme logic for line breaker control and interlocking and dynamic setting group changes.

Scalable Hardware The L30 is available with a multitude of I/O configurations to suit the most demanding application needs. The expandable modular design allows for easy configuration and future upgrades. • Flexible, modular I/O covering a broad range of input signals and tripping schemes • Mechanically latching outputs can be used to develop secure interlocking applications and replace electromechanical lockout relays

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The very high sampling rate and large amount of storage space available for data recording in the L30 can eliminate the need for installing costly stand-alone recording equipment.

Advanced Device Health Diagnostics The L30 performs comprehensive device health diagnostic tests at startup and continuously during run-time to test its own major functions and critical hardware. These diagnostic tests monitor for conditions that could impact security and availability of protection, and present device status via SCADA communications and front panel display. Providing continuous monitoring and early detection of possible issues help improve system uptime. • Comprehensive device health diagnostic performed at startup • Monitors the CT/VT input circuitry to validate the integrity of all signals

Cyber Security – CyberSentry UR CyberSentry UR enabled UR devices deliver full cyber security features that help customers to comply with NERC CIP and NIST® IR 7628 cyber security requirements. This software option delivers the following core features:

L30 Line Differential System

AAA Server Support (Radius/LDAP) Enables integration with centrally managed authentication and accounting of all user activities and uses modern industry best practices and standards that meet and exceed NERC CIP requirements for authentication and password management.

Role Based Access Control (RBAC)

Event Recorder (Syslog for SEM) Capture all cyber security related events within a SOE element (login, logout, invalid password attempts, remote/local access, user in session, settings change, FW update, etc), and then serve and classify data by security level using standard Syslog data format. This will enable integration with established SEM (Security Event Management) systems.

Communications The L30 provides for secure remote data and engineering access, making it easy and flexible to use and integrate into new and existing

• IEC 61850 Ed. 2 with 61850-9-2 and 6185090-5 support • DNP 3.0 (serial & TCP/IP) • Ethernet Global Data (EGD) • IEC 60870-5-103 and IEC 60870-5-104 • Modbus RTU, Modbus TCP/IP • HTTP, TFTP, SFTP and MMS file transfer • SNTP and IEEE 1588 for time synchronization • PRP as per IEC 62439-3

Interoperability with Embedded IEC 61850 Edition 2 The new IEC 61850 implementation in the UR Family positions GE as an industry leader in this standard. • Implements Edition 2 of the standard across the entire family of UR devices

• Provides full relay setting management via standard SCL files (ICD, CID and IID) • Enables automated relay setting management using 3rd party tools through standard file transfer services (MMS and SFTP) • Increases the number of Logical Devices and data mapped to them, GOOSE messages, and reports to support different organizational needs for data transfer and reduce dependency on generic logical nodes • Configures GE Systems based on IEC 61850 using universal 3rd party tools • Multicast IEEE C37.118 synchrophasor data between PMU and PDC devices using IEC 91850-90-5

LAN Redundancy Substation LAN redundancy has been traditionally accomplished by reconfiguring the active network topology in case of failure. Regardless of the type of LAN architecture (tree, mesh, etc), reconfiguring the active LAN requires time to switchover, during which the LAN is unavailable. UR devices deliver redundancy as specified by PRP-IEC 62439-3, which eliminates the dependency on LAN reconfiguration and the associated switchover time. The UR becomes a dual attached node that transmits data packets over both main and redundant networks simultaneously, so in case of failure, one of the data packets will reach the receiving device with no time delay.

Power System Troubleshooting The L30 contains many tools and reports that simplify and reduce the amount of time required for troubleshooting power system events.

Record the operation of the internal L30 elements and external connected devices with 1ms time-stamped accuracy to identify the Sequence of Operation of station devices during line faults and disturbances.

Analyze line faults using both analog and digital power system quantities that are measured and recorded up to a rate of 64 samples per cycle.

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Transmission Protection

Efficiently administrate users and roles within UR devices. The new and advanced access functions allow users to configure up to five roles for up to eight configurable users with independent passwords. The standard “Remote Authentication Dial In User Service” (Radius) is used for authentication.

infrastructures. Fiber optic Ethernet provides high-bandwidth communications allowing for low-latency controls and high-speed file transfers of relay fault and event record information. The available three independent Ethernet ports, redundant Ethernet option and the embedded managed Ethernet switch provide the means to create fault tolerant communication architectures in an easy, costeffective manner. The L30 supports the most popular industry standard protocols enabling easy, direct integration into monitoring and SCADA systems.

L30 Line Differential System

Multi-Language

Trasmission Protection

UR devices support multiple languages: English, French, Russian, Chinese, Turkish and German. These language options are available on the front panel, in the EnerVista setup software, and in the product manuals. Easily switch between English and an additional language on the local displays without uploading new firmware.

EnerVista Software The EnerVista suite is an industry-leading set of software programs that simplifies every aspect of using the L30 relay. The EnerVista suite provides all the tools to monitor the status of the protected asset, maintain the relay, and integrate information measured by the L30 into DCS or SCADA monitoring systems. Convenient COMTRADE and SOE viewers are an integral part of the UR setup software included with every UR relay, to carry out postmortem event analysis and ensure proper protection system operation.

Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed. Documents made available include:

Viewpoint UR Engineer

• Application Notes

Viewpoint UR Engineer is a set of powerful tools that allows the configuration and testing of GE relays at a system level in an easy-touse graphical drag-and-drop environment . Viewpoint UR Engineer provides the following configuration and commissioning utilities:

• Guideform Specifications

• Graphical Logic Designer

• Brochures

• Graphical System Designer

• Wiring Diagrams

• Graphical Logic Monitor

• FAQ’s

• Graphical System Monitor

• Service Bulletins

Viewpoint Maintenance

Viewpoint Monitoring

Viewpoint Maintenance provides tools that will create reports on the operating status of the relay, simplify the steps to download fault and event data, and reduce the work required for cyber security compliance audits. Tools available in Viewpoint Maintenance include:

• Manuals

Viewpoint Monitoring is a simple-to-use and full-featured monitoring and data recording software package for small systems. Viewpoint Monitoring provides a complete HMI package with the following functionality: • Plug-&-Play Device Monitoring

EnerVista Launchpad

• System Single-Line Monitoring & Control

EnerVista Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining GE Multilin products. The setup software within Launchpad allows for the configuration of devices in real-time by communicating using serial, Ethernet , or modem connections, or offline by creating setting files to be sent to devices at a later time.

• Annunciator Alarm Screens

• Settings Security Audit Report • Device Health Report • Single-Click Fault Data Retrieval

• Trending Reports

EnerVista Integrator

• Automatic Event Retrieval

EnerVista Integrator is a toolkit that allows seamless integration of GE Multilin devices into new or existing automation systems. Included in EnerVista Integrator is:

• Automatic Waveform Retrieval

• OPC/DDE Server • GE Multilin Drivers • Automatic Event Retrieval • Automatic Waveform Retrieval

User Interface The L30 front panel provides extensive local HMI capabilities. The local display is used for monitoring, status messaging, fault diagnosis, and device configuration. User-configurable messages that combine text with live data, can be displayed when user-defined conditions are met. 48 Configurable LED Indicators

Multi-Language Display • English • Russian • French • Chinese • Turkish • German

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L30 Line Differential System

Typical Wiring

A

B

C

52

N

Transmission Protection

F8a

F8c VX

VX

F7a

F7c VC

VC

VB

F6a

VA

F6c

F5a

F5c

VA

VB

F4b

F4a

F4c

F3c

IG5

IG1

F3b IC

IC1

IG

F2c

IB

F3a

F2a

F2b

IA1

IB5

IB1

F1c

IA

IC5

F1a

F1b

IA5

OPTIONAL

8L

H5a H5c H6a H6c H5b

H1

V I

H2

H7a H7c H8a H8c H7b

V I

H3

V I

H4

H8b

SURGE

U7a U7c U8a U8c U7b

V

U1

V I

U2

U8b

V

SURGE

I

U3

V I

U4

Multilin

U5

6K

V

N1a N1b N1c N2a N2b N2c N3a N3b N3c N4a N4b N4c N5a N5b N5c N6a N6b N6c N7a N7b N7c N8a N8b N8c

6D

N1

N2

L3a L3c L4a L4c L3b

N3

N4

L5a L5c L6a L6c L5b

N5

N6

L7a L7c L8a L8c L7b L8b

N7

N8

SURGE

FIBER

RS-232

S1a S1b S1c S2a S2b S2c S3a S3b S3c S4a S4b S4c S5a S5b S5c S6a S6b S6c S7a S7b S7c S8a S8b S8c

S1

DB-9 (front)

1

CRITICAL FAILURE

6C

Rx1 Rx2

INTER-RELAY COMMS. W7A

Tx1 Tx2

FIBER

B1b B1a B2b B3a B3b B5b HI B6b LO B6a B8a B8b

DC

V I

U6

L1a L1c L2a L2c L1b

TO REMOTE L30

V I

L30

S2

S3

OUTPUT CONTROL POWER

S4

SURGE FILTER

S5

S6 Fibre * Optic

Tx1

10BaseFL

NORMAL

Rx1 Tx2

10BaseFL Rx2

Shielded

S7 COM 1

ALTERNATE

S8

10BaseT

Remote Device

D1a D2a D3a D4b D4a

TC 2

U1a U1b U1c U2a U2b U2c U3a U3b U3c U4a U4b U4c U5a U5b U5c U6a U6b U6c

I

6H

TC 1

H1a H1b H1c H2a H2b H2c H3a H3b H3c H4a H4b H4c

I

6G

UR TXD RXD

SGND

1 2 3 4 5 6 7 8 9

CONNECTOR

COMPUTER

1 2 3 4 5 6 7 8 9

8 3 RXD 2 TXD 20 7 SGND 6 4 5 22

CONNECTOR

PERSONAL COMPUTER

RS485 com

Co-axial

BNC

Co-axial

BNC

IRIG-B Input IRIG-B Output

minimum

X W PROVIDED

V

U

T

S

7 6 6 Inputs/ Inputs/ COM outputs outputs * *

R

P

N

M

L

6 6 Inputs/ Inputs/ outputs outputs * *

K

H G

J

F

D

B

6

8

9

1

Inputs/ outputs

CT/VT

CPU

Power supply

GEDigitalEnergy.com

L30-H00-HCL-F8L-H6G-L6D-N6K-S6C-U6H-W7A

163

Ordering Base Unit CPU

L30 - * 00 -H * * -F ** -H ** -L ** -N ** -S ** -U ** -W/X ** L30 E J K N T U

Software Options (see note 1 below)

V

Mount / Coating

User Interface NOTE: These selections are only for horizontal units

Power Supply (see note 2 below) CT/VT DSP

IEC 61850 Process Bus Digital I/O

Transducer I/O Select a maximum of 3

Inter-Relay Communications Select a maximum of 1

00 03 06 07 18 19 24 25 26 27 A0 B0 C0 D0 M0

H A V B

A C D R B P G S U V K L M N I J Q T W Y

H H L

RH 8F 8H 8L 8N

81 XX 4A 4C 4D 4L 67 6C 6D 6E 6F 6K 6L 6M 6N 6P 6R 6S 6T 6U 6V 5A 5C 5D 5E 5F

XX 4A 4C 4D 4L 67 6C 6D 6E 6F 6K 6L 6M 6N 6P 6R 6S 6T 6U 6V 5A 5C 5D 5E 5F

XX 4A 4C 4D 4L 67 6C 6D 6E 6F 6K 6L 6M 6N 6P 6R 6S 6T 6U 6V 5A 5C 5D 5E 5F

XX 4A 4C 4D 4L 67 6C 6D 6E 6F 6K 6L 6M 6N 6P 6R 6S 6T 6U 6V 5A 5C 5D 5E 5F

XX 4A 4C 4D 4L 67 6C 6D 6E 6F 6K 6L 6M 6N 6P 6R 6S 6T 6U 6V 5A 5C 5D 5E 5F

2A 2B 2I 2J 7A 7B 7H 7I 7R 7S 7T 7W 72 73 76 77

** For Full Sized Horizontal Mount Base Unit RS485 + RS485 (IEC 61850 option not available) RS485 + multimode ST 100BaseFX RS485 + multimode ST Redundant 100BaseFX RS485 + 10/100 BaseT RS485 + three multimode SFP LC 100BaseFX. Req FW v7xx or higher RS485 + two multimode SFP LC 100BaseFX + one SFP RJ45 100BaseT. Req FW v7xx or higher RS485 + three SFP RJ45 100BaseT. Req FW v7xx or higher No Software Options IEC 61850 Phasor Measurement Unit (PMU) IEC 61850 + Phasor Measurement Unit (PMU) 3P Autoreclose and Synchrocheck 3P Autoreclose, Synchrocheck, IEC 61850 and Phase Measurement Unit (PMU) In-zone TX protection In-zone TX protection + IEC 61850 In-zone TX protection + PMU In- zone TX protection + IEC 61850 + PMU CyberSentry UR Lvl 1. Req UR FW 7.xx or higher IEEE 1588. Req UR FW 7.xx or higher PRP IEEE 1588 + CyberSentry. Req UR FW 7.xx or higher IEC 61850 + PMU + 61850-90-5 Horizontal (19" rack) - Standard Horizontal (19" rack) - Harsh Environment Coating Vertical (3/4 size) - Standard Vertical (3/4 size) - Harsh Environment Coating Chinese English French Russian Chinese with Additional 4 Small and 12 Large Programmable Pushbuttons English with Additional 4 Small and 12 Large Programmable Pushbuttons French with Additional 4 Small and 12 Large Programmable Pushbuttons Russian with Additional 4 Small and 12 Large Programmable Pushbuttons Enhanced Chinese Front Panel Enhanced Chinese Front Panel with User-Programmable Pushbuttons Enhanced English Front Panel Enhanced English Front Panel with User-Programmable Pushbuttons Enhanced French Front Panel Enhanced French Front Panel with User-Programmable Pushbuttons Enhanced German Front Panel Enhanced German Front Panel with User-Programmable Pushbuttons Enhanced Russian Front Panel Enhanced Russian Front Panel with User-Programmable Pushbuttons Enhanced Turkish Front Panel Enhanced Turkish Front Panel with User-Programmable Pushbuttons 125 / 250 V AC/DC 125/250 V AC/DC with redundant 125/250 V AC/DC 24 - 48 V (DC only) Standard 4CT/4VT Standard 8CT Standard 4CT/4VT with enhanced diagnostics Standard 8CT with enhanced diagnostics 8 Port IEC 61850 Process Bus Module No Module 4 Solid State (No Monitoring) MOSFET Outputs 4 Solid State (Current w/opt Voltage) MOSFET Outputs 16 Digital Inputs with Auto-Burnish 14 Form-A (No Monitoring) Latchable Outputs 8 Form-A (No Monitoring) Outputs 8 Form-C Outputs 16 Digital Inputs 4 Form-C Outputs, 8 Digital Inputs 8 Fast Form-C Outputs 4 Form-C & 4 Fast Form-C Outputs 2 Form-A (Current w/ opt Voltage) & 2 Form-C Outputs, 8 Digital Inputs 2 Form-A (Current w/ opt Voltage) & 4 Form-C Outputs, 4 Digital Inputs 4 Form-A (Current w/ opt Voltage) Outputs, 8 Digital Inputs 6 Form-A (Current w/ opt Voltage) Outputs, 4 Digital Inputs 2 Form-A (No Monitoring) & 2 Form-C Outputs, 8 Digital Inputs 2 Form-A (No Monitoring) & 4 Form-C Outputs, 4 Digital Inputs 4 Form-A (No Monitoring) Outputs, 8 Digital Inputs 6 Form-A (No Monitoring) Outputs, 4 Digital Inputs 2 Form-A (Cur w/ opt Volt) 1 Form-C Output, 2 Latching Outputs, 8 Digital Inputs 4 dcmA Inputs, 4 dcmA Outputs 8 RTD Inputs 4 RTD Inputs, 4 dcmA Outputs 4 dcmA Inputs, 4 RTD Inputs 8 dcmA Inputs 2A C37.94SM, 1300nm singlemode, ELED, 1 Channel singlemode 2B C37.94SM, 1300nm singlemode, ELED, 2 Channel singlemode 2I Channel 1 - IEEE C37.94, 820nm, multimode fiber, 64/128 kbps; Channel 2 - 1300 nm, singlemode, LASER 2J Channel 1 - IEEE C37.94, 820nm, multimode fiber, 64/128 kbps; Channel 2 - 1550 nm, singlemode, LASER 7A 820 nm, multimode, LED, 1 Channel 7B 1300 nm, multimode, LED, 1 Channel 7H 820 nm, multimode, LED, 2 Channels 7I 1300 nm, multimode, LED, 2 Channels 7R G.703, 1 Channel 7S G.703, 2 Channels 7T RS422, 1 Channel 7W RS422, 2 Channels 72 1550 nm, singlemode, LASER, 1 Channel 73 1550 nm, singlemode, LASER, 2 Channels 76 IEEE C37.94, 820 nm, multimode, LED, 1 Channel 77 IEEE C37.94, 820 nm, multimode, LED, 2 Channel

Ordering Note: 1. To view all the options available for L30, please visit GE’s On-Line Store http://store.gedigitalenergy.com/viewprod.asp?model=L30 2. Redundant power supply only available in horizontal unit. If redundant chosen, must be same type. Maximum 2 per chassis.

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12759I(E) English 150121

Multilin D90 ™

Plus

Sub-Cycle Distance Protection and Advanced Automation Controller Modern power systems are under increasing constraints in their ability to transmit power from generation facilities to major load centers, and are forced to operate closer to their natural stability limits. Under these conditions, the critical clearing angle and corresponding critical clearing time become progressively smaller, creating an increasing need to minimize the fault clearing time on these constrained circuits. The Multilin D90Plus is ideally suited for application on circuits where fast fault detection and small breaker failure margin are required. The Multilin D90Plus allows transmission limits to be maintained or even increased while respecting the transient stability limits of the power system.

Key Benefits • Secure sub-cycle distance protection to improve system stability and increase line loading • True Capacitively Coupled Voltage Transformers (CCVT) filter for improved distance protection performance without intentional delays or reduced fault coverage • Superior phase selection algorithms ensures secure high-speed single-pole tripping • Reliable and secure protection on lines equipped with series compensation • Configurable alarm annunciator, eliminating the need for separate annunciator panel

Protection & Control • Secure time-domain algorithm providing sub‑cycle distance protection • Phase distance with independent compensation settings for in-zone power transformers • Ground distance with independent self and mutual zero sequence compensation • Out-of-step tripping and power swing blocking • Synchronism check for dual breaker applications • Advanced automation controller with independent automation programmable logic • Bay control through front panel HMI

Advanced Communications

• Embedded Synchrophasor measurement capabilities (per IEEE® C37.118), eliminating the need for dedicated PMUs

• Wide range of supported industry protocols: IEC 61850, DNP 3.0, Modbus Serial/TCP, IEC 60870-5-104, PRP

• Increased network availability via failover time reduced to zero through IEC® 62439-3 “PRP” support

• Up to three independent IP addresses

• Fault and disturbance recording, including internal relay operating signals at up to 128 samples/cycle • Advanced fault and disturbance recording, including internal relay operating signals, eliminating the need for external recording devices

Applications • Overhead lines including series compensated lines and underground cables of different voltage levels • Single and dual-breaker circuits requiring single/three-pole autoreclosing and independent synchrocheck supervision • Backup protection for generators, transformers and reactors • Sub-cycle tripping with CCVT • Circuits with in-zone power transformers and tapped transformer feeders • Wide area monitoring and control using integrated protection and synchrophasor measurement

Monitoring & Metering • Continuous monitoring of AC input channels • Current, voltage, frequency, power, energy and synchrophsors (per IEEE C37.118) measurement • Advanced recording capabilities with high-capacity event recorder, transient & disturbance recording, configurable and extended waveform capture and data logger • Large, integrated color HMI and annunciator for metering, phasors, maintenance, and fault information via front panel displays

D90Plus Line Distance Protection System

D90Plus Line Distance Protection System Intuitive HMI • Customizable bay diagrams for various applications

Digital Alarm Annunciator Trasmission Protection

• 96 customizable alarms in multiple pages

• Local control and status indication of breakers & disconnect switches • Local/remote control

Advanced Protection • Sub-cycle distance protection

• Eliminates the need for separate annunciator

• Fault, event, disturbance and transient reports

Advanced Automation Controller

Advanced Communication Capabilities

Advanced Recorders

• Built-in programmable logic engine

• Up to three Ethernet ports

• Advanced math, Boolean and control operations

• IEC  61850, DNP 3.0, Modbus TCP/IP, IEC 60870-5-104 protocols

• Eliminate the need for stand-alone disturbance recorders

• IEEE C37.118 synchrophasors over Ethernet • Front USB port for high-speed data transfer

• 512 lines of Protection FlexLogic @ 1 msec execution

• 128 samples/cycle, 1 min duration transient recorder • Seperate dynamic disturbance recorder for recording long term events • Synchrophasors PMU recording

Advanced Disturbance Recorder Eliminates Stand-Alone DFR and Phasor Measurement Unit

Integrated Bay Controller and Intuitive HMI Eliminates Stand-Alone HMI and Controller

Digital fault recorder summary with the latest information on events, faults, transients and disturbances.

Control screen for the pre-configured bay with breaker & disconnect control in multiple pages using dedicated pushbuttons in the front panel.

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GEDigitalEnergy.com

D90Plus Line Distance Protection System

Protection and Control

CCVT Transient Filter

Phase Distance Operating Times

Ground Distance Operating Times

Generally, CCVT transients will cause the magnitude of the voltage signal to be underestimated, causing distance elements to overreach. Most relays detect CCVT transients under high SIR and incorporate an intentional operating delay on the distance elements to ride through the period with CCVT transients. Dynamically reducing the reach of the distance elements to prevent them from overreaching is another strategy to cope with CCVT transients.

Phase Distance Element; CCVT Filter Enabled and Tuned.

Ground Distance Element; CCVT Filter Enabled and Tuned.

The D90Plus offers a high degree of functionality, providing superior performance while meeting the toughest requirements of the marketplace. Advanced protection and control features of this relay includes:

D90Plus Sub-Cycle Distance Protection The D90 Plus sub-cycle distance algorithm employs a combination of energy-based integrator/comparators and high-speed phase comparators to determine if a fault is internal or external.

Transients generated by CCVTs tend to have relatively significant magnitudes and long durations. The impact of these transients is particularly pronounced when protecting transmission lines where the Source Impedance Ratio (SIR), the ratio between the system equivalent impedance and the relay reach impedance, is large. The voltage signals are crucial for proper operation of a distance element, but become significantly distorted by transient components that are generated but the CCVT. This presents a significant challenge particularly for fast impedance protection algorithms.

Functional Block Diagram 52

52

Monitoring

CLOSE

TRIP

59X(2) 27X(2)

25 (2)

79 50DD

50P(4)

50_2 (2)

51P(4)

51_2 (2)

50BF (2)

21P(5)

Pilot

67P (2)

FlexElement

Schemes

78

68

67_2 (2)

50G(4)

Metering

TM

51N(4)

50N(4)

67N/G (2)

Transducer Inputs

21G(5)

59P(2)

27P (2)

51G(4)

59_2(2) 59N(2)

D90Plus

Line Distance Protection System

ANSI Device Numbers & Functions ®

DEVICE NUMBER

FUNCTION

DEVICE NUMBER

FUNCTION

DEVICE NUMBER

FUNCTION

21G 21P 25 27P 27X 50BF 50DD 50G 50N

Ground Distance Phase Distance Synchronism Check Phase Undervoltage Auxiliary Undervoltage Breaker Failure Current Disturbance Detector Ground Instantaneous Overcurrent Neutral Instantaneous Overcurrent

50P 50_2 51G 51N 51P 51_2 52 59N 59P

Phase Instantaneous Overcurrent Negative Sequence Instantaneous Overcurrent Ground Time Overcurrent Neutral Time Overcurrent Phase Time Overcurrent Negative Sequence Time Overcurrent AC Circuit Breaker Neutral Overvoltage Phase Overvoltage

59X 59_2 67N 67P 67_2 68 78 79 81 U/O

Auxiliary Overvoltage Negative Sequence Overvoltage Neutral Directional Overcurrent Phase Directional Overcurrent Negative Sequence Directional Overcurrent Power Swing Blocking Out-of-Step Tripping Automatic Recloser Under and Over Frequency

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Transmission Protection

The energy integrator algorithm uses both the magnitude of the operating and polarizing signals as well as the relative phase information to provide fast, secure operation for obvious internal faults. The high-speed phase comparators examine the angular relationship between operating and polarizing signals independent of magnitude to provide greater security in the presence of CCVT transients. For faults with low SIR or close-in high magnitude faults, the D90Plus can provide trip times under ½ cycle for phase-phase faults and between ½ to ¾ of a cycle for ground faults.

Trasmission Protection

D90Plus Line Distance Protection System

The D90Plus introduces a true digital filter into the voltage signal path that removes distortions generated by the CCVT, resulting in a signal that is a more accurate reproduction of the power system voltage. The D90Plus is then able to provide sub-cycle distance protection in the presence of CCVT transients, without adding intentional delays or reducing fault coverage. The D90 Plus sub-cycle distance algorithm is secure and sufficiently fast for a wide range of power system scenarios. The CCVT filter increases the speed of operation of the D90Plus for an even wider range of contingencies.

Custom Programmable Logic Designer

As with all filters, the D90Plus CCVT filter needs to be tuned to a specific application, so that the behaviour of the CCVT is characterized and reduced to 3 critical parameters that become settings for the relay. D90Plus user-programmable protection logic and independent automation logic allow users to build custom protection and automation schemes. The D90Plus provides fully independent breaker failure protection for breaker-and-a-half or ring bus arrangements with consistent sub-cycle resetting times (5/8 of a power system cycle), allowing for shorter critical clearing times and increased line loading.

Even with CT saturation, current reversal and severe subsidence, the URPlus breaker failure element provides secure, dependable protection with consistent sub-cycle reset times.

In-Zone Transformer Compensation

Fast Breaker Failure Reset With stability limits shrinking, the ability to achieve fast breaker failure resetting times becomes more challenging to achieve. When the total worst-case clearing time including breaker failure starts to approach 10-12 cycles, often there is little more than 1 cycle margin left to allow for breaker failure protections to reset.

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Single-Pole Tripping The D90 Plus relay uses a highly secure and dependable phase selection algorithm that provides fast and accurate fault type identification. A convenient trip function is builtin to coordinate actions of the key protection and teleprotection operands in single-pole tripping applications.

CCVT Transient for Fault at Voltage Maximum and Corrected Voltage Signal.

CCVT Transient for Fault at Voltage ZeroCrossing and Corrected Voltage Signal.

Depending on the needs of the application, the relay can be programmed to dynamically be self-polarized or use memory voltage for polarization for additional security.

Phase distance elements in the D90 Plus can be used to detect faults “through” different types of three-phase wye/delta transformers, allowing application of the D90Plus for backup protection at generating stations.VTs and CTs can be installed independently of each other on either side of the power transformer. The relay automatically compensates for transformer connections for accurate far-reaching stepped distance backup protection schemes.

Series-Compensated Lines The D90Plus provides enhanced stability and security by employing an adaptive distance reach control to cope with the overreaching and sub-synchronous oscillations when applied to, or in the vicinity of, series-compensated lines.

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Communication Aided (Pilot) Schemes The D90 Plus supports several common teleprotection schemes for coordinated fault clearance within the zone of protection. The following types of pilot-aided schemes are available in the D90Plus: • Direct Underreach Transfer Trip (DUTT) • Permissive Underreach Transfer Trip (PUTT) • Permissive Overreach Transfer Trip (POTT) • Hybrid Permissive Overreach Transfer Trip (HYB POTT), permissive echo and transient blocking logic incorporated • Directional Comparison Blocking Scheme (DCB) • DirectionalComparison Unblocking Scheme (DCUB)

D90Plus Line Distance Protection System

To support single-pole tripping applications, up to four bits can be keyed from the various teleprotection schemes.

Multiple Breaker

Advanced Automation The D90Plus incorporates advanced automation features including powerful FlexLogic (userprogrammable logic) independent for protection and automation schemes. Combined with the communication capabilities, the D90Plus provides an advanced, highly flexible platform for substation automation applications. The D90Plus integrates seamlessly with other relays for distributed applications like interlocking and special protection schemes.

FlexLogic FlexLogic is the integral D90 platform programming logic engine that facilitates customizing the relay protection to meet the specific requirements of a given application without requiring auxiliary components and wiring. Plus

Using Protection FlexLogic, the D90Plus can be programmed to provide required tripping logic along with custom scheme logic for breaker control, transfer tripping schemes for remote breakers and dynamic setting group changes. Automation FlexLogic features math, Boolean and control functions that can be employed in advanced load shedding, load restoration and dynamic Volt/VAR control schemes.

Scalable Hardware The D90Plus is available with a multitude of I/O configurations to suit a variety of application needs. The expandable modular design allows for easy configuration and future upgrades. Digital outputs include trip-rated Form-A and Solid State Relay (SSR), available with optional circuit continuity monitoring and current detection, to monitor the health of downstream circuits like breaker trip coils.

storage capacity available for data recording in the D90Plus can eliminate the need for installing stand-alone recording equipment.

The D90 Plus includes detailed metering and recording for all AC signals. Voltage, current, and power metering are built into the relay as a standard feature. Current and voltage parameters are available as total RMS magnitude, and as fundamental frequency magnitude and angle.

Communications The D90Plus provides for secure remote data and engineering access, making it easy and flexible to use and integrate into new and existing infrastructures. Fiber optic Ethernet provides high-bandwidth communications allowing for low-latency controls and highspeed file transfers of relay fault and event record information. The availability of three independently configurable Ethernet options provides the means to create fault tolerant communication architectures in an easy, costeffective manner.

Transient Recorder A high resolution (128 samples/cycle) transient recorder with 1 minute or more of storage capacity is provided to record short duration system events like faults and reclosing sequences.

Disturbance Recorder An independent disturbance recorder with a 5 minute storage capacity is intended to record long duration events like power swings and voltage sags and swells.

The D90Plus supports the most popular industry standard protocols enabling easy, direct integration into SCADA systems. • IEC 61850

Sequence of Event Recorder

• DNP 3.0

The advanced event recorder has the capability to store up to 8000 events.

• IEC 60870-5-104

Information for all three recorders can be accessed either through the front panel HMI or through EnerVista Launchpad software. The very high sampling rate and large amount of

• PRP as per IEC 62439-3

• Modbus RTU, Modbus TCP/IP

D90Plus Dual Breaker Configuration CB1

CT1

CB2

CT2

VT1 1PH BF1

BF2

SRC1

SRC2

D90Plus

SRC1

SRC3

Synchrocheck

DISTANCE and OVERCURRENT

SRC2

SRC3 3PH VT2

PROTECTED LINE

D90Plus supports dual breaker configurations. Two CTs can be measured individually and logically summed within the relay.

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169

Transmission Protection

The D90 Plus supports multi-breaker busbar configurations such as breaker-and-a-half or ring bus arrangements, providing dual breaker autoreclose, dual synchrocheck elements, and dual independent breaker failure elements.

Monitoring and Metering

D90Plus Line Distance Protection System

Interoperability with Embedded IEC 61850

Trasmission Protection

The D90Plus with integrated IEC 61850 can be used to lower costs associated with protection, c o n t ro l a n d a u t o m a t i o n . G E M u l t i l i n ’ s leadership in IEC 61850 comes from thousands of installed devices and follows on Multilin’s extensive development experience with UCA 2.0. • Replace expensive copper wiring between devices with direct transfer of data using GOOSE messaging • Configure systems based on IEC 61850 and also monitor and troubleshoot them in realtime with EnerVista Viewpoint Engineer • Integrate GE Multilin IEDs and generic IEC 61850-compliant devices seamlessly in EnerVista Viewpoint Monitoring

LAN Redundancy Substation LAN redundancy has been traditionally accomplished by reconfiguring the active network topology in case of failure. Regardless of the type of LAN architecture (tree, mesh, etc), reconfiguring the active LAN requires time to switchover, during which the LAN is unavailable. UR devices deliver redundancy as specified by PRP-IEC 62439-3, which eliminates the dependency on LAN reconfiguration and the associated switchover time. The UR becomes a

dual attached node that transmits data packets over both main and redundant networks simultaneously, so in case of failure, one of the data packets will reach the receiving device with no time delay.

setting files to be sent to devices at a later time. Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed. Documents made available include:

EnerVista Software

• Manuals

The EnerVista suite is an industry-leading set of software programs that simplifies every aspect of using the D90Plus relay. The EnerVista suite provides all the tools to monitor the status of your protected asset , maintain the relay, and integrate information measured by the D90Plus into DCS or SCADA monitoring systems. Convenient COMTRADE and Sequence of Events viewers are an integral part of the URPlus setup software included with every URPlus relay, to carry out postmortem event analysis and ensure proper protection system operation.

• Application Notes

EnerVista Launchpad EnerVista Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining GE Multilin products. The setup software within Launchpad allows for the configuration of devices in real-time by communicating using serial, Ethernet , or modem connections, or offline by creating

• Guideform Specifications • Brochures • Wiring Diagrams • FAQ’s • Service Bulletins

Viewpoint Engineer Viewpoint Engineer is a set of powerful tools that will allow you to configure and test UR relays at a system level in an easy-to-use graphical dragand-drop environment . Viewpoint Engineer provides the following configuration and commissioning utilities: • Graphical Logic Designer • Graphical System Designer • Graphical Logic Monitor • Graphical System Monitor

Power System Troubleshooting The UR Plus setup software contains many tools and reports that simplify and reduce the amount of time required for troubleshooting power system events.

View characteristic shapes for phase and ground distance, power swing and load encroachment elements.

Analyze transmission line faults using system voltage, current and appropriate pickup flags that are measured & recorded up to 128 samples/cycle. View the operation of the internal D90Plus inputs and outputs with time-stamped accuracy.

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D90Plus Line Distance Protection System

User Interface

HMI

The D90Plus provides local HMI capability through two color LCD display panels. One serves as a digital annunciator and the other optional HMI is for display and control functions.

• Comprehensive data visualization

Annunciator

• The status of any contact or remote input or internally generated FlexLogic operand can be assigned to the annunciator.

• User pushbuttons can be assigned to several functions through multiple menu levels • Local/remote control • Pre-programmed comprehensive displays for: - Metering - Bay Control - Fault Reports - Sequence of Event Reports - Transient Records Summaries - Disturbance Record Summaries - Real-Time Phasor Displays of Voltage, Current and Sequence Components

Sequence of event records with the ability to view the time difference between two events for troubleshooting and analysis.

Front Panel USB The front panel of the D90Plus provides a USB 2.0 host for field laptop connections for highspeed data transfer, making downloading and uploading faster than an RS232 connection.

12 to 48 user-configurable alarms per page eliminate the need for separate annunciator. • The annunciator can display 12/24/48 targets per page to a maximum of 8 pages. • A separate self-test message page on the annunciator panel shows error messages and troubleshooting advice.

Tabular display of metering values.

Bay Configurations The D90Plus supports customizable single line diagrams along with 12 pre-configured diagrams and corresponding controls for each bay-level equipment.

Breaker-and-Half Configuration

Double Bus Configuration

Single Bus Configuration

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Two-Main and Transfer Bus Configuration

171

Transmission Protection

The D90Plus provides an embedded, configurable color LCD annunciator on the front panel of the device eliminating the need for separate annunciators in the relay panel.

• Single line diagrams for bay monitoring and control

D90Plus Line Distance Protection System

Trasmission Protection

Typical Wiring Diagram

g

172

Multilin D90Plus Line Distance Protection System

GEDigitalEnergy.com

D90Plus Line Distance Protection System

General Specifications AC CURRENT

SOLID STATE RELAY

CT rated secondary: 1 A to 5 A Relay burden: < 0.2 VA ar rated secondary Conversion range: 0.02 to 46 x CT rating RMS symmetrical Current withstand: 20 ms at 250 times rated 1 sec at 100 times rated Continuous at 3 times rated

Make and carry for 0.2 s: Carry continuous: Break at L/R of 40 ms: Operate time:

VT rated primary: 50.0 to 240.0 V VT ratio: 1.00 to 24000.00 Relay burden: < 0.25 VA at 120 V Conversion range: 1 to 275 V Voltage withstand: Continuous at 260 V to neutral 1 min/hr at 420 V to neutral

CONTACT INPUTS Input rating: 300 V dc maximum Selectable threshholds: 20 to 250 V Maximum current: 10 ma during turn-on 0.5 ma steady state IRIG-B Input Amplitude modulation: 1 to 10 Vpk-pk DC shift: TTL Input impedance: 50 kΩ Isolation: 2 kV

FORM-A RELAY Make and carry for 0.2 s: 30 A per ANSI C37.90 Carry continuous: 6A Break at L/R of 40 ms: 0.250 A dc at 125 Vdc 0.125 A dc at 250 Vdc Operate time: < 4 ms Contact material: Silver alloy

ETHERNET PORTS

CRITICAL FAILURE RELAY Make and carry for 0.2 s: Carry continuous: Break at L/R of 40 ms: Operate time: Contact material:

10 A 6A 0.250 A dc at 125 Vdc 0.125 A dc at 250 Vdc 0.10 A dc at 125 V < 8 ms Silver alloy

POWER SUPPLY Nominal DC voltage: 125 to 250 Vdc Min/max DC voltage: 80/300 Vdc Nominal AC voltage: 100 to 240 Vac at 50/60 Hz Min/max AC voltage: 80/275 Vac at 48 to 62 Hz Voltage withstand: 2 x Highest nominal voltage for 10 ms 1 sec at 100 times rated Voltage loss hold-up: 200 ms duration at nominal Power consumption: Typical-30 VA; Max-65 VA

CONTROL POWER EXTERNAL OUTPUT (For dry contact input) Capacity: Isolation:

19.2 to 115 kbps supporting Modbus RTU & DNP3.0 Distance: 1200 m Isolation: 2 kV

Standard: 1 port supporting Modbus RTU and DNP 3.0 10/100Base-TX: RJ45 connector Optional: 2 ports supporting DNP 3.0, IEC 60870-104, IEC 61850 or PRP on communications card 100Base-FX: 1300 nm, multi-mode, halfduplex/full-duplex, fiber optic with ST connector Power budget: 10 db Max optical input power: -14 dBm Max optical output power: -20 dBm Receiver sensitivity: -30 dBm Typical distance: 2.0 km SNTP clock synchronization error: <10 ms (typical)

APPROVALS UL listed for the USA and Canada manufactured under an ISO9000 registered system. CE: LVD EN61010-1, EN60255-5 EMC EN50263, IEC 60255-26

100 mA dc at 48 V dc 2 kV

FRONT USB Standard: Type B USB connector supporting setup software

Dimensions 7.50” (190) 7.50” (190)

9.80” (249) 9.80” (249)

11.43” (290) 11.43” (290)

18.31” (465) 18.86” (479) 18.31” (465) 7.50” (190)

18.86” (479)

9.80” (249)

11.43” (290)

4 x 0.28” Dia (7.1) 18.37” (466.6) 18.31” (465)

7.13” (81.1) 7.13” (81.1)

18.86” (479) 18.37” (466.6)

17.75” (450.8)

4 x 0.28” Dia (7.1) 4.00” (101.6) 4.00” 4 x 0.28” Dia (101.6) 1.57” (7.1) (39.8)

18.37” (466.6) 17.75” (450.8) 7.13” (81.1)

1.57”

(39.8) GEDigitalEnergy.com 4.00” (101.6)

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Transmission Protection

AC VOLTAGE

REAR RS485 30 A as per ANSI C37.90 6A 10.0 A dc at 250 Vdc < 100 µs

Ordering

Interface Front Panel

D90P - * A H

Language

*

-

*

* ** *

*

*

-

*

*

*

* ** *

*

*

*

E

3-pole Distance (Standard) 3-pole Distance + Tele Protection + FlexLogic 1/3-pole Sub-cycle Distance + Series Compensation + Tele- Protection + FlexLogic Breaker Control + Synchrocheck (Standard) + Automation FlexLogic ModBus TCP/IP + ModBus Serial + DNP 3.0 (Standard) ModBus TCP/IP + IEC 61850 ModBus TCP/IP + IEC 61850 + DNP 3.0 TCP/IP ModBus TCP/IP + IEC 61850 + IEC 60870-5-104 ModBus TCP/IP, IEC 61850 & PRP ModBus TCP/IP, IEC 61850, DNP 3.0 TCP/IP & PRP ModBus TCP/IP, IEC 61850, IEC 60870-5-104 & PRP + ModBus TCP/IP + IEC61850 + IEC 60870-5-104 Basic Metering (Standard) + Synchrophasors + Data Logger + Data Logger + Synchrophasors Transient Recorder + Sequence of Events (Standard) + Disturbance Recorder Circuit Breaker/Communication Statistics + Battery Monitor (Standard)

S E A S E

Automation Communications

01 02 03 04 A2 A3 A4

Metering

DFR

S P L U

Equipment Manager

S D

S

Hardware Harsh Environment Coating

X C

Power Supply

None (Standard) Harsh Environment Conformal Coating High (88-275VAC/80-300VDCI) (Standard)

H

Peer-to-Peer Communications Module

X

Communication Module Type CA AC Module Type A01 Type A02 I/O Module Type IA Type IB Type IC Type ID Type IE Type IF

E

Description Annunciator (Standard) + HMI English (Standard)

Features Protection

Order Code Example: D90P - H

*

-

None (Standard) X A

A

E

04 U

D

S

-

C H

X

A

X A B C D E F

X A B C D E F

X A B C D E F

X A B C D E F

B

C

X

D

01 02

X A B C D E F

None (Standard) Dual ST fiber & copper 5 VT & 7 CT (5 Amp current) (Standard) 5 VT & 7 CT (1 Amp current) None 8 Inputs, 4 Form-A Outputs with Voltage + Current Monitoring (Standard) 8 Inputs, 4 Solid State Outputs with Voltage + Current Monitoring 8 Inputs, 4 Form-A Outputs 4 Inputs, 8 Form-A Outputs 23 Inputs 12 Form-A Outputs

01 X

Note: The order code is for a D90 with sub-cycle distance protection, front panel HMI, advanced automation features, dual redundant IP communications, transient & disturbance recorders with the appropriate I/O cards for dual configurations. Plus

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12591A(E) English 150121

Multilin™ D60 High-Speed Transmission Line Protection with Single and Three-Pole Tripping The Multilin D60 is a high-end, cost-effective distance protection relay intended for protecting transmission lines and cables, providing reliable and secure operation even under the worst case power system conditions. Part of the Universal Relay (UR) family, the D60 comes with a variety of versatile features, truly integrating protection, monitoring, metering, communication and control in one easyto-use device.

Protection & Control • Phase & Ground distance (5 zones) with independent settings • Reverse power, out-of-step tripping and power swing blocking • Line pickup, thermal protection, under/over frequency • Four-shot dual breaker autorecloser broken conductor

Key Benefits • High-speed five zone quad or mho, phase and ground distance protection for greater system reliability • Superior phase selection algorithm ensures secure high-speed single-pole tripping

Advanced Communications

• Supports multiple standard and customizable pilot schemes for fast fault clearance within the protected zone

• 3 independent Ethernet ports with IEEE 1588 support

• Flexible programmable logic for building customized schemes

• Advanced IEC 61850 Edition 2 implementation and IEC 61850-9-2 process bus support

• Reliable and secure protection on series compensated lines

• Simplified teleprotection interfaces with direct I/O communications hardware for transfer trip and pilot-aided distance schemes • Embedded Synchrophasor measurement capabilities (per IEEE C37.118), eliminating the need for dedicated PMUs and support for synchrophasor multi-cast (per IEC® 61850-90-5) reducing bandwidth and communications infrastructure costs

• Supported industry protocols: IEC 61850 Ed. 2, SFTP, MMS File Transfer Service, DNP 3.0, Modbus Serial/TCP, IEEE 1588, IEC 60870‑5‑104 and 103, PRP, SNTP, HTTP, TFTP

• Advanced IEC 61850 Ed. 2 implementation, complete settings via SCL files and IEC 61850-9-2 process bus solution enable resource and platform managing optimization and reduce cost of ownership

• Direct I/O for secure, high-speed exchange of data for DTT & pilot-aided schemes

®

• Increased network availability via failover time reduced to zero through IEC® 62439-3 “PRP” support • Advanced fault and disturbance recording, including internal relay operating signals, eliminating the need for external recording devices

Applications • Overhead lines and underground cables of different voltage levels • Single and dual-breaker circuits requiring single/three pole autoreclosing and independent synchrocheck • Circuits with in-zone power transformers and tapped transformer feeders • Secure application with Capacitively-Coupled Voltage Transformers (CCVTs) • Backup protection for generators, transformers and reactors

Cyber Security • CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog) • Setting for security audit trails, tracking changes to D60 configurations

Monitoring & Metering • Advanced recording capabilities with highcapacity event recorder, configurable and extended waveform capture and data logger • P & M class synchrophasors of voltage, current, and sequence components

D60 Line Distance Protection System

Protection & Control

D60 - Protection, Metering, Monitoring and Control

As part of the UR family of Protection & Control devices, the D60 offers a high degree of modularity in its design and functionality, providing superior performance while meeting the toughest requirements of the marketplace.

Trasmission Protection

Advanced protection and control features of this relay includes:

Distance Protection The core of the D60 relay is the distance function providing a high degree of sensitivity and selectivity for all types of faults. The distance function comes with five zones of phase distance and ground distance, providing the user maximum flexibility to cater to different applications, including primary line protection and backup protection for busbars, generators, transformers and reactors. The relay can be applied to power systems with different earthing conditions, lines with in-zone transformers or tapped transformer

The D60 is the single point for protection, control, metering, and monitoring in one integrated device that can be easily connected directly to HMI or SCADA monitoring and control systems.

Functional Block Diagram

52

52

Monitoring

CLOSE

79

TRIP

49 (2)

(via Communications)

27X (2)

68

78

81U/O

25 (4)

32S (2)

50DD 50P (4) 50_2 (2) 51P (4) 51_2 (2) 50BF (2)

Data From/To Remote End

59X (2)

21P (5)

Pilot

67P (2)

67_2 (2)

Metering

TM

FlexElement

Schemes

50G (4)

50N (4)

51N (4)

67N/G (2)

59P (3)

Transducer Inputs

27P (3)

51G (4) 52_2(3)

D60

21G (5)

59N (3)

Line Distance Protection System

ANSI Device Numbers & Functions ®

DEVICE NUMBER

FUNCTION

DEVICE NUMBER

FUNCTION

21G 21P 25 27P 27X 32 49 50BF 50DD 50G 50N

Ground Distance Phase Distance Synchronism Check Phase Undervoltage Auxiliary Undervoltage Sensitive Reverse Power Thermal Overload Breaker Failure Current Disturbance Detector Ground Instantaneous Overcurrent Neutral Instantaneous Overcurrent

50P 50_2 51G 51N 51P 51_2 52 59C 59N 59P 59X

Phase Instantaneous Overcurrent Negative Sequence Instantaneous Overcurrent Ground Time Overcurrent Neutral Time Overcurrent Phase Time Overcurrent Negative Sequence Time Overcurrent AC Circuit Breaker Compensated Overvoltage Neutral Overvoltage Phase Overvoltage Auxiliary Overvoltage

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DEVICE NUMBER

FUNCTION

59_2 67N 67P 67_2 68 78 79 81U/O ROCOF

Negative Sequence Overvoltage Neutral Directional Overcurrent Phase Directional Overcurrent Negative Sequence Directional Overcurrent Power Swing Blocking Out-of-Step Tripping Automatic Recloser Under/Over Frequency Rate of Change of Frequency

D60 Line Distance Protection System

feeders, and overhead lines with series compensation. Each zone element for the phase and ground distance can be independently set as quad or mho characteristics with the flexibility of designing different characteristic shapes to suit different power system conditions.

The load encroachment feature offers discrimination between line loading conditions and fault conditions, especially for long lines under heavy loads, by supervising the distance elements or any overcurrent element . This prevents unwanted tripping under heavy line load conditions and enables optimum operation of the line, while meeting regulatory requirements for line loading.

Z3

Z1

Distance relay quadrilateral characteristics supervised by the load encroachment function.

Fault Locator

Line Pickup (Switch-on-to Fault) The line pickup feature uses a combination of undercurrent and undervoltage to identify a line that has been de-energized (line end open). Three instantaneous overcurrent elements are used to identify a previously de-energized line that has been closed on to a fault.

Power Swing Detection Z3 Z1 Z1 & Z3 looking through a transformer.

In-Zone Transformer Compensation Phase distance protection in the D60 can be used to detect faults through different types of three-phase wye/delta transformers, allowing the application of the D60 for backup protection on generators. VTs and CTs can be installed independently of each other on either side of the power transformer. The relay automatically compensates for transformer connections, to guarantee accurate reach for any type of fault.

Series Compensated Lines D60 provides enhanced stability and security by employing an adaptive distance reach control to cope with the overreaching and sub-synchronous oscillations when applied to, or in the vicinity of, series compensated lines. For directional integrity the relay uses memory voltage polarization and a multi-input comparator to deal with current inversion issues in series compensated lines.

Single-Pole Tripping

The integrated fault locator provides distance to fault in kilometers or miles. Parallel line zero-sequence current compensation and load current compensation enable the D60 to provide improved accuracy for fault distance measurement. Z1 looking through a transformer.

operating characteristic. Negative sequence current supervisors provide extended selectivity for detecting evolving faults that may appear as a power swing event (faults with slow moving impedance locus).

Dynamic transients in the power system, due to short-circuits, circuit switching, or load unbalance changes, can travel across the power network as power swings that are characterized by fluctuating currents and voltages. This can result in unwanted tripping since distance elements can respond to these power swings as faults. The D60 power swing detection element provides both power swing blocking and out-ofstep tripping functions. The element measures the positive sequence apparent impedance and traces its locus with respect to either a two or three-step user-selectable mho or quad

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The D60 relay uses an advanced phase selection algorithm that provides fast and accurate fault type identification even under weak in-feed conditions. A convenient trip function is built-in to coordinate actions of the key elements of the single-pole tripping package.

Communication Aided (Pilot) Schemes D60 supports different teleprotection functions for fast fault clearance for any faults within the protected line. The following types of pilot-aided schemes are available in the D60: • Direct Underreach Transfer Trip (DUTT) • Permissive Underreach Transfer Trip (PUTT) • Two Permissive Overreach Transfer Trip (POTT) • Hybrid Permissive Overreach Transfer Trip (HYB POTT): permissive echo and transient blocking logic incorporated • Directional Comparison Blocking Scheme (DCB) • Directional Comparison Unblocking Scheme (DCUB) • Customizable version of the POTT and DCB schemes (POTT1 and DCB1)

Undervoltage & Overvoltage Protection Long lines under lightly loaded or no-load conditions may experience voltages exceeding the rated insulation voltage level. Use the three phase overvoltage elements in the D60 to detect and trip on this condition. A second compensated overvoltage element detects overvoltage caused by breakers opening at the remote end. The D60 also provides additional voltage functions, including neutral overvoltage, negative sequence overvoltage and phase undervoltage.

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Transmission Protection

The advanced comparator-based distance elements provide the utmost security, sensitivity and selectivity for different types of faults. Superior digital filtering techniques provide secure and optimum reach accuracy even under worst case CVT transients. Secure directional discrimination is achieved by using positive sequence memory voltage polarization, providing reliable directionality for worst case close-in faults. Dual distance algorithms deliver exceptional security and speed performance to ensure average operating times of 1.5 cycles for 75% line reach and SIR 30, and <2.5 cycles for 90% line reach and SIR 60. The D60 employs a well-proven algorithm for phase selection, which provides faster, secure and reliable faulted phase identification for singlepole tripping and proper fault distance calculation for a variety of power system conditions. An additional voltage monitoring function provides extra security to the distance element, which can be used to block the distance elements under voltage source fuse failure conditions.

Load Encroachment

Trasmission Protection

D60 Line Distance Protection System

Overcurrent Functions

Breaker Failure

Scalable Hardware

The D60 provides thermal overload, and time and instantaneous overcurrent elements for phase, neutral, ground, negative sequence, phase and neutral directional. All of them can run in parallel with distance elements or can be programmed to provide overcurrent protection under conditions when the distance element is blocked (example VT fuse failure).

The D60 is able to provide fully independent breaker failure protection for the breakers associated to the line when connected to a substation with a breaker-and-a-half or ring bus arrangement. The D60 provides the elements to perform two independent breaker failure functions.

The D60 is available with a multitude of I/O configurations to suit the most demanding application needs. The expandable modular design allows for easy configuration and future upgrades.

Autorecloser The D60 provides multi-shot autoreclosing (up to 4 shots) for single or three-pole autoreclose on all types of faults with independently programmable dead time for each shot . Autoreclosing can be dynamically blocked by user-programmable logic. Four different autoreclose operation modes are available, enabling users to select the reclosing mode to suit specific applications.

Synchronism Check The D60 provides four synchrocheck elements that monitor voltage difference, phase angle difference and slip frequency, to ensure proper breaker closure as per user-defined settings. The D60 provides additional enhancements in synchronizing, by checking dead source conditions for synchronism bypass under these conditions.

Multiple Breaker Configurations The D60 supports dual-breaker busbar configurations, such as breaker-and-a-half or ring bus arrangements, providing dual-breaker autoreclose, dual synchrocheck elements, and dual independent breaker failure elements. The design provides secure operation during external faults with possible CT saturation.

D60 Breaker-and-a-Half Configuration

IEC 61850 Process Bus The IEC 61850 Process Bus module is designed to interface with the Multilin HardFiber System, allowing bi-directional IEC 61850 fiber optic communications. The HardFiber System is designed to integrate seamlessly with existing UR applications, including protection functions, FlexLogic™, metering and communications. The Multilin HardFiber System offers the following benefits: • Communicates using open standard IEC 61850 messaging • Drastically reduces P&C design, installation and testing labor by eliminating individual copper terminations • Integrates with existing D60’s by replacing traditional CT/VT inputs with the IEC 61850 Process Bus module • Does not introduce new cyber security concerns Visit the HardFiber System product page on the GE Digital Energy website for more details.

Advanced Automation The D60 incorporates advanced automation features including powerful FlexLogic programmable logic, communication, and SCADA capabilities that far surpass what is found in the average line protection relay. The D60 integrates seamlessly with other UR relays for complete system protection, including unit and auxiliary transformers, and balance of plant protection.

FlexLogic

D60 supports breaker-and-a-half configuration. Two CTs can be brought in individually and summed off at each terminal.

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FlexLogic is the powerful UR-platform programming logic engine that provides the ability to create customized protection and control schemes, minimizing the need and associated costs of auxiliary components and wiring. Using FlexLogic, the D60 can be programmed to provide required tripping logic along with custom scheme logic for breaker control (including interlocking with external synchronizers), transfer tripping schemes for remote breakers and dynamic setting group changes.

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• Flexible, modular I/O covering a broad range of input signals and tripping schemes • Types of digital outputs include triprated Form-A and Solid State Relay (SSR) mechanically latching, and Form-C outputs • RTDs and DCmA inputs are available to monitor equipment parameters, such as temperature and pressure

Monitoring and Metering The D60 includes high accuracy metering and recording for all AC signals. Voltage, current, and power metering are built into the relay as a standard feature. Current and voltage parameters are available as total RMS magnitude, and as fundamental frequency magnitude and angle.

Fault and Disturbance Recording The advanced disturbance and event recording features within the D60 can significantly reduce the time needed for postmortem analysis of power system events and the creation of regulatory reports. Recording functions include: • Sequence of Event (SOE) - 1024 time stamped events • Oscillography - 64 digital & up to 40 analog channels - Events with up to 45s length • Data Logger and Disturbance Recording - 16 channels up to 1 sample/cycle/channel • Fault Reports - Powerful summary report of pre-fault and fault values The very high sampling rate and large amount of storage space available for data recording in the D60 can eliminate the need for installing costly stand-alone recording equipment.

Advanced Device Health Diagnostics The D60 performs comprehensive device health diagnostic tests at startup and continuously during run-time to test its own major functions and critical hardware. These diagnostic tests monitor for conditions that could impact security and availability of protection, and present device status via SCADA communications and front panel display. Providing continuous monitoring and early detection of possible issues help improve system uptime.

D60 Line Distance Protection System

• Comprehensive device health diagnostic performed at startup

Settings Security & Device Status Reports

• Monitors the CT/VT input circuitry to validate the integrity of all signals

Cyber Security – CyberSentry UR

Transmission Protection

CyberSentry UR enabled UR devices deliver full cyber security features that help customers to comply with NERC CIP and NIST® IR 7628 cyber security requirements. This software option delivers the following core features:

AAA Server Support (Radius/LDAP) Enables integration with centrally managed authentication and accounting of all user activities and uses modern industry best practices and standards that meet and exceed NERC CIP requirements for authentication and password management.

Role Based Access Control (RBAC) Efficiently administrate users and roles within UR devices. The new and advanced access functions allow users to configure up to five roles for up to eight configurable users with independent passwords. The standard “Remote Authentication Dial In User Service” (Radius) is used for authentication.

Track changes of settings to your D60 & view health and operating status by generating a report with the click of a button.

• DNP 3.0 (serial & TCP/IP)

• Multicast IEEE C37.118 synchrophasor data between PMU and PDC devices using IEC 91850-90-5

Event Recorder (Syslog for SEM)

• Ethernet Global Data (EGD)

Direct I/O Messaging

Capture all cyber security related events within a SOE element (login, logout, invalid password attempts, remote/local access, user in session, settings change, FW update, etc), and then serve and classify data by security level using standard Syslog data format. This will enable integration with established SEM (Security Event Management) systems.

• IEC 60870-5-103 and IEC 60870-5-104

Communications

The new IEC 61850 implementation in the UR Family positions GE as an industry leader in this standard.

Direct I/O allows for the sharing of high-speed digital information between multiple UR relays via direct back-to-back connections or multiplexed through a standard DS0 multiplexer channel bank. Regardless of the connection method, direct I/O provides continuous real-time channel monitoring that supplies diagnostics information on channel health. Direct I/O provides superior relay-to-relay communications that can be used in advanced interlocking and other special protection schemes.

The D60 provides for secure remote data and engineering access, making it easy and flexible to use and integrate into new and existing infrastructures. Fiber optic Ethernet provides high-bandwidth communications allowing for low-latency controls and high-speed file transfers of relay fault and event record information. The available three independent Ethernet ports, redundant Ethernet option and the embedded managed Ethernet switch provide the means to create fault tolerant communication architectures in an easy, costeffective manner. The D60 supports the most popular industry standard protocols enabling easy, direct integration into monitoring and SCADA systems.

• IEC 61850 Ed. 2 with 61850-9-2 and 61850-90-5 support

• Modbus RTU, Modbus TCP/IP • HTTP, TFTP, SFTP and MMS file transfer • SNTP and IEEE 1588 for time synchronization • PRP as per IEC 62439-3

IInteroperability with Embedded IEC 61850 Edition 2

• Implements Edition 2 of the standard across the entire family of UR devices • Provides full relay setting management via standard SCL files (ICD, CID and IID) • Enables automated relay setting management using 3rd party tools through standard file transfer services (MMS and SFTP) • Increases the number of Logical Devices and data mapped to them, GOOSE messages, and reports to support different organizational needs for data transfer and reduce dependency on generic logical nodes

• Communication with up to 16 UR relays in single or redundant rings rather than strictly limited to simplistic point-to-point configurations between two devices • Connect to standard DS0 channel banks through standard RS422, G.703 or IEEE C37.94 interfaces or via direct fiber optic connections • No external or handheld tester required to provide channel diagnostic information

• Configures GE Systems based on IEC 61850 using universal 3rd party tools

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179

Trasmission Protection

D60 Line Distance Protection System

LAN Redundancy

EnerVista Software

• Manuals

Substation LAN redundancy has been traditionally accomplished by reconfiguring the active network topology in case of failure. Regardless of the type of LAN architecture (tree, mesh, etc), reconfiguring the active LAN requires time to switchover, during which the LAN is unavailable. UR devices deliver redundancy as specified by PRP-IEC 62439-3, which eliminates the dependency on LAN reconfiguration and the associated switchover time. The UR becomes a dual attached node that transmits data packets over both main and redundant networks simultaneously, so in case of failure, one of the data packets will reach the receiving device with no time delay.

The EnerVista suite is an industry-leading set of software programs that simplifies every aspect of using the D60 relay. The EnerVista suite provides all the tools to monitor the status of the protected asset, maintain the relay, and integrate information measured by the D60 into DCS or SCADA monitoring systems. Convenient COMTRADE and SOE viewers are an integral part of the UR setup software included with every UR relay, to carry out postmortem event analysis and ensure proper protection system operation.

• Application Notes

Multi-Language UR devices support multiple languages: English, French, Russian, Chinese, Turkish and German. These language options are available on the front panel, in the EnerVista setup software, and in the product manuals. Easily switch between English and an additional language on the local displays without uploading new firmware.

EnerVista Launchpad EnerVista Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining Multilin products. The setup software within Launchpad allows for the configuration of devices in real-time, by communicating using serial, Ethernet, or modem connections, or offline by creating setting files to be sent to devices at a later time. Included in Launchpad is a document archiving and management system that ensures critical documentation is up-todate and available when needed. Documents made available include:

• Guideform Specifications • Brochures • Wiring Diagrams • FAQ’s • Service Bulletins

Viewpoint Monitoring Viewpoint Monitoring is a simple-to-use and full-featured monitoring and data recording software package for small systems. Viewpoint Monitoring provides a complete HMI package with the following functionality: • Plug-&-Play Device Monitoring • System Single-Line Monitoring & Control • Annunciator Alarm Screens • Trending Reports • Automatic Event Retrieval • Automatic Waveform Retrieval

Power System Troubleshooting The D60 contains many tools and reports that simplify and reduce the amount of time required for troubleshooting power system events.

Analyze transmission line faults using system voltage, current and appropriate pickup flags that are measured & recorded up to 64 samples/cycle.

180

Record the operation of the internal D60 elements and external connected devices with 1ms time-stamped accuracy to identify the Sequence of Operation of station devices during faults and disturbances.

GEDigitalEnergy.com

Graphically view zone settings for ground phase distance elements for the selected zones and the power swing detection element.

D60 Line Distance Protection System

Viewpoint UR Engineer

Typical Wiring

Viewpoint UR Engineer is a set of powerful tools that will allows the configuration and testing of GE relays at a system level in an easy-touse graphical drag-and-drop environment . Viewpoint UR Engineer provides the following configuration and commissioning utilities:

A

B

52

52

C

A

• Graphical Logic Designer

B

C

CURRENT POLARIZATION SOURCE

Transmission Protection

• Graphical System Designer F 8a

F 8c VX

VX

F 7a

F 7c VC

VC

F 6a

F 6c

VA

VB

F 5a

F 5c

VA

VB

F 4b

IG5

F 4c

IC1

IG

F 3c

F 4a

IC

IG1

F 3a

F 3b

IC5

F 2b

F 2c

IB

IB1

F 1c

F 2a

IA1

IB5

F 1a

F 1b IA

• Graphical System Monitor

IA5

• Graphical Logic Monitor

Viewpoint Maintenance Viewpoint Maintenance provides tools that will create reports on the operating status of the relay, simplify the steps to download fault and event data, and reduce the work required for cyber security compliance audits. Tools available in Viewpoint Maintenance include:

H7a H7c H8a H8c H7b

H1a H1b H1c H2a H2b H2c H3a H3b H3c H4a H4b H4c H5a H5b H5c H6a H6b H6c

I

H1

V I

H2

H8b

V

SURGE

I

H3

V I

Digital Energy Multilin

H4

V I

D60

• Settings Security Audit Report

H5

H6

W5a W5c W6a W6c W5b

• Single-Click Fault Data Retrieval

EnerVista Integrator is a toolkit that allows seamless integration of Multilin devices into new or existing automation systems. Included in EnerVista Integrator is:

V

W1

V I

W2

V

W3

W4

W8b

6C

SURGE

• OPC/DDE Server

6D

P3

P4

U3a U3c U4a U4c U3b

• Multilin Drivers • Automatic Event Retrieval

P5

U5a U5c U6a U6c U5b

P6

P7

U7a U7c U8a U8c U7b U8b

P8

SURGE

RS-232

B1b B1a B2b B3a B3b B5b HI B6b LO B6a B8a B8b

DC

Fibre * Optic

Tx1

CRITICAL FAILURE

2

(front)

3

CONTROL POWER

4

SURGE FILTER

5

10BaseFL

NORMAL

10BaseFL

COM 1

ALTERNATE

Rx2

Shielded

M1a M1b M1c M2a M2b M2c M3a M3b M3c M4a M4b M4c M5a M5b M5c M6a M6b M6c M7a M7b M7c M8a M8b M8c

1

DB-9

OUTPUT

Rx1 Tx2

6K

User Interface

1

• Automatic Waveform Retrieval

6

10BaseT

Remote Device

7

D1a D2a D3a D4b D4a

RS485 com

Co-axial

BNC

Co-axial

BNC

TC 2

P1a P1b P1c P2a P2b P2c P3a P3b P3c P4a P4b P4c P5a P5b P5c P6a P6b P6c P7a P7b P7c P8a P8b P8c

P1

P2

U1a U1c U2a U2c U1b

TC 1

W1a W1b W1c W2a W2b W2c W3a W3b W3c W4a W4b W4c

I

6A

W7a W7c W8a W8c W7b

EnerVista Integrator

V I

D60-H07-HLH-F8L-H6H-M6K-P6C-U6D-W6A

• Device Health Report

The D60 front panel provides extensive local HMI capabilities. The local display is used for monitoring, status messaging, fault diagnosis, and device configuration. User-configurable messages that combine text with live data can be displayed when user-defined conditions are met.

6H

8 IRIG-B Input

PERSONAL COMPUTER

CONNECTOR

CONNECTOR TXD RXD

SGND

1 2 3 4 5 6 7 8 9 UR

1 2 3 4 5 6 7 8 9

8 3 RXD 2 TXD 20 7 SGND 6 4 5 22

COMPUTER

IRIG-B Output

837774A6.CDR Minimum

PROVIDED

X W

V

U

6 6 Inputs/ Inputs/ outputs outputs * *

T

S

R

P

N

M

6 6 Inputs/ Inputs/ outputs outputs * *

L

K

H G

J 6

F 8

Inputs/ CT/VT outputs

D

B

9

1

CPU

Power Supply

This diagram is based on the following order code: D60-H07-HLH-F8L-H6H-M6K-P6C-U6D-W6A .This diagram provides an example of how the device is wired, not specifically how to wire the device. Please refer to the Instruction Manual for additional details on wiring based on various configurations.

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181

Ordering

D60 - * ** - H * * - F ** - H ** - M ** - P ** - U ** - W **

For Full Sized Horizontal Mount

Base Unit D60 Base Unit CPU E RS485 & RS485 (IEC 61850 option not available) J RS485 + multimode ST 100BaseFX K RS485 + multimode ST Redundant 100BaseFX N RS485 + 10/100 BaseT T RS485 + three multimode SFP LC 100BaseFX. Req FW v7xx or higher U RS485 + two multimode SFP LC 100BaseFX + one SFP RJ45 100BaseT. Req FW v7xx or higher V RS485 + three SFP RJ45 100BaseT. Req FW v7xx or higher Software Options 00 No Software Options (see note 1 below) 02 Breaker and Half 03 IEC 61850 05 Breaker and Half + IEC 61850 06 Phasor Measurement Unit (PMU) 07 IEC 61850 + Phasor Measurement Unit (PMU) 08 Breaker and Half + Phasor Measurement Unit (PMU) 09 Breaker and Half + IEC 61850 + Phasor Measurement Unit (PMU) A0 CyberSentry UR Lvl 1. Req UR FW 7.xx or higher B0 IEEE 1588. Req UR FW 7.xx or higher C0 PRP D0 IEEE 1588 + CyberSentry. Req UR FW 7.xx or higher M0 IEC 61850 + PMU + 61850-90-5 Mount H Horizontal (19" rack) - Standard A Horizontal (19" rack) - Harsh Chemical Environment Option V Vertical (3/4 size) - Standard B Vertical (3/4 size) - Harsh Chemical Environment Option User Interface F Vertical Front Panel with English Display I Enhanced German Front Panel J Enhanced German Front Panel with User-Programmable Pushbuttons K Enhanced English Front Panel L Enhanced English Front Panel with User-Programmable Pushbuttons M Enhanced French Front Panel N Enhanced French Front Panel with User-Programmable Pushbuttons Q Enhanced Russian Front Panel T Enhanced Russian Front Panel with User-Programmable Pushbuttons U Enhanced Chinese Front Panel V Enhanced Chinese Front Panel with User-Programmable Pushbuttons W Enhanced Turkish Front Panel Y Enhanced Turkish Front Panel with User-Programmable Pushbuttons Power Supply H RH 125/250 V AC/DC w/ redundant 125/250 V AC/DC power supply (see note 2 below) H 125/250 V AC/DC CT/VT DSP 8L 8L Standard 4CT/4VT w/ enhanced diagnostics 8M 8M Sensitive Ground 4CT/4VT w/ enhanced diagnostics IEC 61850 Process Bus 81 8 Port IEC 61850 Process Bus Module Digital I/O XX XX XX XX XX No module 4A 4A 4A 4A 4A 4 Solid State (No Monitoring) MOSFET Outputs 4C 4C 4C 4C 4C 4 Solid State (Current w/opt Voltage) MOSFET Outputs 4D 4D 4D 4D 4D 16 Digital Inputs with Auto-Burnish 4L 4L 4L 4L 4L 14 Form-A (No Monitoring) Latchable Outputs 67 67 67 67 67 8 Form-A (No Monitoring) Outputs 6C 6C 6C 6C 6C 8 Form-C Outputs 6D 6D 6D 6D 6D 16 Digital Inputs 6E 6E 6E 6E 6E 4 Form-C Outputs, 8 Digital Inputs 6F 6F 6F 6F 6F 8 Fast Form-C Outputs 6K 6K 6K 6K 6K 4 Form-C & 4 Fast Form-C Outputs 6L 6L 6L 6L 6L 2 Form-A (Current w/ opt Voltage) & 2 Form-C Outputs, 8 Digital Inputs 6M 6M 6M 6M 6M 2 Form-A (Current w/ opt Voltage) & 4 Form-C Outputs, 4 Digital Inputs 6N 6N 6N 6N 6N 4 Form-A (Current w/ opt Voltage) Outputs, 8 Digital Inputs 6P 6P 6P 6P 6P 6 Form-A (Current w/ opt Voltage) Outputs, 4 Digital Inputs 6R 6R 6R 6R 6R 2 Form-A (No Monitoring) & 2 Form-C Outputs, 8 Digital Inputs 6S 6S 6S 6S 6S 2 Form-A (No Monitoring) & 4 Form-C Outputs, 4 Digital Inputs 6T 6T 6T 6T 6T 4 Form-A (No Monitoring) Outputs, 8 Digital Inputs 6U 6U 6U 6U 6U 6 Form-A (No Monitoring) Outputs, 4 Digital Inputs 6V 6V 6V 6V 6V 2 Form-A (Cur w/ opt Volt) 1 Form-C Output, 2 Latching Outputs, 8 Digital Inputs Transducer I/O 5A 5A 5A 5A 5A 4 dcmA Inputs, 4 dcmA Outputs 5F 5F 5F 5F 5F 8 dcmA Inputs Inter-Relay Communications 2B C37.94SM, 1300nm singlemode, ELED, 2 Channel singlemode 2I Channel 1 - IEEE C37.94, 820nm, multimode fiber, 64/128 kbps; Channel 2 - 1300 nm, singlemode, LASER 2J Channel 1 - IEEE C37.94, 820nm, multimode fiber, 64/128 kbps; Channel 2 - 1550 nm, singlemode, LASER 7A 820 nm, multimode, LED, 1 Channel 7B 1300 nm, multimode, LED, 1 Channel 7C 1300 nm, singlemode, ELED, 1 Channel 7H 820 nm, multimode, LED, 2 Channels 7I 1300 nm, multimode, LED, 2 Channels 7J 1300 nm, singlemode, ELED, 2 Channels 7S G.703, 2 Channels 7W RS422, 2 Channels 73 1550 nm, singlemode, LASER, 2 Channels 77 IEEE C37.94, 820 nm, multimode, LED, 2 Channel

Ordering Notes: 1. To view all the options available for D60, please visit GE’s On-Line Store http://store.gedigitalenergy.com/viewprod.asp?model=D60 2. Redundant power supply only available in horizontal unit. If redundant is chosen, must be same type. Maximum 2 per chassis.

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12592H(E) English 150122

Multilin™ D30 High-Speed Primary and Backup Distance Protection

Protection & Control

The Multilin D30 is a cost-effective distance protection relay intended for protecting sub-transmission lines and underground cables of different voltage levels. Part of the Universal Relay (UR) family, the D30 comes with a variety of versatile features truly integrating protection, monitoring, metering, communication and control in one easy-to-use device.

• Phase & Ground distance (5 zones) with independent settings

Key Benefits • Cost-effective, high-speed, 5 zone quad or mho, phase and ground distance protection • Application flexibility with programmable logic and multiple I/O options for customized pilot schemes • Simplified teleprotection interfaces with direct I/O communications hardware for transfer trip and pilot-aided distance schemes • Reduced relay-to-relay wiring and associated installation costs through high-speed inter-relay communications • Advanced IEC 61850 Ed. 2 implementation, complete settings via SCL files and IEC 61850-9-2 process bus solution enable resource and platform managing optimization and reduce cost of ownership • Increased network availability via failover time reduced to zero through IEC® 62439-3 “PRP” support • Advanced fault and disturbance recording, including internal relay operating signals, eliminating the need for external recording devices

Applications • Overhead sub-transmission lines and underground cables including series compensated lines • Circuits requiring three-pole autoreclosing and independent synchrocheck supervision • Circuits with in-zone power transformers • Secure application with Capacitively-Coupled Voltage Transformers (CCVTs) • Backup protection for generators, transformers and reactors

• Out-of-step tripping and power swing blocking • Line pickup, thermal protection, under/over frequency • Four-shot autorecloser, VT fuse failure detection, and synchronism check

Advanced Communications • 3 independent Ethernet ports for simultaneous & dedicated network connections with IEEE 1588 support • Advanced IEC 61850 Edition 2 implementation and IEC 61850-9-2 process bus support • Supported industry protocols: IEC 61850 Ed. 2, SFTP, MMS File Transfer Service, DNP 3.0, Modbus Serial/TCP, IEEE 1588, IEC 60870-5-104 and 103, PRP, SNTP, HTTP, TFTP • Direct I/O for secure, high-speed exchange of data for DTT & pilot-aided schemes

Cyber Security • CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog) • Setting for security audit trails, tracking changes to D30 configurations

Monitoring & Metering • Advanced recording capabilities with highcapacity event recorder, configurable and extended waveform capture and data logger • Metering: current, voltage, power, energy, frequency

D30 Line Distance Protection System

Protection and Control

D30 - Protection, Metering, Monitoring and Control

Trasmission Protection

As part of the UR family of Protection & Control devices, the Multilin D30 offers a high degree of modularity in its design and functionality, providing superior performance while meeting the toughest requirements of the marketplace. Advanced protection and control features of this relay includes:

Distance Protection The core of the D30 relay is the distance function providing a high degree of sensitivity and selectivity for all types of faults. The D30 comes with five zones of phase distance and ground distance providing the user maximum flexibility to cater to different applications, including primary sub-transmission line protection and backup protection for busbars, EHV and HV transmission lines, generators, transformers and reactors. The relay can be applied to power systems with different earthing conditions, lines

The D30 is the single point for protection, control, metering, and monitoring in one integrated device that can be easily connected directly to HMI or SCADA monitoring and control systems.

Functional Block Diagram

52

Close

Monitoring

Trip

59X

27X

68

78

25 (4)

79

50DD

50P (2)

50_2 (2)

51 (2)

51_2 (2)

21P (5)

67P (2)

67_2 (2)

50N (2)

Metering

50G (2)

51N (2)

67N/G (2)

Transducer Inputs

21G (5) 59P (3) 27P (3)

51G (2) 59_2 (3)

59N (3)

D30 Line Distance Protection System ANSI Device Numbers & Functions ®

DEVICE NUMBER

FUNCTION

DEVICE NUMBER

FUNCTION

21G 21P 25 27P 27X 49 50DD 50G 50N

Ground Distance Phase Distance Synchronism Check Phase Undervoltage Auxiliary Undervoltage Thermal Overload Current Disturbance Detector Ground Instantaneous Overcurrent Neutral Instantaneous Overcurrent

50P 50_2 51G 51N 51P 51_2 52 59N 59P

Phase Instantaneous Overcurrent Negative Sequence Instantaneous Overcurrent Ground Time Overcurrent Neutral Time Overcurrent Phase Time Overcurrent Negative Sequence Time Overcurrent AC Circuit Breaker Neutral Overvoltage Phase Overvoltage

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DEVICE NUMBER

FUNCTION

59X 59_2 67N 67P 67_2 68 78 79

Auxiliary Overvoltage Negative Sequence Overvoltage Neutral Directional Overcurrent Phase Directional Overcurrent Negative Sequence Directional Overcurrent Power Swing Blocking Out-of-Step Tripping Automatic Recloser

D30 Line Distance Protection System

Load Encroachment

Z3

Z1

Z1 looking through a transformer.

Fault Locator

Z3

Z1

The integrated fault locator provides distance to fault in kilometers or miles. Parallel line zero-sequence current compensation and load current compensation enables the D30 to provide improved accuracy for fault distance measurement .

Z1 & Z3 looking through a transformer.

Line Pickup (Switch-on-to-Fault) with in-zone transformers or tapped transformer feeders, and overhead lines with series compensation. Each zone element for the phase and ground distance can be independently set as quad or mho characteristics with the flexibility of designing different characteristic shapes to suit different power system conditions. The advanced comparator-based distance elements provide utmost security, sensitivity and selectivity for different types of faults. Superior digital filtering techniques provide secure and optimum reach accuracy even under worst-case CVT transients. Secure directional discrimination is achieved by using positive sequence memory voltage polarization providing reliable directionality for worst-case close-in faults. Dual distance algorithms deliver exceptional security and speed performance to ensure average operating times of 1.5 cycles for 75% line reach and SIR 30, and <2.5 cycles for 90% line reach and SIR 60. An additional voltage monitoring function provides extra security to the distance element, which can be used to block the distance elements under voltage source fuse failure conditions.

The line pickup feature uses a combination of undercurrent and undervoltage to identify a line that has been de-energized (line end open). Three instantaneous overcurrent elements are used to identify a previously de-energized line that has been closed on to a fault.

Power Swing Detection Dynamic transients in the power system, due to short-circuits, circuit switching, or load changes, can travel across the power network as power swings characterized by fluctuating currents and voltages. This can result in unwanted tripping since distance elements can respond to these power swings as faults. The D30 swing detection element provides both power swing blocking and out-of-step tripping functions. The element measures the positive sequence

Overvoltage and Undervoltage Protection Long lines under lightly loaded or no-load conditions may experience voltages exceeding the rated insulation voltage level of the line. Use the three phase overvoltage elements of the D30 to initiate a local trip as well as a remote trip using direct I/O. The D30 also provides additional voltage functions including neutral overvoltage, negative sequence overvoltage and phase undervoltage.

Overcurrent Functions The D30 provides thermal overload, time and instantaneous overcurrent elements for phase, neutral, ground, negative sequence, phase and neutral directional. All of them can run in parallel with distance elements or can be programmed to provide overcurrent protection under conditions when the distance element is blocked (Eg. VT fuse failure).

Autorecloser The D30 provides multi-shot auto reclosing (up to 4 shots) for three-pole autoreclose on all types of faults with independent settings for each shot. The autoreclose element can be dynamically blocked or unblocked by other elements or user logic. This way they can be coordinated with the D30 protection setting groups.

In-Zone Transformer Compensation Phase distance elements in the D30 can be used to detect faults through different types of three-phase wye/delta transformers allowing the application of the D30 for backup protection on generators. VTs and CTs can be installed independently on either side of the power transformer. The relay automatically compensates for transformer connections, to guarantee accurate reach for any type of fault. Distance relay quadrilateral characteristics supervised by the load encroachment function.

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Transmission Protection

The load encroachment feature offers discrimination between line loading and fault conditions, especially for long lines under heavy loads by supervising the distance elements or any overcurrent element . This prevents unwanted tripping under heavy load conditions and enables optimum operation of the line while meeting regulatory requirements for line loading.

apparent impedance and traces its locus with respect to either a two or three-step userselectable mho or quad operating characteristic. Negative sequence current supervisors provide extended selectivity for detecting evolving faults that may appear as a power swing event (faults with slow moving impedance locus).

Trasmission Protection

D30 Line Distance Protection System

Synchronism Check

Scalable Hardware

The D30 provides four synchrocheck elements that monitor voltage difference, phase angle difference and slip frequency to ensure proper breaker closure as per user-defined settings. The D30 provides additional enhancements in synchronizing by checking dead source conditions for synchronism bypass under these conditions.

The D30 is available with a multitude of I/O configurations to suit the most demanding application needs. The expandable modular design allows for easy configuration and future upgrades.

IEC 61850 Process Bus The IEC 61850 Process Bus module is designed to interface with the Multilin HardFiber System, allowing bi-directional IEC 61850 fiber optic communications. The HardFiber System is designed to integrate seamlessly with existing UR applications, including protection functions, FlexLogic, metering and communications. The Multilin HardFiber System offers the following benefits: • Communicates using open standard IEC 61850 messaging • Drastically reduces P&C design, installation and testing labor by eliminating individual copper terminations • Integrates with existing D30’s by replacing traditional CT/VT inputs with the IEC 61850 Process Bus module • Does not introduce new cyber security concerns Visit the HardFiber System product page on the Multilin web site for more details.

Advanced Automation The D30 incorporates advanced automation features including powerful FlexLogic programmable logic, communication, and SCADA capabilities that far surpass what is found in the average line protection relay used for subtransmission. The D30 integrates seamlessly with other UR relays for complete system protection.

FlexLogic FlexLogic is the powerful UR-platform programming logic engine that provides the ability to create customized protection and control schemes, minimizing the need and associated costs of auxiliary components and wiring. Using FlexLogic, the D30 can be programmed to provide the required tripping logic along with custom scheme logic for breaker control (including interlocking), transfer tripping schemes for remote breakers and dynamic setting group changes.

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• Flexible, modular I/O covering a broad range of input signals and tripping schemes • Types of digital outputs include triprated Form-A and Solid State Relay (SSR) mechanically latching, and Form-C outputs

monitor for conditions that could impact security and availability of protection, and present device status via SCADA communications and front panel display. Providing continuous monitoring and early detection of possible issues help improve system uptime. • Comprehensive device health diagnostic performed at startup • Monitors the CT/VT input circuitry to validate the integrity of all signals

Cyber Security – CyberSentry UR

• Form-A and SSR outputs available with optional circuit continuity monitoring and current detection to verify continuity and health of the associated circuitry

CyberSentry UR enabled UR devices deliver full cyber security features that help customers to comply with NERC CIP and NIST® IR 7628 cyber security requirements.

• Mechanically latching outputs can be used to develop secure interlocking applications and replace electromechanical lockout relays

This software option delivers the following core features:

Monitoring and Metering The D30 includes high accuracy metering and recording for all AC signals. Voltage, current , and power metering are built into the relay as a standard feature. Current and voltage parameters are available as total RMS magnitude, and as fundamental frequency magnitude and angle.

Fault and Disturbance Recording The advanced disturbance and event recording features within the D30 can significantly reduce the time needed for postmortem analysis of power system events and the creation of regulatory reports. Recording functions include: • Sequence of Event (SOE) - 1024 time stamped events • Oscillography - 64 digital & up to 40 analog channels - Events with up to 45s length • D  ata Logger and Disturbance Recording - 16 channels up to 1 sample/cycle/channel • Fault Reports - Powerful summary report of pre-fault and fault values The very high sampling rate and large amount of storage space available for data recording in the D30 can eliminate the need for installing costly stand-alone recording equipment.

Advanced Device Health Diagnostics The D30 performs comprehensive device health diagnostic tests at startup and continuously during run-time to test its own major functions and critical hardware. These diagnostic tests

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AAA Server Support (Radius/LDAP) Enables integration with centrally managed authentication and accounting of all user activities and uses modern industry best practices and standards that meet and exceed NERC CIP requirements for authentication and password management.

Role Based Access Control (RBAC) Efficiently administrate users and roles within UR devices. The new and advanced access functions allow users to configure up to five roles for up to eight configurable users with independent passwords. The standard “Remote Authentication Dial In User Service” (Radius) is used for authentication.

Event Recorder (Syslog for SEM) Capture all cyber security related events within a SOE element (login, logout, invalid password attempts, remote/local access, user in session, settings change, FW update, etc), and then serve and classify data by security level using standard Syslog data format. This will enable integration with established SEM (Security Event Management) systems.

Communications The D30 provides advanced commun-ications technologies for remote data and engineering access, making it easy and flexible to use and integrate into new and existing infrastructures. Direct support for fiber optic Ethernet provides high-bandwidth communications allowing for low-latency controls and high-speed file transfers of relay fault and event record information. The available three independent

D30 Line Distance Protection System

Ethernet ports, redundant Ethernet option and the embedded managed Ethernet switch provide the means to create fault tolerant communication architectures in an easy, costeffective manner.

Substation Monitoring

The D30 supports the most popular industry standard protocols enabling easy, direct integration into monitoring and SCADA systems. Transmission Protection

• IEC 61850 Ed. 2 with 61850-9-2 support • DNP 3.0 (serial & TCP/IP) • Ethernet Global Data (EGD) • IEC 60870-5-103 and IEC 60870-5-104 • Modbus RTU, Modbus TCP/IP • HTTP, TFTP, SFTP and MMS file transfer • SNTP and IEEE 1588 for time synchronization • PRP as per IEC 62439-3

Interoperability with Embedded IEC 61850 Edition 2 The new IEC 61850 implementation in the UR Family positions GE as an industry leader in this standard. • Implements Edition 2 of the standard across the entire family of UR devices • Provides full relay setting management via standard SCL files (ICD, CID and IID) • Enables automated relay setting management using 3rd party tools through standard file transfer services (MMS and SFTP) • Increases the number of Logical Devices and data mapped to them, GOOSE messages, and reports to support different organizational needs for data transfer and reduce dependency on generic logical nodes • Configures GE Systems based on IEC 61850 using universal 3rd party tools

Direct I/O Messaging Direct I/O allows for the sharing of high-speed digital information between multiple UR relays via direct back-to-back connections or multiplexed through a standard DS0 multiplexer channel bank. Regardless of the connection method, direct I/O provides continuous real-time channel monitoring that supplies diagnostics information on channel health. Direct I/O provides superior relay-to-relay communications that can be used in advanced interlocking, and other special protection schemes. • Communication with up to 16 UR relays in single or redundant rings rather than strictly limited to simplistic point-to-point configurations between two devices

Monitor the status of your substation using the easy to use Viewpoint Monitoring HMI.

• Connect to standard DS0 channel banks through standard RS422, G.703 or IEEE C37.94 interfaces or via direct fiber optic connections • No external or handheld tester required to provide channel diagnostic information

LAN Redundancy Substation LAN redundancy has been traditionally accomplished by reconfiguring the active network topology in case of failure. Regardless of the type of LAN architecture (tree, mesh, etc), reconfiguring the active LAN requires time to switchover, during which the LAN is unavailable. UR devices deliver redundancy as specified by PRP-IEC 62439-3, which eliminates the dependency on LAN reconfiguration and the associated switchover time. The UR becomes a dual attached node that transmits data packets over both main and redundant networks simultaneously, so in case of failure, one of the data packets will reach the receiving device with no time delay.

Multi-Language UR devices support multiple languages: English, French, Russian, Chinese, Turkish and German. These language options are available on the front panel, in the EnerVista setup software, and in the product manuals. Easily switch between English and an additional language on the local displays without uploading new firmware.

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EnerVista Software The EnerVista suite is an industry-leading set of software programs that simplifies every aspect of using the D30 relay. The EnerVista suite provides all the tools to monitor the status of the protected asset, maintain the relay, and integrate information measured by the D30 into DCS or SCADA monitoring systems. Convenient COMTRADE and SOE viewers are an integral part of the UR setup software included with every UR relay, to carry out postmortem event analysis and ensure proper protection system operation.

EnerVista Launchpad EnerVista Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining Multilin products. The setup software within Launchpad allows for the configuration of devices in real-time by communicating using serial, Ethernet , or modem connections, or offline by creating setting files to be sent to devices at a later time. Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed. Documents made available include:

187

D30 Line Distance Protection System

• Manuals

Viewpoint UR Engineer

EnerVista Integrator

• Application Notes

EnerVista Integrator is a toolkit that allows seamless integration of Multilin devices into new or existing automation systems. Included in EnerVista Integrator is:

• FAQ’s

Viewpoint UR Engineer is a set of powerful tools that allows the configuration and testing of GE relays at a system level in an easy-touse graphical drag-and-drop environment . Viewpoint UR Engineer provides the following configuration and commissioning utilities:

• Service Bulletins

• Graphical Logic Designer

Viewpoint Monitoring

• Graphical System Designer

Viewpoint Monitoring is a simple-to-use and full-featured monitoring and data recording software package for small systems. Viewpoint Monitoring provides a complete HMI package with the following functionality:

• Graphical Logic Monitor

• Guideform Specifications • Brochures

Trasmission Protection

• Wiring Diagrams

• Automatic Waveform Retrieval

Viewpoint Maintenance

The D30 front panel provides extensive local HMI capabilities. The local display is used for monitoring, status messaging, fault diagnosis, and device configuration. User-configurable messages that combine text with live data can be displayed when user-defined conditions are met.

• Automatic Event Retrieval

• Settings Security Audit Report

• Automatic Waveform Retrieval

• Device Health Report

• Annunciator Alarm Screens

• Automatic Event Retrieval

User Interface

• Trending Reports

• System Single-Line Monitoring & Control

• Multilin Drivers

• Graphical System Monitor

Viewpoint Maintenance provides tools that will create reports on the operating status of the relay, simplify the steps to download fault and event data, and reduce the work required for cyber security compliance audits. Tools available in Viewpoint Maintenance include:

• Plug-&-Play Device Monitoring

• OPC/DDE Server

• Single-Click Fault Data Retrieval

Power System Troubleshooting The D30 contains many tools and reports that simplify and reduce the amount of time required for troubleshooting power system events.

Analyze transmission line faults using system voltage, current and appropriate pickup flags that are measured & recorded up to 64 samples/cycle.

Graphically view zone settings for ground & phase distance elements for the selected zones. Record the operation of the internal D30 elements and external connected devices with 1ms time-stamped accuracy to identify the Sequence of Operation of station devices during faults and disturbances.

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D30 Line Distance Protection System

Typical Wiring A

B

52

52

C

A

B

C

F 8a

V I

H2

H8b

V

SURGE

I

H3

V I

H4

Multilin

V I

H5

D30

V I

H6

W5a W5c W6a W6c W5b

V

W1

V I

W2

W7a W7c W8a W8c W7b

V

W3

W4

W8b

6C

SURGE

6D

P3

P4

U3a U3c U4a U4c U3b

P5

U5a U5c U6a U6c U5b

P6

P7

U7a U7c U8a U8c U7b U8b

6K

P8

SURGE

DC

1

CRITICAL FAILURE

M1a M1b M1c M2a M2b M2c M3a M3b M3c M4a M4b M4c M5a M5b M5c M6a M6b M6c M7a M7b M7c M8a M8b M8c

M1

RS-232 DB-9

B1b B1a B2b B3a B3b B5b HI B6b LO B6a B8a B8b

M2

(front)

M3

OUTPUT CONTROL POWER

M4

SURGE FILTER

M5

M6

Fibre * Optic

Tx1

10BaseFL

NORMAL

Rx1 Tx2

10BaseFL

COM 1

ALTERNATE

Rx2

Shielded

M7

10BaseT

Remote Device

D1a D2a D3a D4b D4a

M8 RS485

Minimum

PROVIDED

CONNECTOR

CONNECTOR TXD RXD

SGND

1 2 3 4 5 6 7 8 9 UR

1 2 3 4 5 6 7 8 9

8 3 RXD 2 TXD 20 7 SGND 6 4 5 22

COMPUTER

IRIG-B Input IRIG-B Output

BNC

Co-axial

PERSONAL COMPUTER

com

BNC

Co-axial

TC 2

P1a P1b P1c P2a P2b P2c P3a P3b P3c P4a P4b P4c P5a P5b P5c P6a P6b P6c P7a P7b P7c P8a P8b P8c

P1

P2

U1a U1c U2a U2c U1b

TC 1

W1a W1b W1c W2a W2b W2c W3a W3b W3c W4a W4b W4c

I

6A

F 8c

VX

H1a H1b H1c H2a H2b H2c H3a H3b H3c H4a H4b H4c H5a H5b H5c H6a H6b H6c

I

H1

VX

F 7c

F 7a

6H

VC

VC

F 6a VB

F 6c

VA

VB

F 5a

F 5c

VA

F 4b

IG5

F 4c

IC1

IG

F 3c

F 4a

IC

IG1

F 3a

F 3b

IC5

F 2b

F 2c

IB

IB1

F 1c

F 2a

IA1

IB5

F 1a

F 1b IA

H7a H7c H8a H8c H7b

Transmission Protection

IA5

CURRENT POLARIZATION SOURCE

X W

V

U

6 6 Inputs/ Inputs/ outputs outputs * *

T

S

R

P

N

M

6 6 Inputs/ Inputs/ outputs outputs * *

L

K

H G

J 6

F 8

Inputs/ CT/VT outputs

D

B

9

1

CPU

Power Supply

D30-H00-HCL-F8F-H6H-M6K-P6C-U6D-W6A

configurations.

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189

Ordering

D30 - * ** - H * * - F ** - H ** - M ** - P ** - U ** - W**

For Full Sized Horizontal Mount

Base Unit D30 Base Unit CPU E RS485 + RS485 (IEC 61850 option not available) J RS485 + Multimode ST 100BaseFX K RS485 + Multimode ST Redundant 100BaseFX N RS485 + 10/100 BaseT T RS485 + three Multimode SFP LC 100BaseFX. Req FW v7xx or higher U RS485 + two Multimode SFP LC 100BaseFX + one SFP RJ45 100BaseT. Req FW v7xx or higher V RS485 + three SFP RJ45 100BaseT. Req FW v7xx or higher Software Options 00 No Software Options (see note 1 below) 03 IEC 61850 A0 CyberSentry UR Lvl 1. Req UR FW 7.xx or higher B0 IEEE 1588. Req UR FW 7.xx or higher C0 PRP D0 IEEE 1588 + CyberSentry. Req UR FW 7.xx or higher Mount H Horizontal (19" rack) - Standard A Horizontal (19" rack) - Harsh Chemical Environment Option V Vertical (3/4 size) - Standard B Vertical (3/4 size) - Harsh Chemical Environment Option User Interface F Vertical Front Panel with English Display I Enhanced German Front Panel J Enhanced German Front Panel with User-Programmable Pushbuttons K Enhanced English Front Panel L Enhanced English Front Panel with User-Programmable Pushbuttons M Enhanced French Front Panel N Enhanced French Front Panel with User-Programmable Pushbuttons Q Enhanced Russian Front Panel T Enhanced Russian Front Panel with User-Programmable Pushbuttons U Enhanced Chinese Front Panel V Enhanced Chinese Front Panel with User-Programmable Pushbuttons W Enhanced Turkish Front Panel Y Enhanced Turkish Front Panel with User-Programmable Pushbuttons Power Supply H 125 / 250 V AC/DC (see note 2 below) H RH 125/250 V AC/DC with redundant 125/250 V AC/DC power supply L 24 - 48 V (DC only) CT/VT DSP 8L Standard 4CT/4VT w/ enhanced diagnostics 8M Sensitive Ground 4CT/4VT w/ enhanced diagnostics IEC 61850 Process Bus 81 8 Port IEC 61850 Process Bus Module Digital I/O XX XX XX XX XX No module 4A 4A 4A 4A 4A 4 Solid State (No Monitoring) MOSFET Outputs 4C 4C 4C 4C 4C 4 Solid State (Current w/opt Voltage) MOSFET Outputs 4D 4D 4D 4D 4D 16 Digital Inputs with Auto-Burnish 4L 4L 4L 4L 4L 14 Form-A (No Monitoring) Latchable Outputs 67 67 67 67 67 8 Form-A (No Monitoring) Outputs 6C 6C 6C 6C 6C 8 Form-C Outputs 6D 6D 6D 6D 6D 16 Digital Inputs 6E 6E 6E 6E 6E 4 Form-C Outputs, 8 Digital Inputs 6F 6F 6F 6F 6F 8 Fast Form-C Outputs 6K 6K 6K 6K 6K 4 Form-C & 4 Fast Form-C Outputs 6L 6L 6L 6L 6L 2 Form-A (Current w/ opt Voltage) & 2 Form-C Outputs, 8 Digital Inputs 6M 6M 6M 6M 6M 2 Form-A (Current w/ opt Voltage) & 4 Form-C Outputs, 4 Digital Inputs 6N 6N 6N 6N 6N 4 Form-A (Current w/ opt Voltage) Outputs, 8 Digital Inputs 6P 6P 6P 6P 6P 6 Form-A (Current w/ opt Voltage) Outputs, 4 Digital Inputs 6R 6R 6R 6R 6R 2 Form-A (No Monitoring) & 2 Form-C Outputs, 8 Digital Inputs 6S 6S 6S 6S 6S 2 Form-A (No Monitoring) & 4 Form-C Outputs, 4 Digital Inputs 6T 6T 6T 6T 6T 4 Form-A (No Monitoring) Outputs, 8 Digital Inputs 6U 6U 6U 6U 6U 6 Form-A (No Monitoring) Outputs, 4 Digital Inputs 6V 6V 6V 6V 6V 2 Form-A (Cur w/ opt Volt) 1 Form-C Output, 2 Latching Outputs, 8 Digital Inputs Transducer I/O 5A 5A 5A 5A 5A 4 dcmA Inputs, 4 dcmA Outputs 5F 5F 5F 5F 5F 8 dcmA Inputs Inter-Relay Communications 2B IEEE C37.94SM, 1300nm singlemode, ELED, 2 Channel singlemode 2I Channel 1 - IEEE C37.94, 820nm, multimode fiber, 64/128 kbps; Channel 2 - 1300 nm, singlemode, LASER 2J Channel 1 - IEEE C37.94, 820nm, multimode fiber, 64/128 kbps; Channel 2 - 1550 nm, single mode, LASER 7A 820 nm, multimode, LED, 1 Channel 7B 1300 nm, multimode, LED, 1 Channel 7C 1300 nm, singlemode, ELED, 1 Channel 7H 820 nm, multimode, LED, 2 Channels 7I 1300 nm, multimode, LED, 2 Channels 7J 1300 nm, singlemode, ELED, 2 Channels 7S G.703, 2 Channels 7W RS422, 2 Channels 73 1550 nm, singlemode, LASER, 2 Channels 77 IEEE C37.94, 820 nm, multimode, LED, 2 Channel

Ordering Note: 1. To view all the options available for D30, please visit GE’s On-Line Store http://store.gedigitalenergy.com/viewprod.asp?model=D30 2. Redundant power supply only available in horizontal unit. If redundant is chosen, must be same type. Maximum 2 per chassis.

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12593G(E) English 150121

Bus Protection Bus Principles & Protection

192

Bus protection reliability issues and how GE Multilin products provide enhanced reliability through special techniques and methods are described in this section. Different bus protection applications and how GE Multilin products fit into each are provided at the end of the section.

Typical Applications

196

Typical bus protection applications showing small to large applications and how different GE Multilin protection and control products can be applied to each application.

Technical Resources

198

Access an extensive library of interactive tools and videos showcasing innovative solutions, as well as online publications, technical resources, how-to videos and bus protection configurators.

Selector Guide

199

Highlighting the feature set for GE bus protection systems and assisting in comparing and selecting the correct product for specific applications.

Featured Products Detailed product information of the bus protection systems offered by GE Multilin.

200

Bus Protection

Bus Protection

Bus Protection

Introduction

Incoming Source

Busbars in power systems are the location where transmission lines, generation sources, and distribution loads converge. Because of this convergence, short circuits located on or near the busbar tend to have very high magnitude currents. The high magnitude fault currents require high-speed operation of the busbar protection to limit equipment damage. However, this high-speed clearing must be performed securely. Tripping incorrectly for an external fault may cause large outages, and jeopardize power system stability. The high fault magnitudes increase the possibility of CT saturation during external faults close to the busbar, and CT saturation increases the possibility of an incorrect operation of the busbar protection. Protection of the busbar may be complicated and varies with the topology of the bus. Many busbars connect all circuits to one common segment of busbar. The complication for these buses is simply the number of connected circuits. However, a specific busbar may have multiple bus segments, with individual circuits that connect to different bus segments depending on operating needs. For such complex buses, busbar protection must be able to protect each bus segment individually, and dynamically keep track of the circuits connected to a specific bus segment.

Busbar Protection Techniques The choice of protection technique used for a specific busbar depends on the protection requirements for speed and security, balanced against the cost of implementing a specific solution, and the operating requirements for a specific bus. Common methods of protecting busbars include overcurrentbased interlocking schemes, overcurrent-based differential protection, high-impedance differential protection, and percentage differential protection. Interlocking and overcurrent differential protection can be implemented with any suitable overcurrent relay from GE Multilin, and performance has to be balanced in terms of speed and security against the reduced cost of protection. These types of protection are typically applied on distribution busbars, where fault current magnitudes are lower and speed is generally less critical than with transmission busbars. Differential protection provides high speed fault-clearing necessary for critical busbars such as transmission busbars, or distribution busbars where arc flash hazards are a concern. High-impedance differential protection or percentage differential protection may be the correct choice depending on the bus configuration and specifics of application. Both methods address the security for external faults due to CT saturation.

Distribution Busbar Protection Distribution busbars typically have a single incoming source supplying multiple radial distribution feeders. For these applications, the main concerns for protecting the bus are normally meeting operating requirements and cost of protection. High speed clearing to maintain system stability is not normally necessary. Security is maintained by simple time coordination, or via hardwired communications in reverse interlocking protection schemes. The most significant factor in terms of operating speed is arc-flash hazards. The slow operating time of overcurrent-based bus protection can result in a larger arc-flash zone or in more restrictive hazard protection requirements. In these instances, high speed differential protection is appropriate.

192

51

51N

50

50N

Inverse Time Overcurrent or Reverse Interlocked Overcurrent

52

52

51

51

51

51

51N

51N

51N

51N

52

52

52

Radial Feeders Overcurrent based interlocking schemes for simple Bus protection

Transmission Busbar Protection The predominant requirements for protecting transmission busbars is the speed and security of the protection scheme. These requirements are built around the need to minimize equipment damage and maintain system stability during fault events. If these are the only two considerations for transmission busbar protection, then high-impedance differential protection may be appropriate. High-impedance voltage differential protection is a solution to the challenge of CT saturation during external faults, as the high impedance of the relay forces the error current due to the saturated CT back through the CTs instead of the relay operating coil. The relay uses a setpoint to differentiate between the maximum error voltage due to CT saturation, and the full voltage of an internal fault. When considering the requirements for operating a specific bus, and the cost of installation, high-impedance differential protection schemes have some limitations. The major limitation is the strict requirements on the CT circuits necessary for the high-impedance scheme. All CTs used in the scheme must have the identical performance class and turns ratio, must be tapped at full ratio, and must be dedicated to the bus protection scheme. Additionally, the secondary lead burden from the each CT to the relay should also be identical. These requirements are necessary to keep the level of error voltage as low as possible to prevent maloperation of the relay. Making modifications to an existing bus protection scheme, such as adding an additional circuit, may be very challenging in engineering and installation. In addition, high-impedance differential relays also have some limitations in terms of normal operations and maintenance. The relay sees only the voltage from the differential junction point, and therefore cannot provide any auxiliary protection functions such as breaker failure, or record the individual currents from each CT connected to the relay. Data to analyze fault events must therefore come from additional sources. Another operating limitation of high-impedance differential is the ability to handle routine bus switching, such as removing a circuit breaker for maintenance. Typically, the differential relay must be blocked during such switching operations.

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Bus Protection

While this type of switching is uncommon with the typical single segment busbar, it is a routine occurrence with multiple segment busbars, making high-impedance differential schemes difficult to apply.

Differential characteristic region Bus Protection

Percentage differential relays, also known as low-impedance differential relays, provide similar operating speed, and can provide a similar level of security, as high-impedance differential relays. In addition, low-impedance relays are simple to apply, as there are no special requirements for CT performance class, turns ratio, or secondary lead burden other than good performance practice. A microprocessor-based low-impedance differential relay measures input currents from each set of CTs, and therefore can provide auxiliary functions such as breaker failure for every circuit, and measure and record all currents during a fault event. In addition, switching events can be routinely handled in the relay, and low-impedance differential relays can be specifically designed for multiple segment busbars.

GE Multilin Busbar Protection GE Multilin provides protective relays that support all busbar protection techniques, including overcurrent , high-impedance differential, and percentage (low-impedance) differential. The protection techniques for overcurrent and high-impedance differential protection are well known. GE Multilin low-impedance differential relays are designed to provide specific performance advantages on applications for all busbars, from single segment busbars with up to 24 connected circuits, or large multiple segment busbar configurations. These include the correct restraint while facing CT saturation during a fault event, detecting the failure of a CT secondary circuit connected to the relay, protection of multiple segment busbars, and providing enough digital inputs and outputs for proper protection.

CT Saturation Saturation of a CT connected to a low-impedance differential relay during an external fault produces an incorrect differential current that may cause the relay to operate. GE Multilin relays use adaptive trip logic to prevent an operation due to CT saturation during external faults. The adaptive trip logic is designed around the differential characteristic. The restraint current of the differential element is based on the maximum measured current, as opposed to the traditional magnitude sum of the currents. This ensures ideal restraint for the actual fault condition, balancing sensitivity and security. The differential element uses a dual slope-dual breakpoint characteristic matching the differential characteristic to the saturation performance of the CT ensuring security, while maintaining sensitivity. The differential characteristic can correctly restrain for many external faults when CT saturation occurs. However, the differential element itself is not enough to ensure correct restraint to external faults when severe CT saturation occurs. The differential protection is always supervised by a directional element. The directional element compares the angle of the measured fault currents. If at least one current is away from the sum of the remaining currents by an angle greater than 900, the fault is considered an external fault. If all fault currents are within 90° of each other, the fault is considered internal. During low magnitude fault events, the differential element must assert and the directional element must declare an internal fault for the relay to trip. A low magnitude fault event is one where the differential current is less than the breakpoint for the second slope of the characteristic. During high magnitude faults a CT saturation detector additionally supervises the differential protection. During such a fault, the differential protection may operate only if the differential element asserts, while no CT saturation is

Adaptive Trip logic

present or when the directional element declares an internal fault when CT saturation is present. The CT saturation detector simply sets a logic flag when the restraint current exceeds the setting for the second breakpoint of the differential characteristic, and the differential current remains below the first slope of the characteristic.

CT Trouble Any differential protection scheme depends on the correctness of the CT secondary circuits connected to the relay. In addition to CT saturation and linear CT measurement error, broken or shorted CT connections cause the relay to see a false differential current. During normal operations, the false differential current due to a broken or shorted CT secondary circuit is typically too small to cause a relay operation. However, during external faults or high load periods, this false differential current can result in an incorrect relay operation. The CT Trouble function in the B30, B90 and B90Plus relays detects this condition by using a low-set differential element, typically set around 10% of the least heavily loaded circuit connected to the bus, that asserts after a settable time delay. The CT Trouble alarm can be sent via SCADA to operating personnel, or it may be used to block the differential element.

Multiple segment busbar protection Multiple segment busbars, such as double busbar and triple busbar arrangements, are used to balance loads between various transmission circuits, limit short circuit currents, minimize the physical space required for a substation, and provide simpler operating procedures when performing breaker maintenance. The protection challenge for these busbar configurations actually lies in operations. The busbar protection must recognize which segment is faulted, and clear only that segment.

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Bus Protection

Additionally, the busbar protection must not operate when circuits or feeders are transferred between busbar segments.

Bus Protection

The figure shows a typical double busbar configuration. For an internal fault, the busbar protection must identify the faulted bus segment, and trip the circuit breakers attached to that bus segment. This requires the busbar protection to use a dynamic bus replica to track which circuits are connected to the bus segment. The B90 Bus Differential Relay provides protection of multiple segment busbars, using a phase-segregated, centralized protection scheme. The B90 is phase-segregated to simplify the design of the system. One B90 is used for each phase, and processes only the AC signals for that phase, eliminating the need for data transfer and synchronized sampling between the devices. The B90 uses a centralized protection scheme to also simplify the design of the system. The relays are in the substation control house, and all current circuits and control wiring are brought to the control house as per typical relay installations. No special equipment needs to be mounted in the substation yard or circuit breaker control cabinets. The B95Plus Bus Differential Relay also provides protection of multiple segment busbars, but using a distributed protection scheme. A single B95Plus device, typically located in the substation control house, is connected by fiber optical cable to multiple HardFiber Bricks located in the switchyard. The Bricks send to the B95Plus signals representing the breaker current waveforms, breaker open/close status, and isolator switch open/close status. The Bricks also trip and/or lockout the circuit breakers in response to signals received from the B95Plus. This arrangement greatly reduces the amount of copper wiring between the switchyard and the control house. It also greatly reduces the secondary wiring burden on the CTs thus reducing the tendency for CT saturation.

Dynamic bus replica The objective for protecting complex busbar arrangements is to provide for optimum protection by avoiding blind spots or unnecessary bus outages. As a rule, this task calls for dynamic adjustments of boundaries of differential zones of protection, and can be safely accomplished when using numerical relays. Dynamic bus replica and CT switching were historically done outside the relay and as such complicated the bus protection schemes. The B90 and B30 relays provide user programmable logic to create a dynamic bus replica inside the system, catering for dynamic switching schemes necessary to make the bus protection scheme secure and reliable. The B95Plus relay provides a pre-programmed dynamic bus replica function and a graphical dynamic bus replica setup tool that together greatly simplifies the configuration of bus protection.

End fault protection End fault protection is one use of a dynamic bus replica. When using line-side CTs, the circuit breaker currents are normally included in the bus zone of protection. When the relay determines the circuit breaker is open through the use of breaker status contacts, the dynamic bus replica excludes the circuit breaker from the bus zone, as a fault between the CT location and the circuit breakerdoes not require tripping the busbar. It is the transmission line that needs to be tripped, but the fault in this scenario is in a line protection blind spot. Since the B30/B90/B95Plus is still measuring the current, the dynamic bus replica together with a simple overcurrent function, can be used to determine such a fault exists, and send a direct transfer trip signal to the circuit breaker on the other end of the transmission line.

ZONE 1

Dynamic bus replica knows breaker status, isolator status

ZONE 2 Bus side CT: bus protection must detect this fault when CB is open

T

1

2

3

Zone 2 trips CB-3, CB-4, and T for this fault, based on dynamic bus replica End-zone fault: bus protection must detect this fault when CB is open

Re-configurable busbar with zone boundaries

194

GEDigitalEnergy.com

4

5

Bus Protection

Bus Protection

End Zone Fault - Bus side CTs

Flexible input and output options Traditional busbar protection and control schemes typically use a lockout relay to open the connected circuit breakers when a bus fault is detected. For simple busbars, this is the most effective way to open the circuit breakers. GE Multilin relays can replace the separate lockout relay with mechanically latched output contacts. Once the circuit breaker is tripped, these contacts latch open the breaker close circuit until manually reset via contact input, pushbutton control from the relay HMI, or SCADA command.

End Zone Fault - Line side CTs

Bus side CTS Bus side CTs provide another illustration of the use of a dynamic bus replica. A fault between the circuit breaker and the CT is in a blind spot of the bus protection. To clear the fault the busbar must be tripped, but the differential zone will not see this fault as it is outside of the zone normally defined by the CTs. To enable the differential to see such faults, as with end fault protection, the dynamic bus replica excludes the circuit breaker currents from the bus protection zone when the circuit breaker is open. The fault is cleared sequentially. First, protection of the circuit, fed from the CT, responds to the fault and opens the breaker. When the breaker opens, the CT current is removed from the differential zone by the dynamic bus replica. As a result, the zone expands to the bus-side pole of the opened breaker, the fault becomes internal, and the bus protection clears the busbar.

For applications where the bus protection relay will be used for control and status information, or the relay is protecting a complex busbar where the status of circuit breakers and isolator switches is vital, the number of inputs and outputs is quite large. Taking a double busbar example with 5 feeders and a tie breaker, the relay requires 12 output contacts (trip and close for each circuit breaker), and 16 to 32 contact inputs (1 or 2 status inputs for each circuit breaker and isolator switch). This many inputs and outputs may be beyond the physical limits of an individual relay. For this reason, B90 bus protection schemes typically require an additional B90 to add a combination of up to 96 additional inputs and 84 additional outputs for a bus protection system. The relays can communicate via Direct I/O communications to pass digital input status and control output contacts. Direct I/O is a robust communications protocol that uses copper or fiber optic communications. The protocol is very reliable, and includes 32-bit CRC error checking, and may integrate up to 16 different relays on one communications circuit. B95Plus bus protection schemes typically have a sufficient number input and output contacts in its directly connected Bricks that additional equipment is not required.

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195

Typical Applications

Bus Protection – Typical Applications Single Busbar, 8 Feeders or less, 1 Zone Typical Functions

ZONE 1

2

3

Bus Protection

1

Double Busbar, 24 Feeders or less, Multiple Zones ZONE 1 ZONE 2

23 1

2

24

3

21

22

87B

Bus Differential

86

Lockout auxiliary

50/51

TOC and IOC (Phase, ground, neutral)

Functions

Typical Product Order Code

Typical Functions (Phase segregated bus differential) + check zone

B90-U00-HPH-F8N-H6P-L8N-N6P-S8N-U6D-WXX

Alternative (Up to 6 feeders) + check zone

B30-U03-HPH-F8N-H6P-L8N-N6P-S8N-U6D-WXX B30-U03-HPH-F8N-H6P-L8N-N6P-S8N-U6D-WXX

+ Harsh Environment Conformal Coating

B30-N03-APH-F8N-H6C-L8N-N6C-S8N-U6C-WXX

Alternative (high Impedance bus differential with HID)

MIB-3-0-HI-C-E-000-00 with HID-3-2

Alternative (B30 with HID High Impedance)

B30-U03-HPH-F8N-H6P-LXX-N6P-SXX-U6D-WXX with HID-3-2

Auxiliary lockout relay (optional)

HEA61-A-RU-220-X2

B90-U00-HPH-F8N-H6P-L8N-N6P-S8N-U6D-WXX

Typical Functions 87B

Bus Differential

87B

Check Zone

86

Lockout auxiliary

50/51

TOC and IOC (Phase, ground, neutral)

50EF

Breaker Failure End Zone Fault

Functions

Typical Product Order Code

Typical Functions (Phase segregated bus differential)

B90-U03-HPH-F8N-H4L-L8N-N4L-S8N-U4D-W7A (3 B90s required) Logic Unit: B90-U03-HPH-F6D-H4L-L6P-N4L-S6P-U4D-W7A

+ Harsh Environment Conformal Coating

B90-U03-APH-F8N-H4L-L8N-N4L-S8N-U4D-W7A (3 B90s required) Logic Unit: B90-U03-APH-F6D-H4L-L6P-N4L-S6P-U4D-W7A

Alternative Distributed Low Impedance 1 x B95P-HE-BX03SSX-XHXAXPXXPX 16 x BRICK-4-HI-CC55 3 x XPC-16-HI 16 x FOA-0000-M005 16 x FOR-0000-M005 16 x CUD-CC55-M005 16 x CUC-0000-M005 16 x CUB-0000-M005 Alternative (high Impedance bus differential with HID)

MIB-3-0-HI-C-E-000-00 with HID-3-2

Auxiliary lockout relay (Optional)

HEA61-A-RU-220-X2

Breaker-and-Half Busbar, 24 Feeders or less, Multiple Zones ZONE 1

1

3

21

22

1

3

21

22

Functions

Typical Product Order Code

Typical Functions (Phase segregated bus differential)

Protection units: B90-U03-HPH-F8N-H4L-L8N-N4L-S8N-U4D-W7A (3 B90s required)

+ Harsh Environment Conformal Coating

Protection units: B90-U03-APH-F8N-H4L-L8N-N4L-S8N-U4D-W7A (3 B90s required)

Alternative Distributed Low Impedance

1 x B95P-HE-BX03SSX-XHXAXPXXPX 16 x BRICK-4-HI-CC55 3 x XPC-16-HI 16 x FOA-0000-M005 16 x FOR-0000-M005 16 x CUD-CC55-M005 16 x CUC-0000-M005 16 x CUB-0000-M005

Auxiliary lockout relay (Optional)

HEA61-A-RU-220-X2

Alternative (high Impedance bus differential with HID)

MIB-3-0-HI-C-E-000-00 with HID-3-2

ZONE 2

Typical Functions

196

87B

Bus Differential

87B

Check Zone

86

Lockout auxiliary

50/51

TOC and IOC (Phase, ground, neutral)

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Typical Applications

Two Section Busbar with a Bus Tie, 24 Feeders, Multiple Zones Typical Functions

ZONE 1

1

2

23

24

3

ZONE 2

12

13

22

87B

Bus Differential

87B

Check Zone

86

Lockout auxiliary

50/51

TOC and IOC (Phase, ground, neutral)

Typical Product Order Code

Typical Functions (Phase segregated bus differential)

Protection units: B90-U03-HPH-F8N-H4L-L8N-N4L-S8N-U4D-W7A (3 B90s required)

+ Harsh Environment Conformal Coating

Protection units: B90-U03-APH-F8N-H4L-L8N-N4L-S8N-U4D-W7A (3 B90s required)

Auxiliary lockout relay (Optional)

HEA61-A-RU-220-X2

Alternative (high Impedance bus differential with HID)

MIB-3-0-HI-C-E-000-00 with HID-3-2

Bus Protection

Functions

Double Busbar with Transfer Bus and Tie-Breaker Typical Functions ZONE 1 ZONE 2

23

24 22

2

Bus Differential

87B

Check Zone

86

Lockout auxiliary

50/51

TOC and IOC (Phase, ground, neutral)

Functions

Typical Product Order Code

Typical Functions (Phase segregated bus differential)

Protection units: B90-U03-HPH-F8N-H4L-L8N-N4L-S8N-U4D-W7A (3 B90s required) Logic Unit: B90-U03-HPH-F6D-H4L-L6P-N4L-S6P-U4D-W7A

+ Harsh Environment Conformal Coating

B90-U03-APH-F8N-H4L-L8N-N4L-S8N-U4D-W7A (3 B90s required) Logic Unit: B90-U03-APH-F6D-H4L-L6P-N4L-S6P-U4D-W7A

Alternative Distributed Low Impedance 1 x B95P-HE-BX03SSX-XHXAXPXXPX 16 x BRICK-4-HI-CC55 3 x XPC-16-HI 16 x FOA-0000-M005 16 x FOR-0000-M005 16 x CUD-CC55-M005 16 x CUC-0000-M005 16 x CUB-0000-M005

ZONE 3

1

87B

21

Auxiliary lockout relay (Optional)

HEA61-A-RU-220-X2

Alternative (high Impedance bus differential with HID)

MIB-3-0-HI-C-E-000-00 with HID-3-2

Triple Busbar 23

Typical Functions

24

ZONE 1 ZONE 2

87B

Bus Differential

87B

Check Zone

86

Lockout auxiliary

50/51

TOC and IOC (Phase, ground, neutral)

Functions

Typical Product Order Code

Typical Functions (Phase segregated bus differential)

Protection units: B90-U03-HPH-F8N-H4L-L8N-N4L-S8N-U4D-W7A (3 B90s required) Logic Unit: B90-U03-HPH-F6D-H4L-L6P-N4L-S6P-U4D-W7A

+ Harsh Environment Conformal Coating

B90-U03-APH-F8N-H4L-L8N-N4L-S8N-U4D-W7A (3 B90s required) Logic Unit: B90-U03-APH-F6D-H4L-L6P-N4L-S6P-U4D-W7A

Alternative Distributed Low Impedance

1 x B95P-HE-BX03SSX-XHXAXPXXPX 16 x BRICK-4-HI-CC55 3 x XPC-16-HI 16 x FOA-0000-M005 16 x FOR-0000-M005 16 x CUD-CC55-M005 16 x CUC-0000-M005 16 x CUB-0000-M005

Alternative (high Impedance bus differential with HID)

MIB-3-0-HI-C-E-000-00 with HID-3-2

ZONE 3

21 1

2

22 19

20

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WATCH. INTERACT. LEARN.

Bus Protection

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Extensive library of interactive tools & videos 

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SELECTOR GUIDES

to bus challenges

for bus products

From System Integrity Protection to Digitized Substations, explore advanced bus protection solutions using our 3D power system.

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Compare, filter and select your product by protection, control, automation, and communications features to fit your application needs.

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Product Selector Guide

Bus Protection – Selector Guide Features

B30

87B

•

87B

B90

87B 50G/N/P 51G/N/P 59X/N 27P 50BF 86

MIB

•

87B 87B

B95plus

• •*

•

2 <1 • G/N/P G/N/P X/N • • • Logic • • •

6 <1 • P P

6 <1 • P P

• • • •

• • • •

•

• •

• • 6 16 80 64 32 64 • 48

• • 6 16/box 96/box 64/box 32 64 • 48/box

12 • • • • • • • •

12/box • • • •

• 3 SLDs • •

• •

•

• • • • • • • 1024 • •

• •

• •

• 1024 • •

• 12288 • •

• •

• •

1 •

1 •

• • • • • • • • • •

• • • • • • • • •

1 <2 •

•

•

•

2 48 288 96 64 288

2

•

• • 3

• • • • • • • • • •

Bus Protection

APPLICATIONS Busbars with up to 6 circuits (low-impedance diff. ,centralized architecture) Busbars with up to 24 circuits (low-impedance diff. , centralized architecture) Busbars with up to 24 circuits (low-impedance diff. , distributed architecture) High impedance Bus differential PROTECTION & CONTROL Number of Differential Protection Zones Typical Operating Time (cycles) Bus differential IOC, Ground/Neutral/Phase TOC, Ground/Neutral/Phase Overvoltage Auxiliary/Neutral Phase Undervoltage Current Transformer Supervision Breaker Failure End Fault Protection Breaker Flashover Lockout Functionality Dynamic Bus Replica AUTOMATION Programmable Logic FlexElements™ Settings Groups Non-volatile latches (up to) Contact Inputs Programmable - (up to) Contact Outputs Programmable - (up to) Virtual Inputs - (up to) Virtual Outputs - (up to) Direct Inputs/Outputs User-Programmable LEDs (up to) User-definable mimic, metering, and annunciator displays User-Programmable Push Buttons (up to) User-Programmable Self Test User Definable Displays User Programmable Self-Test Contact Timers Selector Switch Digital Counters Digital Elements IRIG-B Input MONITORING & METERING Current Voltage Symmetrical Components Power - Apparent , Real, Reactive Energy Power Factor Frequency Event Recorder - Number of Events Oscillography Trip/Close Coil Supervision COMMUNICATIONS RS232 Port RS485 Port USB Ethernet Port (Fiber and Copper, up to) Direct Fiber Communications (800nm, 1330nm, 1550nm) PROTOCOLS ModBus (RTU) ModBus (TCP/IP) DNP 3.0 IEC60870-5-104 UCA2/MMS IEC61850 Simple Network Time Protocol (SNTP) HTTP TFTP Process Bus (IEC 61850-9-2)

Device

4 4

4

•

•

24 • • • •

•

* High impedance bus differential is available when applying the Multilin B30 with the Multilin HID module.

For the most up-to-date selector guides, please visit

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199

Featured Products

Bus Protection – Featured Products B95Plus

Bus Protection System

201

The B95 is a distributed low impedance busbar protection system that utilizes the HardFiber IEC 61850 process bus technology to protect bus schemes up to 24 bays. The B95Plus greatly reduces the time and cost of field wiring for bus protection, and promotes quick expansion to other zones of protection by implementing process bus. The simple, intuitive configuration of the B95Plus reduces the cost of configuring bus protection, and the dynamic element design reduces risk while performing routine bus operations and circuit breaker maintenance. Plus

B90

Low Impedance Numerical Bus Differential System

211

Bus Protection

The B90, a member of the UR Family, features integrated protection and breaker failure for re- configurable LV, HV, EHV multi-section busbars up to 24 feeders. Use one or more B90s together to build a sophisticated protection system that can be engineered to meet the specific application requirements. The B90 performs fast and secure low impedance bus protection with sub-cycle tripping time averaging 0.75 cycles.

B30

Cost Effective Low Impedance Bus Protection and Metering for up to Six Feeders The B30, a member of the UR Family, is a digital device that features integrated protection for HV and EHV busbars, providing cost effective, feature focused busbar protection. Use the B30 to protect busbars with up to 6 feeders, 1 zone. Consider the B30 as a cost effective alternative to high impedance schemes, ideal for breaker-and-a-half bus schemes, with integrated feeder backup protection and metering.

Go online for the full listing of Multilin Protection & Control products

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Multilin™ B95Plus Reduce the time and cost of field wiring for bus protection The Multilin™ B95Plus Bus Protection System is the ideal solution for one of the biggest challenges for large bus protection: the time and cost involved in the design, installation and commissioning of the field wiring between measurements from the switchyard and the bus relay in the control room. The HardFiber Brick, the environmentally hardened distributed bay unit of the B95Plus, directly reduces the time and costs involved in field wiring in both the short term and the long term. Save time and money in the short term with flexible mounting options for the bay unit. The compact size and rugged design of the HardFiber Brick bay unit allows installation anywhere: outdoors in the switchyard, in equipment cabinets or in the control room. All data signals are converted to digital signals per the IEC 61850 standard and communicated over a single fiber optic cable, making the best location for installation next to the primary signal source, virtually eliminating all field wiring. To save money in the long term, use the Brick bay unit as an IEC 61850 process bus merging unit. This becomes the complete I/O interface (including currents, voltages, equipment status and equipment control) for all protective relays and all zones of protection. Relay installation for any future zone of protection literally becomes plug-and-play: mount the relay on a panel, plug the relay into the fiber from the Brick bay unit and commission.

Key Benefits • Reduce field wiring costs by replacing multiple copper wires and terminations with a fiber optic cable • Save installation costs by mounting the bay unit in harsh environments without requiring specialized enclosures • Increase savings by connecting other relays to the same process bus bay unit • Protect six three-phase differential zones with one central device

Applications • Reconfigurable multi-section bus bar with up to 24 feeders • Retrofit and greenfield installations for power generation, transmission and distribution systems

Saves Field Wiring • Terminate field wiring directly at bay unit located at the primary equipment • Install connectorized fiber optic cable as only wiring across the switchyard • Transfer work of designing, installing and commissioning field wiring for new installations to primary equipment suppliers

Use as Distributed I/O • The bay unit can be a distributed I/O interface for any protective relay • Environmentally hardened, compact design allows installation in a substation without additional cost or equipment • Measurements and commands transmitted via IEC 61850 message formats • Interface to protective relays that support appropriate sampled value message formats per IEC 61850

Meets Protection Needs • Meets requirements for speed and reliability of bus protection for all configurations and voltage levels • 6 zones of 3-phase protection and 24 feeders for breaker-and-a-half, double bus and segmented bus zones

• Reconfigurable bus bars for single bus, breaker-and-a-half and double bus with and without bus couplers

• CT saturation detector capable of detecting CT saturation even with only 2 msec of saturation free current for enhanced fault stability

• Air-insulated and GIS stations

• Reconfigurable dynamic bus replica

B95Plus Bus Protection System

The Challenge in Bus Protection

We Solve the Field Wiring Challenge with the B95Plus

Bus Protection

The Cost of Field Wiring The challenge in bus protection for large bus architectures is the time to design, install and commission all of the associated field wiring. Every source in a bus protection zone requires extensive field wiring for the relay to acquire the current measurements and equipment status, and to issue control commands. Every signal used by bus protection requires a pair of copper wires. Every one of these wires between the primary equipment and the relay, and the terminations of these wires, must be designed, installed and commissioned for the specific project. Every one of these wires will be wired in series or parallel to protective relays associated with the zones of protection for the source, so this effort will be duplicated. This process is exceedingly labor-intensive, with most of the labor requirements being on-site manual labor. The end result is a very intensive and error-prone process that adds significant time and cost to every project and makes long term maintenance costly, and changes difficult to implement. This effort is very much the same if the project is installing a new bus protection system, or simply adding an additional source to an existing system.

The Multilin B95 Plus Bus Protection System changes the focus of bus protection to that of application by replacing most of the field wiring with distributed I/O and fiber optic cables. The protection system consists of a distributed process interface (data acquisition and tripping) architecture using HardFiber Bricks as bay units, with centralized processing performed by the B95Plus. All copper field wiring is between primary equipment in the switchyard and Bricks, which ideally should be located at the primary equipment in the switchyard. Fiber optic cables connect Bricks to the B95Plus. For all applications, the installation is then identical: the physical interface consists of Bricks connected to a fiber optic cable. A single B95Plus is mounted in a relay cabinet, with the process cards in the unit patched to the fiber optic cables coming from the Bricks.

HardFiber System The HardFiber System can easily be incrementally scaled to include new equipment as stations evolve. Duplicated Bricks in the switchyard provide a drastic improvement in reliability and security over today’s technology.

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B95Plus Bus Protection System

B95Plus System Overview

B95Plus as Part of Process Bus The B95Plus system uses HardFiber Bricks as bay units. The Brick is a process bus interface unit that combines a process bus merging unit (to sample currents and voltages) with contact I/O (for equipment status and control). Once a Brick is installed in a B95Plus system, the Brick can interface with any other device that supports sampled value messages as per the IEC 61850 standard. Rather than duplicate field wiring from the bus source for a feeder zone of protection, simply patch any member of the Universal Relay family to the fiber optic cable from the Brick.

B95Plus Unit The B95Plus unit is the heart of the system. This unit performs all processing functionality, including protection functions, metering, monitoring, FlexLogic and SCADA communications. • Simplifies use through a Graphical User Interface (GUI) that includes configurable single line diagrams for bus sources, local control and status indication of breakers and disconnects, and a configurable digital alarm annunciator

• Supports 2 process cards per unit, for a total of 16 Bricks and 24 bus sources • Provides identical connections and installation for all bus configurations

HardFiber Brick as Bay Unit • Measurement and control for primary apparatus, including AC measurements (4 currents and 4 voltages, or 8 currents) and contact I/O (18 digital inputs and 7 digital outputs including a latching relay)

The B95Plus system provides robust and reliable protection for all bus protection applications. Highlights of the protection functions related to bus protection include: • Multi-zone differential protection with both restrained (dual-slope percent or biased) and unrestrained (unbiased or instantaneous) functions incorporated. Differential protection is fast (typical response time: 1 power system cycle) and secure. Security is achieved by using a fast and reliable CT saturation detection algorithm and a phase comparison operating principle. Security is further enhanced by support for redundant process interface units (Bricks). Supports both three-phase tripping and individual phase tripping. • Dynamic bus replica functionality and multi-zone protection (up to 6 zones) is supported allowing application of the B95Plus to multi-section reconfigurable buses. A zone expansion/contraction to an open breaker feature is included. Isolator position monitoring for up to 48 isolators.

• Simple device with no field configuration or configuration settings

• Check-zone functionality configured by programming one of the differential zones to enclose the entire bus.

• Environmentally hardened for outdoor mounting in switchyards • Connectorized cables for simple, tools-free field installation and removal • IEC 61850 message formats for communications, including sampled value messaging for currents and voltages

• Additional bus protection functions including end fault protection, breaker fail and overcurrent protection for e ach bus source, CT trouble monitoring for each bus zone.

Functional Block Diagram ANSI Device Numbers & Functions ®

HardFiber Brick

ZONE 6

ZONE 5

ZONE 4

ZONE 3

ZONE 2

ZONE 1

87B

87B

87B

87B

87B

87B

50/87

50/87

50/87

50/87

50/87

50/87

50/74

50/74

50/74

50/74

50/74

50BF

B95

Bus Protection System

51

50

27

50BF

50BF

51

50

50BF

50BF

51

50

50/74

FUNCTION Percent bus differential Undervoltage Instantaneous overcurrent CT trouble Unrestrained bus differential End fault protection Time overcurrent Breaker failure

27

50BF

Plus

50BF

DEVICE NUMBER 87B 27 50 50/74 50/87 50EF 51 50BF

Metering: currency, voltage & frequency

50BF 50BF

51

50

Isolator Monitoring & Dynamic Bus Replica

Breaker position & trip

Isolator position

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Bus Protection

• Connects up to 8 Bricks for each process card while, supporting up to 12 bus sources per card

Protection

B95Plus Bus Protection System

Applying the B95Plus

Simple Cable Installation

Bus Protection

Reducing the Cost of Field Wiring The distributed design of the B95Plus system separates field wiring from the control room. Bricks are environmentally hardened I/O devices, with no sophisticated processing and no configuration necessary, designed and intended to be installed in the switchyard close to the source of all measurements. Field wiring simply starts at the primary equipment, and ends at a Brick installed at the primary equipment . The number of wiring terminations is greatly reduced, and one fiber optic cable installed across the switchyard replaces multiple sets of copper cables. For new installations, the equipment supplier can mount the Brick and install and terminate all field wiring to the Brick during their manufacturing process, transferring the work of field wiring completely away from the utility. Functionally this makes field wiring for the B95Plus part of the primary equipment of the switchyard, and allows all field wiring to be installed during the substation construction process.

Brick with Primary Equipment Reducing the equipment to control wiring to one fiber optic cable per Brick reduces wiring costs. There are fewer cables to install, requiring less time and effort. With fewer cables, less space in cable trench is required, saving costs by reducing the size of the cable trench. The fiber optic cables are designed to be direct buried, and can quickly be installed between primary equipment and cable trench. The cables are designed to be used with standard pulling equipment.

Brick cables are connectorized cables for tools free installation and removal, to simply become an off-the-shelf component of the protection and control system. The connectors for the Brick cables are industry-standard parts that meet the MIL-DTL-38999 specification for cabling connectors. Each Brick has 3 copper cables (1 for AC measurements, 1 for inputs, and 1 for outputs) and 1 fiber optic cable. These cables are available for purchase from GE, or may be provided by any qualified cable supplier. The end result is that field wiring is separated from the protection and control device, resulting in substantial savings in wiring costs by installing field wiring with the primary equipment.

Flexible Mounting Options to Simplify Installation Bricks are designed to be mounted outdoors in the switchyard directly on primary equipment or equipment cabinets. Mounting at the primary equipment is the most cost-effective method when new equipment is being installed in the substation, replacing field wiring terminations with Bricks and connectorized cables, while simultaneously needing a smaller cable trench. In many cases, however, the B95Plus will be used during a substation expansion project or refurbishment project. In these projects, much of the existing field wiring, already installed to the control house, may be used. The compact design of the Brick permits a wide range of mounting locations for where it is most cost effective to acquire measurement and status signals. Bricks are compact enough to install inside existing equipment cabinets in the switchyard to keep field wiring and terminations in one common enclosure. Bricks may also be installed in the control house mounted on relay panels, directly connected to field wiring to acquire measurements and equipment status signals installed during the installation of the original primary equipment..

Additional Mounting Options for the Brick B90Plus

Add line bay

Bricks installed with primary equipment

Existing bays: Bricks installed in relay panels 52

52

52

Brick as primary equipment

52

Simple fiber optic cable installation

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B95Plus Bus Protection System

Standardize on the B95Plus for Any Bus Configuration

CB12

The B95 can be applied on a multitude of bus configurations due to the distributed architecture, and includes support for up to 6 zones of bus differential protection and support for up to 24 bus sources. The physical connection and wiring architecture for the B95Plus system will be identical for any bus configuration: Bricks installed to acquire measurements and equipment status, with the B95Plus unit connected to Bricks via fiber optic cables. The relay panel design will be identical for all applications, for all bus configurations. The only difference from application to application is the number and location of Bricks, and the programming of the B95Plus unit. Plus

Some typical bus configurations that can be protected by the B95Plus:

Brick CB3

CB5

Brick

CB4

CB6

Brick

Brick

Brick

Zone 2 F5

F3

Zone 1

F4

F6

F8

F10

B95Plus

Zone 3

F7

F9 Brick

CB7

CB9

B95Plus

Brick

Zone 4

Brick

CB8

Bus Protection

Brick

CB10

CB34

T1

Zone 1

T2

Zone 2

Brick

Breaker-and-a-half arrangement Brick CB2

BU2 Brick

Brick

CB4

Brick

F3

CB6

Brick

F5

Brick

F4

F6

Two single buses with a bus coupler

T1

Add L90 to F6 by patching to fiber cables from CB6 Brick

T2

B95Plus Brick

Brick

CB5

F3

Brick F5

Double bus with a bus coupler

BUS COUPLER

DS62 DS61

CB3

CB6

CB6

CB4

CB12 Brick

Brick Brick

Zone 2

Zone 1

CB4

CB12

BU2

DS42 DS41

DS122

BU1 DS52 DS51

DS32 DS31

DS62 DS61

DS121

CB2

CB1

Zone 2

Zone 1

CB5

DS42 DS41

DS52 DS51

DS32 DS31

BU2

T2 Brick

DS11 DS12

DS21 DS22

DS11 DS12

BU1

L90

Brick

CB2

CB1

CB3

B95Plus

T1

DS21 DS22

CB5

CB3

The B95Plus Bus Protection System is intended to operate as a standalone, distributed bus protection system. The bay units for this system are Bricks, part of the HardFiber IEC 61850 process bus solution. Once the Bricks for the B95Plus are installed process bus data is available for use for any other zone of protection. The Bricks, then, are a distributed I/O interface for all protection functions and zones, not just the B95Plus. With the B95Plus in place, installing line protection or feeder protection is a simple process: mount the relays in a panel, and patch to the fiber optic cable from the appropriate Bricks. The only requirement is the relays must implement the appropriate IEC 61850 datasets to interface successfully with the Bricks. All members of the Universal Relay family have the ability to interface with Bricks.

DS122

CB12

BU1

Quickly Expand Protection through Process Bus

DS121

Brick CB1

Brick F4

Brick F6

Brick F3

Brick F5

Bricks installed with B95Plus

Brick BUS COUPLER

F4

Brick F6

Expand protection through process bus

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B95Plus Bus Protection System

Simple, Risk-Free Operation

Bus Protection

The B95 Plus system is designed to provide dependable and secure protection during normal bus maintenance operations, without requiring re-configuring of the bus protection, or enabling or disabling bus protection zones. The zone expansion/contraction feature dynamically changes the bus zone when a circuit breaker is opened to provide reliable protection and risk-free operations. The bus protection zone automatically reconfigures to one protection zone when a circuit breaker is connected to 2 buses during a bus transfer operation, once again providing risk-free operations. The B95Plus also supports the use of check zones by configuring one zone to protect the entire bus to account for unusual operating events such as a failure of isolator position monitoring.

Breaker Maintenance End fault protection directly provides dependable and secure protection during breaker maintenance operations. End fault protection dynamically adjusts the bus protection zone based on the position of circuit breakers and their associated isolators. Once enabled during configuration, no user or operator input is required, as end fault protection adjusts the bus protection zone by monitoring the position of the isolators and the circuit breaker. No bus protection zone must be enabled or disabled, and no check zone is required to ensure dependable and secure protection.

Switching Operations The B95Plus also provides dependable and secure protection when rolling a circuit breaker from one bus section to a different bus section. When a second isolator is closed, paralleling the two bus sections together, the B95Plus dynamically expands one of the bus protection zones to cover the entire paralleled bus. Once the first isolator is opened, and the buses are no longer paralleled, the B95Plus returns to two independent bus protection zones. Dependable and secure protection is maintained without requiring user or operator action, without the need to enable or disable bus protection zones, and without the need for a check zone.

Simple Configuration Reduces Operating and Maintenance Costs The B95Plus system carries the time and cost savings on field wiring through to provide time and cost savings on system configuration. EnerVista™ B95Plus Setup software provides an intuitive method for configuring the 6 bus protection zones, the 24 bus sources, and the dynamic bus replica used for protection. Bus zones and bus sources are each configured on a single page with navigation to view all the settings. The software includes a search tool to find specific bus sources and settings. The bus replica configuration uses an easy to understand electrical diagram in a graphical user interface to set up the system and the B95Plus relay. Each bus source is represented by a graphical object that simply snaps together with the objects for other sources on the electrical diagram. The entire bus replica is contained on one page for simple navigation and configuration. This results in simple management of the bus sources, the different protection zones, and the protection parameters.

No Configuration of the Bay Unit The simple configuration of the B95Plus system also carries over to the bay units. The HardFiber Brick simply provides measurement, contact I/O, and communications, with no sophisticated processing. Therefore, there is no field configuration necessary for the Brick. The only configuration required is in the B95Plus central unit, to define the connections to specific Bricks.

B95Plus Features Use the B95Plus as a Centralized DFR The B95Plus has the capability to function as a basic centralized Digital Fault Recorder (DFR) at no additional cost. The unit includes specific transient recorder settings and digital triggers to initiate recording. The B95Plus can capture up to 50 individual oscillography records at sampling rates of up to 128 samples per cycle. Oscillographic data will include AC waveform channels from every enabled bus source and every enabled protection zone differential and restraint current. The oscillographic data can also include up to 384 digital channels. In addition, the B95Plus provides an event recorder that records the last 8,192 events time tagged at a 1 microsecond accuracy.

Bus zone configuration

Bus source configuration

Intuitive configuration of bus replica

206

Transient recording data from the B95Plus

GEDigitalEnergy.com

B95Plus Bus Protection System

FlexLogic™ Automation Logic FlexLogic™ is the powerful user programmable logic engine that provides the ability to create customized protection and control schemes thereby minimizing the need, and the associated costs, of auxiliary components and wiring. FlexLogic can be used to implement basic control applications such as device interlocking and automatic switching routines, and advanced applications such as bus reclosing schemes. The B95Plus includes 512 line of FlexLogic with a deterministic execution rate of 1 msec irrespective of the number of lines of logic, plus an additional 512 lines of FlexLogic for each individual process card installed.

Cyber Security and Process Bus

Cables The HardFiber Brick uses connectorized cables to interface with primary equipment and with system measurements, and to interface to the B95Plus itself. The cables at the Brick end uses an IP67 certified industry standard connector designed for rugged environments. These connectors screw onto the Brick for a simple, tools-free connection. Three of the cables are copper cables used to acquire AC measurements, acquire equipment status, and provide equipment control. The fourth cable provides the fiber interface to the B95Plus central unit as well as DC power to the Brick. These cables therefore can become standard parts, manufactured in advance of installation by any cable manufacturer. These cables are also directly available from GE Digital Energy.

Communications The B95Plus provides for secure remote data and engineering access, making it easy and flexible to use and integrate into new and existing infrastructures. Fiber optic Ethernet provides high-bandwidth communications allowing for low-latency controls and high-speed file transfers of relay fault and event record information. The availability of three independently configurable Ethernet option provides the means of creating fault tolerant communication architectures in an easy, cost-effective manner. The B95Plus supports the

• IEC 61850

• IEC60870-5-104

• DNP3.0

• Modbus RTU, Modbus TCP/IP

Interoperability with Embedded IEC 61850 The B95Plus with integrated IEC 61850 can be used to lower costs associated with protection, control and automation. • Replace expensive copper wiring between devices with direct transfer of data using GOOSE messaging • Configure systems based on IEC 61850 and also monitor and troubleshoot them in real-time with EnerVista™ Viewpoint Engineer Bus Protection

The B95 , despite the use of the HardFiber Brick as a bay unit, does not introduce any special cyber security requirements under NERC CIP rules. The communications architecture is a point-to-point architecture, with no remote access to the communications between the B95Plus central unit and the Bricks. The messaging between the B95Plus and the Bricks is completely, physically sealed from the outside world, so there are no special concerns with regards to cyber security. Plus

most popular industry standard protocols enabling easy, direct integration into SCADA systems.

• Integrate GE Multilin IEDs and generic IEC 61850-compliant devices seamlessly in EnerVista™ Viewpoint Monitoring

EnerVista™ Software The EnerVista™ Suite is an industry-leading set of software programs that simplifies every aspect of using the B95Plus relay. The EnerVista™ suite provides all the tools to monitor the status of your the protected asset, maintain the relay, and integrate information measured by the B95Plus into DCS or SCADA monitoring systems. Convenient COMTRADE and Sequence of Events viewers are an integral part of the B95Plus Setup software included with every relay, to carry out postmortem event analysis to ensure proper protection system operation.

EnerVista™ Launchpad EnerVista™ Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining GE Multilin products. The setup software within Launchpad allows configuring devices in real-time by communicating using serial, Ethernet, or modem connections, or offline by creating setting files to be sent to devices at a later time. Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed. Documents made available include: • Manuals

• Wiring Diagrams

• Application Notes

• FAQ’s

• Guideform Specifications

• Service Bulletins

• Brochures

Station Interface Existing SCADA

Gateway

Station HMI

Station LAN (IEC 61850 Station Bus)

B95Plus

NERC CIP Security Boundary

Brick

Brick

Brick

Brick

Brick

Brick

Process BUS, IEC 61850 Process Interface

Cyber security and process bus

B95Plus cables

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B95Plus Bus Protection System

User Interface The B95Plus provides local HMI capability through two color LCD display panels. One serves as a digital annunciator and the other HMI is for display and control functions.

Annunciator

HMI

The B95 provides an embedded, configurable color LCD annunciator on the front panel of the device eliminating the need for separate annunciators in the relay panel.

• Comprehensive data visualization.

Bus Protection

Plus

• Single line diagrams for bay monitoring and control. • User pushbuttons can be assigned to several functions through multiple menu levels. 12 to 48 user configurable alarms per page eliminates the need for separate annunciator.

• Local/Remote control

• The status of any contact or remote input or internally generated Flexlogic command can be assigned to the annunciator. • The annunciator can display 12/24/48 targets per page to a maximum of 8 pages. • A separate self-test message page on annunciator panel shows error messages and troubleshooting advice. • Display analog values to create a customized metering screen

Typical Wiring Diagram

208

Sequence of event records with the ability to

view time difference between two events for • Pre-programmed troubleshooting and analysis. comprehensive displays for: - Metering - Bay Control - Fault Reports - Sequence of Event Reports - Transient Records Summaries - Disturbance Record Summaries - Real Time Phasor Displays of Voltage, Current and Sequence Components

GEDigitalEnergy.com

B95Plus Bus Protection System

Specifications BUS DIFFERENTIAL PROTECTION

EVENT RECORDER

Number of differential zones

Storage capacity

8,192 events plus 8,192 events on each process card

Time tag:

to 1 µs

Triggers

all FlexLogic™ operand activations

Six 3-phase zones

Max number of currents: Total dynamic number of bus source to zone connections closed at any one moment in time up to 120 CT ratio compensation range

32:1

Operating time

< 1 power system cycle - typical bus fault

PROCESS I/O Number of process bus ports

BUS REPLICA

Current inputs CT rated primary CT rated secondary Nominal frequency CT Trouble Monitoring Breaker failure protection

per SFF-8472

Brick synch frame jitter

±1µs

POWER SUPPLY Nominal DC voltage

125 to 250 V

12 per process card included in the order code.

Minimum DC voltage

80 V

3-phase currents

Maximum DC voltage

300 V

1 to 65000 A

Nominal AC voltage

100 to 240 V at 50/60 Hz

1 A or 5 A

Minimum AC voltage

80 V at 48 to 62 Hz

50 or 60 Hz

Maximum AC voltage

275 V at 48 to 62 Hz

1 element per bus source

Voltage withstand

2 × highest nominal voltage for 10 ms

1 element per bus source

Voltage loss ride-through

200 ms duration at nominal input voltage

Power consumption

150 VA maximum

BUS SOURCES Number of bus sources

Transceiver diagnostics

Bus Protection

Features Dynamic bus source current assignment to each zone, dynamic zone trip assignment to each bus source, dynamic blocking of zones on CT bypassed, 1 user programmable auxiliary zone trip inputs, 3 user programmable bus source trip inputs, dynamic zone expansion/reduction

8 per process card

Port type 100Base-BX-D, in SFP package with LC 50/125µm multimode connector

Instantaneous Phase Overcurrent 1 element per bus source Inverse Time Phase Overcurrent 1 element per bus source

PROCESS CARD OPTICAL Number of transceivers

VOLTAGE SOURCES

8

Number of voltage sources

2 per process card included in the order code

Voltage inputs

3-phase voltages, wye or delta

Transceiver type: Transmit 1550 nm, receive 1310 nm, 100Mb/s, bi-directional single-fiber 50/125µm multi-mode module (levels comply with IEEE 802.3 standard 100Base-BX-D)

VT ratio

1.00 V to 24000.00

Optical transmit power

–14 to –8 dBm

VT rated secondary

25.0 V to 240.0 V

Maximum optical input power

–8dBm

Nominal frequency

50 or 60 Hz

Optical receiver sensitivity

–30dBm

Termination

LC fiber connector

ISOLATORS Number of isolators

Laser class Class 1. This product is eye-safe under all operating conditions.

48 per process card included in the order code

Isolator status inputs Form “a” and form “b” contact inputs, each optionally dual redundant Configurable failsafe modes

Open, closed, last valid state

Monitoring Alarm on inconsistent inputs persisting longer than a user set time

REMOTE RESOURCE SPECIFICATIONS Number of field units

8 per process card

Number of field contact inputs

1 for each brick contact input

Number of field contact outputs 1 for each brick contact output Number of field latching outputs 1 for each brick latching output

TRANSIENT RECORDER Storage capacity Five records with all channels recorded, at 128 samples per cycle, spanning 1 second with no retriggers

Number of shared inputs

16 per process card

Number of shared outputs

16 per process card

Number of records

1, 2, 5, 10, 20, 30, 40, or 50 records

Sampling rate

16, 32, 64 or 128 samples per power cycle

APPROVALS AND CERTIFICATION

AC waveform channels

All enabled bus sources and voltages sources

Compliance

CE, UL, ISO

Analog channels Magnitudes and angles of all ac waveforms recorded plus all enabled zone differential and zone restraint phase current magnitudes and angles

COMPLIANCE

APPLICABLE COUNCIL

CE

Digital channels 128 user configurable channels on the main card and 128 user configurable channels on each process card

Low voltage directive EN 60255-27 (normative sections)



EMC directive EN 60255-26 / EN 50263 EN 61000-6-5 (Area G)

UL

cULus UL 508 UL 1053 C22.2 No 14

ISO

Quality management system

Configurable digital data

Any FlexLogic™ operand

Storage modes

Automatic overwrite, protected

Triggering modes Time window from rising edge of trigger, continuous recording up to 4 additional basic record lengths as long as retrigger is active Pre-trigger window

0 to 100% of the basic record length

Data storage

non-volatile memory

GEDigitalEnergy.com

DIRECTIVE ACCORDING TO

ISO 9001

209

Ordering B95Plus

-

*

Interface Front Panel Language Features Protection

*

-

*

*

**

*

*

*

-

A *

*

B *

C *

E *

Slot F G * *

H *

J *

K * Description

H

Annunciator + HMI (Standard) English (Standard)

E S B

Automation Communications

Dynamic Bus Differential Protection (Standard) Dynamic Bus Differential Protection with Breaker Failure None ModBus TCP/IP (Standard) + IEC 61850 + IEC61850 + DNP 3.0 TCP/IP + IEC61850 + IEC 60870-5-104 AC Input Phasors + Differential & Restraint Phasors (Standard) Transient Recorder + Sequence of Events (Standard) None

X 01 02 03 04

Metering DFR Equipment Manager Hardware Harsh Environment Coating

S S X X C

Power Supply Peer-to-Peer Communications Module Communication Module URPlus Process Card (If only one process card, it must be in slot J)

Brick

-

H X A X

4

-

H

I

-

CT/VT Inputs

X P

X

X

X P

X

None (Standard) Harsh Environmental Conformal Coating High (88-275Vac/80-300Vdc) (Standard) None (Standard) Dual ST Fiber & Copper (Standard) None Each Supports 8 Bricks & 12 Bus/Voltage Sources

*

*

*

*

Description

C C C C

C V C V

5 5 1 1

5 0 1 0

Standard Brick with Eight 5 A CT Inputs Standard Brick with Four 5 A CT Inputs and Four VT Inputs Standard Brick with Eight 1 A CT Inputs Standard Brick with Four 1 A CT Inputs and Four VT Inputs

Order Code Example (1) (12)

B95P Brick

-

H 4

E -

H

B I

X -

03 C

S C

S 5

X 5

-

X

H

X

A

X

P

X

X

P

X

Note: the order code is for a B95Plus system. The B95Plus provides bus differential protection for 6 zones, annunciator and display, breaker failure protection. IEC 61850 and DNP 3.0 communications, metering, transient fault recording, and 2 process cards to support connections for up to 16 Bricks. This system also includes 12 Bricks with eight 5 A current inputs each.

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12872-(E) English 150121

Multilin™ B90 Secure, Dependable and Scalable Bus Differential Protection System from LV to EHV Busbars The Multilin B90 bus differential system provides fast and secure low impedance bus protection for reconfigurable LV to EHV busbars. Use one B90 to protect up to 8 feeders and use three or more B90s together in a centralized phase-segregated architecture to protect up to 24 feeders. Many busbar applications, such as single, double, triple, breaker-and-a-half, with or without transfer bus, can be protected using the B90. The B90 is ideally suited for applications where high impedance schemes are typically used.

Protection and Control • Multi-zone bus differential protection with restrained and unrestrained function • Fast and reliable CT saturation detection • Breaker failure & End Fault (dead zone) protection • CT ratio mismatch compensation • Dynamic bus replica

The Multilin B90 comes with a variety of versatile features truly integrating protection, monitoring, metering, communication and control in one easy-to-use device.

• Backup time, instantaneous overcurrent elements and undervoltage function

Key Benefits

Communications

• High-speed protection algorithm for enhanced stability with trip times of 0.75 power cycle • Superior CT saturation detector capable of detecting CT saturation even with only 2 msec of saturation free current for enhanced stability during fault conditions • Suitable for different bus configurations and a scalable architecture, protecting systems with up to 24 feeders • Pre-engineered bus protection systems, utilizing experienced GE Digital Energy application engineers to develop busbar protection schemes matching your specific configurations • Advanced IEC 61850 Ed. 2 implementation, complete settings via SCL files enable resource and platform managing optimization and reduce cost of ownership • Increased network availability via failover time reduced to zero through IEC® 62439-3 “PRP” support

• 3 independent Ethernet ports for simultaneous & dedicated network connections with IEEE 1588 support • Supported industry protocols: IEC 61850 Ed. 2, SFTP, MMS File Transfer Service, DNP 3.0, Modbus Serial/TCP, IEEE 1588, IEC 60870-5-104 and 103, PRP, SNTP, HTTP, TFTP

Cyber Security

• CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog)

• CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog)

• Advanced fault and disturbance recording, including internal relay operating signals, eliminating the need for external recording devices

• Setting for security audit trails, tracking changes to device configurations

Applications

Monitoring & Metering

• Re-configurable multi-section busbar with up to 24 feeders • Single bus, breaker-and-a-half busbar configurations, double bus and triple bus with and without bus couplers

• Isolator monitoring (up to 48) and alarming • CT trouble monitoring & VT supervision • Advanced recording capabilities with highcapacity event recorder, configurable and extended waveform capture and data logger • Metering: current, voltage, frequency, and harmonics

B90 Bus Differential System

Protection and Control As part of the UR family of Protection & Control devices, the B90 offers a high degree of modularity in its design and functionality, providing superior performance while meeting the toughest requirements of the marketplace. Advanced protection and control features of this relay includes:

Bus Protection

Segregated Bus Differential Protection The B90 provides fast and secure low impedance bus protection with sub-cycle tripping times averaging 0.75 cycles. Multiple phasesegregated zones of differential protection are available in the B90. The primary protection is based on differential and directional protection principles, and uses a dedicated CT saturation mechanism for additional through-fault stability. This mechanism is capable of detecting saturation of CTs as quickly as two milliseconds into an external fault. The overall system costs can be reduced with the B90 since there is no need for dedicated or interposing, external CTs. It offers extreme flexibility, including a CT ratio mismatch of up to 32:1 between feeders, making the B90 an ideal solution in a wide variety of bus differential applications.

Architecture The B90 is based on a centralized phasesegregated architecture that does not rely on extensive communications between IEDs,

The B90 is the single point for protection, control, metering, and monitoring in one integrated device that can easily be connected directly into DCS or SCADA monitoring and control systems like Viewpoint Monitoring as shown.

an approach that increases overall reliability. This architecture allows for greater flexibility and is scalable to any low impedance busbar protection application, all in a relatively small form factor. Each unit in the system is capable of exchanging digital states quickly and reliably over direct I/O, allowing the user to distribute input and output contacts in various IEDs. The B90 protection system can incorporate as few as one IED and as many as five IEDs to

accommodate a wide range of applications. This scalability and flexibility allows for optimum hardware utilization with an overall lower system cost , which was was not previously possible. A single B90 configuration is available to protect up to 8 feeders. A more typical B90 configuration for non-re-configurable busbars, without breaker fail protection, consists of three B90s. This configuration can protect up to 24 feeders. Each B90 in the system can

Functional Block Diagram ANSI® Device Numbers & Functions Isolator Monitoring & Dynamic Bus Replica

Isolator position 50

51

50BF 50EF

27 50

50

51

51

51

50/74

50/74

50/74

50/74

50/74

50/74

50/87

50/87

50/87

50/87

50/87

50/87

87B

87B

87B

87B

87B

87B

ZONE 1

ZONE 2

ZONE 3

ZONE 4

ZONE 5

ZONE 6

50BF 50EF

50BF 50EF

27 50

Metering: A, V, Hz

50BF 50EF

B90

BUS DIFFERENTIAL SYSTEM

Breaker position & trip B90 - Protection, Metering, Monitoring and Control

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DEVICE NUMBER

FUNCTION

27 50

Undervoltage Instantaneous Overcurrent

51 50/74 87B 50/87 51 50BF 50EF

Time Overcurrent CT Trouble Bus Differential Unrestrained Bus Differential Time Overcurrent Breaker Fail End Fault Protection

B90 Bus Differential System

also be configured to support multiple I/O configurations (up to 48 inputs or up to 18 outputs on each unit). If breaker failure, isolator monitoring functions, and more I/O points are needed, an additional B90 can be added into the system. A fifth unit can also be added for even more I/O capabilities.

Dynamic Bus Replica

Breaker Failure Protection Three-pole breaker failure (BF) protection is available. The B90 system provides for up to 24 BF elements that can respond to currents and/ or auxiliary contacts. The current supervision provides fast reset time and separate settings for low-set and hi-set supervision in the phase IEDs. The BF can be initiated internally from

Overcurrent Protection Backup protection is available with instantaneous and time overcurrent functions for each current input of the B90 system. For supervision purposes, an undervoltage function is also provided for each voltage input of the B90 system. • Time O/C elements can individually be set to use IEEE, IEC or custom FlexCurvesTM

End Fault (Blind Spot) Protection The location of the current transformer normally limits the zone of the busbar protection and can create a blind spot when the isolator is open. The section between the current transformer and the circuit breaker can be effectively protected by means of the end-fault protection. In the event of a fault , instantaneous and selective tripping of the busbar section or intertripping of the circuit breaker at the remote end can be configured.

Check-Zone The B90 provides for multiple zones of differential protection. One zone can be configured to encompass the entire busbar in order to act as a supervisory check-zone for other zones of protection.

CT Trouble Monitoring One CT trouble monitoring function is provided for each zone of differential protection. The element is a definite time TOC function responding to a differential current . The CT trouble element shall be used in conjunction with undervoltage supervision or a check-zone.

Advanced Automation The B90 incorporates advanced automation features including powerful FlexLogic™ programmable logic, communication, and SCADA capabilities that far surpass what is found in the average bus protection relay. The B90 integrates seamlessly with other UR relays for complete system protection.

FlexLogic FlexLogic is the powerful UR-platform programming logic engine that provides the ability to create customized protection and control schemes, minimizing the need and associated costs of auxiliary components and wiring. Using FlexLogic, the B90 can be programmed to provide required tripping logic along with custom scheme logic.

Typical B90 Configurations

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Bus Protection

The B90 provides a dynamic bus replica for each zone of differential protection. Built-in programmable logic removes the need for external auxiliary relays, and provides the ability to include or exclude currents dynamically from the differential zone. This allows the B90 to follow the actual busbar configuration with no external switching of CT circuits required. The B90 also avoids blind and overtripping spots in simple bus configurations. Reliability is increased and costs reduced by eliminating auxiliary relays that would otherwise be used for switching physical currents. The ability to monitor auxiliary switches and a contact discrepancy alarm also provides increased security.

the busbar protection or externally via input contacts or communications.

B90 Bus Differential System

Scalable Hardware

Monitoring and Metering

The B90 is available with a multitude of I/O configurations to suit the most demanding application needs. The expandable modular design allows for easy configuration and future upgrades.

The B90 includes high accuracy metering and recording for all AC signals. Voltage, and current are built into the relay as a standard feature. Current and voltage parameters are available as total RMS magnitude, and as fundamental frequency magnitude and angle.

The very high sampling rate and large amount of storage space available for data recording in the B90 can eliminate the need for installing costly stand-alone recording equipment.

Fault and Disturbance Recording

Advanced Device Health Diagnostics

The advanced disturbance and event recording features within the B90 can significantly reduce the time needed for postmortem analysis of power system events and creation of regulatory reports. Recording functions include:

The B90 performs comprehensive device health diagnostic tests at startup and continuously during run-time to test its own major functions and critical hardware. These diagnostic tests monitor for conditions that could impact security and availability of protection, and present device status via SCADA communications and front panel display. Providing continuous monitoring and early detection of possible issues help improve system uptime.

• Multiple CT/VT configurations allow for the implementation of many different schemes

Bus Protection

• Flexible, modular I/O covering a broad range of input signals and tripping schemes • Types of digital outputs include triprated Form-A and Solid State Relay (SSR) mechanically latching, and Form-C outputs • Form-A and SSR outputs available with optional circuit continuity monitoring and current detection to verify continuity and health of the associated circuitry • Mechanically latching outputs can be used to develop secure interlocking applications and replace electromechanical lockout relays

• Sequence of Event (SOE) - 1024 time stamped events • Oscillography - 64 digital & up to 40 analog channels - Events up to 45s in length

• Fault Reports - Powerful summary report of pre-fault and fault values

• Data Logger and Disturbance Recording - 16 channels up to 1 sample/cycle/channel

Built-in Advanced Disturbance Recording The built-in advanced disturbance recording function allows users to view the COMTRADE files and troubleshoot bus faults. The internal operation of the B90 elements, logic, and outputs can be monitored in real-time to simplify commissioning and troubleshooting procedures. Two cases are shown here: External Fault: Even with heavy CT saturation and with only 1 msec of saturation free current, B90 is stable for through faults. See the directional comparison element output, which adds additional security to the bus differential function. Internal Fault: For internal faults the CT saturation flag is not set and the directional element output is safely ignored, resulting in an operating time of less than 10 msec.

All the fault currents are seen in one direction Despite heavy CT saturation the external fault is seen in the opposite direction The bus differential element picks up due to heavy CT saturation The CT saturation flag is set safely before the pickup flag The directional flag is not set The element does not maloperate

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The bus differential element picks up The CT saturation flag is not set - no directional decision required The directional flag is set The element operates in 10 ms

B90 Bus Differential System

• Comprehensive device health diagnostic performed at startup • Monitors the CT/VT input circuitry to validate the integrity of all signals

Cyber Security – CyberSentry UR CyberSentry UR enabled UR devices deliver full cyber security features that help customers to comply with NERC CIP and NIST® IR 7628 cyber security requirements. This software option delivers the following core features:

Enables integration with centrally managed authentication and accounting of all user activities and uses modern industry best practices and standards that meet and exceed NERC CIP requirements for authentication and password management.

Role Based Access Control (RBAC) Efficiently administrate users and roles within UR devices. The new and advanced access functions allow users to configure up to five roles for up to eight configurable users with independent passwords. The standard “Remote Authentication Dial In User Service” (Radius) is used for authentication.

Event Recorder (Syslog for SEM) Capture all cyber security related events within a SOE element (login, logout, invalid password attempts, remote/local access, user in session, settings change, FW update, etc), and then serve and classify data by security level using standard Syslog data format. This will enable integration with established SEM (Security Event Management) systems.

Communications The B90 provides for secure remote data and engineering access, making it easy and flexible to use and integrate into new and existing infrastructures. Fiber optic Ethernet provides high-bandwidth communications allowing for low-latency controls and high-speed file transfers of relay fault and event record information. The available three independent Ethernet ports and redundant Ethernet option provide the means to create fault tolerant communication architectures in an easy, costeffective manner.

• IEC 61850 Ed. 2 with 61850-9-2 and 61850-90-5 support • DNP 3.0 (serial & TCP/IP) • Ethernet Global Data (EGD) • IEC 60870-5-103 and IEC 60870-5-104

• Communication with up to 16 UR relays in single or redundant rings rather than strictly limited to simplistic point-to-point configurations between two devices • Connect to standard DS0 channel banks through standard RS422, G.703 or IEEE C37.94 interfaces or via direct fiber optic connections

• Modbus RTU, Modbus TCP/IP

• No external or handheld tester required to provide channel diagnostic information

• HTTP, TFTP, SFTP and MMS file transfer

LAN Redundancy

• SNTP and IEEE 1588 for time synchronization

Substation LAN redundancy has been traditionally accomplished by reconfiguring the active network topology in case of failure. Regardless of the type of LAN architecture (tree, mesh, etc), reconfiguring the active LAN requires time to switchover, during which the LAN is unavailable. UR devices deliver redundancy as specified by PRP-IEC 62439-3, which eliminates the dependency on LAN reconfiguration and the associated switchover time. The UR becomes a dual attached node that transmits data packets over both main and redundant networks simultaneously, so in case of failure, one of the data packets will reach the receiving device with no time delay.

• PRP as per IEC 62439-3

Interoperability with Embedded IEC 61850 Edition 2 The new IEC 61850 implementation in the UR Family positions GE as an industry leader in this standard. • Implements Edition 2 of the standard across the entire family of UR devices • Provides full relay setting management via standard SCL files (ICD, CID and IID) • Enables automated relay setting management using 3rd party tools through standard file transfer services (MMS and SFTP) • Increases the number of Logical Devices and data mapped to them, GOOSE messages, and reports to support different organizational needs for data transfer and reduce dependency on generic logical nodes • Configures GE Systems based on IEC 61850 using universal 3rd party tools

Direct I/O Messaging Direct I/O allows for the sharing of high-speed digital information between multiple UR relays via direct back-to-back connections or multiplexed through a standard DS0 multiplexer channel bank. Regardless of the connection method, direct I/O provides continuous real-time channel monitoring that supplies diagnostics information on channel health. Direct I/O provides superior relay-to-relay communications that can be used in advanced interlocking, and other special protection schemes.

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Bus Protection

AAA Server Support (Radius/LDAP)

The B90 supports the most popular industry standard protocols enabling easy, direct integration into DCS and SCADA systems.

B90 Bus Differential System

Multi-Language

EnerVista Launchpad

Viewpoint UR Engineer

UR devices support multiple languages: English, French, Russian, Chinese, Turkish and German. These language options are available on the front panel, in the EnerVista setup software, and in the product manuals. Easily switch between English and an additional language on the local displays without uploading new firmware.

EnerVista Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining Multilin products. The setup software within Launchpad allows for the configuration of devices in real-time by communicating using serial, Ethernet , or modem connections, or offline by creating setting files to be sent to devices at a later time.

Viewpoint UR Engineer is a set of powerful tools that allows the configuration and testing of GE relays at a system level in an easy-touse graphical drag-and-drop environment . Viewpoint UR Engineer provides the following configuration and commissioning utilities:

Bus Protection

EnerVista Software The EnerVista suite is an industry-leading set of software programs that simplifies every aspect of using the B90 relay. The EnerVista suite provides all the tools to monitor the status of the protected asset, maintain the relay, and integrate information measured by the B90 into DCS or SCADA monitoring systems. Convenient COMTRADE and SOE viewers are an integral part of the UR setup software included with every UR relay, to carry out postmortem event analysis and ensure proper protection system operation.

Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed. Documents made available include:

• Graphical Logic Designer • Graphical System Designer • Graphical Logic Monitor • Graphical System Monitor

EnerVista Integrator

• Guideform Specifications

EnerVista Integrator is a toolkit that allows seamless integration of Multilin devices into new or existing automation systems. Included in EnerVista Integrator is:

• Brochures

• OPC/DDE Server

• Wiring Diagrams

• Multilin Drivers

• FAQs

• Automatic Event Retrieval

• Service Bulletins

• Automatic Waveform Retrieval

• Manuals • Application Notes

Simplifying Commissioning and Testing

Record the operation of the internal B90 elements and external connected devices with 1ms time-stamped accuracy.

216

Create B90 setting file templates to ensure critical settings are not altered.

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B90 Bus Differential System

User Interface

48 Configurable LED Indicators

The B90 front panel provides extensive local HMI capabilities. The local display is used for monitoring, status messaging, fault diagnosis, and device configuration. User-configurable messages that combine text with live data can be displayed when user-defined conditions are met.

Multi-Language Display • English • Russian • French • Chinese • Turkish • German User-Programmable Pushbuttons

The B90 is a multi-IED protection scheme. Each IED may be ordered with different hardware components and must be wired accordingly. The following drawing illustrates the principles behind a typical B90 wiring. A

CURRENT INPUTS 8H

IED 1

F 1b

IA1

F 1c

IB5

F 2a

IB

F 2b

IB1

F 2c

IC5

F 3a

IC

F 3b

IC1

F 3c

IG5

F 4a

IG

F 4b

IG1

F 4c

IA5

F 5a

IA

F 5b

IA1

F 5c

IB5

F 6a

IB

F 6b

IB1

F 6c

IC5

F 7a

IC

F 7b

IC1

F 7c

C

F1

IED 2

IA5

F 1a

IA

F 1b

IA1

F 1c

IB5

F 2a

IB

F 2b

IB1

F 2c

IC5

F 3a

IC

F 3b

IC1

F 3c

IG5

F 4a

IG

F 4b

IG1

F 4c

IA5

F 5a

IA

F 5b

IA1

F 5c

IB5

F 6a

IB

F 6b

IB1

F 6c

IC5

F 7a

IC

F 7b

IC1

F 7c

CURRENT INPUTS 8H

B90 BUS DIFFERENTIAL SYSTEM

F 1a

IA

CURRENT INPUTS 8H

Multilin

IA5

B

IED 3

IA5

F 1a

IA

F 1b

IA1

F 1c

IB5

F 2a

IB

F 2b

IB1

F 2c

IC5

F 3a

IC

F 3b

IC1

F 3c

IG5

F 4a

IG

F 4b

IG1

F 4c

IA5

F 5a

IA

F 5b

IA1

F 5c

IB5

F 6a

IB

F 6b

IB1

F 6c

IC5

F 7a

IC

F 7b

IC1

F 7c

F 1a F 1b F 1c F 2a F 2b F 2c F 3a F 3b F 3c F 4a F 4b F 4c F 5a F 5b F 5c F 6a F 6b F 6c F 7a F 7c F 8a F 8c F 7b

6H

I

F1

V I

F2

V I

F3

V I

F4

V I

F5

V I

DIGITAL I/O

F6

V

CONTACT IN 7a F CONTACT IN 7c F CONTACT IN 8a F CONTACT IN 8c F COMMON 7b F

F 8b

SURGE

GE Multilin

B90 BUS DIFFERENTIAL SYSTEM IED 4

A2

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Bus Protection

Typical Wiring

Ordering (Please Contact GE Energy for Engineered Bus Protection Solutions) B90 - * * * -H * * - F ** - H ** - L **- N **- S ** - U ** - W/X ** For full sized horizontal mount Base Unit B90 Base Unit CPU E RS485 + RS485 (IEC 61850 option not available) G RS485 + 10BaseF H RS485 + Redundant 10BaseF J RS485 + multimode ST 100BaseFX K RS485 + multimode ST Redundant 100BaseFX N RS485 + 10/100 BaseT T RS485 + three multimode SFP LC 100BaseFX. Req FW v7xx or higher U RS485 + two multimode SFP LC 100BaseFX + one SFP RJ45 100BaseT. Req FW v7xx or higher V RS485 + three SFP RJ45 100BaseT. Req FW v7xx or higher Software Options 0 Without Breaker Failure (see note 1 below) 1 With Breaker Failure (With Engineered Solution Only) 0 8-feeders, 06 zones 1 16-feeders, 06 zones 2 24-feeders, 06 zones 4 8-feeders, 06 zones, IEC 61850 5 16-feeders, 06 zones, IEC 61850 6 24-feeders, 06 zones, IEC 61850 A0 CyberSentry UR Lvl 1 + 08 feeders, 06 zones B0 IEEE 1588 + 08 feeders, 06 zones C0 PRP D0 IEEE 1588 + CyberSentry UR Lvl 1 + 08 feeders, 06 zones Mount/ Coating H Horizontal (19" rack) A Horizontal (19" rack) - Harsh Chemical Environment Option User Interface F Vertical Front Panel with English Display I Enhanced German Front Panel J Enhanced German Front Panel with User-Programmable Pushbuttons K Enhanced English Front Panel L Enhanced English Front Panel with User-Programmable Pushbuttons M Enhanced French Front Panel N Enhanced French Front Panel with User-Programmable Pushbuttons Q Enhanced Russian Front Panel T Enhanced Russian Front Panel with User-Programmable Pushbuttons U Enhanced Chinese Front Panel V Enhanced Chinese Front Panel with User-Programmable Pushbuttons W Enhanced Turkish Front Panel Y Enhanced Turkish Front Panel with User-Programmable Pushbuttons Power Supply H 125 / 250 V AC/DC (see note 2 below) H RH 125 / 250 V AC/DC with redundant 125/250 V AC/DC L 24 - 48 V (DC only) CT/VT DSP 8F 8F 8F Standard 4CT/4VT 8H 8H 8H Standard 8CT 8K 8K 8K Standard 7CT/1VT Digital I/O XX XX XX XX XX XX No module 4A 4A 4A 4A 4A 4A 4 Solid State (No Monitoring) MOSFET Outputs 4C 4C 4C 4C 4C 4C 4 Solid State (Current w/opt Voltage) MOSFET Outputs 4D 4D 4D 4D 4D 4D 16 Digital Inputs with Auto-Burnish 4L 4L 4L 4L 4L 4L 14 Form-A (No Monitoring) Latchable Outputs 67 67 67 67 67 67 8 Form-A (No Monitoring) Outputs 6C 6C 6C 6C 6C 6C 8 Form-C Outputs 6D 6D 6D 6D 6D 6D 16 Digital Inputs 6E 6E 6E 6E 6E 6E 4 Form-C Outputs, 8 Digital Inputs 6F 6F 6F 6F 6F 6F 8 Fast Form-C Outputs 6K 6K 6K 6K 6K 6K 4 Form-C & 4 Fast Form-C Outputs 6L 6L 6L 6L 6L 6L 2 Form-A (Current w/ opt Voltage) & 2 Form-C Outputs, 8 Digital Inputs 6M 6M 6M 6M 6M 6M 2 Form-A (Current w/ opt Voltage) & 4 Form-C Outputs, 4 Digital Inputs 6N 6N 6N 6N 6N 6N 4 Form-A (Current w/ opt Voltage) Outputs, 8 Digital Inputs 6P 6P 6P 6P 6P 6P 6 Form-A (Current w/ opt Voltage) Outputs, 4 Digital Inputs 6R 6R 6R 6R 6R 6R 2 Form-A (No Monitoring) & 2 Form-C Outputs, 8 Digital Inputs 6S 6S 6S 6S 6S 6S 2 Form-A (No Monitoring) & 4 Form-C Outputs, 4 Digital Inputs 6T 6T 6T 6T 6T 6T 4 Form-A (No Monitoring) Outputs, 8 Digital Inputs 6U 6U 6U 6U 6U 6U 6 Form-A (No Monitoring) Outputs, 4 Digital Inputs Inter-Relay Communications 2I Channel 1 - IEEE C37.94, 820nm, multimode fiber, 64/128 kbps; Channel 2 - 1300 nm, singlemode, LASER 2J Channel 1 - IEEE C37.94, 820nm, multimode fiber, 64/128 kbps; Channel 2 - 1550 nm, singlemode, LASER 7A 820 nm, multimode, LED, 1 Channel 7B 1300 nm, multimode, LED, 1 Channel 7H 820 nm, multimode, LED, 2 Channels 7I 1300 nm, multimode, LED, 2 Channels 7S G.703, 2 Channels 7W RS422, 2 Channels 77 IEEE C37.94, 820 nm, multimode, LED, 2 Channel

Ordering Notes: 1. To view all the options available for B90, please visit GE’s On-Line Store at http://store.gedigitalenergy.com/viewprod.asp?model=B90D 2. Redundant power supply only available in horizontal unit. If redundant is chosen, must be same type. Maximum 2 per chassis 3. All “06 zones” software options become “04 zones” when FW version prior to 7.30 is ordered.

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Passport.GEDigitalEnergy.com GEA-12588N(E) English 150122

Multilin™ B30 Low Impedance Biased Bus Differential Protection for up to Six Feeders The Multilin B30 bus differential system provides secure and sub-cycle low impedance bus protection for a single busbar with up to six feeders. The B30 is ideally suited in applications where high impedance schemes were typically used. Overall system costs can be reduced with the B30, since there is no need for dedicated, or interposing, CTs. The B30 comes with advanced features, such as breaker failure, CT trouble detection, under-voltage supervision, and dynamic bus replica. With its extreme flexibility, which includes a CT ratio mismatch of up to 32:1 between terminals, the B30 is the ideal solution in a wide variety of bus differential applications.

Key Benefits • High-speed protection algorithm for enhanced stability with trip times of 0.75 power cycle • Superior CT saturation detector capable of detecting CT saturation even with only 2 msec of saturation free current for enhanced stability during fault conditions • Cost-effective alternative to high impedance schemes protection • Advanced automation capabilities for providing customized protection and control solutions • Advanced IEC 61850 Ed. 2 implementation, complete settings via SCL files and IEC 61850-9-2 process bus solution enable resource and platform managing optimization and reduce cost of ownership • Increased network availability via failover time reduced to zero through IEC 62439-3 “PRP” support ®

• CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog) • Advanced fault and disturbance recording, including internal relay operating signals, eliminating the need for external recording devices

Applications • Re-configurable and pre-defined bus arrangements for simple bus applications, up to 6 feeders and 2 differential zones with breaker failure • Integrated bus protection and metering for HV and EHV substations

Protection and Control • Differential protection with restrained and unrestrained function • Fast and reliable CT saturation detection & CT ratio mismatch compensation • Breaker fail protection, external check zone, and dynamic bus replica, and Undervoltage function for supervision • Thermal overload and backup phase ground and neutral time and instantaneous overcurrent protection

Communications • 3 independent Ethernet ports for simultaneous & dedicated connections with IEEE 1588 support • Supported industry protocols: IEC 61850 Ed. 2, SFTP, MMS File Transfer Service, DNP 3.0, Modbus Serial/TCP, IEEE 1588, IEC 60870-5-104 and 103, PRP, SNTP, HTTP, TFTP • Direct I/O: secure, high-speed exchange of data between UR relays

Cyber Security • CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog) • Setting for security audit trails, tracking changes to device configurations

Monitoring & Metering • Isolator monitoring and alarming • CT trouble monitoring & VT supervision • Advanced recording capabilities with highcapacity event recorder, configurable and extended waveform capture and data logger • Metering: current, voltage, power, energy, frequency, and harmonics

B30 Bus Differential System

Protection and Control

B30 - Protection, Metering, Monitoring and Control

As part of the UR family of Protection & Control devices, the B30 offers a high degree of modularity in its design and functionality, providing superior performance while meeting the toughest requirements of the marketplace. Advanced protection and control features of this advanced relay includes:

The B30 is based on a centralized phasesegregated architecture that does not rely on extensive communications between IEDs, an approach that increases overall reliability.

The B30 provides fast and secure low impedance bus protection with sub-cycle tripping times averaging 0.75 cycles. The primary protection is based on differential and directional protection principles, and uses a dedicated CT saturation mechanism for additional through-fault stability. This mechanism is capable of detecting saturation of CTs as quickly as two milliseconds into an external fault. The overall system costs can be reduced with the B30 since there is no need for dedicated, or interposing, external CTs. The two differential zones can handle two small buses, split bus, or single bus bar with supervision zone.

The B30 is the single point for protection, control, metering, and monitoring in one integrated device that can easily be connected directly into DCS or SCADA monitoring and control systems like Viewpoint Monitoring.

Functional Block Diagram ANSI® Device Numbers & Functions

The B30 provides a dynamic bus replica for each zone of differential protection. Built-in programmable logic removes the need for external auxiliary relays, and provides the ability to include or exclude currents dynamically from the differential zones. This allows the B30 to follow the actual busbar configuration with no external switching of CT circuits required. The B30 also avoids blind and overtripping spots in simple bus configurations. Reliability is increased and costs reduced by eliminating auxiliary relays that would otherwise be used for switching physical currents. The ability to monitor auxiliary switches and a contact discrepancy alarm also provides increased security.

Breaker Failure Protection Three-pole breaker failure (BF) protection is available. The B30 system provides for up to 6 BF elements that can respond to currents and/ or auxiliary contacts. The current supervision provides fast reset time and separate settings for low-set and hi-set implementations. The BF can be initiated internally from the busbar protection or externally via input contacts or communications.

220

50P

27

50P

50P

27

50P

51P

51P

51P

51P

50N

50N

50N

50N

51N

51N

51N

51N

50G

50G

50G

50G

51G

51G

51G

51G

50BF

50BF

50BF

50BF

Metering: current, voltage, and frequency

Dynamic Bus Replica

Breaker position and trip

Bus Protection

Bus Differential Protection

Zone 1 87B

50/87

50/74

87B

50/87

50/74

Zone 2

B30 Bus Differential Protection System 836719AE.CDR

GEDigitalEnergy.com

DEVICE NUMBER

FUNCTION

27P 49 50BF 50G 50N 50P 50/74 50/87 51G 51N 51P 59N 59X 87B

Phase Undervoltage Thermal Overload Breaker Failure Protection Ground Instantaneous Overcurrent Neutral Instantaneous Overcurrent Phase Instantaneous Overcurrent CT Trouble Unrestrained Bus Differential Ground Time Overcurrent Neutral Time Overcurrent Phase Time Overcurrent Neutral Overvoltage Auxiliary Overvoltage Restrained Bus Differential

B30 Bus Differential System

Backup Protection

External Check-Zone

Backup protection is available with instantaneous and time overcurrent functions for each current input of the B30 system. For supervision purposes, an undervoltage function is also provided for each voltage input of the

An optional external check-zone can be used to prevent operation of the differential protection due to CT troubles. If one B30 current input is left unused and an alternative set of current signals is available from independent CTs, the currents can be combined externally and connected to the relay. Two phase overcurrent elements are available to check the level of this independently formed differential current to supervise the main differential protection.

B30 system. • IOC Functions: Two separate IOC functions are available for trip supervision or other user-configurable applications

• Voltage Supervision: up to two undervoltage elements are available per each VT input of the relay. This function may be used to supervise the current-based protection functions for extra security.

IEC 61850 Process Bus The IEC 61850 Process Bus module is designed to interface with the GE Multilin HardFiber System, allowing bi-directional IEC 61850 fiber optic communications. The HardFiber System is designed to integrate seamlessly with existing UR applications, including protection functions, FlexLogic, metering and communications. The GE Multilin HardFiber System offers the following benefits:

Built-in Advanced Disturbance Recording The built-in advanced disturbance recording function allows users to view the COMTRADE files and troubleshoot bus faults. The internal operation of the B30 elements, logic, and outputs can be monitored in real-time to simplify commissioning and troubleshooting procedures. Two cases are shown here:

• Drastically reduces P&C design, installation and testing labor by eliminating individual copper terminations • Integrates with existing B30’s by replacing traditional CT/VT inputs with the IEC 61850 Process Bus module • No new cyber security concerns

Visit the HardFiber System product page on the GE Multilin web site for more details.

Advanced Automation The B30 incorporates advanced automation features including powerful FlexLogic programmable logic, communication, and SCADA capabilities that far surpass what is found in the average bus relay. The B30 integrates seamlessly with other UR relays for complete system protection.

External Fault: Even with heavy CT saturation and with only 1 msec of saturation free current, B30 is stable for through faults. See the directional comparison element output, which adds additional security to the bus differential function. Internal Fault: For internal faults the CT saturation flag is not set and the directional element output is safely ignored, resulting in an operating time of less than 10 msec.

All the fault currents are seen in one direction Despite heavy CT saturation the external fault is seen in the opposite direction The bus differential element picks up due to heavy CT saturation The CT saturation flag is set safely before the pickup flag The directional flag is not set The element does not maloperate

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The bus differential element picks up The CT saturation flag is not set - no directional decision required The directional flag is set The element operates in 10 ms

221

Bus Protection

• TOC: One TOC function is incorporated for each CT input of the relay. Up to 6 TOCs are available for backup protection. The TOC function can use standard or userprogrammable curves

• Communicates using open standard IEC 61850 messaging

B30 Bus Differential System

Custom Programmable Logic Designer

• Fault Reports - Powerful summary report of pre-fault and fault values The very high sampling rate and large amount of storage space available for data recording in the B30 can eliminate the need for installing costly stand-alone recording equipment.

Advanced Device Health Diagnostics

Bus Protection

The B30 performs comprehensive device health diagnostic tests at startup and continuously during run-time to test its own major functions and critical hardware. These diagnostic tests monitor for conditions that could impact security and availability of protection, and present device status via SCADA communications and front panel display. Providing continuous monitoring and early detection of possible issues help improve system uptime. • Comprehensive device health diagnostic performed at startup The internal operation of the B30 elements, logic, and outputs can be monitored in real-time to simplify commissioning and troubleshooting procedures.

FlexLogic FlexLogic is the powerful UR-platform programming logic engine that provides the ability to create directional comparison customized protection and control schemes, minimizing the need and associated costs of auxiliary components and wiring. Using FlexLogic, the B30 can be programmed to provide required tripping logic along with custom scheme logic for breaker control, transfer tripping schemes for remote breakers and dynamic setting group changes.

Scalable Hardware The B30 is available with a multitude of I/O configurations to suit the most demanding application needs. The expandable modular design allows for easy configuration and future upgrades. • Multiple CT/VT configurations allow for the implementation of many different schemes • Flexible, modular I/O covering a broad range of input signals and tripping schemes • Types of digital outputs include triprated Form-A and Solid State Relay (SSR) mechanically latching, and Form-C outputs • Form-A and SSR outputs available with optional circuit continuity monitoring and current detection to verify continuity and health of the associated circuitry

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• Mechanically latching outputs can be used to develop secure interlocking applications and replace electromechanical lockout relays • RTDs and DCmA inputs are available to monitor equipment parameters, such as temperature and pressure

Monitoring and Metering The B30 includes high accuracy metering and recording for all AC signals. Voltage, current, power and energy metering are built into the relay as a standard feature.Current and voltage parameters are available as total RMS magnitude, and as fundamental frequency magnitude and angle.

• Monitors the CT/VT input circuitry to validate the integrity of all signals

Cyber Security CyberSentry UR CyberSentry UR enabled UR devices deliver full cyber security features that help customers to comply with NERC CIP and NIST® IR 7628 cyber security requirements. This software option delivers the following core features:

AAA Server Support (Radius/LDAP) Enables integration with centrally managed authentication and accounting of all user activities and uses modern industry best practices and standards that meet and exceed NERC CIP requirements for authentication and password management.

Fault and Disturbance Recording

Role Based Access Control (RBAC)

The advanced disturbance and event recording features within the B30 can significantly reduce the time needed for postmortem analysis of power system events and the creation of

Efficiently administrate users and roles within UR devices. The new and advanced access functions allow users to configure up to five roles for up to eight configurable users with independent passwords. The standard “Remote Authentication Dial In User Service” (Radius) is used for authentication.

regulatory reports. Recording functions include: • Sequence of Event (SOE) - 1024 time stamped events • Oscillography

Event Recorder (Syslog for SEM)

• - 64 digital & up to 40 analog channels - Events up to 45s in length

Capture all cyber security related events within a SOE element (login, logout, invalid password attempts, remote/local access, user in session, settings change, FW update, etc), and then

• Data Logger and Disturbance Recording - 16 channels up to 1 sample/cycle/channel

GEDigitalEnergy.com

B30 Bus Differential System

serve and classify data by security level using standard Syslog data format. This will enable integration with established SEM (Security Event Management) systems.

• Increases the number of Logical Devices and data mapped to them, GOOSE messages, and reports to support different organizational needs for data transfer and reduce dependency on generic logical nodes

simultaneously, so in case of failure, one of the data packets will reach the receiving device with no time delay.

Communications

• Configures GE Systems based on IEC 61850 using universal 3rd party tools

UR devices support multiple languages: English, French, Russian, Chinese, Turkish and German. These language options are available on the front panel, in the EnerVista setup software, and in the product manuals. Easily switch between English and an additional language on the local displays without uploading new firmware.

• Multicast IEEE C37.118 synchrophasor data between PMU and PDC devices using IEC 91850-90-5

Direct I/O Messaging Direct I/O allows for the sharing of high-speed digital information between multiple UR relays via direct back-to-back connections or multiplexed through a standard DS0 multiplexer channel bank. Regardless of the connection method, direct I/O provides continuous real-time channel monitoring that supplies diagnostics information on channel health.

The B30 supports the most popular industry standard protocols enabling easy, direct integration into DCS and SCADA systems. • IEC 61850 Ed. 2 with 61850-9-2 and 6185090-5 support • DNP 3.0 (serial & TCP/IP) • Ethernet Global Data (EGD) • IEC 60870-5-103 and IEC 60870-5-104 • Modbus RTU, Modbus TCP/IP • HTTP, TFTP, SFTP and MMS file transfer • SNTP and IEEE 1588 for time synchronization

Direct I/O provides superior relay-to-relay communications that can be used in advanced interlocking, generation rejection and other special protection schemes. • Communication with up to 16 UR relays in single or redundant rings rather than strictly limited to simplistic point-to-point configurations between two devices

• No external or handheld tester required to provide channel diagnostic information

Interoperability with Embedded IEC 61850 Edition 2

LAN Redundancy

• Implements Edition 2 of the standard across the entire family of UR devices • Provides full relay setting management via standard SCL files (ICD, CID and IID) • Enables automated relay setting management using 3rd party tools through standard file transfer services (MMS and SFTP)

The EnerVista suite is an industry-leading set of software programs that simplifies every aspect of using the B30 relay. The EnerVista suite provides all the tools to monitor the status of the protected asset, maintain the relay, and integrate information measured by the B30 into DCS or SCADA monitoring systems. Convenient COMTRADE and SOE viewers are an integral part of the UR setup software included with every UR relay, to carry out postmortem event analysis and ensure proper protection system operation.

• Connect to standard DS0 channel banks through standard RS422, G.703 or IEEE C37.94 interfaces or via direct fiber optic connections

• PRP as per IEC 62439-3

The new IEC 61850 implementation in the UR Family positions GE as an industry leader in this standard.

EnerVista Software

Substation LAN redundancy has been traditionally accomplished by reconfiguring the active network topology in case of failure. Regardless of the type of LAN architecture (tree, mesh, etc), reconfiguring the active LAN requires time to switchover, during which the LAN is unavailable. UR devices deliver redundancy as specified by PRP-IEC 62439-3, which eliminates the dependency on LAN reconfiguration and the associated switchover time. The UR becomes a dual attached node that transmits data packets over both main and redundant networks

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223

Bus Protection

The B30 provides for secure remote data and engineering access, making it easy and flexible to use and integrate into new and existing infrastructures. Fiber optic Ethernet provides high-bandwidth communications allowing for low-latency controls and high-speed file transfers of relay fault and event record information. The available three independent Ethernet ports, and redundant Ethernet option provide the means to create fault tolerant communication architectures in an easy, costeffective manner.

Multi-Language

Bus Protection

B30 Bus Differential System

EnerVista Launchpad

Viewpoint UR Engineer

EnerVista Integrator

EnerVista Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining GE Multilin products. The setup software within Launchpad allows for the configuration of devices in real-time by communicating using serial, Ethernet , or modem connections, or offline by creating setting files to be sent to devices at a later time.

Viewpoint UR Engineer is a set of powerful tools that allows the configuration and testing of GE relays at a system level in an easy-touse graphical drag-and-drop environment . Viewpoint UR Engineer provides the following configuration and commissioning utilities:

EnerVista Integrator is a toolkit that allows seamless integration of GE Multilin devices into new or existing automation systems. Included in EnerVista Integrator is:

Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed. Documents made available include: • Manuals

• Brochures

• Application Notes

• Wiring Diagrams

• Guideform Specifications

• FAQ’s • Service Bulletins

• Graphical Logic Designer • Graphical System Designer • Graphical Logic Monitor

• OPC/DDE Server • GE Multilin Drivers • Automatic Event Retrieval • Automatic Waveform Retrieval

• Graphical System Monitor

User Interface

Viewpoint Maintenance

The B30 front panel provides extensive local HMI capabilities. The local display is used for monitoring, status messaging, fault diagnosis, and device configuration. User-configurable messages that combine text with live data can be displayed when user-defined conditions are met.

Viewpoint Maintenance provides tools that will create reports on the operating status of the relay, simplify the steps to download fault and event data, and reduce the work required for cyber security compliance audits. Tools available in Viewpoint Maintenance include:

Viewpoint Monitoring

• Settings Security Audit Report

Viewpoint Monitoring is a simple-to-use and full-featured monitoring and data recording software package for small systems. Viewpoint Monitoring provides a complete HMI package with the following functionality:

• Device Health Report • Single-ClickFault Data Retrieval

48 Configurable LED Indicators

• Plug-&-Play Device Monitoring • System Single-Line Monitoring & Control

Multi-Language Display • English • Russian • French • Chinese • Turkish • German

• Annunciator Alarm Screens • Trending Reports • Automatic Event Retrieval • Automatic Waveform Retrieval

User-Programmable Pushbuttons SimplifyingCommissioning and Testing

Record the operation of the internal B30 elements and external connected devices with 1ms time-stamped accuracy.

224

Create B30 setting file templates to ensure critical settings are not altered.

GEDigitalEnergy.com

B30 Bus Differential System

Typical Wiring I I I

H3

V I

H4

V I

H5

V I

H6

V

B30 B30-H00-HCL-F8H-L8H-N6A-S8H-U6H

I

U2

V I

U3

V I I

U5

V I

U6

V

I

N1

V

6A

SURGE

I

N2

V

N3

N4

N7a N7c N8a N8c N7b N8b

Fibre * Optic

Tx1

SURGE

10BaseFL Rx1

Tx2

10BaseFL Rx2

Shielded

F1a

IA

F1b

IA1

F1c

IB5

F2a

IB

F2b

IB1

F2c

IC5

F3a

IC

F3b

IC1

F3c

IA5

F5a

IA

F5b

IA1

F5c

IB5

F6a

IB

F6b

IB1

F6c

IC5

F7a

IC

F7b

IC1

F7c

NORMAL COM 1

ALTERNATE

IA5

L1a

IA

L1b

IA1

L1c

IB5

L2a

IB

L2b

IB1

L2c

IC5

L3a

IC

L3b

IC1

L3c

IA5

L5a

IA

L5b

IA1

L5c

IB5

L6a

IB

L6b

IB1

L6c

IC5

L7a

IC

L7b

IC1

L7c

IA5

S 1a

IA

S 1b

IA1

S 1c

IB5

S 2a

IB

S 2b

IB1

S 2c

IC5

S 3a

IC

S 3b

IC1

S 3c

10BaseT

D1a D2a D3a D4b D4a

RS485 com

BNC

Co-axial

BNC

Co-axial

B1b B1a B2b B3a B3b B5b HI B6b LO B6a B8a B8b

DC

IRIG-B Input IRIG-B Output

CRITICAL FAILURE

1

Remote Device

F1

F2

U4

V

U8b N1a N1b N1c N2a N2b N2c N3a N3b N3c N4a N4b N4c N5a N5c N6a N6c N5b

6H

I

U1

V

IA5

IA5

S 5a

IA

S 5b

IA1

S 5c

IB5

S 6a

IB

S 6b

OUTPUT

IB1

S 6c

CONTROL POWER

IC5

S 7a

IC

S 7b

IC1

S 7c

SURGE FILTER

F3

F4

F5

F6

Minimum

X PROVIDED

W

U

V

T

S

R

N

P

M

L

K

J

H

G

F

D

B

6

8

6

8

6

8

9

1

Inputs/ outputs *

CT *

Inputs/ outputs *

CT *

Inputs/ outputs

CT

CPU

Power Supply

(Rear View)

B30-H00-HCL-F8H-H6H-L8H-N6A-S8H-U6H

GEDigitalEnergy.com

225

Bus Protection

Digital Energy Multilin

SURGE

U1a U1b U1c U2a U2b U2c U3a U3b U3c U4a U4b U4c U5a U5b U5c U6a U6b U6c U7a U7c U8a U8c U7b

Dry

A B C

H2

V

H8b

Wet

H1

V

6H

H1a H1b H1c H2a H2b H2c H3a H3b H3c H4a H4b H4c H5a H5b H5c H6a H6b H6c H7a H7c H8a H8c H7b

Ordering B30 - * ** - H * * - F ** - H ** - L ** - N ** - S ** - U ** - W ** For Full Sized Horizontal Mount Base Unit B30 Base Unit CPU E RS485 + RS485 (IEC 61850 option not available) G RS485 + 10BaseF H RS485 + Redundant 10BaseF J RS485 + multimode ST 100BaseFX K RS485 + multimode ST Redundant 100BaseFX N RS485 + 10/100 BaseT T RS485 + three multimode SFP LC 100BaseFX. Req FW v7xx or higher U RS485 + two multimode SFP LC 100BaseFX + one SFP RJ45 100BaseT. Req FW v7xx or higher V RS485 + three SFP RJ45 100BaseT. Req FW v7xx or higher Software Options 00 No Software Options (see note 1 below) 03 IEC 61850 A0 CyberSentry UR Lvl 1. Req UR FW 7.xx or higher B0 IEEE 1588. Req UR FW 7.xx or higher C0 PRP D0 IEEE 1588 + CyberSentry UR. Req UR FW 7.xx or higher Mount/Coating H Horizontal (19" rack) A Horizontal (19" rack) - Harsh Chemical Environment Option User Interface C Basic Front Panel with English Display I Enhanced German Front Panel J Enhanced German Front Panel with User-Programmable Pushbuttons K Enhanced English Front Panel L Enhanced English Front Panel with User-Programmable Pushbuttons M Enhanced French Front Panel N Enhanced French Front Panel with User-Programmable Pushbuttons Q Enhanced Russian Front Panel T Enhanced Russian Front Panel with User-Programmable Pushbuttons U Enhanced Chinese Front Panel V Enhanced Chinese Front Panel with User-Programmable Pushbuttons W Enhanced Turkish Front Panel Y Enhanced Turkish Front Panel with User-Programmable Pushbuttons Power Supply H 125 / 250 V AC/DC (see note 2 below) H RH 125/250 V AC/DC with redundant 125/250 V AC/DC power supply L 24 - 48 V (DC only) CT/VT DSP 8L 8L 8L Standard 4CT/4VT w/ enhanced diagnostics 8M 8M 8M Sensitive Ground 4CT/4VT w/ enhanced diagnostics 8N 8N 8N Standard 8CT w/ enhanced diagnostics 8R 8R 8R Sensitive Ground 8CT w/ enhanced diagnostics IEC 61850 Process Bus 81 8 Port IEC 61850 Process Bus Module Digital I/O XX XX XX No module 4A 4A 4A 4 Solid State (No Monitoring) MOSFET Outputs 4C 4C 4C 4 Solid State (Current w/opt Voltage) MOSFET Outputs 4D 4D 4D 16 Digital Inputs with Auto-Burnish 4L 4L 4L 14 Form-A (No Monitoring) Latchable Outputs 67 67 67 8 Form-A (No Monitoring) Outputs 6C 6C 6C 8 Form-C Outputs 6D 6D 6D 16 Digital Inputs 6E 6E 6E 4 Form-C Outputs, 8 Digital Inputs 6F 6F 6F 8 Fast Form-C Outputs 6K 6K 6K 4 Form-C & 4 Fast Form-C Outputs 6L 6L 6L 2 Form-A (Current w/ opt Voltage) & 2 Form-C Outputs, 8 Digital Inputs 6M 6M 6M 2 Form-A (Current w/ opt Voltage) & 4 Form-C Outputs, 4 Digital Inputs 6N 6N 6N 4 Form-A (Current w/ opt Voltage) Outputs, 8 Digital Inputs 6P 6P 6P 6 Form-A (Current w/ opt Voltage) Outputs, 4 Digital Inputs 6R 6R 6R 2 Form-A (No Monitoring) & 2 Form-C Outputs, 8 Digital Inputs 6S 6S 6S 2 Form-A (No Monitoring) & 4 Form-C Outputs, 4 Digital Inputs 6T 6T 6T 4 Form-A (No Monitoring) Outputs, 8 Digital Inputs 6U 6U 6U 6 Form-A (No Monitoring) Outputs, 4 Digital 6V 6V 6V 2 Form-A (Cur w/ opt Volt) 1 Form-C Output, 2 Latching Outputs, 8 Digital Inputs Transducer I/O 5A 5A 5A 4 dcmA Inputs, 4 dcmA Outputs 5F 5F 5F 8 dcmA Inputs Inter-Relay Communications 2B C37.94SM, 1300nm singlemode, ELED, 2 Channel singlemode 2I Channel 1 - IEEE C37.94, 820nm, multimode fiber, 64/128 kbps; Channel 2 - 1300 nm, singlemode, LASER 2J Channel 1 - IEEE C37.94, 820nm, multimode , 64/128 kbps; Channel 2 - 1550 nm, singlemode, LASER 7A 820 nm, multimode, LED, 1 Channel 7B 1300 nm, multimode, LED, 1 Channel 7C 1300 nm, singlemode, ELED, 1 Channel 7H 820 nm, multimode, LED, 2 Channels 7I 1300 nm, multimode, LED, 2 Channels 7J 1300 nm, singlemode, ELED, 2 Channels 7S G.703, 2 Channels 7W RS422, 2 Channels 77 IEEE C37.94, 820 nm, multimode, LED, 2 Channel

Ordering Notes: 1. To view all available model order codes, options for B30 or to order the UR Classic Front Panel, please visit GE’s On-Line Store at http://store.gedigitalenergy.com/viewprod.asp?model=B30 2. Redundant power supply only available in horizontal unit. If redundant is chosen, must be same type. Maximum 2 per chassis

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Distribution Feeder Protection Distribution Feeder Principles & Protection

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An overview of distribution feeder principles, outlining typical construction of three phase overhead and underground transmission lines, and the common causes of abnormal operating conditions.

Typical Applications

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Typical distribution feeder protection schemes showing small to large applications and how different Multilin protection and control products can be applied.

Spotlight Application

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Highlighting unique distribution feeder applications and the benefits of deploying GE Multilin transmission distribution protection products in such applications. This applications details the importance of double ended fault location capabilities of Multilin protection and control systems.

Technical Resources

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Access an extensive library of interactive tools and videos showcasing innovative solutions, as well as online publications, technical resources, how-to videos and distribution protection configurators.

Selector Guide

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Reference table highlighting the feature set for each Multilin distribution protection system.

Featured Products Detailed product information for distribution feeder protection products offered by GE.

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Distribution Feeder Principles

Distribution Feeder Principles Introduction Electrical distribution is the final stage in the delivery of electricity to end users. The distribution system’s network carries electricity from the transmission system and delivers it to consumers. Since the transmission system is typically rated from 130kV up to 765kV, substation step-down transformers are used to bring the voltage levels down to under 50kV levels for distribution to consumers.

Feeder Protection

As the distribution system is rated up to 50kV many large industrial end users will be fed at these voltage levels and will supply their own on-site substation that will step-down the voltage to more useful voltage levels for their facility. For consumer consumption various step-down transformers and pole mounted transformers will be located in the geographical region that will supply electricity for consumer use.

The Purpose of Distribution Systems With power generating stations being remote to urban centers, it’s required that the generated voltage be stepped up to higher voltage levels for transmission in order to reduce the electrical losses in the overhead transmission lines. By transmitting the electricity at high voltage levels, this reduces the transmission line losses and makes the transmissions line more efficient. Since transmission voltage levels cannot be used by consumers it is required to step-down the transmission voltage to more usable voltages. The transmission power lines will enter a distribution substation where the voltage will be stepped down to distribution levels where it will be distributed for use by industrial, commercial and residential customers.

As the distribution network will typically be rated at no greater than 50kV, this voltage will be distributed to geographical areas where connection to industrial and commercial customers will be achieved. It is most common to find that industrial and large commercial customers are connected to the grid at this distribution level. It is then the responsibility of the industrial or commercial customer to employ their own on-site substations that will stepdown the distribution voltage to levels that are required within the facility. Residential consumers are typically supplied from overhead or underground feeders emanating from utility-owned substations. Pole mounted transformers are typically used in older residential neighborhoods and rural areas. Pole mounted transformers will be limited in the number of customers they supply in order to minimize the interruption time should a fault occur. Connection from the pole mounted transformer is made to each home. In newer developed areas, residential and commercial distribution is done via underground services. Distribution feeders use underground cables, AIS or GIS MV switchgears and conventional or padmount transformers for the final service connection to each home or business.

Distribution in the Power System

Residential 120V - 240V

Generating Station

Distribution Substation

Transmission Substation 138kV - 765kV

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Feeder Distribution

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Commercial 4kV - 13kV

Industrial 26kV - 69kV

Distribution Feeder Principles

Distribution System Configurations Distribution networks are typically of two types, radial or networked. A radial feeder leaves the station and passes through the service area with no normal connection to any other supply. This is typical of long rural lines with isolated load areas. A networked system, having multiple connections to other points of supply, is generally found in more urban areas. These points of connection are normally open but allow various configurations by the operating utility by closing and opening switches. Operation of these switches may be by remote control from a control centre or by a lineman. The benefit of the networked model is that in the event of a fault or required maintenance a small area of network can be isolated and the remainder kept on supply.

Within these networks there may be a mix of overhead lines utilizing traditional utility poles and wires and, increasingly, underground construction with cables and indoor or cabinet substations. Underground distribution, however, is significantly more expensive than overhead construction and therefore often co-located with other utility lines in what are called common utility ducts. Distribution feeders emanating from a substation are generally controlled by a circuit breaker which will open when a fault is detected. Automatic Circuit Reclosers may be installed to further segregate the feeder thus minimizing the impact of faults.

Abnormal Conditions

Fault conditions can also be caused by the contamination of connections and insulators. When the insulation in the connection degrades, the insulation properties are lost (weaken) and may cause a flashover between phases or to ground. Common causes of insulation failure are salt, air pollution, water, and ice.

Figure 1. Radial Network

System transformer faults can also interrupt the distribution system. As transformers become older and insulating material degragades from age, overload conditions, weather, etc. this may also cause a fault in the system.

Figure 1a. Interconnected Network

Typical Distribution Substation

Lightning Arrester

Incoming Transmission Lines

Perimeter Fence

Step-down Transformer

Outgoing LV Distribution Line

Control House

Distribution Bus

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Circuit Breakers

Underground Line to Ditribution Circuit

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Feeder Protection

Common distribution system faults occur on above ground distribution lines. In most cases these faults are caused by trees coming in contact with a distribution lines, or rodents coming in contact with phase connections. Usually, these faults can be cleared by the system, quickly restoring power with the use of auto-reclosers or reslosing function on the circuit breakers.

Distribution Feeder Protection

Feeder Protection Introduction Faults occurring on overhead and underground distribution feeders can be because of external or internal causes. Faults are temporary or permanent and caused by various sources including: • Faulty equipment

Feeder Protection

• Environmental induced faults: wind, lightning, ice, snow-storm, sag due to extreme temperature, salt spray

as those that “do not produce enough fault current to be detectable by conventional overcurrent relays or fuses”. As such, it should be noted that whereas traditional protection is designed to protect the power system, Hi-Z protection is primarily focused on the protection of property and the safety of personnel. High impedance faults can be caused by a number of events, including: • Broken conductor laying on the ground (Downed Conductor)

• Falling tree limbs

• Broken pole allowing line to contact ground or other surface

• Animal contacts

• Broken pole or tree limb causing primary conductor to sag

• People induced including: pole and overhead contacts and underground digging

• Contact with tree limb or other objects

Faults occurring in the distribution system must be sensed quickly and immediately isolated to prevent hazards to the general public and utility personnel. Protective relays are used to sense short circuit conditions caused by faults in distribution protection schemes and the use of proper schemes and settings can help to maximize sensitivity and selectivity. Some permanent faults can be equipment failures or cables cut or shortcircuited by excavation equipment. The type of grounding of the distribution system affects the voltage and current characteristics during a fault . Proper protection strategies should be employed to make dependability an utmost criterion. Basic feeder protection principles are well-known. Phase and ground overcurrent functions reliably detect most faults. Reclosing is often applied to restore service following temporary faults on overhead circuits. Security is maintained through time and pickup coordination between overcurrent devices that may operate for a specific fault event. The challenge in feeder protection is reliable operation during unusual fault events such as high impedance ground faults and adjacent feeder faults. A key advantage of microprocessor based feeder relays is the ability to protect against these unusual faults, while improving the operation of the distribution system through flexibility, programmability, and communications. In addition to the protection of underground and overhead lines, feeder protection relays can also be used for protection of small transformers (distribution transformers), protection of switchgears and busbars (incomer feeders and bus-ties), various types of capacitor banks (i.e. back-to-back), reactors, high-voltage line and transformer back-up protection, etc. The following applications illustrate ways that GE Multilin products can improve feeder protection and system reliability while bringing down the cost and down time.

High Impedance (Hi-Z) Fault Detection Arcing and downed distribution conductors, although not necessarily of immediate concern from an equipment damage point of view, do pose a safety threat from a personnel and property perspective. An energized downed conductor can cause fires, injuries, and even fatalities. Traditional protection devices typically do not detect the fault current levels resulting from these fault conditions. Distribution protection engineers are being challenged with the detection of these high impedance (Hi-Z) faults. The ability to detect Hi-Z faults has been a topic of research and development for over 30 years. The IEEE Power System Relay Committee’s working group on High Impedance Fault Detection Technology defines Hi-Z faults

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• Contaminated or failing equipment (insulators, transformers, conductors, etc.)

Common Misconceptions There are many misconceptions about Hi-Z faults and a lack of understanding of high impedance fault phenomena may lead to injuries and fatalities. The following table lists a few of the common misconceptions about Hi-Z faults. Importance of Hi-Z detection: • If not detected and isolated, live Downed Conductors can be fatal to public and lines crewmen • Hi-Z faults often arc and can be a significant fire hazard • Detect failing insulation before complete device failure, which can lead to power outages and loss of production • Inability to detect Hi-Z can cost utilities liabilities and customer service issues MISCONCEPTIONS

REALITY

Properly set overcurrent protection will trip and clear all faults. Sensitive ground protection typically used to detect low ground current, will clear Hi-Z faults. Over time, the fault current will increase and cause overcurrent protection to operate.

Hi-Z faults often draw less current (10 – 100 amps) than the minimum allowable overcurrent pickup setting, making overcurrent protection impossible. Hi-Z faults can occur where the primary conductor remains intact while in contact with ground through a high fault impedance. No change in the primary current means no change in neutral current to be detected. In most cases, the fault current decreases as the arcing heats the contact surface and the fault impedance actually increases (moisture evaporates, sand fuses). Overcurrent protection seldom operates after first minute.

Faults always clear on my system.

Operations staffs believe the Hi-Z fault rate is low, but many line crews report many downed conductors are still energized when they arrive on scene.

Table 1: Misconceptions about Hi-Z faults.

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Distribution Feeder Protection

The GE Multilin Hi-Z Solution The Hi-Z element in the F60 provides reliable detection of faults caused by downed conductors and high impedance arcing faults. This unique, field proven algorithm incorporates a signature-based expert pattern recognition system developed at Texas A&M University. Harmonic energy levels in the arcing current are used for HiZ fault detection and a sophisticated expert system assures security and dependability for detection of Hi-Z faults. This algorithm has shown a success rate in detecting downed conductors of almost 90% based on actual in-service utility data.

R

1

Key Benefits of Hi-Z Detection Using the F60:

R

2

Out-of-Zone Fault

• Reliable detection of faults caused by downed conductors, high impedance arcing faults • Allows for fast response to hazardous situations • Dependable and secure operation

Feeder Protection

Depressed Voltage

M

• Easy retrofit to existing F60 installations through addition of a single module Figure 2a. System undervoltage sympathetic trip. GE Multilin feeder relays can easily prevent sympathy feeder trips by employing a blocking logic. The blocking logic uses phase undervoltage and phase overcurrent elements in the logic to discriminate between an out-of-zone fault and fault on the protected feeder (Figure 2). The pick up of an undervoltage elements indicates a fault is occurring somewhere on the system. If the fault is on the protected feeder, then the overcurrent element will also pick up near instantly. If the definite time overcurrent element does not pick up in one cycle, then this logic (Figure 2) indicates a condition where a sympathy trip may occur, and blocks the primary instantaneous overcurrent elements. The sympathy trip block logic is removed when the system voltage returns to nominal. Additional logic is used to prevent operation of the scheme for open breaker conditions.

Figure 2. System undervoltage sympathy trip blocking logic.

Sympathy Feeder Trip Prevention Feeder sympathy trips may be defined as incorrect operation of a feeder relay for faults in other areas of the power system or abnormal operating conditions. The likelihood of a sympathy trip is dependent on the system configuration, the types of loads on the circuits, system grounding configuration and protective relay settings. There are many possible causes for sympathy trip. One cause is a system undervoltage, resulting in higher load currents to serve constant VA devices such as large motors. Another cause is adjacent circuit ground faults and adjacent intercircuit coupling.

R

R

1

System Undervoltage Sympathy Trips This type of sympathy trip occurs when a fault occurs on an adjacent feeder depresses the system voltage at the distribution bus (Figure 2a). Motors run at a constant VA, and demand a larger current if the voltage decreases. The system voltage drops nearly instantly with the occurrence of the out of zone fault, however the load current ramps up at slower rate to serve the constant VA loads and may grow considerably as motors stall and draw locked rotor current. With motor loads of sufficient size, the increased load current may appear as on overcurrent condition on unfaulted feeder circuit connected to the bus.

2

Reverse 3I0 and I2

SLG Fault LOAD

Out-of-Zone Fault Figure 3. Load unbalance sympathy trip

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Distribution Feeder Protection

Load unbalance sympathy trips Sympathy trips due intercircuit current coupling are dependent on the system configuration, system grounding, soil resistivity, and load configuration. Figure 3 illustrates a typical intercircuit current coupling event. A phase-toground fault occurs on one circuit. One possible return path, depending on grounding and soil conditions, is through a grounded loads on the unfaulted circuit. This causes the relay on the unfaulted circuit to detect zero-sequence and negative-sequence current due to the fault on the adjacent circuit, and this current may be high enough to operate the relay.

Feeder Protection

The solution to this situation is easily implemented in GE Multilin feeder relays. Desensitizing the relay when an out-of-zone fault exists will prevent operation. Ground and negative sequence directional overcurrent elements operating in the reverse direction from the protected feeder determine an out-of-zone fault and can be used to supervise primary overcurrent protection elements.

Direct I/O is highly reliable, both in performance and communications media. The performance is continuously monitored using a 32-bit CRC to verify bit error rates and package reception, and by routinely sending integrity messages. An individual relay can support single-channel or dual-channel Direct I/O communications for point-to-point communications, dual pointto-point communications, or ring communications between up to 16 relays without the use of a communications hub or other ancillary equipment.

Dynamic Setting groups change Electric power distribution changes hourly to seasonally due to various reasons, including: • Scheduled switching • Emergency switching for repairs • Breaker maintenance • Seasonal load changes and transfers

Pilot Protection for Distribution Networks

• Transformer inrush

Distribution systems are networked to maintain a high level of reliability for critical areas or loads. Networked distribution systems have similar protection challenges to transmission systems in terms of identifying the fault location to correctly isolate the fault.

• Motor starting currents

One very reliable method of protecting networked distribution feeders is to use pilot protection schemes on the feeder, based on directional overcurrent elements and inter-relay communications. One implementation uses a permissive over-reaching transfer trip (POTT) scheme as the primary system (Figure 4), and a time-delayed directional comparison blocking (DCB) scheme (Figure 5) as the backup. The DCB scheme will operate correctly even when the feeder is temporarily operated radially. The operation of POTT and DCB schemes is well known from transmission protection. The challenge in implementing these schemes in distribution protection is in communications, as inter-relay communications is rarely part of the distribution system. GE Multilin relays meet this challenge through the use of IEC61850 GOOSE messaging or Direct I/O communications built directly into one of the Universal Relays. Either IEC61850 GOOSE or Direct I/O securely transmits digital status points between processing these messages exactly the same as contact inputs and outputs. The POTT scheme illustrated sends the permissive signal from one relay to the other using either one of these communications methods, and also sends Direct Transfer Trip (DTT) command using the same method. The DCB sends the blocking signal, and DTT command, via Direct I/O.

• The effect of such change produces: • Major changes in load current • Changes in unbalance levels • Variations in fault levels • Coordination problems • Increased fault duty on conductors and equipment It is important that the protective relay provides sensitive settings under such conditions to provide secure and dependable protection. The ability to have several relay settings groups that can be dynamically activated manually or automatically to meet the needs of the system is one of the most powerful features of most microprocessor based relays. When system conditions change, relay settings are changed instantly. There is no need to compromise a setting to fit two or more different system conditions. Switchgear status can be used to modify protection settings by switching to appropriate setting groups to maximize dependability. The setting groups can be changed in GE Multilin relays via communication ports, digital inputs actual system measurements using logic decisions.

s

52 52

Line 1

52

Line 2

52

67P, 67G (inverse time)

67P, 67G (def. time)

67P, 67G (def. time) 52

67P, 67G (inverse time) 52 IEC61850 GOOSE or Direct I/O Fiber Optic Communications

permissive send, DTT send 2 channels for reliability

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67P, 67G (def. time)

52

IEC61850 GOOSE or Direct I/O Fiber Optic Communications

Figure 4. Pilot Protection for Distribution Networks example 1.

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Figure 6. Parallel feeders

67P, 67G (def. time)

52

52

block send, DTT send 2 channels for reliability

Figure 5. Pilot Protection for Distribution Networks example 2.

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Distribution Feeder Protection

The shown curve can be conveniently separated into three regions: • Long-time . . . in which opening is timed in minutes up to a maximum of 1 hour or 2 hour—depending on the circuit breaker size and the degree of overcurrent—to provide an inverse-time characteristic. The provided time delay allows intermittent or cyclical loads above the pickup current to be carried without causing an interruption. It trips on sustained overcurrent to protect conductors and other equipment. • Short-time . . . in which opening is timed in seconds or tenths of seconds. Overcurrent might be in the range expected in the case of a motor locked rotor or an arcing ground fault. Time delay in this region allows for starting and inrush transient currents or for selective coordination with supply-side or load-side devices.

Figure 7. Dynamic cold load pickup.

Attempts to employ standard IEEE and IEC overcurrent curves to provide protection over this MCCB would result in lack of coordination or unnecessarily slow clearing times. The Flexcurves™ of GE Multilin relays allows building custom overcurrent curve characteristics to suit application like this to achieve proper coordination with a downstream MCCB.

Cold Load Pick-up A cold load condition can be caused by a prolonged feeder outage. Upon the return of the power to the load, the circuit will experience inrush current into connected transformers, starting currents into motors, and simultaneous demand from many loads as the normal load diversity has been lost. During the cold load pickup condition, the feeder current can be above the pickup setting of some protection elements, so this feature can be used to prevent the tripping that would otherwise be caused by the normal settings. Without historical data on a particular feeder, some utilities assume an initial cold load current of about 500% of normal load, decaying to 300% after 1 second, 200% after 2 seconds, and 150% after 3 seconds. There are two methods of initiating the operation of this feature. The first initiation method is intended to automatically respond to a loss of the source to the feeder, by detecting that all phase currents have declined to zero for some time. When zero current on all phases has been detected, a timer is started. This timer is set to an interval after which it is expected the normal load diversity will have been lost, so setting groups are not changed for short duration outages. After the delay interval, cold load pick up setting are used. A second initiation method can use a digital input, including breaker status or SCADA commands.

Custom Overcurrent Curves Maximize Sensitivity and Coordination A typical TOC curve for a thermal-magnetic MCCB (Molded Case Circuit Breaker) is depicted in Figure 8 and 9. This particular curve is for a 600 A frame in ratings of 125 A to 600 A at the typical rated operating temperature of 40 °C. The operating time varies inversely with current level. The shaded band covers manufacturing tolerances and other variables of a typical installation.

Figure 8. Custom Overcurrent Curves Maximize Sensitivity and Corrdination

Arc-flash Mitigation Using Feeder Protection System Arc flash in industrial and utility distribution systems can cause severe damage to equipment and personnel. When arcing occurs, the pressure generated by the sudden increase in the temperature (approximately 30,000°F) is strong enough to break off the metal cabinet door. The plasma emitted from the arc incidents of high energy is very dangerous. Since an arcing fault must travel through air, its fault current is usually lower than that of bolted fault or close-in fault currents. Figure 10 shows Circuit Breaker Tripping Curve and clearance times for bolted faults and arcing faults. As shown in Figure 10, the smaller value of the arcing fault current can significantly delay the fault clearing time of the protection system and result in increased flash damage.

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Feeder Protection

One such application where a dynamic setting group change is required is illustrated in the following example. During normal operation, both lines are in service and carry a portion of the load. The time and instantaneous overcurrent elements are coordinated with the downstream relays according to the system conditions. When line 2 goes out of service the entire load current is carried by line 1 and the time and instantaneous overcurrent settings have to be changed due to the change in system conditions to achieve proper coordination. With multiple settings groups this can be easily achieved by examining the status of the line breakers to switch the settings groups accordingly.

• Instantaneous . . . in which opening is not intentionally delayed and is timed in milliseconds. Typical operation is a result of short circuit from a bolted fault.

As arc flash hazards are recognized, investments in personnel protection are required. Although the amount of energy released in an arc-flash may be greater for higher voltage installations found in some large industrial facilities and utility power plants and substations, the sheer volume of low voltage equipment in commercial and smaller industrial facilities means that these installations account for the greatest number of electrical safety incidents. Many industries and regulatory agencies are currently showing interest in mitigating arc-flash energy and reduce personnel safety hazards.

Feeder Protection

In the recent years many techniques have been proposed to mitigate arc-flash hazards using microprocessor based protective relays. As far as the installations with legacy protective relays are concerned, they are only left with a single expensive incomplete option to reduce arc-flash hazards. To clear the fault quickly as possible coordination studies of the particular system needs to be revised to tighten up the coordination time settings between Time Over Current relays.

TIME

Distribution Feeder Protection

50 51

Flex Inverse Time O/C Curve

IEC/IEEE Inverse Time O/C Curve

MCCB

MCCB CURRENT Maximum Fault Level

Figure 9. Typical TCC curve example.

GE Multilin’s leading edge protection and control products such as F60, F35, 850 and F650 relays can be used to provide advanced arc flash mitigation solutions that are easy to implement. Key benefits of these solutions are: • Improved personnel safety

Arc flash

• Increase production uptime • Easy and cost-effective implementation • Reduce damage to the facility and decreased cost of repair or replacement

Hi-speed Interlocking Schemes Figures 11 shows examples of typical distribution configurations that can be used to provide advance arc-flash mitigation using F60, F35, 850 and F650 protective relay systems. The built-in peer to peer communication capabilities in these relays allow hi-speed data exchange between relays without the use of a communications hub or other ancillary equipment. By using the IEC61850 GOOSE or hi-speed Direct I/O capability, Interlocked protection can be provided to protect buses. Fast clearance can be achieved for a feeder Fault 2 during maintenance and still maintain coordination for fault 1 during normal operation. If the blocking signal from feeder is not received within given time delay then the main breaker will trip the bus. Another method of reducing arc flash hazards is to use a maintenance mode scheme. During the maintenance mode the relay protecting the potential arc flash hazard zone will have its settings changed to instantaneous from coordinated time over current. Although coordination is sacrificed during the maintenance interval, the clearing time is greatly reduced.

Clearing time 14.8 sec

Bolted fault

Clearing time 0.020 sec

Figure 10. Circuit Breaker Tripping Curve

Key advantages of Hi-speed Tripping Schemes: • Fast clearance (2-3 cycles) • Sensitivity and security not compromised during normal operation. • Easy implementation using existing F60, F35, 850, F650 using IEC61850 or Direct I/O • Reduced wiring and commissioning cost

Arc Detected (H8c) On Off

20

AND AND

Arc trip (P8) Arc Trip (VO96)

Operate Seal-In

SRC1 50DD OP

Arc Trip On (VO96)

Figure 12. Fast and secure arc flash clearance with A60 device

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Figure 11. Reverse zone interlocking protection - By using the IEC61850 GOOSE or hi-speed direct I/O capability blocking signal can be transferred upstream, allowing minimal coordination delays. Fast clearance can be provided for Fault 1 and still maintain coordination for Fault 2.

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Distribution Feeder Protection

F35/F60

F35/F60

Key advantages of On-line Breaker Monitoring: • Reduce costs by postponing unnecessary maintenance — with confidence that breakers are operating within normal wear limits. • Detect breaker problems in order to schedule just-in-time maintenance to prevent malfunction or failure. • Implement a predictive Reliability Centered Maintenance (RCM) Program based on historical intelligence continuously gathered in real time. • Extend the operational life of older oil-type circuit breakers. • Better power system reliability.

Dry contact

Figure 13. Dual incomer configuration with sensors and junction box.

With today’s emphasis on reducing maintenance spending, industrials and utilities are being pressured to reduce their overhaul and maintenance costs, which represent a significant portion of the overall operating costs. One way to accomplish this is by extending the interval between maintenance cycles and doing less maintenance, or performing maintenance based on equipment condition rather than elapsed time. The present trend for scheduled maintenance, which is usually based on equipment type, elapsed time, equipment maintenance history, or number of operations, is being directed more towards Reliability Centered Maintenance (RCM) programs based on the criticality of the assert to the system, maintenance history and diagnostic technologies available to identify problems or indications when maintenance is required. This approach provides guidance to staff to target maintenance on the most critical apparatus. Legacy protective relays can only provide number of breaker operations and I2t. This data is not adequate to monitor a breaker and to identify performance variation, developing circuit breaker problems or decide on RCM maintenance. GE Multilin’ s leading technology products from the Universal Relay and 650 families of products can be used to measure additional key parameters from the circuit breakers and process them using the Flexlogic to derive breaker health conditions. • Arc duration — A good indication of dielectric condition

In metal-clad switchgear and MCC applications, current transformers are often selected based on size limitations and full load current. The result is that CTs in these applications are severely underrated, with the available fault current potentially hundreds of times larger than the CT primary (e.g. 50 kA short circuit capacity on a 50:5 C10 CT). When subjected with these large fault currents a CT will saturate severely, passing only a small fraction of the ratio current with the end result being a potential loss of coordination with upstream protection. Relays using fundamental frequency measurements are affected by this problem, but products using true RMS measurements, like GE Multilin relays, are unaffected.

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52

52

52

52

52

Figure 14. Multiple Feeder Protection and Control.

Transformer Protection

• Maximum Fault Current — Each operation, by phase

Feeder relays can be used to protect small and medium-sized transformers mainly used in distribution networks. A simple feeder relay with over current, earth fault and thermal overload functions can be used in circuit breaker switchgears.

• Contact interrupting duty — Accumulated I2T per phase • Latch health indication – Trip command to “52a” opening • Balance of mechanism health – Trip command to “52b” closing • Number of Operations Alarm • Real time data availability – Immediate detection of impeding problem immediately. • Visible record available, using waveform capture of breaker operations.

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Feeder Protection

On-line Breaker Monitoring

CT Saturation in Industrial Applications

Distribution Feeder Protection

Back-up Protection Back-up protection increases system protection reliability and provides protection redundancy. Back-up relays operate independently of primary protection system and that is intended to operate in case of primary protection failure or if it is out of service for maintenance and other purposes. Back-up protection systems are additional equipment arranged to trip the same circuit breaker or in case of breaker failure, it can initiate breaker failure protection to trip other breakers.

Feeder Protection

Multilin 350 Multilin 350

Multilin F650

Multilin 850

Feeder protection relays can be used as local back-up for equipment such as transformers and lines. In case of using back-up feeder relays, based on the application, selectivity and speed should be considered.

Fault Location Modern feeder relays have an option to show the distance to the fault location. This feature provides an accurate estimate of fault location without communications channels, special instrument transformers, or pre-fault information.

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Distribution Feeder Protection

Power Quality and System Disturbance Analytics Modern feeder relays provide high accuracy power quality monitoring for fault and system disturbance analysis. Power quality is important not only to plant and process operations, system equipment and machinery only, but also for computers and other electronic devices as well. International Committee for Information Technology Standards is imposing requirements for the safe operation of the computers through the well-known CBEMA curve (CBEMA-Computer and Business Equipment Manufacturers’ Association). Other than basic electrical parameters like voltage, current and power, power quality monitoring consists of harmonics measurement and transient recorder.

Capacitor Bank Protection Capacitor banks are used to improve the power system quality and they role is to generate reactive power. Feeder protection relays can be used to protect various types of capacitor banks including fixed and switched banks against short circuits, overloads, unbalances and other types of faults. As an example, in back-to-back capacitor banks which capacitors are Y-connected, the current flowing through the common point of coupling (neutral point), should be measured and supervised. This usually be done with an unbalance over current relay that continuously measure the unbalance current in order to detect internal shortcircuits and blown fuses. Voltage should also be monitored to be in tolerable range for capacitors. Over voltages can cause overload for capacitor units. Feeder Protection

Multi-feeder Protection Modern feeder relays with a large number of inputs/outputs, large number of current transformer inputs, and independent protection elements can be used to protect multi feeders. Modern relays have a robust hardware design and relay failure would rarely happen. So, reliability is less of a concern and a single device can be used to protect a number of feeders. Load-shedding, interlocking and bus transfer schemes are also easier to implement with a single device. It can be applied to distributed generation applications when interconnect protection (i.e. anti-islanding) is needed. Another application is to protect both MV and LV side of a transformer with a single device. It is a cost effective solution especially for distribution utility MV and LV switchgears.

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Typical Applications

Distribution Feeder Protection – Typical Applications Simple Radial Feeders (mostly underground cables)

Feeder Protection

Bus

50P 51P 50N 51N

3CTs

50 G/SG 51 G/SG

49

79

1CT

52

Typical Functions

Additional Functions

50P

Phase Instantaneous Overcurrent

50G/SG

Ground Instantaneous Overcurrent

51P

Phase Time Overcurrent

51G/SG

Ground Time Overcurrent

50N

Neutral Instantaneous Overcurrent

49

Thermal Overcurernt

79

Auto Reclose

HiZ

Hi Impedance

51N

Neutral Time Overcurrent

Hi Z

Functions

Typical Product Order Code

350

350-E-P5-G5-H-E-M-N-N-SN-N-N

350

350-E-P5-G5-H-E-M-C-N-SN-D-N (with 79)

F60

F60-U00-HPH-F8L-H6L-M6L-P6E-UXX-WXX

Advanced Feeder Protection

Bus

50P 51P 50N 51N

3CTs

50_2 1CT

50 G/SG 51 G/SG

49

Additional Functions

50P

27x

Auto Reclose

67P

Phase Direcdtional Overcurrent

Phase Instantaneous Overcurrent

51P

Phase Time Overcurrent

50N

Neutral Instantaneous Overcurrent

67N

Neutral Directional Overcurrent

51N

Neutral Time Overcurrent

67G

27P

Phase Undervoltage

Ground Directional Overcurrent

59P

Auxiliary Overvoltage

67_2

Negative Sequence Directional Overcurrent

59x

Auxiliary Overload

59N

Neutral Overvoltage

27P 59P 27X

52

67P 67N 67G 67_2 59X 59N 59_2 25 32

238

51_2

Typical Functions

32N 79

Additional Functions 50_2

Negative Sequence Instantaneous Overcurrent

59_2

Negative Sequence Overvoltage

51_2

Negative Sequence Time Overcurrent

25

Synchrocheck

50G/SG

Ground Instantaneous Overcurrent

32

Directional Power

32N

Neutral Power

51G/SG

Ground Time Overcurrent

79

Auto Reclose

49

Thermal Overload

Functions

Typical Product Order Code

350

350-E-P5-G5-H-E-M-N-P-SN-D-N

F650

F650-B-F-B-F-1-G-0-HI-E

850

850-E-P5-NN-G5-H-N-N-A-N-N-G-A-P-F-CSE-N-N-B-N

F60

F60-U00-HPH-F8L-H6L-M6L-P6E-UXX-WXX

GEDigitalEnergy.com

Typical Applications

Feeders with Reclosure Automation

Typical Functions

50P 51P 50N 51N

79

51P

Phase Time Overcurrent

50N

Neutral Instantaneous Overcurrent

51N

Neutral Time Overcurrent

51G/SG Ground Time Overcurrent

67P 67N 67G 32

Phase Instantaneous Overcurrent

50G/SG Ground Instantaneous Overcurrent

50G/SG 51G/SG

52

50P

32N 25

R2

Phase Direcdtional Overcurrent

67N

Neutral Directional Overcurrent

67G

Ground Directional Overcurrent

25

Synchrocheck

32

Directional Power

32N

Netual Power

79

Auto Reclose

Functions

Typical Product Order Code

350

350-E-P5-G5-H-E-E-C-P-1E-D-N

F60

F60-U00-HPH-F8L-H6L-M6L-P6E-UXX-WXX

850

850-E-P5-NN-G5-H-N-N-A-N-N-G-A-P-C-BSE-N-N-B-N

Feeder Protection

R1

67P

Incomer Feeder

Bus

50P 51P 50N 51N

3CTs

50 G/SG 51 G/SG

49

59X 59N 59_2

52

Typical Functions

Additional Functions

50P

Phase Instantaneous Overcurrent

50G/SG

Ground Instantaneous Overcurrent

51P

Phase Time Overcurrent

51G/SG

Ground Time Overcurrent

50N

Neutral Instantaneous Overcurrent

49

Thermal Overload

27x

Auto Reclose

59x

Auxiliary Overload

59N

Neutral Overvoltage

59_2

Negative Sequence Overvoltage

25

Synchrocheck

51N

Neutral Time Overcurrent

27P

Phase Undervoltage

59P

Auxiliary Overvoltage

27P 59P 27X 25

Functions

Typical Product Order Code

350

350-E-P5-G5-H-E-M-N-P-SN-D-N

F650

F650-B-F-B-F-1-G-0-HI-E

850

850-E-P5-NN-G5-H-N-N-A-N-N-G-S-P-F-BSE-N-N-B-N

F60

F60-U00-HPH-F8L-H6L-M6L-P6E-UXX-WXX

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Typical Applications

Bus Tie Protection Typical Functions

Additional Functions

50P

Phase Instantaneous Overcurrent

46

51P

Phase Time Overcurrent

50N

Neutral Instantaneous Overcurrent

51N

Neutral Time Overcurrent

52 50P 51P 50N 51N

Stator Current Unbalance

Functions

Typical Product Order Code

350

350-E-P5-G5-H-E-M-N-N-SN-D-N



Feeder Protection

46

5-Feeder Protection with Voltage Metering Typical Functions

Additional Functions

50P

Phase Instantaneous Overcurrent

50G

Ground Instantaneous Overcurrent

51P

Phase Time Overcurrent

51G

Ground Time Overcurrent

50_2

Negative Sequence Instantaneous Overcurrent

27P

Phase Undervoltage

51_2

Negative Sequence Time Overcurrent

27X

Auto Reclose

59N

Neutral Overvoltage

49

Thermal Overload

59X

Auxiliary Overload

50N 51N 50G 51G

50N

Neutral Instantaneous Overcurrent

81U

Under Frequency

79(5)

Automatic Recloser

27P 27X 59N 59X 81U

51N

CB2

CB3

CB4

52 50P 51P 50_2 51_2

49

CB5

Neutral Time Overcurrent

Functions

Typical Product Order Code

F35

F35-T00-HKH-F8L-H6L-M8N-P6L-U8N-W6L



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Typical Applications

6-Feeder Protection

CB2

CB3

CB4

CB5

CB6

52 50P 51P 50_2 51_2

49

50N 51N 50G 51G

Typical Functions

Additional Functions

50P

Phase Instantaneous Overcurrent

50G

Ground Instantaneous Overcurrent

51P

Phase Time Overcurrent

51G

Ground Time Overcurrent

50_2

Negative Sequence Instantaneous Overcurrent

79(6)

Automatic Recloser

51_2

Negative Sequence Time Overcurrent

49

Thermal Overload

50N

Neutral Instantaneous Overcurrent

51N

Neutral Time Overcurrent

87G

Generator Differential

Functions

Typical Product Order Code

F35

F35-T00-HKH-F8N-H6L-M8N-P6L-U8N-W6L

Feeder Protection

Transformer-Feeder Typical Functions

50P 51P 50N 51N

52

50G/SG 51G/SG

49

87G

50P

Phase Instantaneous Overcurrent

51P

Phase Time Overcurrent

50N

Neutral Instantaneous Overcurrent

51N

Neutral Time Overcurrent

50G/SG Ground Instantaneous Overcurrent 51G/SG Ground Time Overcurrent 49

Thermal Overload

87G

Generator Differential

Functions

Typical Product Order Code

350

350-E-P5-G5-H-E-M-N-N-SN-N-N

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Application Spotlight

Early Fault Detection and Warning Arc Flash Electrical Technicians are exposed to various hazardous conditions when they work live in switchgears or on a power system. Arc flash is the most devastating of these hazards as it can cause catastrophic equipment damage, fire or injury. An arc flash is a voltage breakdown of the resistance of air resulting in a flash over from one exposed live conductor to another conductor or to ground.

Three factors determine the Arc Flash intensity on line personnel - the available system fault current, the time for the arc flash to clear, and the individual’s distance from the arc. Various configuration choices can be made with Multilin’s leading edge protection and control products such as F60, F35, F650, 850 protective relays and dedicated A60 arc flash system to affect these factors and in turn reduce the Arc Flash hazard.

Feeder Protection

The massive energy released during an arc flash fault sends concentrated radiant energy, hot gases and melting metal outward at 35,000 degrees Fahrenheit (F) or four times the temperature of the sun’s surface. In addition

to the explosive blast, Electrical workers caught in such a condition may suffer severe radiation burns, damaged eyesight from high-intensity flash, and hearing loss and brain damage from accompanying pressure waves.

Prevent Dangerous Arc-flash explosions Significant energy is released during an arc-flash condition, rapidly vaporizing metal conductors, blasting molten metal outward with extreme force endangering local personnel and damaging equipment.

Solution F60, F35, F650, 850 Feeder Protection System and A60 arc flash detection system The above menioned mitigates arc-flash hazards without false trips protection personnel and primary equipment.

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Application Spotlight

with Comprehensive Feeder Protection High Impedance Fault Detection

Incipient Cable Splice

Arcing and downed distribution conductors pose personnel and property safety threats such as fires, injuries, and even fatalities. Since high impedance (Hi-Z) faults do not produce enough fault current to be detectable by conventional over-current relays, they are not detected by traditional protection devices.

Moisture ingress due to defective terminations is one of the major cause of underground cable failures. When water gathers in a subversive cable splice, a momentary line-to-ground fault occurs. Although the fault is selfclearing, the repetitive cycle of water ingress causes the splice insulation to deteriorate and in due course fail. These underground cable faults last a very short duration, which makes the design of an incipient fault protection function quite challenging The basic Multilin incipient cable splice protection algorithm detects a single incipient fault pattern. Incipient fault detection can be used either to alarm or trip. Either option is reasonable, however the occurrence of a half-cycle event indicates the cable is failing, and a full fault is about to occur in the circuit. Feeder Protection

Hi-Z protection in the GE Multilin’s F60 is a unique, field proven algorithm incorporating a signature-based expert pattern recognition system. Harmonic energy levels in the arcing current and a sophisticated expert system assures security and dependability for detection of Hi-Z faults. This algorithm has shown a 90% success rate in detecting downed conductors based on actual in-service utility data. While traditional protection is designed to protect the power system, Hi-Z protection focuses on people and property.

Prevent

Prevent

Undetected live downed conductors

Explosion caused by Incipient cable faults

Downed live power lines caused by wind, fallen tree branches, or ice accumulation, can cause fires, injuries, or other high-risk incidences, if left undetected.

Incipient faults can cause insulation material around underground lines to heat, building up gas, and resulting in an explosion.

Solution

Solution

F60 Feeder Protection System

F60, F35 Feeder Protection System

The field proven algorithm in the Multilin F60 provides fast response to down conductors maximizing system availability and public safety.

The F60 uniquely recognizes the criteria that could lead to these faults, providing sufficient notification ensuring system dependability and safety.

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WATCH. INTERACT. LEARN.

Feeder Protection

OVER 10,000 interactive tools and technical resources t hat showcase our Grid Modernization Solutions

Extensive library of interactive tools & videos 

Broad range of publications & technical resources

SOLUTIONS

SELECTOR GUIDES

for distribution feeders

Discover innovative solutions to distribution systems challenges using our interactive 3D power system.

“How To” videos &

for distribution feeder products

Compare, filter and select your product by protection, control, automation, and communications features to fit your application needs.

online product

TRAINING

CONFIGURATORS

Access over 60 step-by-step product videos and technical training to help you get the most out of your products.

Configure, price and easily order your distribution feeder protection products on the Digital Energy online store.

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Product Selector Guide

Distribution Feeder Protection – Selector Guide Features

Device

32 67P/N/G/_2 50BF 50 P/N/G/_2 50SG 51 P/N/G/_2 51SG 27 P/X RGF

350

F650

750/760

•

•

•

•

•

• • •

• • • P/N/G/_2 • P/N/G/_2 • P/X

• • • P/N/G/_2 • P/N/G/_2 • P/X •

• • • P/N/G/_3 • P/N/G/_3 • P/X • •

Logic P/N/G • P/N/G • P/X

P/N/G •

P/N •

P/N/G/_2 •

X/N

4 • • • • • • • •

4 • • •

4 • • • • • • • • • • • • 4 • •

• P/G • P/G P/X

•

HiZ 59P/X/N/_2 25 50DD 79 81U 81O 86 I2/I1

4

• • •

49 81R 55 67SG 87G(RGF) 38/49T

• 2 • 20x In 72000 4 4 2 5 2 4 168.2x201.51x100.6 • • 2

TCM(74) / CCM • •

• • • • • •

4 • •

2

20x In 1650000 5 4 32 16

20x In 6000000 5

16 237x266.3x168 • 3 • • • • 8 8

•

14 8 216x252x191 • • 4 • • • •

• • • • • • 21FL

256 32 •

• •

•

• • • • • • •

•

•

• • • • • • • • • • 479 16 •

• • • • • • • • • • 512 16 •

•

•

• • • • • •

• •

• •

• • • •

•

• • • •

850

F35

F60

• Logic •

•

• 4 • • •

Logic • 4 • 6

• Logic • • • • P/N/G/_2 • P/N/G/_2 • P/X • • • P/X/N/_2 • • 4 • • • • • • • • Logic • • • 4 • • 2

Feeder Protection

APPLICATIONS Simple Radial Feeders Protection Feeders with Reclosure Automation Advanced Feeder Protection LV /MV Bus Transfer Schemes Up to 6 Feeders in One Box HiZ Fault Detection PROTECTION & CONTROL Directional Power Directional, Phase/Neutral/ Ground/ Negative Seq. Breaker Failure IOC, Phase/Neutral/Ground/Negative Seq. IOC, Sensitive Ground TOC, Phase/Neutral/Ground/ Negative Seq. TOC, Sensitive Ground Undervoltage, Phase/Auxiliary Restrictive Ground Fault Wattmetric Zero Seq. Directional High Impedance Fault Detection (Hi-Z) Overvoltage, Phase/Auxiliary/Neutral/ Negative Seq. Synchronism Check Current Disturbance Detector AC Reclosing (Shots) Underfrequency Overfrequency Lockout Protection Broken Conductor Detection Voltage Transformer Fuse Failure Cold Load Pickup Thermal Overload (Thermal Model) Frequecy Rate of Change Power Factor Sensitive Ground Directional Element Restricted Earth Fault Temperature monitoring (RTD) FlexCurves™ (Number of Elements) Load Encroachment Custom programmable overcurrent curve Multi Feeder Protection HARDWARE Current Inputs (max. from the range) Voltage Inputs (primary volts) Number of Current Inputs Number of Voltage Inputs Contact Inputs (Min. & Max.) Contact Outputs (Min. & Max.) Types of outputs (Form-A) Types of outputs (Form-C) Dimensions (WxHxD in mm) Harsh Conformal Coating Draw-out Design AUTOMATION Settings Groups Non-volatile latches Trip/Close Coil Supervision FlexElements™ (Number of Elements) Breaker Control Programmable Logic Timers (Number) Digital Counters (Number) Digital Elements (Number) Automatic Transfer Scheme Virtual Inputs (Number) Virtual Outputs (Number) Trip Bus MONITORING & METERING Voltage Current Power Factor Real, Reactive & Apparent Power Current, MW, MVAR, MVA Demand Energy Frequency Frequency Decay Analog Inputs Fault Location Event Recorder - Number of Events Oscillography - Sampling Rate Breaker Arcing Current Breaker Health Environmental Monitoring Data Logger THD & Harmonics Meter COMMUNICATIONS RS232 Port RS485 Port RS422 Port, G.703, C73.94 Ethernet Fiber (800nm, 820nm,850nm,1300nm, 1550nm) USB Front Port Wifi ModBus RTU ModBus TCP/IP DNP3.0 Protocol IRIG-B Input TCP/IP Simple Network Time Protocol (SNTP) IEEE 1588 IEC 60870-5-103 IEC 60870-5-104 IEC61850 Protocol IEC62439 / PRP IEC62439 / HSR

46 x In 46 x In 46 x In 1250000 5760000 5760000 5 24 4 4 4 4 7 to 14 4 to 80 4 to 80 4 to 12 4 to 40 4 to 40 2 to 4 40 40 4 to 9 40 40 214 x 251.3 x 191.8 446.02x176.78x279.81 446.02x176.78x279.81 • • • • 6 • • 8 • • 32 16 • 32 32 • • • • • • • • • • 1024 128 • • • • • • • • • • • • • • • • • • • • • •

6 • • 16 Logic • 32 8 48 Logic 64 96 •

6 • • 8 • • 32 8 48 Logic 64 96 •

• • • • • • • • • 1024 64 •

• • • • • • • • • • 1024 64 •

• •

• •

• • • • • •

• • • • • •

• • • • • • • • • • •

• • • • • • • • • • •

For the most up-to-date selector guides, please visit

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245

Featured Products

Distribution Protection – Featured Products F60

Advanced Protection, Control and Automation Solutions for Distribution Feeders

247

The F60, a member of the UR Family of protection relays, provides high performance feeder protection, control, monitoring and metering in an integrated, economical, and compact package. The F60 includes GE Multilin’s unique high impedance fault detection for fast and reliable detection of downed conductors.

F35

Cost-effective Protection and Control for Single/Multiple Distribution Feeders

255

Feeder Protection

The F35, a member of the UR Family of protection relays, provides cost-effective feeder protection, control and metering for up to five feeders with busbar voltage measurement, or six feeders without busbar voltage in one integrated package. Use the F35 as a stand-alone device or as a component of an automated substation control system.

850

Draw-out Feeder Protection and Control for Industrial and Utility Feeders

263

The Multilin 850 relay, a member of the 8 Series protective relay platform, provides primary or backup protection for underground and overhead medium voltage feeders in industrial and distribution utility applications. Designed with comprehensive communication options and detailed asset monitoring and diagnostic capabilities, the 850 provides advananed protection & control.

F650

Comprehensive Feeder Protection with Bay Controller

283

The F650, a member of the 650 Family of protection relays, incorporates protection, control, automation and metering in a economical package. F650 comes with a large LCD and single line diagrams can be built for bay monitoring and control for various feeder arrangements including ring-bus, double breaker or for breaker and half.

350

Intuitive and Innovative Feeder Protection

293

The 350 is a member of the new SR 3 series family of protection and control devices from Multilin. This cost-effective protective device is used to perform primary circuit protection on low and medium voltage feeders. The protection functions of this relay include multiple phase, ground, and neutral time and instantaneous overcurrent elements, plus essential feeder breaker control features such as cold load pickup blocking, breaker failure, and auto-reclose. The 350 also offers enhanced features such as diagnostics, preventative maintenance, arc-flash mitigation and security.

A60

Arc Flash Detection System

305

The Multilin A60 Arc Flash System utilizes GE’s patented light and pressure signal fiber sensor to help ensure fast and reliable protection against arcing events. Based on a known time relationship between the speed of light and sound, (pressure wave), GE’s patented sensor is able to detect and issue a trigger signal to clear the fault in under 2 milliseconds – significantly reducing incident energy from an arc flash event.

Go online for the full listing of Multilin Protection & Control products

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Multilin™ F60 Advanced Protection, Control & Automation for Distribution Feeders The Multilin F60 Feeder Protection System provides feeder protection, control, monitoring and metering in an integrated, economical, and compact package.

Protection & Control • High-impedance fault detection (downed conductor detection) • Thermal overload, incipient cable fault and broken conductor detection

The F60 incorporates a unique and matured algorithm to detect high-impedance faults, such as downed conductor detection. It also provides fast and deterministic execution of programmable logic, which is necessary for substation automation applications. Graphical programming tools (Viewpoint Engineer), supported by a library of logic components, make the F60 simple to use and configure.

• Four-shot autorecloser, VT fuse failure detection, and synchronism check

Key Benefits

• 3 independent Ethernet ports for simultaneous & dedicated network connections with IEEE 1588 support

• Advanced and flexible protection and control for distribution feeder applications with unique and secure downed conductor detection backed by many years of field experience

Communications

• Voltage and frequency elements provide load shedding & transfer schemes for increased system uptime and stability

• Supported industry protocols: IEC 61850 Ed. 2, SFTP, MMS File Transfer Service, DNP 3.0, Modbus Serial/TCP, IEEE 1588, IEC 60870-5-104 and 103, PRP, SNTP, HTTP, TFTP

• Embedded Synchrophasor measurement capabilities (per IEEE® C37.118), eliminating the need for dedicated PMUs and support for synchrophasor multi-cast (per IEC® 61850-90-5) reducing bandwidth and communications infrastructure costs

• Direct I/O for secure, high-speed exchange of data between URs for DTT & pilot-aided schemes

• Flexible load encroachment allows secure operation during heavy load conditions

• Advanced IEC 61850 Ed. 2 implementation, complete settings via SCL files and IEC 61850-9-2 process bus solution enable resource and platform managing optimization and reduce cost of ownership • Increased network availability via failover time reduced to zero through IEC® 62439-3 “PRP” support • CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog) • Advanced fault and disturbance recording, including internal relay operating signals, eliminating the need for external recording devices

Applications • Primary protection and control for feeders on solidly, impedance or resonant (Petersen coil) grounded systems • Busblocking / interlocking schemes • Distribution load shedding schemes based on voltage and frequency elements • High-speed fault detection for arc flash mitigation • Throw over schemes (bus transfer scheme applications) • Backup protection for transmission lines, feeders and transformers • Distributed Generation (DG) interconnect protection , including active and passive anti-islanding

Cyber Security • CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog) • Setting for security audit trails, tracking changes to device configurations

Monitoring & Metering • P&M class synchrophasors of voltage, current, and sequence components • Advanced recording capabilities with highcapacity event recorder, configurable and extended waveform capture and data logger • Metering: current, voltage, power, energy, frequency, and harmonics

F60 Feeder Protection System

Protection and Control

F60 - Protection, Metering, Monitoring and Control

As part of the Universal Relay (UR) family, the F60 features high-performance protection, expandable I/O options, integrated monitoring and metering, high-speed communications, and extensive programming and configuration capabilities including:

Downed Conductor (Hi-Z) Detection

Feeder Protection

Fires, injuries, and even fatalities may be caused by a live downed conductor. Unfortunately, these high risk incidences often go undetected by conventional protective relays. The Hi-Z element in the F60, unique to Multilin, provides reliable detection of faults caused by downed conductors. Sophisticated algorithms developed over the past 20 years, detect downed conductors, tree branch contacts, and insulation fault in underground cables. This unique, field-proven algorithm incorporates artificial intelligence to maximize dependability. Key benefits of Hi-Z detection in the F60:

The F60 offers an integrated protection, control, metering and monitoring package that can directly connect into DCS or SCADA monitoring control systems, such as Viewpoint Monitoring.

Functional Block Diagram

52 79(4)

CLOSE

2

81U

TRIP

Monitoring

6

50P 50_2 51_2 50BF 51P/V 67P 67_2 4

2

2

2

4

2

32

2

49 2

50N 2

51N 67N/G 50NBF

4

4

2

2

81O 4

27P 3

METERING

FlexElement™

87G

50G 4

59P

Transducer Inputs

3

59N

51G

3

4

27X

2

59X

59_2 2

F60 Feeder Protection System

3

25 4

ANSI® Device Numbers & Functions DEVICE NUMBER

FUNCTION

DEVICE NUMBER

FUNCTION

DEVICE NUMBER

FUNCTION

25 (2) 27P 27X 32 50BF/50BNF(2) 50DD 50G (2) 50N (2) 50P (2)

Synchrocheck Phase Undervoltage Auxiliary Undervoltage Sensitive Directional Power Breaker Failure Disturbance Detector Ground Instantaneous Overcurrent Neutral Instantaneous Overcurrent Phase Instantaneous Overcurrent

50_2 (2) 51G (2) 51N (2) 51N (2) 51P (2) 51_2 (2) 52 59N 59P

Negative Sequence Instantaneous Overcurrent Ground Time Overcurrent Neutral Time Overcurrent Phase Time Overcurrent Negative Sequence Time Overcurrent AC Circuit Breaker Neutral Overvoltage Phase Overvoltage

59X 59_2 67N (2) 67P (2) 67_2 (2) 79 81O (4) 81U (6) 87G(RFG)

Auxiliary Overvoltage Negative Sequence Overvoltage Neutral Directional Overcurrent Phase Directional Negative Sequence Directional Overcurrent Automatic Recloser Overfrequency Underfrequency Restricted Ground Fault

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F60 Feeder Protection System

Auto-Transfer Scheme Implementation Example

It allows the phase overcurrent elements to be set to see end-of-line phase faults in heavily loaded feeder applications.

Over/Under Voltage Protection

FIBER/COPPER

CB1 F60-1

CB2

The F60 includes the following voltage elements:

F60-2

• Up to 2 phase undervoltage and 3 phase overvoltage elements • 1 auxiliary under/over voltage element • 1 neutral overvoltage element The following are some of the key applications where voltage elements can be used:

TCB1 CB3

CB4

CB5

CB6

• Source transfer schemes • Load shedding schemes Feeder Protection

• Backup capacitor bank protection and control Auto-transfer schemes can be implemented using programmable FlexLogic. Wiring between relays can be eliminated using peer-to-peer communication.

• Reliable detection of faults caused by downed conductors • Fast response to hazardous situations • Dependable and secure operation using artificial intelligence • Detection of arcing faults • Easy integration by the addition of a Hi-Z module to a new or existing F60 relay

Directional Overcurrent Protection The F60 also has built-in standard IEEE, IEC, IAC and FlexCurves™ overcurrent characteristics (TOC), most commonly used for primary and backup protection in various protective zones. It has phase IOC elements with separate outputs for each phase. Each TOC element has the following programmable characteristics: • Pickup current level for trip, alarm, or control • Choice of 17 curve shapes (including FlexCurves) and curve multipliers • Instantaneous or linear reset time characteristic to coordinate with upstream transformer damage curves and downstream reclosers and fuses

The F60 allows the use of directional elements for supervision of ground overcurrent protection elements and provide sensitive tripping for faults in one direction. Typical application for directional overcurrent includes: • Isolation of faulted feeders in ring bus or parallel feeder arrangements • Prevention of back-feeding utility source fault from industrial plant generators • Sensitive high-speed ground fault protection for transformers For neutral directional sensing, the residual current of the phase CTs is used as the operating current . For current polarization, a residual CT is used to measure zero-sequence current. For voltage polarization, the calculated or measured zero-sequence voltage can be used. The maximum torque angle is programmable. Two enhanced dual polarization modes use both current and voltage signals to determine polarity. “Dual-V” polarization gives priority to polarity determined based on voltage while “Dual-I” polarization gives priority to polarity determined based on current.

• Voltage restraint to increase sensitivity

Load Encroachment

The majority of distribution systems are either solidly grounded or grounded through a low impedance. Fast fault clearance is required due to the ground fault impact. The following functions are incorporated in the F60 to provide secure ground protection:

The load encroachment function in the F60 provides the capability to manage load growth in feeders. The load encroachment element can be set for the feeder’s expected maximum load, reducing the likelihood of false tripping for load conditions while maintaining dependability to trip for legitimate faults.

• Neutral IOC and TOC

• Backup motor protection to prevent automatic restart

Abnormal Frequency Protection The F60 offers over and underfrequency elements to improve network (grid) stability using voltage or frequency-based load shedding techniques. The F60 can be integrated into a communications network containing N60 network stability relays to implement wide area, intelligent load shedding schemes. It also provides backup protection when protecting feeders and other frequencysensitive power equipment.

Frequency Rate of Change Protection Frequency rate of change (df/dt) elements are included in the F60 to provide protection against system disturbances through load shedding and to provide anti-islanding protection for distributed generator interconnections.

Cold Load Pickup A cold load condition can be caused by a prolonged outage of the load, by opening the circuit breaker, or by a loss of supply even if the breaker remains closed (cyclic loads like HVAC, refrigeration systems). F60 can automatically detect conditions that would lead to cold load pickup and selectively block protection elements for security during feeder energization.

Wattmetric Ground Fault Protection A sensitive wattmetric zero-sequence directional function can be used on isolated or resonant (Petersen coil) grounded, low-resistance grounded and solidly grounded systems to detect ground faults.

• Ground IOC and TOC

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249

Feeder Protection

F60 Feeder Protection System

This function determines the presence and direction of ground faults by measuring the value and direction of zero-sequence power. This flexible element responds to power derived from zero-sequence voltage and current in a direction specified by the element characteristic angle. Power can be selected as active, reactive, or apparent . Therefore, the element may be used to sense either forward or reverse ground faults.

The Multilin HardFiber System offers the following benefits:

Autorecloser

• Does not introduce new cyber security concerns

Two autoreclose elements are provided for use with distribution lines in three-pole tripping schemes with up to two breakers. Up to four selectable recloser “shots” are possible prior to locking out. Any of the autoreclose elements can be dynamically blocked or unblocked by other elements or user logic. This way they can coordinate with the F60 protection setting groups.

Synchronism Check The F60 provides four synchrocheck elements that monitor voltage difference, phase angle difference and slip frequency to ensure proper breaker closure as per user requirements. Any of the four synchrocheck elements can be dynamically blocked or unblocked by other elements or user logic. This way they can coordinate with the F60 protection setting groups.

Breaker Failure and Control The F60 provides the required elements to perform two independent breaker failure functions. The F60 can provide independent breaker failure protection for both breakers on a feeder with a breaker-and-a-half or ring bus terminal. The relay also provides for the control of one or two breakers from faceplate pushbuttons, remote communications or contact inputs. A breaker position can be indicated by LEDs on the faceplate.

IEC 61850 Process Bus The IEC 61850 Process Bus module is designed to interface with the Multilin HardFiber System, allowing bi-directional IEC 61850 fiber optic communications. The HardFiber System is designed to integrate seamlessly with existing UR applications, including protection functions, FlexLogic, metering and communications.

• Communicates using open standard IEC 61850 messaging • Drastically reduces P&C design, installation and testing labor by eliminating individual copper terminations • Integrates with existing F60’s by replacing traditional CT/VT inputs with the IEC 61850 Process Bus module

Visit the HardFiber System product page on the GE Digital Energy web site for more details.

Advanced Automation The F60 incorporates advanced automation features including powerful FlexLogic programmable logic, communication, and SCADA capabilities that far surpass what is found in the average feeder relay. The F60 integrates seamlessly with other UR relays for complete system protection, including the unit and auxiliary transformers, and balance of plant protection.

FlexLogic FlexLogic is the powerful UR-platform programming logic engine that provides the ability to create customized protection and control schemes, minimizing the need and associated costs of auxiliary components and wiring. Using FlexLogic, the F60 can be programmed to provide the required tripping logic along with custom scheme logic for auto transfer schemes (main-tie-main), load shedding based on frequency, voltage and communication, loop restoration schemes, other remedial action schemes and dynamic setting group changes.

The F60 includes high accuracy metering and recording for all AC signals. Voltage, current, and power metering are built into the relay as a standard feature. Current and voltage parameters are available as total RMS magnitude, and as fundamental frequency magnitude and angle. The F60 also measures up to the 25th harmonic on voltage and current, suitable for power quality applications.

Fault and Disturbance Recording The advanced disturbance and event recording features within the F60 can significantly reduce the time needed for postmortem analysis of power system events and creation of regulatory reports. Recording functions include: • Sequence of Event (SOE) - 1024 time stamped events • Oscillography - 64 digital & up to 40 analog channels - Events with up to 45s length • Data Logger and Disturbance Recording - 16 channels up to 1 sample/cycle/channel • Fault Reports - Powerful summary report of pre-fault and fault values • Extensive breaker info (continuous coil monitor, arcing current, operating time, operation counter for asset management) The very high sampling rates and large amount of storage space available for data recording in the F60 can eliminate the need for installing costly stand-alone recording equipment.

Advanced Device Health Diagnostics

The F60 is available with a multitude of I/O configurations to suit the most demanding application needs. The expandable modular design allows for easy configuration and future upgrades.

The F60 performs comprehensive device health diagnostic tests at startup and continuously during run-time to test its own major functions and critical hardware. These diagnostic tests monitor for conditions that could impact security and availability of protection, and present device status via SCADA communications and front panel display. Providing continuous monitoring and early detection of possible issues help improve system uptime.

• Flexible, modular I/O covering a broad range of input signals and tripping schemes

• Comprehensive device health diagnostic performed at startup

• Types of digital outputs include triprated Form-A and Solid State Relay (SSR) mechanically latching, and Form-C outputs

• Monitors the CT/VT input circuitry to validate the integrity of all signals

Scalable Hardware

• RTDs and DCmA inputs are available to monitor equipment parameters such as temperature and pressure

250

Monitoring and Metering

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F60 Feeder Protection System

Communications

CyberSentry UR enabled UR devices deliver full cyber security features that help customers to comply with NERC CIP and NIST® IR 7628 cyber security requirements.

The F60 provides advanced commun-ications technologies for remote data and engineering access, making it easy and flexible to use and integrate into new and existing infrastructures. Direct support for fiber optic Ethernet provides high-bandwidth communications allowing for low-latency controls and high-speed file transfers of relay fault and event record information. The available three independent Ethernet ports, redundant Ethernet option and the embedded managed Ethernet switch provide the means to create fault tolerant communication architectures in an easy, cost-effective manner without the need for intermediary communication hardware.

This software option delivers the following core features:

AAA Server Support (Radius/LDAP) Enables integration with centrally managed authentication and accounting of all user activities and uses modern industry best practices and standards that meet and exceed NERC CIP requirements for authentication and password management.

Role Based Access Control (RBAC) Efficiently administrate users and roles within UR devices. The new and advanced access functions allow users to configure up to five roles for up to eight configurable users with independent passwords. The standard “Remote Authentication Dial In User Service” (Radius) is used for authentication.

The F60 supports the most popular industry standard protocols enabling easy, direct integration into DCS and SCADA systems. • IEC 61850 Ed. 2 with 61850-9-2 and 61850-90-5 support • DNP 3.0 (serial & TCP/IP) • Ethernet Global Data (EGD) • IEC 60870-5-103 and IEC 60870-5-104

Event Recorder (Syslog for SEM)

• Modbus RTU, Modbus TCP/IP

Capture all cyber security related events within a SOE element (login, logout, invalid password attempts, remote/local access, user in session, settings change, FW update, etc), and then serve and classify data by security level using standard Syslog data format. This will enable integration with established SEM (Security Event Management) systems.

• HTTP, TFTP, SFTP and MMS file transfer • SNTP and IEEE 1588 for time synchronization • PRP as per IEC 62439-3

Interoperability with Embedded IEC 61850 Edition 2 The new IEC 61850 implementation in the UR Family positions GE as an industry leader in this standard.

Fiber LAN, single or redundant, for added security

Source

• Implements Edition 2 of the standard across the entire family of UR devices • Provides full relay setting management via standard SCL files (ICD, CID and IID) • Enables automated relay setting management using 3rd party tools through standard file transfer services (MMS and SFTP) • Increases the number of Logical Devices and data mapped to them, GOOSE messages, and reports to support different organizational needs for data transfer and reduce dependency on generic logical nodes • Configures GE Systems based on IEC 61850 using universal 3rd party tools • Multicast IEEE C37.118 synchrophasor data between PMU and PDC devices using IEC 91850-90-5

Direct I/O Messaging Direct I/O allows for the sharing of high-speed digital information between multiple UR relays via direct back-to-back connections or multiplexed through a standard DS0 multiplexer channel bank. Regardless of the connection method, direct I/O provides continuous real-time channel monitoring that supplies diagnostics information on channel health. Direct I/O provides superior relay-to-relay communications that can be used in advanced interlocking, generation rejection and other special protection schemes. • Communication with up to 16 UR relays in single or redundant rings rather than strictly limited to simplistic point-to-point configurations between two devices • Connect to standard DS0 channel banks through standard RS422, G.703 or IEEE C37.94 interfaces or via direct fiber optic connections • No external or handheld tester required to provide channel diagnostic information

LAN Redundancy

CB1

Fault 1 CB2

CB3

Fault 2

Reverse zone interlocking protection. By using the IEC 61850/GOOSE or hi-speed direct I/O capability blocking signals can be transferred upstream, allowing for minimal coordination delays. Fast clearance can be provided for Fault 1 while still maintaining coordination for Fault 2.

GEDigitalEnergy.com

Substation LAN redundancy has been traditionally accomplished by reconfiguring the active network topology in case of failure. Regardless of the type of LAN architecture (tree, mesh, etc), reconfiguring the active LAN requires time to switchover, during which the LAN is unavailable. UR devices deliver redundancy as specified by PRP-IEC 62439-3, which eliminates the dependency on LAN reconfiguration and the associated switchover time. The UR becomes a dual attached node that transmits data packets over both main and redundant networks simultaneously, so in case of failure, one of the data packets will reach the receiving device with no time delay.

251

Feeder Protection

Cyber Security – CyberSentry UR

F60 Feeder Protection System

Multi-Language UR devices support multiple languages: English, French, Russian, Chinese, Turkish and German. These language options are available on the front panel, in the EnerVista setup software, and in the product manuals. Easily switch between English and an additional language on the local displays without uploading new firmware.

Feeder Protection

EnerVista Software The EnerVista suite is an industry-leading set of software programs that simplifies every aspect of using the F60 relay. The EnerVista suite provides all the tools to monitor the status of the protected asset, maintain the relay, and integrate information measured by the F60 into DCS or SCADA monitoring systems. Convenient COMTRADE and SOE viewers are an integral part of the UR setup software included with every UR relay, to carry out postmortem event analysis and ensure proper protection of system operation.

Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed. Documents made available include: • Manuals

Viewpoint UR Engineer provides the following configuration and commissioning utilities: • Graphical Logic Designer • Graphical System Designer • Graphical Logic Monitor

• Application Notes

• Graphical System Monitor

• Guideform Specifications

Viewpoint Maintenance

• Brochures • Wiring Diagrams • FAQ’s • Service Bulletins

Viewpoint Monitoring Viewpoint Monitoring is a simple-to-use and full-featured monitoring and data recording software package for small systems. Viewpoint Monitoring provides a complete HMI package with the following functionality: • Plug-&-Play Device Monitoring

Viewpoint Maintenance provides tools that will create reports on the operating status of the relay, simplify the steps to download fault and event data, and reduce the work required for cyber security compliance audits. Tools available in Viewpoint Maintenance include: • Settings Security Audit Report • Device Health Report • Single-Click Fault Data Retrieval

EnerVista Integrator

EnerVista Launchpad

• Annunciator Alarm Screens

EnerVista Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining Multilin products. The setup software within Launchpad allows for the configuration of devices in real-time by communicating using serial, Ethernet , or modem connections, or offline by creating setting files to be sent to devices at a later time.

• Trending Reports

EnerVista Integrator is a toolkit that allows seamless integration of Multilin devices into new or existing automation systems. Included in EnerVista Integrator is:

• Automatic Event Retrieval

• OPC/DDE Server

• Automatic Waveform Retrieval

• Multilin Drivers

Viewpoint UR Engineer

• Automatic Event Retrieval

• System Single-Line Monitoring & Control

Viewpoint UR Engineer is a set of powerful tools that allows the configuration and testing of GE relays at a system level in an easy-touse graphical drag-and-drop environment .

• Automatic Waveform Retrieval

Power System Troubleshooting The F60 contains many tools and reports that simplify and reduce the amount of time required for troubleshooting power system events, increase uptime and reduce loss of production.

Record the operation of the internal F60 elements and external connected devices with 1ms time-stamped accuracy to identify the Sequence of Operation of station devices during faults and disturbances.

252

Analyze feeder faults and disturbances using both analog and digital power system quantities that are measured and recorded up to a rate of 64 samples per cycle.

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F60 Feeder Protection System

User Interface

48 Configurable LED Indicators

The F60 front panel provides extensive local HMI capabilities. The local display is used for monitoring, status messaging, fault diagnosis, and device configuration. User-configurable messages that combine text with live data can be displayed when user-defined conditions are met.

Multi-Language Display • English • Russian • French • Chinese • Turkish • German

User-Programmable Pushbuttons

Typical Wiring Feeder Protection

A B C 52

8L/8M

H7a H7c H8a H8c H7b

H1

V I

H2

H8b

V

SURGE H3

Digital Energy Multilin

H4

H5

F60

H6

W5a W5c W6a W6c W5b

6A V

I

W2

W7a W7c W8a W8c W7b

V

W3

W4

W8b

6C

SURGE P1

6D

U1a U1c U2a U2c U1b

P2

U3a U3c U4a U4c U3b

P3

P4

U5a U5c U6a U6c U5b

P5

P6

U7a U7c U8a U8c U7b U8b

P7

SURGE

P8

RS-232 (front)

6K

CRITICAL FAILURE

1

DB-9

B1b B1a B2b B3a B3b B5b HI B6b LO B6a B8a B8b

DC

W1a W1b W1c W2a W2b W2c W3a W3b W3c W4a W4b W4c P1a P1b P1c P2a P2b P2c P3a P3b P3c P4a P4b P4c P5a P5b P5c P6a P6b P6c P7a P7b P7c P8a P8b P8c

I

W1

M1a M1b M1c M2a M2b M2c M3a M3b M3c M4a M4b M4c M5a M5b M5c M6a M6b M6c M7a M7b M7c M8a M8b M8c

M1

OUTPUT

M2

CONTROL POWER

M3

SURGE FILTER M4

Fibre * Optic

Tx1

10BaseFL 10BaseFL

ALTERNATE

Rx2

Shielded

M5

NORMAL

Rx1 Tx2

COM 1

M6

10BaseT

Remote Device

D1a D2a D3a D4b D4a

M7

RS485 com

Co-axial

BNC

Co-axial

BNC

M8

IRIG-B Input IRIG-B Output

TC 1

TC 2

UR TXD RXD

SGND

1 2 3 4 5 6 7 8 9

CONNECTOR

COMPUTER

1 2 3 4 5 6 7 8 9

8 3 RXD 2 TXD 20 7 SGND 6 4 5 22

CONNECTOR

This diagram is based on the following order code: F60-HG4-HLH-F8L-H6B-M6KP6C-U6D-W6A This diagram provides an example of how the device is wired, not specifically how to wire the device. Please refer to the Instruction Manual for additional details on wiring based on various configurations.

832769A5.CDR

Minimum

X

PROVIDED

F 4c

H1a H1b H1c H2a H2b H2c H3a H3b H3c H4a H4b H4c H5a H5b H5c H6a H6b H6c

I

6B

IG1

IG

F 3c

F 4a

F 4b

IG5

IC1

F 2c

F 3a

F 3b

IB1

IC

IB

IC5

F 2a

F 2b

IB5

F 1a

F 1b

F 1c

IA

IA1

VX

IA5

F 7c

F 8a

F 8c

VC

VB

VC

VX

F 6a

F 6c

F 7a

VB

F 5a

F 5c VA

VC

VA

F 6c

F 7a

F 7c

VB

VA

VB

VC

F 5a

F 5c

F 6a

VA

CONNECTION

W

U

V

6 6 Inputs/ Inputs/ outputs outputs

*

*

T

S

R

P

N

M

6 6 Inputs/ Inputs/ outputs outputs

*

*

L

K

J

H

G

6

F 8

Inputs/ CT/VT outputs

GEDigitalEnergy.com

D

B

9

1

CPU

Power Supply

253

Ordering F60 - * ** - H * * - F ** - H ** - M ** - P ** - U ** - W ** For Full Sized Horizontal Mount Base Unit F60 Base Unit CPU E RS485 + RS485 (IEC 61850 option not available) J RS485 + multimode ST 100BaseFX K RS485 + multimode ST Redundant 100BaseFX N RS485 + 10/100 BaseT T RS485 + three multimode SFP LC 100BaseFX. Req FW v7xx or higher U RS485 + two multimode SFP LC 100BaseFX + one SFP RJ45 100BaseT. Req FW v7xx or higher V RS485 + three SFP RJ45 100BaseT. Req FW v7xx or higher Software Options 00 No Software Options (see note 1 below) 03 IEC 61850 06 PMU 07 IEC 61850 + PMU A0 CyberSentry Lvl 1. Req UR FW 7.xx or higher B0 IEEE 1588. Req UR FW 7.xx or higher C0 PRP D0 IEEE 1588 + CyberSentry. Req UR FW 7.xx or higher M0 IEC 61850 + PMU + 61850-90-5 Mount / Coating H Horizontal (19" rack) - Standard A Horizontal (19" rack) - Harsh Chemical Environment Option V Vertical (3/4 size) - Standard B Vertical (3/4 size) - Harsh Chemical Environment Option User Interface F Vertical Front Panel with English Display I Enhanced German Front Panel J Enhanced German Front Panel with User-Programmable Pushbuttons K Enhanced English Front Panel L Enhanced English Front Panel with User-Programmable Pushbuttons M Enhanced French Front Panel N Enhanced French Front Panel with User-Programmable Pushbuttons Q Enhanced Russian Front Panel T Enhanced Russian Front Panel with User-Programmable Pushbuttons U Enhanced Chinese Front Panel V Enhanced Chinese Front Panel with User-Programmable Pushbuttons W Enhanced Turkish Front Panel Y Enhanced Turkish Front Panel with User-Programmable Pushbuttons Power Supply H 125 / 250 V AC/DC (see note 2 below) H RH 125/250 V AC/DC with redundant 125/250 V AC/DC power supply L 24 - 48 V (DC only) CT/VT DSP 8F Standard 4CT/4VT 8G Sensitive Ground 4CT/4VT 8H Standard 8CT 8J Sensitive Ground 8CT 8L 8L Standard 4CT/4VT w/ enhanced diagnostics 8M 8M Sensitive Ground 4CT/4VT w/ enhanced diagnostics 8N 8N Standard 8CT w/ enhanced diagnostics 8R 8R Sensitive Ground 8CT w/ enhanced diagnostics 8Z HI-Z 4CT (high impedance fault detection) IEC 61850 Process Bus 81 8 Port IEC 61850 Process Bus Module Digital I/O XX XX XX XX XX No module 4A 4A 4A 4A 4A 4 Solid State (No Monitoring) MOSFET Outputs 4C 4C 4C 4C 4C 4 Solid State (Current w/opt Voltage) MOSFET Outputs 4D 4D 4D 4D 4D 16 Digital Inputs with Auto-Burnish 4L 4L 4L 4L 4L 14 Form-A (No Monitoring) Latchable Outputs 67 67 67 67 67 8 Form-A (No Monitoring) Outputs 6C 6C 6C 6C 6C 8 Form-C Outputs 6D 6D 6D 6D 6D 16 Digital Inputs 6E 6E 6E 6E 6E 4 Form-C Outputs, 8 Digital Inputs 6F 6F 6F 6F 6F 8 Fast Form-C Outputs 6K 6K 6K 6K 6K 4 Form-C & 4 Fast Form-C Outputs 6L 6L 6L 6L 6L 2 Form-A (Current w/ opt Voltage) & 2 Form-C Outputs, 8 Digital Inputs 6M 6M 6M 6M 6M 2 Form-A (Current w/ opt Voltage) & 4 Form-C Outputs, 4 Digital Inputs 6N 6N 6N 6N 6N 4 Form-A (Current w/ opt Voltage) Outputs, 8 Digital Inputs 6P 6P 6P 6P 6P 6 Form-A (Current w/ opt Voltage) Outputs, 4 Digital Inputs 6R 6R 6R 6R 6R 2 Form-A (No Monitoring) & 2 Form-C Outputs, 8 Digital Inputs 6S 6S 6S 6S 6S 2 Form-A (No Monitoring) & 4 Form-C Outputs, 4 Digital Inputs 6T 6T 6T 6T 6T 4 Form-A (No Monitoring) Outputs, 8 Digital Inputs 6U 6U 6U 6U 6U 6 Form-A (No Monitoring) Outputs, 4 Digital Inputs 6V 6V 6V 6V 6V 2 Form-A (Cur w/ opt Volt) 1 Form-C Output, 2 Latching Outputs, 8 Digital Inputs Transducer I/O 5C 5C 5C 5C 5C 8 RTD Inputs 5E 5E 5E 5E 5E 4 dcmA Inputs, 4 RTD Inputs 5F 5F 5F 5F 5F 8 dcmA Inputs Inter-Relay Communications 7A 820 nm, multimode, LED, 1 Channel 7B 1300 nm, multimode, LED, 1 Channel 7C 1300 nm, singlemode, ELED, 1 Channel 7H 820 nm, multimode, LED, 2 Channels 7I 1300 nm, multimode, LED, 2 Channels 7J 1300 nm, singlemode, ELED, 2 Channels 7S G.703, 2 Channels 7W RS422, 2 Channels 76 IEEE C37.94, 820 nm, multimode, LED, 1 Channel 77 IEEE C37.94, 820 nm, multimode, LED, 2 Channel

Ordering Note: 1 . To view all the options available for L90, please visit GE’s On-Line Store http://store.gedigitalenergy.com/viewprod.asp?model=F60 2. Redundant power supply only available in horizontal unit. If redundant is chosen, must be same type. Maximum 2 per chassis

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12595G(E) English 150122

Multilin™ F35 Cost-effective Protection & Control for Single/Multiple Distribution Feeders The Multilin F35 feeder protection system provides feeder protection, control, monitoring and metering in an integrated, economical, and compact package. As part of the Universal Relay (UR) Family, the F35 provides cost-effective solutions and features high-performance protection, expandable I/O options, integrated monitoring and metering, high-speed communications, and extensive programming and configuration capabilities. The F35 can be configured to protect up to six feeders or protect up to five feeders when bus voltage measurement is required. It also provides fast and deterministic execution of programmable logic, which is necessary for substation automation applications. Graphical programming tools (Viewpoint Engineer), supported by a library of logic components, make the F35 simple to use and configure.

Key Benefits • Flexible and cost-effective protection and control for multiple distribution feeders backed by many years of field experience • Advanced, high speed communications provide increased system stability at a reduced cost using control schemes • Reduced relay-to-relay wiring and associated installation costs through high-speed inter-relay communications • Advanced IEC 61850 Ed. 2 implementation, complete settings via SCL files and IEC 61850-9-2 process bus solution enable resource and platform managing optimization and reduce cost of ownership • Increased network availability via failover time reduced to zero through IEC® 62439-3 “PRP” support • CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog) • Advanced fault and disturbance recording, including internal relay operating signals, eliminating the need for external recording devices

Applications • Primary protection and control for multiple distribution feeders • Distribution load shedding schemes based on voltage and frequency elements • Busblocking/interlocking schemes • Throw over schemes (bus transfer scheme applications) • Backup protection for transmission lines, feeders and transformers • Distributed Generation (DG) interconnect protection, including active and passive anti-islanding

Protection & Control • Instantaneous and time phase overcurrent protection • Neutral & auxiliary overvoltage, phase & auxiliary undervoltage, under frequency • Wattmetric ground fault detection, breaker control, and breaker failure • Four-shot autorecloser for up to 6 brekaers and broken conductor elements

Communications • 3 independent Ethernet ports for simultaneous & dedicated network connections with IEEE 1588 support • Supported industry protocols: IEC 61850 Ed. 2, SFTP, MMS File Transfer Service, DNP 3.0, Modbus Serial/TCP, IEEE 1588, IEC 60870-5-104 and 103, PRP, SNTP, HTTP, TFTP • Direct I/O for secure, high-speed exchange of data between URs for DTT & pilot-aided schemes

Cyber Security • CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog) • Setting for security audit trails, tracking changes to device configurations

Monitoring & Metering • P&M class synchrophasors of voltage, current, and sequence components • Advanced recording capabilities with highcapacity event recorder, configurable and extended waveform capture and data logger • Metering: current, voltage, power, energy, frequency, and harmonics

F35 Feeder Protection System

Protection and Control

F35 - Protection, Metering, Monitoring and Control

As part of the Universal Relay (UR) Family, the F35 provides cost-effective solutions and features high-performance protection, expandable I/O options, integrated monitoring and metering, high-speed communications, and extensive programming and configuration capabilities including:

Feeder Protection

Overcurrent Protection The F35 has built-in standard IEEE, IEC, IAC and FlexCurves overcurrent characteristics (TOC), most commonly used for primary and backup protection in various protective zones. The F35 has thermal overload and phase IOC elements with level detectors for each phase. Each TOC element has the following programmable characteristics: • Pickup current level for trip, alarm, or control • Choice of 17 curve shapes (including FlexCurves) and curve multipliers

The F35 is the single point for protection, control, metering, and monitoring in one integrated device that can easily be connected directly into DCS or SCADA monitoring and control systems like Viewpoint Monitoring as shown.

Functional Block Diagram 2

52

Monitoring

50P

79(6)

51P 50_2 51_2 2

2

1

49

2

50N 2

51N 2

1

4

51G 2

27X

81U

27P 1

59N 6

3

59X 3

METERING 1 FlexElement

F35

5

For Breaker 1(50_2, 51_2 and 49 excluded) These functions are total, not on a per-breaker basis.

32N 50G

4

Same Functions as Breaker 1

TRIP

CLOSE

3

TM

Transducer Inputs

Multiple Feeder Protection System

ANSI® Device Numbers & Functions DEVICE FUNCTION NUMBER

DEVICE FUNCTION NUMBER

DEVICE FUNCTION NUMBER

27P 27X 32N 49 50G 50N

50P 50_2 51G 51N 51P 51_2

52 59N 59X 79(6) 81

256

Phase Undervoltage Auxiliary Undervoltage Wattmettric Zero-Sequence Directional Thermal Overload Ground Instantaneous Overcurrent Neutral Instantaneous Overcurrent

Phase Instantaneous Overcurrent Negative Sequence Instantaneous Overcurrent Ground Time Overcurrent Neutral Time Overcurrent Phase Time Overcurrent Negative Sequence Time Overcurrent

GEDigitalEnergy.com

AC Circuit Breaker Neutral Overvoltage Auxiliary Overvoltage Automatic Recloser Under Frequency

1

F35 Feeder Protection System

Auto-Transfer Scheme Solution

Under/Over Voltage Protection The F35 includes the following voltage elements: • Up to 6 phase undervoltage elements • Up to 3 auxiliary under/over voltage elements

CB1

CB2

• Up to 3 neutral overvoltage elements The following are some of the key applications where voltage elements can be used:

F35

• Source transfer schemes • Load shedding schemes TCB1 CB3

CB4

CB5

CB6

• Backup capacitor bank protection and control • Backup motor protection to prevent automatic restart

• Instantaneous or linear reset time characteristic to coordinate with upstream transformer damage curves and downstream reclosers and fuses

grounded systems. This can be especially important when using a residual CT connection to detect ground faults.

Wattmetric Ground Fault Protection

• Voltage restraint to increase sensitivity The majority of distribution systems are either solidly or low-impedance grounded. Fast fault clearance is required due to the ground fault impact. The following functions are incorporated in F35 to provide ground protection: • Neutral IOC and TOC • Ground IOC and TOC • Negative Sequence IOC and TOC

Sensitive Ground Input The F35 CT/VT modules may be ordered with a sensitive ground current input, which provides ground fault protection on high-impedance

A sensitive wattmetric zero-sequence directional function can be used on isolated or resonant (Petersen coil) grounded, low-resistance grounded and solidly grounded systems to detect ground faults. This function determines the presence and direction of ground faults by measuring the value and direction of zero-sequence power. This flexible element responds to power derived from zero-sequence voltage and current in a direction specified by the element characteristic angle. Power can be selected as active, reactive, or apparent. Therefore, the element may be used to sense either forward or reverse ground faults.

IEC 61850 Process Bus The IEC 61850 Process Bus module is designed to interface with the Multilin HardFiber System, allowing bi-directional IEC 61850 fiber optic communications. The HardFiber System is designed to integrate seamlessly with existing UR applications, including protection functions, FlexLogic™, metering and communications. The Multilin HardFiber System offers the following benefits: • Communicates using open standard IEC 61850 messaging

Fiber LAN, single or redundant, for added security

Source

Up to 6 programmable breaker autoreclosers for a variety of reclosing practices are provided. These elements are intended for use with distribution lines in tripping schemes for single breaker applications. Up to four selectable recloser “shots” are possible prior to locking out. Any of the six autoreclose elements can be dynamically blocked or unblocked by other F35 elements or user logic, providing coordination with other protection setting groups.

• Drastically reduces P&C design, installation and testing labor by eliminating individual copper terminations

CB1

• Integrates with existing F35’s by replacing traditional CT/VT inputs with the IEC 61850 Process Bus module

Fault 1 CB2

• Does not introduce new cyber security concerns CB3

Visit the HardFiber System product page on the GE Digital Energy web site for more details.

Fault 2

Reverse zone interlocking protection. By using the IEC 61850 GOOSE or high-speed direct I/O capability blocking signals can be transferred upstream, allowing for minimal coordination delays. Fast clearance can be provided for Fault 1 while still maintaining coordination for Fault 2.

GEDigitalEnergy.com

257

Feeder Protection

Autorecloser

Cost-effective single box auto-transfer scheme solution.

F35 Feeder Protection System

Advanced Automation The F35 incorporates advanced automation features including powerful FlexLogic programmable logic, communication, and SCADA capabilities that far surpass what is found in the average line relay. The F35 integrates seamlessly with other UR relays for complete system protection, including the unit and auxiliary transformers, and balance of plant protection.

Feeder Protection

FlexLogic FlexLogic is the powerful UR-platform programming logic engine that provides the ability to create customized protection and control schemes, minimizing the need and associated costs of auxiliary components and wiring. Using FlexLogic, the F35 can be programmed to provide the required tripping logic along with custom scheme logic for line phase comparison (including interlocking with external synchronizers), transfer tripping schemes for remote breakers and dynamic setting group changes.

Scalable Hardware The F35 is available with a multitude of I/O configurations to suit the most demanding application needs. The expandable modular design allows for easy configuration and future upgrades.

• Multiple CT/VT configurations allow for the implementation of many differential schemes, including concurrent split-phase and differential protection • Up to 80 digital inputs and up to 56 digital outputs are available • Types of digital outputs include triprated Form-A and Solid State Relay (SSR) mechanically latching, and Form-C outputs • Form-A and SSR outputs available with optional circuit continuity monitoring and current detection to verify proper operation of the connected primary equipment

Fault and Disturbance Recording The advanced disturbance and event recording features within the F35 can significantly reduce the time needed for postmortem analysis of power system events and the creation of regulatory reports. Recording functions include: • Sequence of Event (SOE) - 1024 time stamped events - Events up to 45s in length • Oscillography - 64 digital & up to 40 analog channels • Data Logger and Disturbance Recording - 16 channels up to 1 sample/cycle/channel

• Mechanically latching outputs can be used to develop secure interlocking applications and replace electromechanical lockout relays

• Fault Reports - Powerful summary report of pre-fault and fault values

• RTDs and DCmA inputs are available to monitor equipment parameters such as temperature and pressure

The very high sampling rates and large amount of storage space available for data recording in the F35 can eliminate the need for installing costly stand-alone recording equipment.

Monitoring and Metering The F35 includes high accuracy metering and recording for all AC signals. Voltage, current , and power metering are built into the relay as a standard feature. Current and voltage parameters are available as total RMS magnitude, and as fundamental frequency magnitude and angle.

Advanced Device Health Diagnostics The F35 performs comprehensive device health diagnostic tests at startup and continuously during run-time to test its own major functions and critical hardware. These diagnostic tests monitor for conditions that could impact security and availability of protection, and present device status via SCADA communications and front panel display. Providing continuous monitoring and early detection of possible issues help improve system uptime.

Power System Troubleshooting The F35 contains many tools and reports that simplify and reduce the amount of time required for troubleshooting power system events.

Record the operation of the internal F35 elements and external connected devices with 1ms time-stamped accuracy to identify the Sequence of Operation of station devices during feeder faults and disturbances.

258

Analyze feeder faults using both analog and digital power system quantities that are measured and recorded up to a rate of 64 samples per cycle.

GEDigitalEnergy.com

F35 Feeder Protection System

• Comprehensive device health diagnostic performed at startup • Monitors the CT/VT input circuitry to validate the integrity of all signals • Input, outputs, trip circuits and analog channels are continuously monitored for accuracy and performance

Cyber Security – CyberSentry UR CyberSentry UR enabled UR devices deliver full cyber security features that help customers to comply with NERC CIP and NIST® IR 7628 cyber security requirements.

fault tolerant communication architectures in an easy, cost-effective manner without the need for intermediary communication hardware. The F35 supports the most popular industry standard protocols enabling easy, direct integration into DCS and SCADA systems. • IEC 61850 Ed. 2 with 61850-9-2 support • DNP 3.0 (serial & TCP/IP) • Ethernet Global Data (EGD) • IEC 60870-5-103 and IEC 60870-5-104 • Modbus RTU, Modbus TCP/IP • HTTP, TFTP, SFTP and MMS file transfer • SNTP and IEEE 1588 for time synchronization

AAA Server Support (Radius/LDAP)

Interoperability with Embedded IEC 61850 Edition 2

Enables integration with centrally managed authentication and accounting of all user activities and uses modern industry best practices and standards that meet and exceed NERC CIP requirements for authentication and password management.

Role Based Access Control (RBAC) Efficiently administrate users and roles within UR devices. The new and advanced access functions allow users to configure up to five roles for up to eight configurable users with independent passwords. The standard “Remote Authentication Dial In User Service” (Radius) is used for authentication.

Event Recorder (Syslog for SEM) Capture all cyber security related events within a SOE element (login, logout, invalid password attempts, remote/local access, user in session, settings change, FW update, etc), and then serve and classify data by security level using standard Syslog data format. This will enable integration with established SEM (Security Event Management) systems.

Communications The F35 provides advanced commun-ications technologies for remote data and engineering access, making it the easiest and most flexible feeder protection relay to use and integrate into new and existing infrastructures. Direct support for fiber optic Ethernet provides high-bandwidth communications allowing for low-latency controls and high-speed file transfers of relay fault and event record information. The available three independent Ethernet ports, redundant Ethernet option and the embedded managed Ethernet switch provide the means to create

• PRP as per IEC 62439-3

The new IEC 61850 implementation in the UR Family positions GE as an industry leader in this standard. • Implements Edition 2 of the standard across the entire family of UR devices • Provides full relay setting management via standard SCL files (ICD, CID and IID) • Enable automated relay setting management using 3rd party tools through standard file transfer services (MMS and SFTP) • Increases the number of Logical Devices and data mapped to them, GOOSE messages, and Reports to support different organizational needs for data transfer and reduce dependency on generic logical nodes. • Configure GE Systems based on IEC 61850 using universal 3rd party tools

Direct I/O Messaging Direct I/O allows for the sharing of high-speed digital information between multiple UR relays via direct back-to-back connections or multiplexed through a standard DS0 multiplexer channel bank. Regardless of the connection method, direct I/O provides continuous real-time channel monitoring that supplies diagnostics information on channel health. Direct I/O provides superior relay-torelay communications that can be used in advanced interlocking, generation rejection and other special protection schemes. • Communication with up to 16 UR relays in single or redundant rings rather than simplistic point-to-point configurations • Connect to standard DS0 channel banks through standard RS422, G.703 or IEEE C37.94 interfaces or via direct fiber optic connections

GEDigitalEnergy.com

LAN Redundancy Substation LAN redundancy has been traditionally accomplished by reconfiguring the active network topology in case of failure. Regardless of the type of LAN architecture (tree, mesh, etc), reconfiguring the active LAN requires time to switchover, during which the LAN is unavailable. UR devices deliver redundancy as specified by PRP-IEC 62439-3, which eliminates the dependency on LAN reconfiguration and the associated switchover time. The UR becomes a dual attached node that transmits data packets over both main and redundant networks simultaneously, so in case of failure, one of the data packets will reach the receiving device with no time delay.

Multi-Language UR devices support multiple languages: English, French, Russian, Chinese, Turkish and German. These language options are available on the front panel, in the EnerVista setup software, and in the product manuals. Easily switch between English and an additional language on the local displays without uploading new firmware.

EnerVista Software The EnerVista suite is an industry-leading set of software programs that simplifies every aspect of using the F35 relay. The EnerVista suite provides all the tools to monitor the status of feeders, maintain the relay, and integrate information measured by the F35 into DCS or SCADA monitoring systems. Convenient COMTRADE and SOE viewers are an integral part of the UR setup software included with every UR relay, to carry out postmortem event analysis and ensure proper protection system operation.

EnerVista Launchpad EnerVista Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining Multilin products. The setup software within Launchpad allows for the configuration of devices in real-time by communicating using serial, Ethernet, or modem connections, or offline by creating setting files to be sent to devices at a later time. Included in Launchpad is a document archiving and management system that ensures critical documentation is up-todate and available when needed. Documents made available include:

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Feeder Protection

This software option delivers the following core features:

• Built-in continuous loop and channel monitoring provides real-time diagnostics of your communication channels with no external or handheld tester required

F35 Feeder Protection System

• Manuals

Viewpoint UR Engineer

EnerVista Integrator

• Application Notes

EnerVista Integrator is a toolkit that allows seamless integration of Multilin devices into new or existing automation systems. Included in EnerVista Integrator is:

• FAQ’s

Viewpoint UR Engineer is a set of powerful tools that will allows you to configure and test GE relays at a system level in an easy-touse graphical drag-and-drop environment . Viewpoint UR Engineer provides the following configuration and commissioning utilities:

• Service Bulletins

• Graphical Logic Designer

Viewpoint Monitoring

• Graphical System Designer

Viewpoint Monitoring is a simple-to-use and full-featured monitoring and data recording software package for small systems. Viewpoint Monitoring provides a complete HMI package with the following functionality:

• Graphical Logic Monitor

• Guideform Specifications • Brochures

Feeder Protection

• Wiring Diagrams

• Automatic Event Retrieval

• Settings Security Audit Report

• Automatic Waveform Retrieval

• Device Health Report

• Annunciator Alarm Screens

• Automatic Event Retrieval • Automatic Waveform Retrieval

Viewpoint Maintenance

• Trending Reports

• System Single-Line Monitoring & Control

• Multilin Drivers

• Graphical System Monitor

Viewpoint Maintenance provides tools that will create reports on the operating status of the relay, simplify the steps to download fault and event data, and reduce the work required for cyber security compliance audits. Tools available in Viewpoint Maintenance include:

• Plug-&-Play Device Monitoring

• OPC/DDE Server

• Single-Click Fault Data Retrieval

User Interface The F35 front panel provides extensive local HMI capabilities. The local display is used for monitoring, status messaging, fault diagnosis, and device configuration. User-configurable messages that combine text with live data can be displayed when user-defined conditions are met.

48 Configurable LED Indicators

Multi-Language Display • English • Russian • French • Chinese • Turkish • German

User-Programmable Pushbuttons

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F35 Feeder Protection System

Typical Wiring

1

IA5

F1b

IA

F1c

IA1

F2a

IB5

F2b

IB

F2c

IB1

F3a

2

P1

I

IC IC1

F4a

IG5

F4b

IG

F4c

IG1

F5a

IA5

F5b

IA

F5c

IA1

F6a

IB5

I

IB

F6c

IB1

F7a

IC5

F7b

IC

F7c

IC1

F8a

IG5

F8b

IG

F8c

IG1

V I

P4

V

P7a P7c P8a P8c P7b P8b

SURGE

Digital Energy Multilin

F35 H1a H1b H1c H2a H2b H2c H3a H3b H3c H4a H4b H4c H5a H5c H6a H6c H5b

I

H1

V I

H2

V I

H3

V

M1a IA5 M1b

I

H4

IA

V

M1c IA1 M2a IB5

3

M2b

IB

M2c IB1

IC

M3c IC1

V

6G

I

W2

IB

V I

W3

M7a IC5

V I

IC

W4

M7c IC1

V

M8a IG5 IG

M8c IG1 U1a

W7a W7c W8a W8c W7b

IA5

U1b

IA

U1c

IA1

U2a IB5

5

U2b

IB

U2c

IB1

W8b

SURGE

B1b B1a B2b B3a B3b B5b B6b B6a B8a B8b

CRITICAL FAILURE

U3a IC5 U3b

IC

U3c

IC1

U4a

IG5

U4b

IG

U4c

IG1

U5a

VA

U5c

VA

U6a

VB

U6c

VB

U7a

VC

U7c

VC

U8a

VX

U8c

VX

CONNECTOR

W1a W1b W1c W2a W2b W2c W3a W3b W3c W4a W4b W4c W5a W5c W6a W6c W5b

I

W1

M6c IB1

M8b

8 3 RXD 2 TXD 20 7 SGND 6 4 5 22

DB-9

M6a IB5

M7b

1 2 3 4 5 6 7 8 9

(front)

IA

M5c IA1

M6b

COMPUTER

RS-232

M5a IA5

4

1 2 3 4 5 6 7 8 9

CONNECTOR

IG

M4c IG1

M5b

SGND

H8b

SURGE

M4a IG5 M4b

UR TXD RXD

H7a H7c H8a H8c H7b

M3a IC5 M3b

TC 2

Feeder Protection

F6b

V

P3

IC5

F3b F3c

V

P2

TC 1

P1a P1b P1c P2a P2b P2c P3a P3b P3c P4a P4b P4c P5a P5c P6a P6c P5b

I

6G

F1a

6G

C

1

B

CONNECTION

A

OUTPUT CONTROL POWER

HI LO

SURGE FILTER

NORMAL COM 1

ALTERNATE

Tx1

DC

10BaseFL Rx2

10BaseT

com

IRIG-B Output

Shielded Remote Device

D1a D2a D3a D4b D4a

RS485

IRIG-B Input

Fibre * Optic

10BaseFL Rx1

Tx2

BNC

Co-axial

BNC

Co-axial

832767A5.CDR X

W 6

U5a

VA

U5c

VA

U6a

VB

U6c

VB

U7a

VC

U7c

VC

U

V 8

Inputs/ CT/VT outputs

T

S

R

P

N

M

L

K

J

H

G

F

D

Minimum

B

6

8

6

8

9

1

Inputs/ outputs

CT

Inputs/ outputs

CT

CPU

Power Supply PROVIDED

F35-H00-HCH-F8H-H6G-M8H-P6G-U8F-W6G

GEDigitalEnergy.com

261

Ordering

F35 - * ** - H * * - F ** - H ** - M ** - P ** - U ** - W *

Base Unit F35 CPU E J K N T U

V Software Options 00 (see note 1 below) 03 A0 B0 C0 D0 Mount / Coating H A V B User Interface F I J K L M N Q T U V W Y Power Supply H (see note 2 below) H RH L CT/VT DSP 8F 8F 8F 8G 8G 8G 8H 8H 8H 8J 8J 8J 8L 8L 8L 8M 8M 8M 8N 8N 8N 8R 8R 8R IEC 61850 Process Bus 81 Digital I/O XX XX XX XX XX 4A 4A 4A 4A 4A 4C 4C 4C 4C 4C 4D 4D 4D 4D 4D 4L 4L 4L 4L 4L 67 67 67 67 67 6C 6C 6C 6C 6C 6D 6D 6D 6D 6D 6E 6E 6E 6E 6E 6F 6F 6F 6F 6F 6K 6K 6K 6K 6K 6L 6L 6L 6L 6L 6M 6M 6M 6M 6M 6N 6N 6N 6N 6N 6P 6P 6P 6P 6P 6R 6R 6R 6R 6R 6S 6S 6S 6S 6S 6T 6T 6T 6T 6T 6U 6U 6U 6U 6U 6V 6V 6V 6V 6V Transducer I/O 5A 5A 5A 5A 5A 5C 5C 5C 5C 5C 5D 5D 5D 5D 5D 5E 5E 5E 5E 5E 5F 5F 5F 5F 5F Inter-Relay Communications 7A 7B 7C 7H 7I 7J 7S 7T 7W 76 77

For Full Sized Horizontal Mount

Base Unit RS485 + RS485 (IEC 61850 option not available) RS485 + multimode ST 100BaseFX RS485 + multimode ST Redundant 100BaseFX RS485 + 10/100 BaseT RS485 + three multimode SFP LC 100BaseFX. Req FW v7xx or higher RS485 + two multimode SFP LC 100BaseFX + one SFP RJ45 100BaseT. Req FW v7xx or higher RS485 + three SFP RJ45 100BaseT. Req FW v7xx or higher No Software Options IEC 61850 CyberSentry UR Lvl 1. Req UR FW 7.xx or higher IEEE 1588. Req UR FW 7.xx or higher PRP IEEE 1588 + CyberSentry UR. Req UR FW 7.xx or higher Horizontal (19" rack) - Standard Horizontal (19" rack) - Harsh Chemical Environment Option Vertical (3/4 size) - Standard Vertical (3/4 size) - Harsh Chemical Environment Option Vertical Front Panel with English Display Enhanced German Front Panel Enhanced German Front Panel with User-Programmable Pushbuttons Enhanced English Front Panel Enhanced English Front Panel with User-Programmable Pushbuttons Enhanced French Front Panel Enhanced French Front Panel with User-Programmable Pushbuttons Enhanced Russian Front Panel Enhanced Russian Front Panel with User-Programmable Pushbuttons Enhanced Chinese Front Panel Enhanced Chinese Front Panel with User-Programmable Pushbuttons Enhanced Turkish Front Panel Enhanced Turkish Front Panel with User-Programmable Pushbuttons 125 / 250 V AC/DC 125/250 V AC/DC with redundant 125/250 V AC/DC power supply 24 - 48 V (DC only) Standard 4CT/4VT Sensitive Ground 4CT/4VT Standard 8CT Sensitive Ground 8CT Standard 4CT/4VT w/ enhanced diagnostics Sensitive Ground 4CT/4VT w/ enhanced diagnostics Standard 8CT w/ enhanced diagnostics Sensitive Ground 8CT w/ enhanced diagnostics 8 Port IEC 61850 Process Bus Module No Module 4 Solid State (No Monitoring) MOSFET Outputs 4 Solid State (Current w/opt Voltage) MOSFET Outputs 16 Digital Inputs with Auto-Burnish 14 Form-A (No Monitoring) Latchable Outputs 8 Form-A (No Monitoring) Outputs 8 Form-C Outputs 16 Digital Inputs 4 Form-C Outputs, 8 Digital Inputs 8 Fast Form-C Outputs 4 Form-C & 4 Fast Form-C Outputs 2 Form-A (Current w/ opt Voltage) & 2 Form-C Outputs, 8 Digital Inputs 2 Form-A (Current w/ opt Voltage) & 4 Form-C Outputs, 4 Digital Inputs 4 Form-A (Current w/ opt Voltage) Outputs, 8 Digital Inputs 6 Form-A (Current w/ opt Voltage) Outputs, 4 Digital Inputs 2 Form-A (No Monitoring) & 2 Form-C Outputs, 8 Digital Inputs 2 Form-A (No Monitoring) & 4 Form-C Outputs, 4 Digital Inputs 4 Form-A (No Monitoring) Outputs, 8 Digital Inputs 6 Form-A (No Monitoring) Outputs, 4 Digital Inputs 2 Form-A (Cur w/ opt Volt) 1 Form-C Output, 2 Latching Outputs, 8 Digital Inputs 4 dcmA Inputs, 4 dcmA Outputs 8 RTD Inputs 4 RTD Inputs, 4 dcmA Outputs 4 dcmA Inputs, 4 RTD Inputs 8 dcmA Inputs 820 nm, multimode, LED, 1 Channel 1300 nm, multimode, LED, 1 Channel 1300 nm, singlemode, ELED, 1 Channel 820 nm, multimode, LED, 2 Channels 1300 nm, multimode, LED, 2 Channels 1300 nm, singlemode, ELED, 2 Channels G.703, 2 Channels RS422, 1 Channel RS422, 2 Channels IEEE C37.94, 820 nm, multimode, LED, 1 Channel IEEE C37.94, 820 nm, multimode, LED, 2 Channel

Ordering Note: 1. To view all the options available for F35, please visit GE’s On-Line Store at http://store.gedigitalenergy.com/viewprod.asp?model=F35 2. Redundant power supply only available in horizontal unit. If redundant is chosen, must be same type. Maximum 2 per chassis

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12666G(E) English 150121

10 YEAR WORLDWIDE

Multilin 850 ™

Innovative Feeder Protection System for Industrial and Utility Feeder Applications The Multilin 850 relay is a member of the Multilin 8 Series protective relay platform and has been designed for the management, protection and control of feeder applications. The Multilin 850 is used to provide primary(main) or backup protection for underground and overhead feeders for utility and industrial power networks. Designed with advanced communications options and detailed asset monitoring capabilities, the Multilin 850 provides advanced functionality, including high-performance protection, extensive programmable logic and flexible configuration capabilities. The advanced communications of the 8 Series platform allows an easy integration into SCADA or electrical control systems for smoother asset monitoring and control.

Key Benefits • Comprehensive feeder protection • Advanced breaker diagnostics with high-end fault and disturbance recording • High-end cyber security such as AAA, Radius, RBAC, and Syslog helps enable NERC® CIP requirements • Draw-out design simplifies testing, commissioning and maintenance, thereby increasing process uptime • Wi-Fi connectivity minimizes system configuration and provides safe relay programming and diagnostic retrieval

WARRANTY

Innovative Technology & Design • Advanced feeder protection, control and diagnostics capability • Patented environmental monitoring and diagnostics • Advanced, flexible and embedded communications: IEC® 61850, IEC 62439/ PRP, Modbus® RTU & TCP/IP, DNP3.0, IEC 60870-5-104 • Single setup and configuration across the platform • Elimination of electrolytic capacitors • Field swappable power supply • Enhanced relay draw-out construction

Exceptional Quality & Reliability • IPC A-610-E Class 3 manufacturing standards

• Relay environmental diagnostic information helps reduce system downtime

• Highest reliability standards for electronics testing

Applications

• 100% Environmental Stress Screening and full functional testing

• Wide range of feeder applications for utility, oil & gas, mining & metals, process industry, commercial, and water wastewater • Comprehensive protection and management of incoming and outgoing feeders • Fast protection pass enables use for load shedding schemes • Advanced communications and flexlogic for reliable automatic bus transfer schemes • High speed fault detection for arc flash mitigation

• Rated for IP54 (front) applications • Standard Harsh Conformal Coating

Uncompromising Service & Support • Covered under GE’s 10 year warranty plan • Designed, tested and manufactured by GE

850 Feeder Protection System

Multilin 8 Series Platform Overview From oil pumping and refining facilities, to open pit or underground mining and processing operations, to large or small utilities, customers demand solutions that ensure maximum process uptime, minimum operational and maintenance efforts, and have the durability to withstand harsh environmental conditions.

The Multilin 8 Series is GE’s next-generation protection and control relay platform provides comprehensive protection and asset monitoring for critical feeders, motors, generators, and transformers.

Feeder Protection

Multilin 8 Series Platform - Application Example

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GEDigitalEnergy.com

850 Feeder Protection System

The Multilin 8 Series is designed to solve the challenges that customers face in running their day-to-day operations including maximizing system and process uptime, simplifying system integration and maintenance, and extending the life of critical assets. Utilizing advanced design practices (IPC A-610 standards), superior technology (elimination of all electrolytic capacitors), and state-of-the art test and manufacturing facilities (every device endures 100% Environmental Stress Screening), GE is raising the bar on system performance and reliability.

With advanced communications the Multilin 8 Series integrates easily and seamlessly into new or existing DCS/SCADA system, along with other Multilin protection devices, providing a comprehensive solution for the end-to-end electrical system within the operations.

Feeder Protection

GEDigitalEnergy.com

265

850 Feeder Protection System

Exceptional Quality & Reliability

The Multilin 8 Series products have an integrated protection integrity engine that utilizes customized algorithms, providing advanced diagnostics to ensure asset protection is not compromised.

Industry-leading quality, reliability and design processes are at the core of GE’s next generation protective relay platform. With significant investments in state-of-the-art type test facilities that simulate a complete range of operating environments and designed to the IPC A-610 Class 3 standard, adhering to the highest reliability standards and ensuring rugged performance, each device completes one hundred percent Electrical Stress Screening prior to shipping from GE’s facility.

Maintaining and safeguarding the electrical supply of an operation is critical to ensuring maximum process availability and performance. The 8 Series incorporates the latest cyber security features, including password complexity, RADIUS authentication, role-based access control (RBAC), customers to comply with NERC CIP and NISTIR 7628 requirements.

The Multilin 8 Series Protection Relays are manufactured in an ISO® 9001:2008 certified manufacturing facility.

Understanding that customers need protection and control devices that must reliably operate in extremely harsh and challenging environments, GE delivers the Multilin 850 with harsh conformal coating on all printed circuit boards and a patented environmental awareness module that provides realtime detection of environmental factors that affect product life, as part of its standard offering, delivering higher reliability and extended relay life.

Feeder Protection

Pioneering Technology & Design The Multilin 850 is part of the 8 Series platform that provides comprehensive, high performance protection and control for critical assets in Industrial and utility environment.

Uncompromised Service and Support

For main-tie-main configurations, the Multilin 850 delivers a more economical and reliable solution, enabling customers to reduce hardware requirements and simplify device integration, including safe and secure Wi-Fi communications for system configuration and diagnostics.

Designed, manufactured and tested to the highest standards in the industry at our state-of-the-art facilities, the Multilin 8 Series delivers maximum performance for today’s most demanding environments. In addition to the superior technology and innovative design advancements that enable delivery of uncompromised performance and reliability, the Multilin 8 Series is also backed by GE’s 10 year warranty plan.

Utilizing decades of experience, GE has implemented ease-of-use features, such as single screen set-ups delivering faster feeder configuration, configurable scheme logic that eliminates the need for complex end-user programming, driving quicker setup times, decreased implementation costs and reduced points of failure.

3

1

Field Swappable Power Supply

2

Harsh Environment Conformal Coating

3

No Electrolytic Capacitors

266

Extends the usable life of the protection relay and minimizes costly, time consuming replacement and re-configuration.

Standard on all printed circuit boards delivering higher reliability and extended relay life

Increasing quality and reliability for continuous plant operations by removing high failure components

4

5

4

IPC A-610 Class 3 Manufacturing

5

Robust Extruded Aluminum Chassis

6

Draw-Out

GEDigitalEnergy.com

Drives to the highest level of reliability standards delivering rugged performance

Custom-designed extruded aluminum chassis delivering optimal operating performance

Providing simplified device fleet management

850 Feeder Protection System

Multilin 850 Overview

Advanced Automation

The Multilin 850 feeder Protection System is a protection device designed for the management, protection and control of incoming and outgoing feeders. The 850 provides comprehensive protection and control for these various feeders.

The Multilin 850 incorporates advanced automation capabilities that exceeds what is found in most motor protection relay. This reduces the need for additional programmable controllers or discrete control relays including programmable logic, communication, and SCADA devices. Advanced Automation also facilitates the Multilin 850 to integrate seamlessly with other protection/process systems.

The 850 relay offers the ideal solution for protecting, monitoring and controlling feeders from disturbances or faults. With a fast protection pass, running every 2 msec, the 850 relay provides faster response to current, voltage, power, and frequency protection elements. Supporting the latest in industry standard communication protocols, including IEC 62439/PRP and IEC 61850, the Multilin 850 relay easily integrates into new or existing networks.

Protection & Control As part of the 8 Series family, the Multilin 850 provides superior protection and control. The 850 offers comprehensive protection and control solutions for incoming, outgoing bus-tie/bus-coupler feeders. It contains a full range of selectively enabled, self contained protection and control elements. • Phase/Neutral/Ground Time Overcurrent (51P/N/G)

FlexLogic is the powerful programming logic engine that provides the ability to create customized protection and control schemes, minimizing the need and associated costs of auxiliary components and wiring. Using FlexLogic, the 850 can be programmed to provide the required tripping logic along with custom scheme logic for feeder control interlocking schemes with adjacent protections (for example, preventing sympathetic tripping of healthy feeders), and dynamic setting group changes.

Monitoring & Diagnostics The Multilin 850 includes high accuracy metering and recording for all AC signals. Voltage, current, and power metering are built into the relay as a standard feature. Current and voltage parameters are available as total RMS magnitude, and as fundamental frequency magnitude and angle.

Breaker Health Monitoring The breaker is monitored by the relay not only for detection of breaker failure, but also for the overall “breaker health” which includes: • Breaker close and breaker open times

• Phase/Neutral/Ground Instantaneous Overcurrent (50P/N/G)

• Trip circuit monitoring

• Phase Directional Overcurrent (67P)

• Spring charging time

• Voltage and Frequency Protection

• Per-phase arcing current

• Synchrocheck (25)

• Trip counters

• Autoreclose (79) • AR Current Supervision And AR Zone Coordination The voltage and frequency protection functions detect abnormal system conditions, potentially hazardous to the system. Some of these conditions may consist of over and undervoltage, over and underfrequency, and phase reversal.

All algorithms provide the user with the flexibility to set up initial breaker trip counter conditions and define the criteria for breaker wear throughout a number of set points.

FlexCurves™ For applications that require greater flexibility, FlexCurves can be used to define custom curve shapes. These curves can be used to coordinate with other feeders to achieve fault selectivity.

Multilin 8 Series Breaker Health Report available on display or via the setup software

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Feeder Protection

The 850 is an advanced feeder protection relay that provides high performance protection, extensive programmable logic and flexible configuration capabilities. With protection and control logic, the 850 allows for simplified coordination with upstream and downstream disconnect devices. This advanced protection relay also offers enhanced features, such as diagnostics, preventative maintenance, condition monitoring, security, and advanced communications options.

FlexLogic™

Feeder Protection

850 Feeder Protection System

Environmental Monitoring

Metering

The 850 implements a patented environmental monitoring system that measures and provides operating condition information. Reliable and secure operation of the 850 relay and other electronic devices in the vicinity may be affected by environmental factors. The 850 relay has been designed to meet or exceed all required industry standards, however some operating conditions may be beyond those standards and reduce total lifespan of the device.

The Multilin 850 offers high accuracy power quality monitoring for fault and system disturbance analysis. The Multilin 8 Series delivers unmatched power system analytics through the following advanced features and monitoring and recording tools:

Typical environmental conditions that may affect electronic device reliability include voltage, current density, temperature, humidity, gas, dust, contamination, mechanical stress, shock, radiation, and intensity of electrical and magnetic fields. These environmental factors are different from natural weather conditions at particular installation conditions and are beneficial to monitor. The 850 relay’s built-in environmental awareness feature (patent “Systems and methods for predicting maintenance of intelligent electronic devices”) collects the histograms of each operating condition from the point the device is put into service. Monitored environmental conditions include temperature, humidity and transient voltage. The histogram of each environmental factor may be retrieved from the diagnostic page accessed through a PC running the EnerVista Multilin 8 Series Setup program.

• Harmonics measurement up to 25th harmonic for both currents and voltages including THD. • The length of the transient recorder record ranges from 31 cycles to 1549 cycles, depending on the user specified configuration. - - This gives the user ability to capture long disturbance records which is critical for some applications.

Multilin 850 Phasor viewer • 32 digital points and 16 analog values, assigned by the user, can be captured in the COMTRADE format by the transient recorder. • Comprehensive data logger provides the recording of 16 analog values selected from any analog values calculated by the relay. Capture rates range from 16 ms, 20ms, 1 second, 30 seconds, 1 minute, 30 minutes, or 1 hour rate. This data capture flexibility allows the operator to measure power factor or reactive power flow (for example), for several hours or even days, enabling detailed analysis and corrective action to be taken, if required. • Detailed Fault Report allows the user to identify the fault location, fault type and element(s) that triggered the 850 to trip. It carries other useful information, such as pre-fault and fault phasors, relay name and model, firmware revision and other details. The 850 stores fault reports for the last 16 events. 1024 Event Recorder chronologically lists all triggered elements with an accurate time stamp over a long period of time. The 850 stores the last 1024 events locally in the relay.

Environmental health report is available via Multilin PC Software

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Feeder Protection

Multilin 850 Event Recorder

The 850 monitoring system performance with harmonic analysis

The 850 monitoring system performance with oscillography and event records

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Communications

Cyber Security

The 850 provides advanced communications technologies for remote data and engineering access, making it easy and flexible to use and integrate into new and existing infrastructures. Direct support for fiber optic Ethernet provides high-bandwidth communications, allowing for low-latency controls and high-speed file transfers of relay fault and event record information. The 850 also supports two independent IP addresses, providing high flexibility for the most challenging of communication networks.

The 850 cyber security enables the device to deliver full cyber security features that help operators to comply with NERC CIP guidelines and regulations.

Providing several Ethernet and serial port options and supporting a wide range of industry standard protocols, the 850 enables easy, direct integration into DCS and SCADA systems. The 850 supports the following protocols: • IEC 61850, IEC 62439 / PRP

Feeder Protection

• DNP 3.0 serial, DNP 3.0 TCP/IP,, IEC 60870-5-103, IEC 60870-5-104 • Modbus RTU, Modbus TCP/IP The 850 has two interfaces as USB front port and Wi-Fi for ease of access to the relay. Wi-Fi Connectivity: • Simplify set-up and configuration • Simplify diagnostic retrieval

AAA Server Support (Radius/LDAP) Enables integration with centrally managed authentication and accounting of all user activities and uses modern industry best practices and standards that meet and exceed NERC CIP requirements for authentication and password management.

Role Based Access Control (RBAC) Efficiently administrate users and roles within UR devices. The new and advanced access functions allow users to configure up to five roles for up to eight configurable users with independent passwords. The standard “Remote Authentication Dial In User Service” (Radius) is used for authentication.

Event Recorder (Syslog for SEM) Capture all cyber security related events within a SOE element (login, logout, invalid password attempts, remote/local access, user in session, settings change, FW update, etc), and then serve and classify data by security level using standard Syslog data format. This will enable integration with established SEM (Security Event Management) systems. Security Server

• Eliminate personnel in front of switchgear • WPA-2 security Access Request: Local HMI / Single Line

SCADA

EMS

D400

DMS

Role, User, Password Encrypted (SSH)

LOCAL AREA NETWORK

A

350

B

850

Cyber Security with Radius Authentication

000 ML3 ITCH SW

000 ML3 ITCH SW

469

Role, User, Password Encrypted (SSH)

Authentication Request:

0 00C H ML3 SWIT

LOCAL AREA NETWORK

000 ML3 ITCH SW

Authentication Request:

D400

000 ML3 ITCH SW

F650

Role, User, Password

Data Historian

869

889

000 ML3 ITCH SW

845

UR

Software & Configuration The EnerVista™ suite is an industry-leading set of software programs that simplifies every aspect of using the Multilin 850. EnerVista provides all the tools to monitor the status of the protected asset, maintain the device and integrate the information measured by the Multilin 8 Series, into SCADA or DCS process control systems. The ability to easily view sequence of events is an integral part of the setup software, as postmortem event analysis is critical to proper system management.

EnerVista Launchpad EnerVista Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining Multilin products. The setup tools within Launchpad allow for the configuration of devices in real-time, by communicating via serial,

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Ethernet or modem connections, or offline by creating device setting files to be sent to devices at a later time. Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed.

8 Series Setup Software 8 Series Setup Software is single setup and configuration across the platform and can reduce device setup and configuration time.

Application Challenge: Intelligent Load Shedding Challenge:

Solution: Being able to dynamically balance and maintain loads in this type of separation scenario requires an intelligent device that has advanced communications, automation and control logic capabilities. The Multilin 850 provides distribution networks and industrial facilities with the system stability functionality and cost saving options, required to maintain power system availability and process continuity. With advanced protection features including underfrequency, overfrequency, frequency rate of change, sensitive reverse power, underfrequency restoration and other elements plus superior communications enabling sharing data with other IEDs, distribution utilities and industrial facilities rely on Multilin’s 850 to deliver reliability, efficiency and security to the power system.

1

Easy to Use - Draw-out case

2

Challenge: Utilities and industrial facilities depend on reliable and secure electricity services to keep their operations running. Regardless of the type of source, a fully integrated protection & control scheme is critical to maintaining uninterrupted power to the entire facility.

Solution: The Multilin 8 Series offers the ideal solution for protecting, monitoring and controlling electrical cables and overhead lines from disturbances or faults. With a fast protection pass, running every 2 msec, the 8 Series provides unmatched overcurrent, overvoltage, undervoltage, and frequency protection. Supporting the latest in industry standard communication protocols, including IEC 62439/PRP and IEC 61850, the Multilin 8 Series easily integrates into new or existing networks.

Simplified Setup and On-Going Maintenance The robust 850 streamlines user workflow processes and simplifies engineering tasks, such as configuration, wiring, testing, commissioning, and maintenance. Building on the history of simplified setup and configuration, the 850 Feeder Protection Relay has implemented simplified setup screens to minimize relay setup time. In addition, for local programming, the 850 comes with a fully functional GCP, which allows users to locally monitor the asset.

Ease-of-Use Continuing its legacy in providing easy-to-use protective relay solutions, the 850 is designed to minimize product and system configurability requirements, for quicker physical installations, easier and simplified setup and configuration.

Easy to Configure - 1 simple step

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Detailed Diagnostics

271

Feeder Protection

In a multiple power source network, it may happen that some power sources are lost utility circuit creating deficit of the power even with a presence of in-facility generator. In these partially islanding situations the deficit of active power may result in a sudden drop of system frequency resulting in power system instability, bringing the processes and operations to a halt.

Application Challenge: Modern Feeder Protection

850 Feeder Protection System

Full Color Graphical HMI Front Display

G = Green: General Condition

A large, full color Graphic Control Panel (GCP) ensures clear representation of critical status and measurements. When the keypad and display are not being used, the GCP will automatically revert to screen saver mode, which will turn off the display until one of the local pushbuttons is pushed.

A = Amber: Alert Condition

The GCP can be used to view device and system status, alarms and event logs, and metering information. The GCP and navigation keys simplify relay configuration and setup, allowing users to make setting changes directly through the front panel.

LED Indicators for Quick Status Indication

The 850 front panel provides 14 LED indicators and 3 LED pushbutton indicators. 10 LED’s are user- programmable, while “In service” and “Pickup” LED’s are non-programmable. “Trip” and “Alarm” LED’s are not color programmable but can be assigned with selected operands. User-programmable LED’s can be turned on by a selection of FlexLogic operands representing protection, control or monitoring elements. Each LED can be configured to be self-reset or latched and labeled based on the application and user requirements. User-programmable LED’s can be selected to be either Red, Green or Orange to give the distinctive indication of selected operations.

Feeder Protection

The front panel includes user configurable LED’s. Each LED can be completely configured and named based on the application and user requirements. The color of each indicator conveys its importance.

R = Red: Serious Alarm or Important Status

Single Click Device Communications Quick Link Diagnostic Information

Online Device Configuration and Monitoring Menu Driven Device Configuration

Offline Device Setting File Configuration

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Front View

Menu path display indicating location within menu structure Graphic Control Panel (GCP) Soft navigation menu Soft menu navigation keys

Navigation keys

User-programmable pushbuttons

Front USB port

Feeder Protection

LED status indicators

Self-captive screw on draw-out handle

Rear View

Grounding screw

Standard serial and RJ45 Ethernet module

Power supply Analog I/O

Advanced communications module (fiber optic port)

Digital I/O CT, VT inputs

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Technical Application Example 1: Industrial Auto Transfer Schemes Challenge Bus or source transfer solutions are often necessary for industrial facilities to ensure power reliability and process continuity. Being able to rapidly transfer sources was often accomplished through a complex combination of discrete and auxiliary relays, timers, and/or programmable logic controllers, all wired together. The usage of these independent devices required a precise sequencing of interlocks, timing, and functions to ensure no momentary loss of power could potentially damage critical equipment or loads. In addition, the large number of physical I/O required made these schemes expensive to design and implement and difficult to test.

FIBER/COPPER CB2

CB1 850

850

850

Feeder Protection

Solution The Multilin 850 offers seamless automated bus transfer scheme solutions, maximizing system availability and process uptime. Using a minimal amount of programming, the 850 eliminates the need for any discrete devices and device inter-wiring by integrating all the functions directly into the intelligent device. With advanced communications including embedded support for IEC 61850 peer-to-peer communications, inter-relay wiring and physical I/O can be eliminated. The 850 provides a reliable, automatic bus transfer solution that is easy to design, configure, and maintain.

TCB1 CB3

CB5

CB4

CB6

Technical Application Example 2: Zone Selective Interlocking Challenge A Fault in an industrial or utility system is a catastrophic event that causes severe damage to equipment and often results in extended system and process downtime. These events require a solution that can quickly and reliably detect and issue a coordinated trip command to clear the fault as fast as possible, reducing total incident energy, equipment damage and system downtime.

Source

Solution

Fault 1

With embedded support for IEC 61850, the 850 provides high-speed data exchange between relays for fast reaction to system issues. As a coordinated system, interlocked protection can be enabled, to provide the necessary bus protection. Fast clearance can be achieved for a fault that occurs at any feeder or bus location by quickly exchanging signals to discriminate the fault location.

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Fiber LAN, single or redundant, for added security

CB1

CB2

CB3 Fault 2

850 Feeder Protection System

Technical Application Example 3: Intelligent Auto-Reclose Challenge A majority of faults that occur on overhead lines are transient in nature, meaning that the fault does not recur when the line is re-energized after tripping. However, in the event the fault is present after the 1st reclose attempt, there is a good possibility that next reclose attempts will be successful and power supply to the customer will be restored. Therefore, in order to maintain system availability and security, utility operators need an intelligent auto-reclose solution that allows them to automatically attempt to re-energize a line multiple times, depending on the system conditions and user requirements. Today’s environment requires integrated solutions into digital relays. In modern feeder topology, substation relay auto-reclose functions should maintain coordination with downstream reclosures installed along the feeder.

For customers wanting a reliable and customized auto-reclose scheme, a device with integrated logic capabilities is necessary. The 850 offers comprehensive protection and auto-reclose functions integrated in one box. Up to four auto-reclose operations are possible, each with a programmable dead time. For each reclose shot, the relay can be programmed to block IOC elements, and to adjust the curve characteristics of any TOC element. The number of shots can be reduced by high currents. Maximum rate per hour

reclose shots would prevent breaker drive and insulation overstressing. 850 relay can be programmed to change protection setting every time the downstream reclosure operates and also maintain same reclosure count as downstream reclosure.

Technical Application Example 4: Adaptive Protection Challenge:

850 Feeder Relay

To effectively manage an electrical system, operators need the ability and flexibility to change power output on a seasonally or even hourly basis due to scheduled maintenance, seasonal load changes and transfers, scheduled switching, transformer inrush or motor starting currents. These changes could have an adverse effect on the reliability of the system and connected loads and requires a protection device that can adapt to ensure secure and dependable protection. One such application where dynamic setting group change ability is ideal, is with a parallel feeder application where two lines are in service and carry a portion of the required load. If there is an unplanned outage with one of the feeder lines, such that all loads are now supplied by one feeder, key protection settings would need to be adjusted to ensure proper coordination with downstream devices and deliver secure reliable service.

S 52

52

52

52

52

Solution: The Multilin 850 offers effective, reliable management of feeders. With dynamic, sensitive settings, the 850 provides secure and dependable protection. With six setting groups the 850 provides the sensitive settings range and groups required to ensure no compromise is made to meet changing system conditions. These setting groups can be enabled automatically or manually to address system needs, ensuring greater system reliability and efficiency.

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Solution

850 Feeder Protection System

Functional Block Diagram BUS

27P V_2

59_2

2

2

V_0

59N

59P

VTFF

81U 4

81O

81R

2

3 CTs 50BF

2 50G/ 50G 51G

51G

Feeder Protection

CT

67P

50P

51P

CLP

51_2

2

50_2 67_2

32

49

32N

50N

51N

2

2

67N 2

RGF

67G

50G/ 67SG 51SG 50SG 51G

BREAKER

METERING TRANSIENT RECORDER EVENT RECORDER FAULT REPORT

52 79 TRIP

CLOSE

MONITORING 25 27X

850 Feeder Protection System

59X 2

892770A1.CDR

LOAD

ANSI Device

Description

25

Synchrocheck

27P (2)

Phase Undervoltage

32 (2)

Directional Power

32N

Wattmetric Ground Fault (Wattmetric zero sequence directional)

27X (2)

Auxiliary Undervoltage

49

Cable Thermal Model

50BF

Breaker Failure

50G

Ground Ground Instantaneous Overcurrent

50SG

Sensitive Ground Instantaneous Overcurrent

50N (2)

Neutral Instantaneous Overcurrent

50P (2)

Phase Instantaneous Overcurrent

50_2

Negative Sequence Instantaneous Overcurrent

51G

Ground Time Overcurrent

51SG

Sensitive Ground Time Overcurrent

51N (2)

Neutral Time Overcurrent

51P (2)

Phase Time Overcurrent

51_2

Negative Sequence Time Overcurrent

52

AC Circuit Breaker

59N

Neutral Overvoltage

59P (2)

Phase Overvoltage

59X

Auxiliary Overvoltage

59_2

Negative Sequence Overvoltage

67G

Ground Directional Element

67SG

Sensitive Ground Directional Element

67N

Neutral Directional Element

67P

Phase Directional Element

67_2

Negative Sequence Directional Element

79

Automatic Recloser

81O

Overfrequency

81U (4)

Underfrequency

81R

Frequency Rate of Change

87G

Restricted Ground Fault

I2/I1

Broken Conductor

VTFF

Voltage Transformer Fuse Failure

Dimensions & Mounting 7.15”

9.90”

8.84”

5”

7.5 5”

8.42”

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Typical Wiring

L O A D

52 WYE VT CONNECTION

SEE VT WIRING IN INSTRUCTION MANUAL

CONTROL POWER

SEE GROUND INPUT WIRING IN INSTRUCTION MANUAL

N

GROUND

VOLTAGE INPUTS

CURRENT INPUTS

CTs and VTs are part of the chassis DIGITAL INPUT 1 DIGITAL INPUT 2 DIGITAL INPUT 3

F17

DIGITAL INPUT 4 DIGITAL INPUT 5

F18

DIGITAL INPUT 6

F19

DIGITAL INPUT 7

F20

COMMON

F21

+24 V

V

F1 F2 F3

V

F4 F5 F6

TRIP

CLOSE OUTPUT RELAYS

F15 F16

GND STUD

SLOTS J&K

DIGITAL INPUTS

F13 F14

PWR SUPPLY

AUXILIARY

CRITICAL FAILURE RELAY

DIGITAL INPUT 3

G17

DIGITAL INPUT 4 DIGITAL INPUT 5

G18

DIGITAL INPUT 6

G19 G20

DIGITAL INPUT 7

G21

+24 V

OUTPUT RELAYS

DIGITAL INPUT 2

COMMON

MANUAL

F9

DIGITAL INPUT 1

DIGITAL INPUTS

G15 G16

CLOSE COIL

SEE TRIP AND CLOSE COIL

MONITORING CLOSE CIRCUIT IN INSTRUCTION

F7 F8

F11 F12

SLOT F: I/O_A

52b

TRIP COIL

GROUND BUS

F10 AUXILIARY

G13 G14

52a

TRIP CIRCUIT

F22 F23 F24

AUXILIARY

G1 G2 G3

AUXILIARY

G4 G5 G6

AUXILIARY

OUTPUT CONTACTS SHOWN WITH NO CONTROL POWER

G7 G8 G9 G10

AUXILIARY

G11 G12

AUXILIARY

PERSONAL COMPUTER

SLOT G: I/O_A (OPTIONAL)

ETHERNET

G22 G23 G24

850 Feeder Protection System

[BACK PANEL ETHERNET PORT RJ45 OR ST]

USB [FRONT PANEL LOCAL PROGRAMMING PORT]

Rear Panel ETHERNET RJ45

ETHERNET

FIBER1

FIBER2

ST

ST

SLOT D: COMMUNICATIONS

Front Panel

PERSONAL COMPUTER

USB TYPE B

COMMUNICATIONS RESERVED

CAN

OPEN DELTA VT CONNECTION

RS485 COM

IRIG-B

WIFI

D1 D2 D3 D4 D5 D6 D7 D8 D9 D10

ACCESS POINT

J9 J10 J11 J12 J13 J14

892771A4.cdr

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PHASE A PHASE B PHASE C

A1 A2 A3 GROUND

VA VA VB VB VC VC VX VX

IB

LINE

J9 J10 J11 J12 J13 J14 J15 J16

IC N IG N Isg N

IA N

NEUTRAL

J1 J2 J3 J4 J5 J6 J7 J8 K7 K8

SLOT A

BUS

850 Feeder Protection System

Technical Specifications POWER SUPPLY

PROTECTION

Power Supply

Phase/Neutral/Ground Time Overcurrent (51)

Timer Accuracy

Nominal DC Voltage

125 to 250 V

Current

Phasor or RMS

Minimum DC Voltage

88 V

Pickup Level

Maximum DC Voltage

300 V

0.050 to 30.000 x CT in steps of 0.001 x CT

Dropout Level

97 to 98% of Pickup

Level Accuracy

For 0.01 to 0.2 x CT: ±0.5% of reading or ±0.4% of rated, whichever is greater; For > 0.2 x CT: ±1.5% of reading

Nominal AC Voltage

100 to 240 V at 50/60 Hz

Minimum AC Voltage

88 V at 50/60 Hz

Maximum AC Voltage

265 V at 50 to 60 Hz

Voltage loss ride through

20 ms duration

Curve Shape

IEEE Extremely/Very/Moderately Inverse ANSI Extremely/Very/ Normally/Moderately Inverse IEC Curve A/B/C and Short Inverse IAC Extremely/Very/Inverse/Short Inverse FlexCurve™ A, FlexCurve™ B, FlexCurve™ C, FlexCurve™ D I2t, I4t, Definite Time

Power Consumption Typical

10 to 15 W/VA

Maximum

18 W/ 56VA

INPUTS

Feeder Protection

AC Currents

Curve Multiplier:

0.05 to 600.00 in steps of 0.01

CT Rated Primary:

1 to 12000 A

Reset Time

Instantaneous, Timed

CT Rated Secondary

1 A or 5 A based on relay ordering

Nominal Frequency

50 and 60 Hz

Curve Timing Accuracy:

Currents > 1.1 x pickup: ± 3% of operate time or ± ½ cycle (whichever is greater) from pickup to operate

AC Voltage VT Range

10 to 260 V

Nominal Frequency

20 to 65 Hz

Burden

<0.25 VA at 120 V

Conversion Range.

1 to 275 V

Voltage Withstand

Continuous at 260 V to neutral 1 min/hr at 420 V to neutral

OUTPUTS

Form-A Relays Configuration

2 (two) electromechanical

Contact material

silver-alloy

Operate time

<8 ms

Continuous current

10 A

Make and carry for 0.2s

30 A per ANSI C37.90

Break (DC inductive, L/R=40 ms

24 V / 1 A 48 V / 0.5 A 125 V / 0.3 A 250 V / 0.2 A

Break (DC resistive)

24 V / 10 A 48 V / 6 A 125 V / 0.5 A 250 V / 0.3 A

Break (AC inductive)

720 VA @ 250 VAC Pilot duty A300

Break (AC resistive)

277 VAC / 10 A

Form-A Voltage Monitor Applicable voltage

20 to 300 VDC

Trickle current

1 to 2.5 mA

Form-C Relays Configuration

electromechanical

Contact material

silver-alloy

Operate time

<8 ms

Continuous current

10 A

Make and carry for 0.2s

30 A per ANSI C37.90

Break (DC inductive, L/R=40 ms)

24 V / 1 A 48 V / 0.5 A 125 V / 0.3 A 250 V / 0.2 A

Break (DC resistive)

24 V / 10 A 48 V / 6 A 125 V / 0.5 A 250 V / 0.3 A

Break (AC inductive)

720 VA @ 250 VAC Pilot duty A300

Break (AC resistive)

277 VAC / 10 A

CONTACT INPUTS Number of Inputs:

Based on relay ordering

Type

Wet or Dry

Wet Contacts

300 V DC maximum

Selectable thresholds

17, 33, 84, 166 VDC

Tolerance

±10%

Recognition time

1ms (typical)

Debounce time

0.0 to 16.0 ms in steps of 0.5 ms

Continuous current draw

2 mA

278

Phase/Neutral/Ground Instantaneous Overcurrent (50P/N/G)

±3% of delay setting or ± ¼ cycle (whichever is greater) frompickup to operate

Sensitive Ground Instantaneous Overcurrent (50SG) Pickup Level

(Gnd IOC): 0.005 to 3.000 x CT in steps of 0.001 x CT

Dropout Level

97 to 98% of Pickup

Level Accuracy

For 0.1 to 2.0 x CT: ±0.5% of reading or ±0.4% of rated, whichever is greate For > 2.0 x CT: ±1.5% of reading

Operate Time

<12 ms typical at 3 × Pickup at 60 Hz <15 ms typical at 3 × Pickup at 50 Hz

Timer Accuracy

±3% of delay setting or ± ¼ cycle (whichever is greater) from pickup to operate

Sensitive Ground Time Overcurrent Overcurrent (51SG) Pickup Level

0.005 to 3.000 x CT in steps of 0.001 x CT

Dropout Level:

97 to 98% of Pickup

Level Accuracy

For 0.1 to 2.0 x CT: ±0.5% of reading or ±0.4% of rated, whichever is greater For > 2.0 x CT: ±1.5% of reading

Curve Shape

IEEE Extremely/Very/Moderately Inverse,

Current (for Phase IOC only)

Phasor or RMS

Current (for Neutral/ Ground IOC only

Fundamental Phasor Magnitude

Pickup Level

0.050 to 30.000 x CT in steps of 0.001 x CT

Dropout Level

97 to 98% of Pickup

Level Accuracy

For 0.01 to 0.2 x CT: ±0.5% of reading or ±0.4% of rated, whichever is greater For > 0.2 x CT: ±1.5% of reading

IEC Curve A/B/C and Short Inverse,

<12 ms typical at >3 × Pickup at 60 Hz (Phase/Ground IOC) <16 ms typical at >3 × Pickup at 60 Hz (Neutral IOC) <15 ms typical at >3 × Pickup at 50 Hz (Phase/Ground IOC) <20 ms at >3 × Pickup at 50 Hz (Neutral IOC)

FlexCurve™ A, FlexCurve™ B, FlexCurve™ C, FlexCurve™ D,

Operate Time

Timer Accuracy

±3% of delay setting or ± ¼ cycle (whichever is greater) from pickup to operate

Negative Sequence Instantaneous Overcurrent (50_2) Current

I_2 Fundamental Phasor Magnitude

Pickup Level

0.050 to 30.000 x CT in steps of 0.001 x CT

Dropout Level

97 to 98% of Pickup

Level Accuracy

For 0.1 to 2.0 x CT: ±0.5% of reading or ±0.4% of rated, whichever is greater For > 0.2 x CT: ±1.5% of reading

Curve Multiplier

0.05 to 600.00 in steps of 0.01

Reset Time

Instantaneous, Timed

Curve Timing Accuracy

Currents > 1.1 x pickup: ± 3% of curve delay or ± ½ cycle (whichever is greater) from pickup to operate

Negative Sequence Time Overcurrent (51_2) Current

I_2 Fundamental Phasor Magnitude

Pickup Level

0.050 to 30.000 x CT in steps of 0.001 x CT

Dropout Level

97 to 98% of Pickup

Level Accuracy

For 0.1 to 2.0 x CT: ±0.5% of reading or ±0.4% of rated, whichever is greater For > 0.2 x CT: ±1.5% of reading

Overreach

< 2%

Operate Time

< 12 ms typical at 3 x Pickup at 60 Hz < 15 ms typical at 3 x Pickup at 50 Hz

GEDigitalEnergy.com

ANSI Extremely/Very/Normally/ Moderately Inverse,

IAC Extreme/Very/Inverse/Short Inverse,

I2t, I4t, Definite Time Curve Multiplier

0.05 to 600.00 in steps of 0.01

Reset Time

Instantaneous, Timed

Curve Timing Accuracy

Currents > 1.1 x pickup: ± 3% of curve delay or ± 1/2 cycle (whichever is greater) from pickup to operate

Phase Directional Overcurrent (67P) Relay Connection:

90º (Quadrature)

Quadrature Voltage:

ABC phase seq.: phase A (Vbc), phase B (Vca), phase C (Vab); ACB phase seq.: phase A (Vcb), phase B (Vac), phase C (Vba)

Polarizing Voltage Threshold:

0.000 to 3.000 x VT in steps of 0.001 x VT

Current Sensitivity Threshold:

0.05 x CT

Characteristic Angle:

0º to 359º in steps of 1°

Angle Accuracy:

± 2º

Operation Time (FlexLogic™ Operands):

Reverse to Forward transition: < 12 ms, typically; Forward to Reverse transition: <8 ms, typically

Negative sequence directional overcurrent (67_2) Directionality

Co-existing forward and reverse

Polarizing

Voltage

Polarizing Voltage:

V_2

Operating Current:

I_2

Level Sensing

Negative-sequence: |I_2| – K x |I_1|

Restraint, K

0.000 to 0.500 in steps of 0.001

Characteristic Angle

0º to 90º in steps of 1°

Limit Angle

40º to 90º in steps of 1°, independent for forward and reverse

Angle Accuracy

± 2º

Pickup Level

0.050 to 30.000 x CT in steps of 0.001 x CT

850 Feeder Protection System

Dropout Level

97 to 98% of Pickup

Pickup Level

Operate Time

< 12 ms typical at 3 x Pickup at 60 Hz

0.00 to 1.50 x VT in steps of 0.01 x VT

Dropout Level

102 to 103% of pickup

Level Accuracy

±0.5% of reading from 15 to 208 V Undervoltage Curves Definite Time or GE IAV Inverse Time

Pickup Time Delay

0.000 to 6000.000 s in steps of 0.001s

Operate Time

< 20 ms at 0.90 x pickup at 60 Hz < 25 ms at 0.90 x pickup at 50 Hz

Curve Timing Accuracy

at < 0.90 x pickup: ± 3.5% of curve delay or ± ½ cycle (whichever is greater) from pickup to operate

< 15 ms typical at 3 x Pickup at 50 Hz

Ground Directional Overcurrent (67G)

Overfrequency (81O) Pickup Level:

20.00 to 65.00 Hz in steps of 0.01

Dropout Level:

Pickup - 0.03 Hz

Pickup Time Delay:

0.000 to 6000.000 s in steps of 0.001 s

Dropout Time Delay:

0.000 to 6000.000 s in steps of 0.001 s

Minimum Operating Voltage:

0.000 to 1.250 x VT in steps of 0.001 x VT

Level Accuracy:

± 0.001 Hz

Timer Accuracy:

± 3% of delay setting or ± ¼ cycle (whichever is greater) from pickup to operate

Operate Time:

typically 7.5 cycles at 0.1 Hz/s change typically 7 cycles at 0.3 Hz/s change typically 6.5 cycles at 0.5 Hz/s change

Co-existing forward and reverse

Polarizing

Voltage, Current, Dual

Polarizing Voltage

V_0 or VX

Polarizing Current:

Isg

Operating Current:

Ig

Level Sensing:

Ig, Isg

Phase Overvoltage (59P)

Characteristic Angle:

-90º to 90º in steps of 1°

Voltage:

Fundamental Phasor Magnitude

Limit Angle

40º to 90º in steps of 1°, independent for forward and reverse

Pickup level:

0.02 to 3.00 x VT in steps of 0.01 x VT

Angle Accuracy

± 2º

Dropout level:

97 to 98% of Pickup

Pickup Level

0.050 to 30.000 x CT in steps of 0.001

Level accuracy:

±0.5% of reading from 10 to 208 V

Underfrequency (81U)

Phases for operation:

Any one, Any two, All three

Pickup level:

20.00 to 65.00 Hz in steps of 0.01

Pickup time delay:

0.000 to 6000.00 s in steps of 0.001 s (definite time)

Dropout level:

Pickup + 0.03 Hz

Pickup time delay:

0.000 to 6000.000 s in steps of 0.001 s

Dropout time delay:

0.000 to 6000.000 s in steps of 0.001 s

Minimum operating voltage:

0.000 to 1.250 x VT in steps of 0.001 x VT

Minimum operating current:

0.000 to 30.000 x CT in steps of 0.001 x CT

Negative Sequence Overvoltage (59_2)

Level accuracy:

±0.001 Hz

Pickup Level

0.00 to 3.00 x VT in steps of 0.01 x VT

Timer accuracy:

± 3% of delay setting or ± ¼ cycle (whichever is greater) from pickup to operate

Operate time:

typically 7.5 cycles at 0.1 Hz/s change typically 7 cycles at 0.3 Hz/s change typically 6.5 cycles at 0.5 Hz/s change

Dropout Level

97 to 98%

Operate Time (no direction transition):

< 12 ms, typically at 3 x Pickup at 60Hz < 15 ms, typically at 3 x Pickup at 50Hz

Dropout time delay:

0.000 to 6000.00 s in steps of 0.001 s (definite time)

Operate time:

< 25 ms at 1.1 x pickup at 60Hz < 30 ms at 1.1 x pickup at 50Hz

Timer accuracy:

± 3% of delay setting or ± ¼ cycle (whichever is greater) from pickup to operate

Sensitive Ground Directional Overcurrent (67SG) Directionality:

Co-existing forward and reverse

Polarizing:

Voltage, Current, Dual

Polarizing Voltage:

V_0 or VX

Polarizing Current:

Ig

Operating Current:

Isg

Level Sensing:

Ig, Isg

Dropout Level

97 to 98% of Pickup

Characteristic Angle:

-90º to 90º in steps of 1°

Level Accuracy

± 0.5% of reading from 15 to 208 V

Limit Angle:

40º to 90º in steps of 1°, independent for forward and reverse

Pickup Time Delay

0.000 to 6000.000 s in steps of 0.001 s

Angle Accuracy:

± 2º

Dropout Time Delay

0.000 to 6000.000 s in steps of 0.001 s

Pickup Level:

0.005 to 3.000 x CT in steps of 0.001 x CT

Operate Time

< 25 ms at 1.1 x pickup at 60 Hz < 30 ms at 1.1 x pickup at 50 Hz

Dropout Level:

97 to 98%

Timer Accuracy

Operate Time (no direction transition):

< 12 ms typical at 3 × Pickup at 60 Hz < 15 ms typical at 3 × Pickup at 50 Hz

± 3% of delay setting or ± ¼ cycle (whichever is greater from pickup to operate

Neutral Overvoltage (59N)

Feeder Protection

Directionality

Frequency Rate Of Change (81R) df/dt trend:

Increasing, Decreasing, Bi-directional

df/dt pickup level:

0.10 to 15.00 Hz/s in steps of 0.01

df/dt dropout level:

96% of Pickup Level

df/dt level accuracy:

80 mHz/s or 3.5%, whichever is greater

Pickup Level

0.02 to 3.00 x VT in steps of 0.01 x VT

Min frequency:

20.00 to 80.00 Hz in steps of 0.01 Hz

Dropout Level

97 to 98% of Pickup

Max frequency:

20.00 to 80.00 Hz in steps of 0.01 Hz

Level Accuracy

±0.5% of reading from 10 to 208 V

Min voltage threshold:

0.000 to 1.250 x VT in steps of 0.001 x VT

Cold Load Pick up

Outage Time Before Cold

Load and Time Before Reset:

0.000 to 6000.000 s in steps of 0.001 s

PIckup and Dropout Level:

0.050 x CT fixed

Level Accuracy:

± 0.5%

Curves Definite time

Flex Curve A,B,C,D

Min current threshold:

0.000 to 30.000 x CT in steps of 0.001 x CT

Timer Accuracy:

± 3% of delay setting or ± ¼ cycle (whichever is greater) from pickup to operate

Pickup Time Delay

0.000 to 6000.000 s in steps of 0.001s (Definite Time)

Pickup time delay:

0.000 to 6000.000 s in steps of 0.001 s

Dropout Time Delay

0.000 to 6000.000 s in steps of 0.001s (Definite Time)

Timer accuracy:

Operate Time

< 25 ms at 1.1 x pickup at 60Hz < 30 ms at 1.1 x pickup at 50Hz

± 3% of delay setting or ± ¼ cycle (whichever is greater) from pickup to operate

at > 1.1 x Pickup ± 3% of curve delay or ± 1 cycle (whichever is greater) from pickup to operate

95% settling time for df/dt:

< 24 cycles

Curve Timing Accuracy

Operate time:

typically 6.5 cycles at 2 × pickup

Neutral Overvoltage

Phase Undervoltage (27P) Voltage:

Fundamental Phasor Magnitude

Minimum Voltage:

0.00 to 1.50 x VT in steps of 0.01 x VT

Pickup Level:

0.00 to 1.50 x VT in steps of 0.01 x VT

Dropout Level:

102 to 103% of pickup

Level Accuracy:

±0.5% of reading from 15 to 208 V

Phases Required for Operation:

Any one, Any two, All three

Undervoltage Curves

Auxiliary Overvoltage (59X)

typically 5.5 cycles at 3 × pickup typically 4.5 cycles at 5 × pickup

Directional Power (32)

Pickup Level

0.00 to 3.00 x VT in steps of 0.01 x VT

Measured Power:

3-phase

Dropout Level

97 to 98% of Pickup

Definite Time or Inverse Time

Number of Stages:

2

Level Accuracy

±0.5% of reading from 10 to 208 V

Pickup Time Delay

0.000 to 6000.000 s in steps of 0.001s

Characteristic Angle:

0º to 359º in steps of 1°

Pickup Time Delay

0.000 to 6000.000 s in steps of 0.001s

Calibration Angle:

0.00º to 0.95º in steps of 0.05°

Operate Time

< 20 ms at 0.90 x pickup at 60 Hz < 25 ms at 0.90 x pickup at 50 Hz

Dropout Time Delay

0.000 to 6000.000 s in steps of 0.001s

Power Pickup Range:

Curve Timing Accuracy

at < 0.90 x pickup: ± 3.5% of curve delay or ± ½ cycle (whichever is greater) from pickup to operate

–1.200 to 1.200 in units of (Rated Power) in steps of 0.001 (Rated Power)

Operate Time

< 25 ms at 1.1 x pickup at 60Hz < 30 ms at 1.1 x pickup at 50Hz

Pickup Level Accuracy:

± 1% or ± 0.001 (Rated Power), whichever is greater

Timer Accuracy

± 3% of operate time or ± ¼ cycle (whichever is greater) from pickup to operate

Hysteresis:

2% or 0.001 (Rated Power), whichever is greater

Auxiliary Undervoltage (27x) Minimum Voltage

0.00 to 1.50 x VT in steps of 0.01 x VT

GEDigitalEnergy.com

279

850 Feeder Protection System

Pickup Time Delay:

0.000 to 6000.000 s in steps of 0.001 s

Operate Time:

< 55 ms at 1.1 x pickup at 60 Hz < 65 ms at 1.1 x pickup at 50 Hz

Timer Accuracy:

± 3% of delay setting or ± ¼ cycle (whichever is greater) from pickup to operate

AR Current Supervision And AR Zone Coordination Operating Parameter:

Ia, Ib, Ic, In (Fundamental Phasor Magnitude)

PIckup Level:

0.050 to 30.000 x CT in steps of 0.001 x CT

Dropout Level:

97 to 98% of Pickup

Level Accuracy:

For 0.1 to 2.0 x CT: ± 0.5% of reading or ± 0.4% of rated, whichever is greater For > 2.0 x CT: ± 1.5% of reading

Demand Measured values:

Feeder Protection

Measurement type:

Phase A/B/C present and maximum current, three-phase present and maximum real/reactive/apparent power Thermal Exponential, 90% response time (programmed): 5, 10, 15, 20, 30, or 60 min Block Interval / Rolling Demand, time interval (programmed): 5, 10, 15, 20, 30, or 60 min

Timer Accuracy:

Trip Bus

Voltages

± 3% of delay time or ± ¼ cycle (whichever is greater)from pickup to operate

Parameters:

Wye VTs: A-n, B-n, C-n, A-B, B-C, C-A, Average Phase, Neutral and Residual Delta VTs: A-B, B-C, C-A, Neutral and Residual

Accuracy:

± 0.5% of reading from 10 to 208 V

Currents

Level accuracy:

±2%

Parameters:

Phase A, B, C, Neutral and Ground

Magnitude Accuracy:

± 0.5% of reading or ± 2.0% of rated (whichever is greater) from 0.1 to 2.0 x CT ± 0.4% of reading > 2.0 x CT

0.01 Lead to 1 to 0.01 Lag in steps of 0.01

Dropout Level:

0.01 Lead to 1 to 0.01 Lag in steps of 0.01

Angle Accuracy:

Delay:

0.000 to 6000.000 s in steps of 0.001 s

Parameters:

Minimum operating Voltage:

0.00 to 1.25 x VT in steps of 0.01 x VT

Level accuracy:

±0.02

Timer accuracy:

± 3% of delay setting or ± 1¼ cycle (whichever is greater) from pickup to operate

None, LB & DL, DB & LL, DB & DL, DB OR DL, DB XOR DL

Dead/Live Levels for Bus and Line:

0.00 to 1.5 x VT in steps of 0.01 x VT

Autoreclose (79) Number of Breakers:

Single breaker application

Number of Poles:

3-pole tripping/autoreclose schemes

Reclose attempts:

Up to 4 before lockout

Blocking:

Each reclose shot can block IOC, raise TOC Pickup or change the setting group

Adjustability:

Timer Accuracy:

280

Current supervision can adjust the maximum number of shots attempted ± 3% of delay setting or ± ¼ cycle (whichever is greater) from pickup to operate

Phase A, B, C, Neutral, Ground and Sensitive Ground

Accuracy:

± 0.2% of reading or ± 0.2% of rated (whichever is greater) from 0.1 to 2.0 x CT ± 0.25% of reading > 2.0 x CT

Wye VTs: A-n, B-n, C-n, A-B, B-C, C-A, Average Phase, Neutral and Residual; Delta VTs: A-B, B-C, C-A, Neutral and Residual

Magnitude Accuracy:

± 5% of reading from 15 to 208 V

Angle Accuracy:

0.5° (10 V
Magnitude Accuracy:

± 0.5% of reading or ± 0.2% of rated (whichever is greater) from 0.1 to 2.0 x CT ± 4.0% of reading > 2.0 x CT

Angle Accuracy:

Real Power (Watts) Range:

-214748364.7 kW to 214748364.7 kW

Parameters:

3-phase; per phase if VT is Wye

Accuracy:

± 1.0% of reading or 0.1 kW (whichever is greater) at -0.8 < PF ≤ -1.0 and 0.8 < PF < 1.0

2°

Voltages

CONTROL

Dead Source Function:

Parameters:

MONITORING AND METERING

Switch-In Level:

0.000 to 6000.00 s in steps of 0.001 s

Currents

< 2 ms at 60 Hz

96-98% of Pickup level

0.01 to 0.10 Hz in steps of 0.01 Hz

RMS Parameters

Timer Accuracy

Apparent power pickup level:

Breaker Closing Time:

reset, up/down, set to pre-set, freeze/reset, freeze/count

Operate Time

Phasors

Difference:

Programmability

0.000 to 6000.000 s in steps of 0.001 s

0.1 to 300000.0 kVA in steps of 0.1 kVA

10 to 600000 V in steps of 1 V

preset, compare

Dropout Time Delay

Apparent power pickup level:

Hysteresis for Maximum Frequency Difference

16

Counting

0.000 to 6000.000 s in steps of 0.001 s

0.1 to 300000.0 kVar in steps of 0.1 kVar

1° to 100° in steps of 1°

Number of Counters

Pickup Time Delay

Reactive power pickup level:

Maximum Angle Difference:

to one microsecond

Digital Counters

16

0.1 to 300000.0 kW in steps of 0.1 kW

0.01 to 5.00 Hz in steps of 0.01 Hz for frequency window of fnom ± 5 Hz

non-volatile memory

Time-tag Accuracy:

Number of Inputs

Real power pickup level:

Maximum Frequency Difference:

Data Storage:

6

10 to 10000 A in steps of 1 A

Synchrocheck (25)

any element pickup, any element operate, digital input change of state, digital output change of state, self-test events

Number of Elements

Current pickup level:

Power Factor (55)

± 3% of delay setting or ± ¼ cycle, (whichever is greater) from pickup to operate

Content:

0.5° (at 50/60 Hz, 15 V
Current And Voltage Harmonics Parameters:

Magnitude of each harmonic and THD

Range:

2nd to 25th harmonic: per-phase displayed as % of f1 fundamental frequency

Accuracy:

0.2% + (1.8e-5*(f/60)^2.7 of reading)%, where f is the harmonic frequency

Transient Recorder Default AC Channels:

5 currents + 4 voltages

Configurable Channels:

16 analog and 32 digital channels

Sampling rate:

128 /c, 64/c, 32/c, 16/c, 8/c

Trigger Souce:.

Any element pickup, dropout or operate, digital input or output change of state, FlexLogic operand

Trigger Position:

0 to 100%

Storage Capability:

non-volatile memory

Event Recorder Number of events

1024

Header:

relay name, order code, firmware revision

GEDigitalEnergy.com

Reactive Power (Vars) Range:

-214748364.7 kVar to 214748364.7 kVar

Parameters:.

3-phase; per phase if VT is Wye

Accuracy:

± 1.0% of reading or 0.1 kVar (whichever is greater) at -0.2 < PF ≤ 0.2

Apparent Power (VA) Range:

0 kVA to 214748364.7 kVA

Parameters:

3-phase; per phase if VT is Wye

Accuracy:

± 1.0% of reading or 0.1 kVA (whichever is greater)

Power Factor Parameters:

3-phase; per phase if VT is Wye

Range:

0.01 Lag to 1.00 to 0.01 Lead

Accuracy:

± 0.02

Watt-hours (positive and negative) Range:

-2147483.647 MWh to 214748364.7 MWh

Parameters:

3-phase only

Update Rate:

50 ms

Accuracy:

± 2.0% of reading

Var-hours (positive and negative) Range:

-2147483.647 MVarh to 214748364.7 MWh

Parameters:

3-phase only

Update Rate:

50 ms

Accuracy:

± 2.0% of reading

COMMUNICATIONS

Ethernet – Base Offering Modes:

10/100 Mbps

One Port

RJ45

Protocol

Modbus TCP

Ethernet – Card Option Modes

100 MB

850 Feeder Protection System

Two Ports

Protocols

Modbus TCP, TFTP

WIFI

Isolated

Standard specification

IEEE802.11bgn

RS485 port

Modbus TCP, DNP3.0, IEC608705-104, IEC 61850, IEC 61850 GOOSE, IEEE 1588, SNTP, IEC 62439-3 clause 4 (PRP)

Baud rates

up to 115 kbps

Range

30 ft (direct line of sight)

Response time:

10 ms typical

Parity

None, Odd, Even

Protocol

Modbus RTU, DNP 3.0, IEC 608705-103

Compliant with USB 2.0

Maximum distance

1200 m (4000 feet)

Isolation

2 kV

ST (with this option both enabled ports are on the communications card; the Ethernet port located on the base CPU is disabled)

Protocol Serial

USB Standard specification

Testing and Certification Reference Standard

Dielectric voltage withstand Impulse voltage withstand Damped Oscillatory Electrostatic Discharge RF immunity Fast Transient Disturbance Surge Immunity Conducted RF Immunity Power Frequency Immunity

EN60255-5 IEC61000-4-18IEC60255-22-1 EN61000-4-2/IEC60255-22-2 EN61000-4-3/IEC60255-22-3 EN61000-4-4/IEC60255-22-4 EN61000-4-5/IEC60255-22-5 EN61000-4-6/IEC60255-22-6 EN61000-4-7/IEC60255-22-7

Voltage interruption and Ripple DC

IEC60255-11

Radiated & Conducted Emissions Sinusoidal Vibration Shock & Bump Siesmic Power magnetic Immunity Pulse Magnetic Immunity Damped Magnetic Immunity Voltage Dip & interruption Conducted RF Immunity 0-150khz Ingress Protection Environmental (Cold) Environmental (Dry heat) Relative Humidity Cyclic EFT Damped Oscillatory RF Immunity ESD Safety

CISPR11 /CISPR22/ IEC60255-25 IEC60255-21-1 IEC60255-21-2 IEC60255-21-3 IEC61000-4-8 IEC61000-4-9 IEC61000-4-10 IEC61000-4-11 IEC61000-4-16 IEC60529 IEC60068-2-1 IEC60068-2-2 IEC60068-2-30 IEEE/ANSI C37.90.1 IEEE/ANSI C37.90.1 IEEE/ANSIC37.90.2 IEEE/ANSIC37.90.3 UL508 UL C22.2-14

Applicable Council Directive

According to

Ambient temperatures:

Low voltage directive

EN60255-5 / EN60255-27 EN60255-26 / EN50263 EN61000-6-2 / EN61000-6-4 UL508 UL1053 C22.2.No 14

Storage/Shipping: Operating:

EMC Directive cULus

North America ISO

2.3 kV 5KV 2.5 kV CM, 1 kV DM Level 4 Level 3 Class A and B Level 3 & 4 Level 3 Class A & B PQT levels based on IEC61000-4-29, IEC61000-4-11 and IEC61000-4-17 Class A Class 1 Class 1 Class 2 Class 5 Class 4 Class 4 0, 40, 70, 80% dips, 250/300 cycle interrupts Level 4 IP54 front -40C 16 hrs 85C 16hrs 6day variant 2 4KV, 2.5 khz 2.5KV, 1 Mhz 20V/m, 80 MhZ to 1Ghz 8KV CD/ 15 kV AD e57838 NKCR e57838 NKCR7

Environmental

Approvals

CE compliance

Test Level

Feeder Protection

Test

Manufactured under a registered quality program

ISO9001

Altitude: Pollution Degree: Overvoltage Category:

- 40C to 85C -40C to 60C Operating up to 95% (non condensing) @ 55C (As per IEC60068-2-30 Variant 2, 6days) 2000m (max) II III

Ingress Protection:

IP54 Front

Humidity:

GEDigitalEnergy.com

281

Ordering 850 Base Unit Language Phase Currents Bank 1/2

E

**

NN **

H

N

N

A

*

N

G

*

*

*

*

*

*

*

*

*

850

Power Supply Slot F - HV I/O

Description English Language; High Voltage PS, Graphical Control Panel

E

English P1

1A three phase current inputs

P5 Ground Currents

N

5A three phase current inputs 1A ground input 5A ground input 1A ground + 1A sensitive ground input 5A ground + 5A sensitive ground input 110 - 250 V dc/110 - 230 Vac 2 Form A (Vmon), 3 Form C, 7 Digital Inputs (Low / High voltage, Int/ Ext supply) None 2 Form A (Vmon), 3 Form C, 7 Digital Inputs (Low / High voltage, Int/ Ext supply)

G1 G5 S1 S5 H A

Slot G - HV I/O

N A

Faceplate Current Protection

G

Color Graphical Display Basic = 50P, 50N, 50G, 51P, 51N, 51G Standard = Basic + 50SG, 50_2, 51SG, 51_2, RGF Advanced = Standard + 49,67P, 67N, 67G, 67SG, 67_2, Load Encroachment, Broken Conductor

S M A

Voltage Monitoring & Protection Control

S P

Standard = 27P, 27X, 59P, 59N, 59X, 81O, 81U Advanced = Standard + 25, 32, 32N, 55, 59_2, 81R Basic Standard = Basic + Flexlogic, CLP, 50BF, Trip Bus Advanced = Standard + Autorelcose, Bus Transfer (Requires voltage option P) Basic Basic + Advanced Breaker Health Standard = Front USB, 1 x Rear RS485 : Modbus RTU, DNP3.0, IEC60870-5-103 + 1 x Ethernet (Modbus TCP) Advanced = Front USB, 1 x Rear RS485 + 2 x Ethernet Fiber, MODBUS RTU / TCP, DNP3.0, IEC 60870-5-103/104, 1588, SNTP Advanced + PRP Advanced + PRP + IEC 61850

B F C

Monitoring Communications

Fiber Optic Connector Wireless Communication

B C S

E

1

E

1 2

P E N

None

S

ST, Multi-mode 850nm N

None

W Security

WiFi 802.11 B A

Basic Advanced - CyberSentry

Note: Harsh Environment Coating is a standard feature on all 8 series units.

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12715D(E) English 150121

Multilin™ F650 Feeder Protection & Bay Controller The Multilin F650, a member of the 650 Family of protection relays, incorporates protection, control, automation and metering in a economical package. The Multilin F650 provides high speed protection and control for feeder management and bay control applications, and comes with a large LCD and single line diagrams that can be built for bay monitoring and control for various feeder arrangements including ring-bus, double breaker or for breaker and half.

Protection and Control

Key Benefits

• Load encroachment supervision

• Advanced automation capabilities

• Wattmetric ground fault detection

• Graphical LCD, programmable buttons, and easy keys for selecting setting menus

• Positive and negative sequence based over/ under voltage elements

• IRIG-B and SNTP time synchronization, event reports, waveform capture, data logger • Voltage and frequency based load shedding and transfer schemes • Modular with card draw-out construction • High-speed inter-relay communications reduces wiring and associated installation costs • Communications supporting serial and Ethernet interfaces and multiple protocols • Embedded IEC61850 Protocol (optional), IEC 60870-5-103 (optional)

Applications • Primary protection and control for distribution feeders on solidly grounded, high impedance grounded or resonant systems

• Time, instantaneous & directional phase, neutral, ground and sensitive ground overcurrent • Manual close with cold load pickup control via PLC, Forward Power and Directional Power Units

• Four-shot autorecloser with synchronism check • Breaker control and breaker failure

Monitoring & Metering • Fault locator, record of last 10 faults - metering - current, voltage, power, energy, frequency and harmonics • Breaker operation & trip failure • Total breaker arcing current

• Bus blocking/Interlocking schemes

• Event recorder - 479 Events

• High-speed fault detection for arc flash

• High resolution oscillography and data logger

• Throw over schemes (bus transfer scheme applications)

• Metering: V I Hz W VA PF

• Load shedding schemes based on voltage and frequency elements

• Configurable graphical HMI interface

• Back-up protection for transmission lines, feeders and transformers

• Alarm Panel

• Distributed Generation (DG) interconnect protection, including active and passive anti-islanding

EnerVista™ Software • Simplified setup, configuration and commissioning • Strong document archive and management system • Simplified full featured monitoring and data recording

F650 Feeder Protection & Bay Controller

Protection and Control

Over/Under Frequency Protection

Directional supervision are available for phase, neutral, ground and sensitive ground currents. The neutral/ground directional elements can be programmed to work under zerosequence voltage, ground sensitive current or dual polarization.

The F650 provides high speed protection and control for feeder management and bay control applications, including:

Overcurrent Protection Instantaneous and time over­current functions are available for phase, neutral, ground/sensitive ground and negative sequence currents. A variety of time curves are provided including IEEE/ANSI, IEC A/B/C/long time inverse/short time inverse, GE IAC, I2t, definite time, rectifier curve and four user-programmable curves.

The F650 offers overfrequency and underfrequency elements to improve network (grid) stability using voltage or frequency based loadshedding techniques. It also allows to provide back up protection and trip breakers directly when protecting feeders and other frequency sensitive power equipment.

Over/Under Voltage Protection The F650 includes the following voltage elements:

Frequency Rate of Change Protection

• Phase undervoltage/overvoltage elements (each element has three individual phase undervoltage/overvoltage components)

Frequency rate of change (df/dt) elements included in the F650 to provide protection against system disturbances through load shedding.

• Auxiliary undervoltage/overvoltageelement • Neutral overvoltage element

Directional Elements

Wattmetric Zero-sequence Directional

Feeder Protection

Following are some of the key applications where voltage elements can be used:

Applications include ground fault protection in solidly grounded transmission networks, grounded/ungrounded/resistor- grounded/ resonant-grounded distribution networks. The wattmetric zero-sequence directional element responds to power derived from zero-sequence voltage and current in a direction specified by the element characteristic angle. The angle can be set within all four quadrants and the power can be active or reactive. Therefore, the

• Source transfer schemes. • Load shedding schemes • Back up capacitor bank protection and control • Backup motor protection to prevent automatic restart.

Flexible load encroachment characteristic in F650 can be set by adjusting the load angle and the reach.

Functional Block Diagram 1

52 79 1

CLOSE Monitoring

27X

TRIP

3

3 50BF 1

49

50PH 50PL

3

3

3

46

48

3

3

32FP 3

32

32N

3

3

BROKEN CONDUCTOR

3

59X 51PH/V 51PL/V 67P R

R

3

3

3

50N 3

51N 3

3

67N 3

25 1

1

2

2

50G 3

1

51G

67G 3

3

50SG 51SG 3

3

27

59

50IG 3

67SG

METERING

3

3V_0

3

47 3

3

3

VTFF 1

81U 3

81O 3

81R 3

59NH 3

59NL

F650 Digital Bay Controller

3

EN F650 BLOCK F.CDR

ANSI® Device Numbers & Functions 25 27/27X 32 32FP 32N 46

Synchrocheck Bus/Line Undervoltage Sensitive Directional Power Forward Power Wattmetric zero-sequence directional Negative Sequence Time Overcurrent

47 48 49 50 BF 50PH/PL

Negative Sequence Voltage Blocked Rotor Thermal Image - overload protection Breaker Failure Phase Instantaneous Overcurrent (High/Low)

284

50N 50G 50SG 50IG 51N 51G 51SG 51PH/V 51PL/V 59/59X 59NH/NL

Neutral Instantaneous Overcurrent Ground Instantaneous Overcurrent Sensitive Ground Instantaneous Overcurrent Isolated Ground Instantaneous Overcurrent Neutral Time Overcurrent Ground Time Overcurrent Sensitive Ground Time Overcurrent Voltage Restraint Phase Time Overcurrent Bus/Line Overvoltage Neutral Overvoltage - High/Low

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67P 67N 67G 67SG 79 81 U/O N/A 81R VTFF

87LG

Phase Directional Overcurrent Neutral Directional Overcurrent Ground Directional Overcurrent Sensitive Ground Directional Overcurrent Autorecloser Under/Over Frequency Broken Conductor Detection Load Encroachment Frequency Rate of Change VT Fuse Failure Detection

Ground Line Current Differential

F650 Feeder Protection & Bay Controller

element may be used to sense either forward or reverse ground faults in either inductive, capacitive or resistive networks.The inverse time characteristic allows time coordination of elements across the network.

Breaker Failure and Control Use the breaker failure function to determine when a trip command sent to a breaker has not been executed within a selectable time delay. In the event of a breaker failure, the unit will issue an additional signal to trip the breakers connected to the same busbar, potential sources of fault current.

The relay also provides for control of one or two breakers from faceplate pushbuttons, remote communications or contact inputs. A breaker pole discrepancy is included in the breaker control scheme. Breaker position is indicated by LEDs on the faceplate.

Load Encroachment Feeders may experience very heavy load increases due to various contingency situations. The Load Encroachment function in F650 provides the capability to manage such load growth in feeders. Load encroachment element can be set for the feeder’s expected maximum load, reducing the likelihood of false tripping for load conditions while maintaining dependability to trip for legitimate faults. The load encroachment supervision in F650 based on positive-sequence voltage and current and applies a characteristic shown in the figure. It allows to set the phase overcurrent elements below peak load current to see end-offline phase faults in heavily loaded feeder applications.

Autoreclosurer This function is applicable to three-pole tripping schemes and single breaker applications. Four reclosing “shots“ are possible prior to locking out, each with an independent time setting. Auto­reclosure outputs can be used to modify circuit protection settings between shots.

One synchronism check element is available. The algorithm allows breaker close time compensation to optimize close conditions. The element monitors maximum difference in voltage magnitudes

(Main-Tie-Main), loadshedding based on frequency, voltage and communication, loop restoration schemes, other remedial action schemes and dynamic setting group changes.

Inputs and Outputs

Three separate groups of protection settings may be stored in the F650 non-volatile memory. The user can edit the active settings internally and externally via contact inputs and communications.

A choice of 16 to 64 inputs and 0 to 16 outputs are available. Digital inputs may be user defined with a separate debounce and chatter time. Programmable “quasi“ analog input levels allow the use of different voltage levels in the same model via setting the requested thresholds. EnerVista™ software allows easy configuration of all the interlocking and switching sequences. A graphic HMI interface provides access to monitoring, metering and alarm panel screens.

Broken Conductor

Virtual Inputs/Outputs

F650 incorporates a broken or fallen conductor detection function. The relay uses the ratio between the negative sequence current, I2, and the positive sequence current I1. In normal and balanced load situations, this ratio is zero, while in severe load fault conditions, an unbalance is produced and this ratio increases.

Traditionally, protective relay logic has been relatively limited. Use virtual inputs and outputs in conjunction with the programmable logic capabilities of the F650 for unusual applications involving interlocks, blocking, or supervisory functions, to minimize the requirement for auxiliary components and wiring while making more complex schemes possible.

( V), phase angles (

), and frequencies

( f) as well as the dead source condition.

Multiple Settings Groups

In order to avoid trips or pickup with very weak loads, there is a current level threshold (I2/I1) to inhibit the operation of the element when the three phase currents are below a fixed level.

Locked Rotor F650 incorporates a locked rotor element . Protection element 48 produces a trip when current (primary values) exceeds the set value. This current setting value is the product of the set Full Load Current by the pickup setting.

Advanced Automation The F650 incorporates advanced automation features including powerful programmable logic, communication, and SCADA capabilities that far surpass what is found in the average feeder relay. The F650 integrates seamlessly with other Multilin relays for complete system protection.

F650 Logic Configuration F650 Logic Configuration is the powerful programming logic engine that provides the ability of creating customized protection and control schemes thereby minimizing the need, and the associated costs, of auxiliary components and wiring. Using F650 Logic Configuration, the F650 can be programmed to provide required tripping logic along with custom scheme logic for auto transfer schemes

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The virtual inputs and outputs are digital signals associated with the F650 internal logic. Virtual inputs include signals generated remotely via communications. The virtual outputs are outputs of programmable logic equations used to customize the device. Virtual outputs can also serve as inputs to programmable logic equations.

CAN BUS Remote I/O (CIO) The F650 can be ordered with up to two additional communication cards on the rear. Besides two identical ports, COM1 and COM2, the cards may incorporate a port for CAN BUS communications used to connect the Remote CAN BUS I/O module (CIO Module). Use the CIO Module to double the number of I/Os of the F650, when the maximum number of I/Os available inside the relay (up to 64 inputs and 16 outputs) is not sufficient to meet the needs of specific applications. In addition to increasing the number of I/Os, the CIO Module allows the F650 to monitor signals located at a remote location with only a connection between both devices, resulting in significant savings in installation costs.

Transducer Inputs dcmA inputs are available to monitor system parameters such as temperature, vibration, pressure, wind speed, and flow.

285

Feeder Protection

The F650 incorporates 3 levels of current and time, together with a trip without current unit, and an internal arc detection unit. The breaker failure unit has three levels: “Retrip” or “Supervision” used to generate a second trip signal to the corresponding breaker on which the initial opening has been executed, “High Level”, and “Low Level” used to executing complex protection schemes. The function can be initiated/blocked via digital inputs as well as communications.

Synchronism Check

F650 Feeder Protection & Bay Controller

Remote I/O

Event Recording and Oscillography

Multi-Language

The remote I/O feature provides a means of sharing digital point state information between F650s or other IEC 61850 compliant IEDs or controllers. The remote outputs interface seamlessly to the remote inputs of other F650 devices via the IEC 61850 GSSE messaging. User secure peer-to-peer communications to develop complex schemes in distributed logic and I/Os.

The F650 is capable of storing 479 time-tagged events (1 ms tagging), to help with trouble­ shooting. The trigger point, the channels, and sampling rate of the oscillography files are user programmable features. Up to five seconds at maximum sample rate can be stored.

The F650 supports multiple languages. French, Chinese, Russian language options are available on the local display, front panel, and EnerVista™ setup software, as well as the product instruction manual. Easily switch between English and an additional user selectable language on the local display.

Monitoring and Metering The F650 provides advanced monitoring and metering that includes:

Feeder Protection

VT Fuse Failure Use the VT Fuse Failure feature to issue an alarm and/or to block voltage driven protection functions that can operate incorrectly due to an abrupt partial or total voltage loss. This loss is caused by the voltage transformers secondary circuit protection fuse failure. Different methods are used to detect the different types of VT fuse failure.

Trip Circuit Monitoring F650 can be used to monitor the integrity of both the breaker trip and closing coils and circuits. The supervision inputs monitor both the battery voltage level, while the outputs monitor the continuity of the trip and/or closing circuits, by applying a small current through the circuits.

Basic Metering Metered values include: • Current: Ia, Ib, Ic, In, Ig, Isg • Phase-to-phase and phase-to-ground voltages for bus and line: Van, Vbn, Vcn, Vbb, Vab, Vbc, Vca • Active power (per-phase and total): Wa, Wb, Wc, W • Reactive power (per-phase and total): VAra, VArb, VArc, VAr

Breaker Arcing Current (I2t) The relay estimates the total interrupted current as an accumulation of the RMS current measured during the time period taken to open the breaker after a trip. It calculates the perphase wear on the breaker contacts to establish a threshold. When the breaker maintenance threshold is exceeded the relay can be set to trigger an alarm.

Communications The F650 includes up to three communication ports that operate simultaneously. Redundant ports are also available for special applications. F650 features an RS232 front port (COM2) and a choice of rear RS485, plastic/glass fiber optics (COM1 and COM2). Additionally, this module may incorporate a port for CAN bus communications, used for the connection to the remote CAN BUS I/O module. F650 COM3 features 10/100 BaseTX and 100 Base FX single or redundant Ethernet ports. Protocols supported by the F650 include IEC 61850, DNP 3.0, Modbus RTU, ModBus TCP/IP and IEC 60870-5-104. These protocols make it easy to connect to a Utility automation system and are integrated into the F650, eliminating the need for external protocol converter devices.

Security Independent passwords for protection and control allow restricting access via keypad and display, or EnerVista™ software.

• Total active, reactive and apparent energy: MWh, MVArh, MVah • Power factor (per-phase and total)

IEC 61850 is the new international standard for information exchange and interoperability between intelligent devices within a substation. Use the F650 with IEC 61850 to lower the costs and simplify the engineering, commissioning, operating, and maintenance associated with substation protection and control applications. IEC 61850 is built on over 7 years of GE leadership in UCA 2.0 implementation. IEC 61850 allows for the seamless connection of IEDs from multiple vendors. In addition to device interoperability, these protocols are designed to control the substation via a LAN instead of through discrete wiring to an RTU. Peer-to-peer communication over Ethernet enables distributed control with several IEDs and eliminates the need for an RTU to remote SCADA master. High-speed message transfer eliminates the need for large and costly hard-wired interconnection.

EnerVista™ Software The EnerVista™ Suite is an industry-leading set of software programs that simplifies every aspect of using the F65 relay. The EnerVista™ suite provides all the tools to monitor the status of your the protected asset, maintain the relay, and integrate information measured by the F650 into DCS or SCADA monitoring systems. Convenient COMTRADE and Sequence of Events viewers are an integral part of the 650 Setup software included with every F650 relay, to carry out postmortem event analysis to ensure proper protection system operation.

EnerVista™ Launchpad

• Frequency

EnerVista™ Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining Multilin products. The setup software within Launchpad allows configuring devices in real-time by communicating using serial, Ethernet, or modem connections, or offline by creating setting files to be sent to devices at a later time.

• Demand • Ia, Ib, Ic, Ig, Isg, Va, Vb, Vc and Vx signals are available locally and remotely and can be stored in the oscillography record or data logger.

286

Interoperability With Embedded IEC 61850 Protocol

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F650 Feeder Protection & Bay Controller

Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed. Documents made available include:

Viewpoint Monitoring

• Manuals

• Wiring Diagrams

Viewpoint Monitoring is a simple-to-use and full-featured monitoring and data recording software package for small systems. Viewpoint Monitoring provides a complete HMI package with the following functionality:

• Application Notes

• FAQ’s

• Plug-&-Play Device Monitoring

• Trending Reports

• Guideform Specifications

• Service Bulletins

• System Single-Line Monitoring & Control

• Automatic Event Retrieval

• Brochures

• Automatic Waveform Retrieval

• Annunciator Alarm Screens

User Interface

Feeder Protection

Display • Graphic 16x40 or text 4x20 LCD display • Fluorescent backlight to improve visibility

LEDs • Multicolor programmable LEDs with label panel • Local/Remote/Off pushbutton with LEDs

Keypad & Shuttle • Local/Remote/Off pushbutton withLEDs • Key control for easy navigation • Ergonomic programmable keys

Front Port • Electrically isolated front USB communication port

Dimensions The F650 uses a “shuttle“ control for ease of use. A choice of text or graphic display, and up to five configurable keys are available for frequently performed control functions. Up to 15 programmable LEDs are available. The F650 can incorporate (option “N” for the second position of the ordering code) a Graphical display with IEC Symbols.

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287

F650 Feeder Protection & Bay Controller

Dimensions REDUNDANT POWER SUPPLY

POWER SUPPLY +

C

A B C

-

+

-

H1

H9

+

-

A

VC VC

B1

IA

B2

IA

B3

IB

B4

IB

B5

IC

B6

IC

B9

IG

B10

IG

B11

ISG

B12

ISG

A11

VX

A12

VX

g

COM1 CAN COM2

Multilin

F650 Digital Bay Controller

RS485 FIBER

TX RX TX RX TX RX

FIBER FIBER FIBER

RS485

CABLE

GND A(-) B(+) GND CAN L CAN H

10/100 UTP

RJ45 TX RX RJ45 TX RX

100FX ST 10/100 UTP 100FX ST

IRIG-B

A9 A10

BACKUP READY

GND A(-) B(+) GND A(-) B(+) TX RX

RS485

COM1

VB

H6

COM2

A8

H5

CAN

VB

BACKUP POWER

READY

H4

ETHERNET 1

A7

POWER VOLTAGE INPUTS

VA

-

ETHERNET 2

1

A6

+

CURRENT INPUTS

Feeder Protection

1

VA

BUS V

1

A5

COM1

H10 H18 H13 H14 H15

B

CAN

52

RS-232

+

H19

-

H20 1

FRONT

1

OPEN DELTA VT CONNECTION C

A B C

A

GROUNDING SCREW

B

VB

A8

VB

A9

VC

A10

1 GROUND AT RELAY LOCATION (NOT CT & PT LOCATION) OPTIONAL ELEMENTS

VC

SLOT G

BOARD TYPE 1, 4 ,5 G1 G2 G3 G4 G5 G6 G7 G8 G9 G10 G11 G12 G13 G14 G15 G16 G17 G18

+ + + + + + + + + + + + + + + +

BOARD TYPE 1

CC1 CC2 CC3 CC4 CC5 CC6 CC7 CC8

O2

COMMON 1/8 COMMON 9/16 CC9 CC10 CC11 CC12 CC13 CC14 CC15 CC16

BOARD TYPE 4 G19 G20 G21 G22 G23 G24 G25 G26 G27 G28 G29 G30 G31 G32 G33 G34 G35 G36

O1

O3 O4 O5 O6 O7 O8

CC17 CC18 CC19 CC20 CC21 CC22 CC23 CC24 COMMON 17/24 COMMON 25/32 CC25 CC26 CC27 CC28 CC29 CC30 CC31 CC32

BOARD TYPE 5 G19 G20 G21 G22 G23 G24 G25 G26 G27 G28 G29 G30 G31 G32 G33 G34 G35 G36

G19

SHIELD 1/4

AI1 AI2 AI3

ANALOG INPUTS

VA

USER CONFIGURABLE INPUTS

A6 A7

CONFIGURABLE OUTPUTS

VA

USER CONFIGURABLE INPUTS

A5

VOLTAGE INPUTS

52

AI4 AI5 AI6 AI7

+ G20 -

G21

+ G22 - G23 + G24 - G25 + G26 - G27 + G28 - G29 + G30 -

G31

+ G32

- G33 + G34 AI8 - G35 SHIELD 5/8 G36

SLOT F

288

V

COIL 1 52/b

CC1 CC2 CC3 CC4 COMMON 1/4 COMMON 5/8 CC5 CC6 CC7 CC8 COIL 2 V 52/a COIL 2 V 52/b

BOARD TYPE 1 O1

O2 O3 O4 O5 O6 O7 O8

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BOARD TYPE 2 F19 F20 F21 F22 F23 F24 F25 F26 F27 F28 F29 F30 F31 F32 F33 F34 F35 F36

O1 O2 O3 O4 O5 O6 I SENS

I

O7 I SENS

O8

I

BOARD TYPE 4 F19 F20 F21 F22 F23 F24 F25 F26 F27 F28 F29 F30 F31 F32 F33 F34 F35 F36

CC17 CC18 CC19 CC20 CC21 CC22 CC23 CC24 COMMON 17/24 COMMON 25/32

CC25 CC26 CC27 CC28 CC29 CC30 CC31 CC32

BOARD TYPE 5 F19 F20 F21 F22 F23 F24 F25 F26 F27 F28 F29 F30 F31 F32 F33 F34 F35 F36

SHIELD 1/4

AI1 AI2 AI3

ANALOG INPUTS

COIL 1 52/a

USER CONFIGURABLE INPUTS

CC9 CC10 CC11 CC12 CC13 CC14 CC15 CC16

V

CONFIGURABLE OUTPUTS

COMMON 9/16

+ + + + + + + + + + + + -

CONFIGURABLE OUTPUTS

COMMON 1/8

BOARD TYPE 2 F1 F2 F3 F4 F5 F6 F7 F8 F9 F10 F11 F12 F13 F14 F15 F16 F17 F18

COIL 1

CC1 CC2 CC3 CC4 CC5 CC6 CC7 CC8

USER CONFIGURABLE INPUTS

+ + + + + + + + + + + + + + + +

COIL 2

F1 F2 F3 F4 F5 F6 F7 F8 F9 F10 F11 F12 F13 F14 F15 F16 F17 F18

USER CONFIGURABLE INPUTS

BOARD TYPE 1, 4 ,5

AI4 AI5 AI6 AI7 AI8 SHIELD 5/8

+ + + + + + + + -

F19 F20 F21 F22 F23 F24 F25 F26 F27 F28 F29 F30 F31 F32 F33 F34 F35 F36

F650 Feeder Protection & Bay Controller

Technical Specifications

SENSITIVE GROUND INSTANTANEOUS OVERCURRENT (50SG) Current: Fundamental Phasor (w/o harmonics) or RMS Rated current: For connection to 1 or 5 A CTs. Pickup level: 0.005 to 16.0 A in steps of 0.001 A. Reset dropout level: 97% to 98% of the pickup level Accuracy: ±1.5% of the reading 1 mA from 0.005 to 16A Overreach: < 2% Trip Delay: 0.00 to 900.00 s. in steps of 0.01 s. Operate Time: < 30 ms at 3 x Pickup at 50 Hz Reset time: 0.00 to 900.00 s. in steps of 0.01 s. Timing accuracy: at 0ms time delay (no intentional delay): 50 ms at non-zero time delay: ± 3% of operate time or 50ms (whichever is greater)

PROTECTION ISOLATED GROUND INSTANTANEOUS OVERCURRENT (50IG) Current Input: Fundamental Phasor (without harmonics) Voltage Input: Fundamental Phasor (without harmonics) Current Pickup level: 0.005 to 0.400 A in steps of 0.001 A Voltage Pickup level: 2 to 70 V in steps of 1 V Dropout level : 97 to 98% of the pickup level Pickup level: for voltage 2 to 70 V in steps of 1 V Dropout Level: 97-98% of the pickup level Level Accuracy: ±1.5% of the reading ± 1 mA from 0.005 to 16 A Trip delay: 0.00 to 900.00 s. in steps of 0.01 s. Time to instantaneous 0.00 to 900.00 s. in steps of 0.01 s. Operate time: <50 ms at 3 x Pickup at 50 Hz, typically Timing accuracy: at 0 ms time delay (no intentional delay): 50ms at non-zero time delay: ±3% of operate time or 50 ms (which ever is greater) Snapshot Events: Selectable by setting

Minimum voltage threshold: 3 to 300 in steps of 1V Logic: Any/two/all phases logic selectable by setting Supervised by breaker: Selectable by setting Timing accuracy: ±3.5% of operation time or 50 ms. (whichever is greater) PROTECTION AUXILIARY OVERVOLTAGE (59X) Pickup level: 3 to 300 in steps of 1 V Reset dropout level: 97% to 98% of the pickup level Accuracy: ±1% of the reading, from 10 to 208 V Timing accuracy: ±3.5% of operation time or 50 ms (whichever is greater) AUXILIARY UNDERVOLTAGE (27X) Pickup level: 3 to 300 in steps of 1 V Reset dropout level: 97% to 98% of the pickup level Accuracy: ±1% of the reading, from 10 to 208 V Operation curves: Fixed time or inverse curve Timing accuracy: ±3.5% of operation time or 50 ms (whichever is greater)

PHASE DIRECTIONAL UNITS (67P) Directionality: Forward and reverse selectable by setting Polarizing: Quadrature Voltage: ABC seq: Phase A (VBC), Phase B (VCA), Phase C (VAB) ACB seq: Phase A (VCB), Phase B (VAC), Phase C (VBA) Polarizing voltage threshold: 0 to 300 Vac in steps of 1 V Current Sensitivity Threshold: 50 mA Characteristic angle: -90º to +90º in steps of 1º Block Logic: Permission or Block selectable by setting Angle accuracy: ±2º for I>0.1 A and V>5 Vac Operate time: <30ms, typically NEUTRAL AND GROUND DIRECTIONAL UNIT (67N/67G) Directionality: Forward and reverse selectable by setting Polarizing: Voltage, current, dual Polarizing Voltage: VN (measured or calculated, selected by setting) Polarizing Current: Isg (measured from 5th current transformer) Operating Current: Ig (measured from 4th current transformer) Polarizing Voltage threshold: 0 to 300 Vac in steps of 1 V Polarizing Current threshold: 0.005 A Characteristic angle: -90º to +90º in steps of 1º Block Logic: Permission or Block selectable by setting Angle accuracy: ±2º for I>0.1 A and V>5 Vac Operate time: <30ms, typically SENSITIVE GROUND DIRECTIONAL UNIT (67SG) Polarization By: Voltage Polarization Voltage: 0 to 300 Vac in steps of 1V Directionality: Forward and reverse selectable by setting Characteristic angle:-90º to +90º in steps of 1º Angle accuracy: ±3º from 0.1 A and 5 Vac Response time: <30ms typically THERMAL MODEL (49) Fundamental phasor (without harmonics) Current: Rated current: Valid for connection to 1 or 5 A CTs Pickup level: 0.05 to 160.00 A in steps of 0.01 A Dropout level: 97% to 98% of the pickup Accuracy: ±0.5% of the reading ±10 mA from 0.05 to 10 A ±1.5% of the reading for higher values Timer accuracy: ±3.5% of the operating time or 50 ms. (whichever is greater) Heating constant: Between 3 and 600 minutes Cooling constant :1 to 6 times the heating constant BREAKER FAILURE (50BF) Current: Fundamental phasor (without harmonics) Rated current: Valid for connection to 1 or 5 A CTs Pickup level for supervision: 0.05 to 160.00 A in steps of 0.01 A Pickup level high level: 0.05 to 160.00 A in steps of 0.01 A Pickup level low level: 0.05 to 160.00 A in steps of 0.01 A Pickup level internal arcing: 0.05 to 160.00 A in steps of 0.01 A Reset dropout level: 97% to 98% of pickup level Accuracy: ±0.5% of the reading ±10 mA from 0.05 to 10A ±1.5% of the reading for higher values Timer accuracy : ±3.5% of the operating time or 50 ms (whichever is greater) PHASE OVERVOLTAGE (59P) Voltage: Fundamental phasor (without harmonics of phase-to phase voltages Pickup level: 3 to 300 in steps of 1 V Reset dropout level: 97% to 98% of the pickup level Accuracy: ±1% of the reading, from 10 to 208 V Operate time : 0.00 to 900.00 s. in steps of 0.01s Reset time: 0.00 to 900.00 s. in steps of 0.01s Timer accuracy: ±3.5% of operation time or 50 ms (whichever is greater) PHASE UNDERVOLTAGE (27P) Voltage: Fundamental phasor of phase-to-ground or phase-to phase voltages (selectable by setting) Pickup level: 3 to 300 in steps of 1 V Reset dropout level: 102% to 103% of the pickup level Accuracy: ±1% of the reading, from 10V to 208 V Operation curves: Fixed time or inverse curve Reset type: Instantaneous

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FREQUENCY (81U ,81O) Pickup level: 20 to 65 Hz in steps of 0.01 Hz Reset dropout level: 30 mHz higher/lower than the pickup level Accuracy: 0.05 Hz Operation time trip delay: 0.00 to 900.00 s. in steps of 0.01 s Reset time delay: 0.00 to 900.00 s. in steps of 0.01 s Timer accuracy: ±3.5% of operation time or 100 ms. (whichever is greater)



Feeder Protection

PROTECTION PHASE/NEUTRAL AND GROUND TIMED OVERCURRENT (51PH/51PL/51N/51G) Current: Fundamental Phasor (w/o harmonics) or RMS Rated current : For connection to 1 or 5 A CTs. Pickup level : 0.05 to 160.00 A in steps of 0.01 A Reset Dropout level: 97% to 98% of the pickup level Accuracy: ±0.5% of the reading ±10 mA from 0.05 to10A ±1.5% of the reading for values higher than 10A OPERATION CURVES IEEE extremely/very/moderately inverse IEC Curve A/B/C/Long-Time Inverse/ Short-Time Inverse ANSI extremely/very/normally/moderately inverseI2t IAC extremely / very / moderately inverse Definite time Rectifier curve User curve FlexCurve™ A/B/C/D Reset time type: Instantaneous or time delayed according to IEEE Snapshot events: Selectable by setting Timer accuracy: From 1.03 times the pickup, ±3% of operation time or 50 ms. (whichever is greater) Voltage restraint: Selectable by setting NEGATIVE SEQUENCE (46) Current: Fundamental phasor (without harmonics) Pickup level: 0.05 to 160.00 A in steps of 0.01 A Reset level: 98% of the pickup level Accuracy: ±0.5% of the reading ±10 mA from 0.05 to 10A ±1.5% of the reading for higher values Operation curves: IEEE extremely/very/moderately inverse IEC Curve A/B/C/Long-Time Inverse/Short- Time Inverse Ansi extremely/very/normally/moderately inverse I2t IAC extremely / very / moderately inverse Definite time Rectifier curve User curve FlexCurve™ A/B/C/D Reset time type: Instantaneous or time delayed according to IEEE Timing: Operate at > 1.03 times the pickup ±3% of operate time or 50 ms. (whichever is greater) SENSITIVE GROUND TIMED OVERCURRENT (51SG) Current: Fundamental Phasor (w/o harmonics)or RMS Rated current : For connection to 1 or 5 A CTs Pickup level: 0.005 to 16.00 A in steps of 0.001 A Reset dropout level: 97% to 98% of the pickup level Accuracy: ±1.5% of the reading ± 1 mA from 0.005 to 16 A Operation curves: IEEE extremely / very / moderately inverse IEC A/B/C/long-time inverse/short time inverse curve IAC extremely / very / normally / moderately inverse ANSI extremely / very / normally / moderately inverse I2t Definite time Rectifier curve FlexCurve™ A/B/C/D user curve Reset time: Instantaneous or time delayed according to IEEE Timing accuracy: Operate at > 1.03 times the pickup ±3% of operate time or 50 ms. (whichever is greater) PHASE/NEUTRAL AND GROUND INSTANTANEOUS OVERCURRENT (50PH/50PL/50N/50G) Current: Fundamental Phasor (w/o harmonics) or RMS Rated current : For connection to 1 or 5 A CTs. Pickup level: 0.05 to 160.0 A in steps of 0.01 Reset dropuout level: 97% to 98% of the pickup level Accuracy: ±0.5% of the reading ±10mA from 0.05 to 10A ±1.5% of the reading for higher values Overreach < 2% Trip Delay: 0.00 to 900.00 s. in steps of 0.01 s. Operate time: <30 ms at 3 x Pickup at 50 Hz, typically Reset time delay: 0.00 to 900.00 s. in steps of 0.01 s. Timing accuracy: at 0ms time delay (no intentional delay): 50 ms at non-zero time delay: ± 3% of operate time or 50ms (whichever is greater)

NEUTRAL OVERVOLTAGE (59NH/59NL) Voltage: Fundamental phasor of the neutral voltage Pickup level: 3 to 300 in steps of 1 V Reset level: 97% of the pickup level Accuracy: ±1% of the reading, from 10 to 208 V Trip delay: 0.00 to 900.00 s. in steps of 0.01 s Reset time: 0.00 to 900.00 s. in steps of 0.01 s Timing accuracy: ±3.5% of operation time or 50 ms. (whichever is greater) NEGATIVE SEQUENCE OVERVOLTAGE (47) Pickup level: 3 to 300 in steps of 1 V Reset dropout level: 97%to 98%of the pickup level Accuracy: ±1% of the reading, from 10 to 208 V Trip delay: 0.00 to 900.00 s. in steps of 0.01 s Reset delay: 0.00 to 900.00 s. in steps of 0.01 s Timing accuracy: ±3.5% of operation time or 50 ms. (whichever is greater) FORWARD POWER (32FP) Current, Voltage: Fundamental phasor (primary values) Pickup level (two steps) 0-10000 MW (primary values) in steps of 0.01 MW Reset dropout level: 97%to 98% of the pickup level Accuracy for primary magnitudes ±3% in the complete range. Reset type: Instantaneous Trip delay (two steps): 0.00 to 900.00 s in steps of 0.01 s Timing accuracy: ±3.5% of operation time or 50 ms. (whichever is greater) SENSITIVE DIRECTIONAL POWER (32) Current, Voltage: Fundamental phasor (primary values) Pickup level (two steps): -10000.00 to 10000.00 MW (primary values) in steps of 0.01 Characteristic angle (two steps): 0.00 to 359.99 in steps of 0.01º Accuracy for primary magnitudes: ±3% of complete range Trip delay (two steps): 0.00 to 900.00s in steps of 0.01s Timing accuracy: ±3.5% of operation time or 50ms (whichever is greater) BROKEN CONDUCTOR (I2/I1) Pickup level: 20.0-100.0% (I2/I1 ratio) in steps of 0.1% Reset dropout level: 97%to 98%of the pickup level Trip delay: 0.00 to 900.00 s in steps of 0.01 s Timing accuracy: ±3.5% of operation time or 30 ms. (whichever is greater) Minimum phase current threshold: I2/I1 current inhibition level: 0.000-1.000 in steps of 0.001 FREQUENCY RATE OF CHANGE Increasing, decreasing, bi-directional df/dt trend: df/dt pickup level: 0.10 to 10.00 Hz/s in steps of 0.01 df/dt level accuracy: 80 mHz/s or 3.5%, whichever is greater Overvoltage supervision: 0.00 to 110.00 % in steps of 0.0 95% settling time for df/dt: < 24 cycles Operate time: at 2 × pickup : 12 cycles at 3 × pickup : 8 cycles at 5 × pickup : 6 cycles Frequency Rate min.: 20.00 to 80.00 Hz in steps of 0.01 Frequency Rate max.: 20.00 to 80.00 Hz in steps of 0.01 Frequency Rate delay: 0.00 to 60.00 s in steps of 0.01 Snapshot Events: Selectable by setting

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F650 Feeder Protection & Bay Controller

Technical Specifications PROTECTION LOAD ENCROACHMENT Responds to: Positive-sequence quantities Minimum voltage: 0.00 to 300.00 V in steps of 0.01 Reach (sec. Ω ): 0.02 to 250.00 Ω in steps of 0.01 Impedance accuracy: ±3% Angle: 5 to 50° in steps of 1 Angle accuracy: ±3° Pickup delay: 0 to 65.535 s in steps of 0.001 Reset delay: 0 to 65.535 s in steps of 0.001 Time accuracy: ±3.5% or ±60 ms, whichever is greater Operate time: < 60 ms at 50 Hz Snapshot Events: Selectable by setting

Feeder Protection

CONTROL AUTORECLOSE (79) Three-phase pole tripping schemes Schemes: No. of reclosing shots: Up to 4 reclose attempts before lockout Dead time: Independent dead time setting before each shot adjustable between 0 and 900 s in steps of 0.01 s Reclaim time: 0.00 to 900.00 s in steps of 0.01 s Condition permission: Selectable by setting Hold time: 0.00 to 900.00 s in steps of 0.01 s Reset time: 0.00 to 900.00 s in steps of 0.01 s Snapshot Events: Selectable by setting Possibility to modify protection settings after each shot SYNCHRONISM CHECK (25) Dead/live levels for line and bus: 0.00 to 300.00 in steps of 0.01 V Maximum voltage difference: 2.00 to 300.00 V in steps of 0.01 V Maximum angle difference: 2.0º to 80.0º in steps of 0.1º Maximum frequency slip: 10 to 5000 mHz in steps of 10 mHz Synchronism time: 0.01 to 600.00 s in steps of 0.01 s Angle accuracy: 3º Dead Source function: None (DL-DB) Dead Line - Dead Bus (LL-DB) Live Line-Dead Bus (DL-LB) Dead Line – Live Bus Snapshot Events: Selectable by setting FUSE FAILURE Activation by Algorithm based onpositive sequence of voltage and current Activation by V2/V1 ratio BREAKER FAILURE (50BF) Current: Fundamental phasor (without harmonics) Rated current: Valid for connection to 1 or 5 A CTs Pickup level for supervision: 0.05 to 160.00 A in steps of 0.01 A Pickup level for high level: 0.05 to 160.00 A in steps of 0.01 A Pickup level for low level: 0.05 to 160.00 A in steps of 0.01 A Pickup level for internal arcing: 0.05 to 160.00 A in steps of 0.01 A Reset level: 97% to 98% of pickup level Accuracy: ±0.5% of the reading ± 10 mA from 0.05 to 10 A ±1.5% of the reading for higher values Reset type: Instantaneous Timing accuracy: ±3.5% of the operating time or 30 ms. (whichever is greater) BREAKER MAINTENANCE Kl2t BKR Ph A, B, C Cnt: 0.00 to 9999.99 in steps of 0.01 (KA)2s BKR Openings Cnt: 0 to 9999 in steps of 1 BKR Closings Cnt: 0 to 9999 in steps of 1 BREAKER SETTINGS Switchgear number: 1 to16 Maximum KI2t: 0.00 to 9999.99 in steps of 0.01 (KA)2s KI2t integ. Time: 0.03 : 0.25 s in steps of 0.01s Maximum openings: 0 to 9999 in steps of 1 Maximum Openings in an hour: 1 to 60 in steps of 1

MONITORING TRIP/CLOSE COIL MONITORS Detect open trip and close circuits OSCILLOGRAPHY Records: Up to 20 oscillography records. Samples: Programmable to 4, 8, 16, 32 or 64 samples per cycle Trigger position: 5% to 95% of total length Trigger: Programmable via programmable logic Data: 5 current channels and 4 voltage channels Up to 16 digital channels selectable from the available internal states programmable through PLC Storage: Permanent in non volatile memory (flash) without battery In non-volatile memory (flash) without battery Format: International Standard COMTRADE ASCII - IEEE C37.111-1999. FAULT LOCATOR Method: Single-ended Positive sequence module: 0.01 to 250.00 Ohm in steps of 0.01 Ohms Positive sequence angle: 25 to 90º in steps of 1º Zero sequence module: 0.01 to 750.00 Ohms in steps of 0.01 Ohm Zero sequence angle: 25 to 90º in steps of 1º Line length: 0.0 to 2000.0 in steps of 0.1 (miles or km) Display fault on HMI: Possibility to show the fault report on the display Accuracy: 5% (typical) SNAPSHOT EVENTS Capacity: 479 scrolling events Labeling time tag: 1 ms using an internal clock of 100 µs Accuracy: 1 ms (using the IRIG-B synchronization input) Trigger: By pickup or dropout or operate of any element By change of state in a Digital input/output change of state By virtual inputs and control events Storage: Permanent in non volatile memory (flash) without battery CONTROL EVENTS Capacity: 128 events programmable through PLC Labeling time tag: 1 ms using an internal clock of 100 µs Accuracy: 1 ms (using the IRIG-B synchronization input) Trigger: By any digital signal programmable through PLC Alarm: Possibility to display the event as an alarm on the alarms panel. Information available always through Communications for all models and also in HMI for models with graphical display (M in ordering code). Storage: Permanent in non volatile memory (flash) without battery DEMAND Channels: 9 Parameters: Ia(kA RMS), Ib(kA RMS), Ic(kA RMS), Ig(kA RMS), Isg(kA RMS), I2 (KA), P(MW), Q (MVAr) and S (MVA) Current and Power Method: Thermal Exponential, block interval, Rolling demand Metering Measurements: Each channel shows the present and maximum measured value, with date and time for the maximum recorded value. Samples: 5, 10, 15, 20, 30, 60 minutes. Accuracy: ±1% DATA LOGGER Channels: 1 to 16 Parameters: Any of the analog Metering actual values Samples: 1 second, 1, 5, 10, 15, 20, 30, 60 minutes. Capacity: Fixed, (32768 measures)

INPUTS CURRENT INPUTS Rated current: Appropriate for 1 or 5 A LoadRelay Burden: < 0.04 Ohm Overload: 20 A permanent 500 A during 1 second Current Withstand: Continuous at 20 A 1 second at 500 A for phases and ground 1 second at 50 A for sensitive ground VOLTAGE INPUTS VAC inputs do not need varistors, as the impulse test is applied to 100% of the transformers Metering range: From 2 to 275 Vac LoadRelay Burden: 0.05 VA at 120 Vac (50 or 60 Hz) Voltage withstand: 260 Vac permanent Continuous at 275 V to neutral 420 Vac during 1 min/hr at 420 to neutral DIGITAL INPUTS Voltage Threshold: Programmable from 20 up to 230Vdc in steps of 1 V Impedance: > 100 kOhm Load for voltage supervision inputs: 2 mA + V/100 kOhm Maximum error: ±10% setting or ± 5 V Acknowledgement time: < 1 ms Debounce time: 1 to 50 ms in steps of 1 ms REMOTE INPUTS No of input points: 32, configured from 64 incoming bit pairs No of remote devices: 16 Default states on loss of comms: On, Off, Latest/on, Latest/off ANALOG INPUTS (dcmA) Current inputs: 0 to -1; 0 to +1; -1 to +1; 0 to 5; 0 to 10; 0 to 20, 4 to 20 Conversion range: -1 to 20 dcmA Accuracy: +/-0.2% of full scale Type: Passive IRIG-B TIME SYNCHRONIZATION INPUT Type: Demodulated input (no carrier) Formats: B000(*) B001, B002 and B003(*) Level: TTL Load: 1.5 mA (*) Signal combinations recognized in accordance with IRIG Standard 200-95 REAL TIME CLOCK Accuracy: Backup energy:

Switchgear Switchgear number: 1 to16 Switchgear: 1 to16 (configurable).

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METERING CURRENT Accuracy: ±0.5% of the reading ± 10 mA from 0.1 to 10 A (for phases and ground) ±1.5% of the reading ± 1 mA from 0.005 to 5 A (for sensitive ground) ±1.5% of the reading for higher values VOLTAGE Accuracy: ±1% reading, from 10 to 208 V POWER Active: ±2,5% of the reading from power factor ±0.8 to 1 Reactive: ±2,5% of the reading from power factor ±0.2 to 0 Apparent: ±2,5% of the reading ENERGY Watts- hour (positive and negative) Accuracy: 2,5% Range: ±0 to 2147 MWh Parameters: three-phase Updating Time: 100 ms Var-hour (positive and negative) Accuracy: 2,5% Range: ±0 to 2147 MVArh Updating Time: 100 ms POWER FACTOR Accuracy: 0.02 FREQUENCY Accuracy: ±50 mHz Accuracy angle: 2º

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Typical 20 ppm More than 1 week

F650 Feeder Protection & Bay Controller

Technical Specifications POWER SUPPLY Options: F range LO, LOR: DC: 24 to 48 V H range HI, HIR: DC: 110 to 250 V AC: 120 to 230 V Power: 25 VA nominal, maximum 45 VA Voltage loss hold-up time: 200 ms typical, worst case 100 ms without unit reset OUTPUTS TRIPPING CONTACTS/OUTPUT RELAYS Permanent current Carry continous 16 A Closing current Make and Carry for 1 second 60 A during 1 second Opening current 0.3 A with L/R = 40 ms at 125 Vdc 0.25 A with L/R = 40 ms at 250 Vdc REMOTE OUTPUTS Standard output points 32 User output points 32

CAN PORT: Type: Cable or Multimode glass F.O. port with ST connectors Fiber Wave length: 1300 nm Isolation: 2kV ETHERNET PORT: Type: Model B: 10/100BaseTX self-negotiable Model C: 10/100BaseTX + 100Base FX with ST connectors Model D: 10/100BaseTX + Double 100BaseFX with ST connectors (physical media redundancy) Model E: Redundant 10/100BaseTX Protocols: ModBus® TCP/IP DNP over TCP/IP and UDP/IP IEC 60870-5-104 IEC 61850 Http, ftp, tftp (allow the use of a standard Internet browser) NOTES: In Models C and D, the 10/100BaseTX port is selected by an internal switch. Two indicating LEDs for transmission and reception are included

Feeder Protection

COMMUNICATIONS FRONT PORT (COM2): Type: RS232 Baude Rate: 300, 600, 1200, 2400, 4800, 9600, 38400, 57600 and 115200 bauds Default baud rate: 19200 bauds Protocol: ModBus® RTU / DNP 3.0 ASYNCHRONOUS REAR PORTS: Two COM1, COM2 (rear COM2 multiplexed with front port) Type: Depending on model Two RS485 ports Two 1mm-plastic F.O. ports Two multimode glass F.O. ports with ST connectors. PROTOCOLS: IEC 60870-5-103 on COM1 DNP on COM1 & COM2 Serial Modbus® on COM1 & COM2

TYPE TESTS CATEGORY STANDARD CLASS TEST EMC IEC 61000-4-1 IEC 60255-22-1 III Oscillatory waves immunity IEC 61000-4-2 IEC 60255-22-2 IV Electrostatic dis- charge immunity test IEC 61000-4-3 IEC 60255-22-3 III Radiated electro magnetic field disturbance test IEC 61000-4-4 IEC 60255-22-4 IV Electrical fast transient IEC 61000-4-5 IEC 60255-22-5 IVA Surge immunity test IEC 61000-4-6 IEC 60255-22-6 III Conducted electro- magnetic field disturbance test IEC 61000-4-8 EN 61000-4-8 IV Power frequency magnetic field immunity ENV50204 III Radiated electro magnetic field disturbance test - 1890 MHz. TYPE TESTS CATEGORY STANDARD CLASS TEST EMC IEC 60255-25 EN 61000-6-4 A Conducted and Emisivity radiated emissions Product IEC 60255-5 2 kV Insulation resistance - dielectric test IEC 60255-5 6kV .5J Impulse test IEC 60255-11 100ms Power supply Voltagedips/inter ruptions/variations: Mechanical IEC 60255-21-1 I Vibration test (sinusoidal) IEC 60255-21-2 I Shock and bump IEC 60255-21-2 II Seismic MECHANICAL CHARACTERISTICS Metallic package in 1/2 19" rack 6 units high Protection class IP52 (according to IEC 529) CONTROL Graphical display: English, Spanish, French and Chinese Basic display: English, Spanish, French, Chinese and Cyrilic PACKAGING Approximate weight: Net: 11 lbs (5 kg) Ship: 13.2 lbs (6 kg) ENVIRONMENTAL Temperature: Storage: -40 to +80° C Operation: -20 to +60° C Humidity: Up to 95% without condensing APPROVALS CE: Conforms to EN/IEC 60255, 61010 UL: UL508 Certicfied under E234610 *Specifications subject to change without notice.

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Ordering F650

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*

*

F

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G *

*

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*

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DISPLAY B M N REAR SERIAL COMMUNICATIONS BOARD 1 F A P G X Y Z C M REAR ETHERNET COMMUNICATIONS BOARD 2 B C D E I/O BOARD IN SLOT F 1 2 4 5 I/O BOARD IN SLOT G 0 1 4 5 AUXILIARY VOLTAGE LO HI LOR HIR LANGUAGE - C F P S COMMUNICATION PROTOCOL - 3 6 ENVIRONMENTAL PROTECTION - H ENHANCED DISPLAY - E

DESCRIPTION

Basic alfanumeric Text Display Graphic Display (without IEC symbols) Graphic Display with IEC symbols None Redundant RS485 Redundant plasticfiber optic Redundant glass fiber optic Redundant RS485 + fiber remote CAN bus I/O Redundant plastic fiber optic + fiber remote CAN bus I/O Redundant glass fiber optic + fiber remote CAN bus I/O Cable Remote CAN Bus I/O RS485 + cable Remote CAN Bus I/O 10/100 Base TX 10/100 Base TX + 100 Base FX 10/100 Base TX + Redundant 100 Base FX Redundant 10/100 Base TX 16 Digital Inputs + 8 Outputs 8 Digital Inputs + 8 Outputs + 2 trip/close circuit supervision circuits 32 Digital Inputs 16 Digital Inputs + 8 Analog Inputs None 16 Digital Inputs + 8 Outputs 32 Digital Inputs (See Note 1) 16 Digital Inputs + 8 Analog Inputs (See Note 1) 24-48 Vdc (range 19.2 - 57.6) 110- 250 Vdc (range 88 – 300) 120-230 Vac (range 96 – 250) Redundant LO Redundant HI English/English Chinese/English (See Note 2) French/English Russian/English (See Note 2) Spanish/English Modbus® RTU, TCP/IP, DNP 3.0 Level 2, IEC 60870-5-104 IEC 60870-5-103, Modbus® RTU, TCP/IP IEC61850, Modbus® RTU and TCP/IP, DNP 3.0 Level 2, IEC 60870-5-104 Without Harsh (Chemical) Environment Conformal Coating Harsh (Chemical) Environment Conformal Coating Display with RS232 Enhanced Display with Front USB port

SPECIAL MODELS: MOD001: 6A output contacts instead of 16A.. (*) Notes: (1) The number selected for option G must be equal or higher than the number selected for option F for models including boards 4 and 5. (2) Display options with language selection: Graphic display (M & N): available for English, French, Spanish and Chinese languages. For chinese only IEC symbols option is available (N in ordering code). Basic display (B): available for English, French, Spanish, Russian and Chinese languages

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12818-(E) English 150121

Multilin™ 350 Intuitive and Innovative Feeder Protection The Multilin 350 is a member of the Multilin 3 Series protective relay platform and has been designed for the protection, control and management of feeders or related applications as a primary or backup protection device. This cost- effective protective device is used to perform advanced feeder protection, control and monitoring in a draw-out or non draw-out design in low, medium and high voltage applications.

Protection and Control

The 350 also offers enhanced features such as metering, monitoring and diagnostics, preventative maintenance, advanced communications and security.

• Wide variety of protection curves

Key Benefits

Metering & Monitoring

• Cost-effective and flexible protection and control device for distribution and industrial feeder applications

• Comprehensive overcurrent, voltage and frequency functions • Synchrocheck & Breaker Failure • Thermal Model Protection

• Comprehensive metering

• Ease of use and setup in one simple step

• Event Recorder: 256 events with 1ms time stamping

• Environmental monitoring system to alarm on destructive operating conditions and plan preventive maintenance

• 32 samples per cycle oscillography

• Advanced power system diagnostics • Flexible communications with multiple ports & protocols allowing seamless integration • Arc flash mitigation via zone inter-tripping, flex curves, and multiple settings group • Powerful Security Audit Trail tool to increase security and minimize system risks • Application flexibility with the use of programmable logic elements • Effortless draw-out construction eliminates requirement for test switches • Draw out or non draw out options available • Increase network availability by reducing failover time to zero through IEC 62439-3 “PRP” support • Accelerated Life Cycle Tested ensuring reliability

Applications • Primary protection and control for medium and high voltage distribution utility and industrial overhead or cable feeder applications

• IRIG-B or IEEE 1588 time synchronization • Security audit trail & password control • Relay health diagnostics

Communications • Front USB and rear serial, Ethernet, Fiber & dual port options for seamless redundancy (IEC 62439, PRP & HSR) • Multiple Communication Protocols including IEC 61850, IEC 61850 GOOSE, MODBUS TCP/ IP, MODBUS RTU, DNP 3.0, IEC60870-5-104, IEC60870-5-103 & OPC-UA (IEC 62541)

EnerVista™ Softwares

• Protection of small and medium size distribution transformers

• Simplify setup and configuration

• Back-up protection of various HV applications • Capacitor bank protection

• Strong document archive and management system

• Advanced control applications including Cold Load Pickup, multi-shot recloser and multiple setting groups

• Full featured monitoring and data recording • Maintenance & troubleshooting tool • Seamless integration toolkit

350 Feeder Protection System

Overview

Easy to Use

Advanced Communications

The 350 relay is a member of the 3 Series family of Multilin relays. This protective device is used to perform primary circuit protection on medium voltage feeders and down stream protection for distribution utilities.

Drawout Construction

Easy integration into new or existing infrastructure

Feeder Protection

The basic protection function of this relay includes multiple phase, ground, and neutral time and instantaneous overcurrent elements for coordination with upstream and downstream devices. Additionally, the device provides essential feeder breaker control features such as cold load pick up blocking, breaker failure, and auto reclose. The robust 350 streamlines user work flow processes and simplifies engineering tasks such as configuration, wiring, testing, commissioning, and maintenance. This cost-effective relay also offers enhanced features such as diagnostics, preventative maintenance, arc flash mitigation and security.

The 350 offers a complete drawout feature eliminating the need for rewiring after testing has been concluded. The withdrawable feature also eliminates the need to open the switch gear door and disconnect communication cables, eg. Ethernet fiber, copper, RJ45, etc prior to removing the relay from the chasis

Effortless Retrofit The small and compact 350 enables multiple relays to be mounted side by side on medium voltage panels. It also allows easy retrofit into existing S1 and S2 cutouts with adapter plates.

Easy to Configure Fast & Simple Configuration The 350 requires minimal settings for configuring standard feeder protection applications. The entire feeder protection setup can be completed in one easy step.

With several Ethernet and serial port options, and a variety of protocols, the 350 provides advanced and flexible communication selections for new and existing energy management, SCADA, and DCS systems.

Enhanced Diagnostics Preventative Maintenance The 350 allows users to track relay exposure to extreme environmental conditions by monitoring and alarming at high ambient temperatures. This data allows users to proactively schedule regular maintenance work and schedule upgrade activities. The diagnostics data enables the user to understand degradation of electronics due to extreme conditions.

350 Relay Features

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Easy to Configure - 1 simple step

Advanced & Flexible Communication Options

Easy to Use - Draw out case

Diagnostic Alarms

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350 Feeder Protection System

Cost Effective

Multiple time current curves are available including IAC, IEC, ANSI and IEEE curves. Additional user programmable flex curves can be used to customize and meet specific coordination requirements. The TOC has both linear and instantaneous reset timing function to coordinate with electro-mechanical relays ®

Robust Design The 350 is subjected to Accelerated Life Testing (ALT) to validate accurate relay function under specified normal conditions. The device is further tested for durability through Highly Accelerated Life Testing (HALT) where it undergoes extreme operating conditions. The robust 350 design ensures long term operation.

Reduced Life Cycle Cost

Multiple Options Several option for protection & communications are provided to match basic to high end application requirements.

Protection The 350 feeder protection system offers protection, control and monitoring in one integrated, economical and compact package.

Timed Overcurrent (Phase, Ground, Neutral) The 350 has three-phase TOC elements which enables coordination with upstream and downstream protection devices such as fuses, overload relays, etc to maximize fault selectivity and minimize interruptions and downtime.

The instantaneous element provides fast clearance of high magnitude faults to prevent damage to the power infrastructure and the equipment connected to it.

Neutral Overcurrent The neutral signal is derived as the residual sum of the three phase CTs eliminating the need for an additional ground sensor.

Sensitive Ground Overcurrent Sensitive ground protection feature detects ground faults on high impedance grounded systems in order to limit damage to conductors and equipment. Special low ratio CT’s are used for this purpose to detect low magnitude ground faults.

Ground Directional The Ground Directional element is used to discriminate whether a fault occurs in a forward or in a reverse direction, and it can be used either individually or as a part of the Ground Time, or Instantaneous over-current elements.

Neutral Directional The Neutral Directional element is used to discriminate between faults that occur in the forward direction, and faults that occur in the reverse direction. The Neutral Directional element can be used either individually for control or alarm by energizing the auxiliary output relays, or as a part of the Neutral Time, or Instantaneous, over-current elements to define the tripping direction.

Over/Under Voltage Protection Overvoltage/Undervoltage protection features can cause a trip or generate an alarm when the voltage exceeds a specified voltage setting for a specified time.

Directional Overcurrent (Phase)

Frequency Protection

This element is intended to send a directional signal to an overcurrent element to prevent an operation when current is flowing in a particular direction.

The 350 offers over frequency and underfrequency elements to improve network (grid) stability using voltage or frequency based load shedding techniques.

The direction of current flow is determined by measuring the phase angle between the current from the phase CTs and the line-line voltage

It also provides back up protection when protecting feeders and other frequency sensitive power equipment.

Functional Block Diagram

ANSI Device Numbers & Functions ®

DEVICE NUMBER 25 27X 49 50P 50N 50G 50BF 50_2 51P 51G 51N 67P 59P 59X 59N 59_2 67G 67N 79 81U 81O CLP

FUNCTION Function Synchrocheck Auxiliary Undervoltage Thermal Model Phase Instantaneous Overcurrent Neutral Instantaneous Overcurrent Ground/Sensitive Ground Instantaneous Overcurrent Breaker Failure Negative Sequence Overcurrent Phase Timed Overcurrent Ground Timed Overcurrent Neutral Timed Overcurrent Phase Directional Overcurrent Phase Overvoltage Auxiliary Overvoltage Neutral Overvoltage Negative Sequence Overvoltage Ground Directional Overcurrent Neutral Directional Overcurrent Autoreclose Underfrequency Overfrequency Cold Load Pickup

Latched Lockout available as a standard feature

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Feeder Protection

The 350 is designed to reduce total installation and life cycle cost for feeder protection. The draw out construction of the device reduces downtime during maintenance and decreases extra wiring needed for relay testing and commissioning.

Instantaneous Overcurrent (Phase, Ground, Neutral)

from the other two phases. The Maximum Torque Angle (MTA) can be set from 0º to 359º in steps of 1°.

350 Feeder Protection System

Synchronism Check

Logic Designer

The Synchrocheck element is used for monitoring the connection of two parts of the circuit by the close of a breaker. Breaker closing can be supervised by ΔV, Δf and ΔHz setpoints. This element verifies that voltages at both sides of the breaker are within the magnitude, angle and frequency limits set by the user before closing the breaker, in order to minimize internal damage that could occur due to the voltage difference, both in magnitude and angle.

Feeder Protection

Arc Flash Mitigation The 350 relay is equipped with multiple setting groups and two user definable inverse curves -FlexCurves A and B for fast and reliable arcflash mitigation and breaker operation. In the event of an arc-flash, the relay can be set to communicate to any upstream or downstream devices via IEC 61850 GOOSE messaging.

Cable Thermal Model The cable thermal modelelement protects feeder cables against overheating due to excessive load. It estimates the temperature rise of current carrying conductors based on the amount of current flow (I2R) and alarms when temperature rise exceeds a threshold value. This protection feature is essential to ensure the longevity of electrical feeders; particularly important to prevent premature cable failures, expensive repair costs and system down time.

Neutral/Ground Directional Overcurrent The directional ground overcurrent isolates faulted feeders in ring bus or parallel feeder arrangements. It also allows detection of back feed of fault current from feeders with motors.

Control Cold Load Pick Up Cold Load Pick up allows automatic or manual blocking or raising of trip settings for a period after the breaker has been closed. This feature adapts the pick up of overcurrent elements to override the higher overload currents resulting from re-energization of feeder after a long period of time.

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Sixteen logic elements available for applications such as manual control, interlocking, and peer to peer tripping.

Breaker Failure The Breaker Failure function is used to determine when a trip command sent to a breaker has not been executed within a selectable time delay. In the event of a breaker failure, the 350 will issue an additional signal to trip the breakers connected to the same busbar or signal the trip of upstream breakers.

Autoreclose Reclose can be initiated externally or from an overcurrent protection. Up to four reclose operations are available, each with a programmable dead time. For each reclose shot, the relay can be programmed to block any overcurrent element.

Automation and Integration Inputs & Outputs The 350 features the following inputs and outputs for monitoring and control of typical feeder applications: • 10 contact Inputs with programmable thresholds • 2 Form A output relays for breaker trip and close with coil monitoring • 5 Form C output relays

In addition, the 350 also supports IEC 61850 GOOSE communication, providing a means of sharing digital point state information between 350’s or other IEC 61850 compliant IED’s. • Eliminates the need for hardwiring contact inputs to contact outputs via communication messaging. • Transmits information from one relay to the next in as fast as 8 ms. • Enables sequence coordination with upstream and downstream devices. • When Breaker Open operation malfunctions, GOOSE messaging sends a signal to the upstream breaker to trip and clear the fault.

Logic Elements The 350 relay has sixteen Logic Elements available for the user to build simple logic using the state of any programmed contact, virtual, remote input or the output operand of a protection or control element. The logic provides for assigning up to three triggering inputs in an “AND/OR” gate for the logic element operation and up to three blocking inputs in an “AND/OR” gate for defining the block signal. Pickup and dropout timers are available for delaying the logic element operation and reset respectively.

IEC 61850 GOOSE

Virtual Inputs

The 350 supports IEC 61850 Logical Nodes which allows for digital communications to DCS, SCADA and higher level control systems.

Virtual inputs allow communication devices the ability to write digital commands to the 350 relay. These commands could be open/close the breaker, changing setting groups, or blocking protection elements.

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350 Feeder Protection System

Multiple Settings Group

Trip/Close Coil Monitoring

Two separate settings groups are stored in nonvolatile memory, with only one group active at a given time. Switching between setting groups 1 and 2 can be done by means of a setting, a communication command or contact input activation.

The 350 can be used to monitor the integrity of both the breaker trip and closing coils and circuits. The supervision inputs monitor both the battery voltage level, while the outputs monitor the continuity of the trip and/or closing circuits, by applying a small current through the circuits.

The two settings groups allow users to store seasonal settings- such as for summer and winter or alternate profiles such as settings during maintenance operations.

Basic Metering

Monitoring & Diagnostics Event Recording

Oscillography/ Transient Fault Recorder The 350 captures current and voltage waveforms and digital channels at 32 samples per cycle. Multiple records can be stored in the relay at any given time with a maximum length of 192 cycles Oscillography is triggered either by internal signals or an external contact.

• Current: Ia, Ib, Ic, In, Ig, Isg • Phase-to-phase and phase-to-ground voltages for bus and line: Van, Vbn, Vcn, Vab, Vbc, Vca • Active power (3-Phase) • Reactive power (3-Phase) • Frequency

Advanced Device Health Diagnostics The 350 performs comprehensive device health diagnostic tests during startup and continuously at runtime to test its own major functions and critical hardware. These diagnostic tests monitor for conditions that could impact system reliability. Device status is communicated via SCADA communications and the front panel display. This continuous monitoring and early detection of possible issues helps improve system availability by employing predictive maintenance.

Temperature Monitoring The 350 continually monitors ambient temperature around the relay and alarms when the device is exposed to extreme temperatures and undesirable conditions such as airconditioning unit or station heater failures. The EnerVista Viewpoint maintenance tool allows users to review and analyze the time period a 350 relay is exposed to certain temperature ranges.

Security Security Audit Trail The Security Audit Trail feature provides complete traceability of relay setting changes at any given time and is NERC CIP compliant. The 350 maintains a history of the last 10 changes made to the 350 configuration, including modifications to settings and firmware upgrades. Security Setting Reports include the following information: • If Password was required to change settings

IRIG-B IRIG-B is a standard time code format that allows time stamping of events to be synchronized among connected devices within 1 millisecond.

• MAC address of user making setting changes • Listing of modified changes • Method of setting changes - Keypad, Front serial port, Ethernet, etc.

Power System Troubleshooting Analyze power system disturbances with transient fault recorder and event records

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Feeder Protection

Events consist of a broad range of change of state occurrences, including pickups, trips, contact operations, alarms and self test status. The 350 relay stores up to 256 events time tagged to the nearest millisecond. This provides the information required to determine sequence of events which facilitates diagnosis of relay operation. Event types are individually maskable in order to avoid the generation of undesired events, and includes the metered values at the moment of the event.

Metered values include:

An IRIG-B input is provided in the 350 to allow time synchronization using a GPS clock over a wide area. The 350 IRIG-B supports both AM and DC time synchronization with an auto detect feature that removes the requirement for manual selection.

350 Feeder Protection System

Password Control With the implementation of the Password Security feature in the 350 relay, extra measures have been taken to ensure unauthorized changes are not made to the relay. When password security is enabled, changing of setpoints or issuing of commands will require passwords to be entered. Separate passwords are supported for remote and local operators, and separate access levels support changing of setpoints or sending commands.

Feeder Protection

Advanced Communications The 350 incorporates the latest communication technologies making it the easiest and the most flexible feeder protection relay for use and integration into new and existing infrastructures. The 350 relay provides the user with one front USB and one rear RS485 communication port. Also available with the 350 is a rear communication port with Ethernet Fiber and Copper. In case of implementing PRP and HSR redundancy protocols, the 350 provides two rear Fiber ports. Through the use of these ports, continuous monitoring and control from a remote computer, SCADA system or PLC is possible.

The 350 provides optional Parallel Redundancy Protocol (PRP) and High Availability Seamless Ring (HSR) according to the IEC 62439-3 standard that defines two protocols to increase network availability by reducing failover time to zero. Both ports are capable of simultaneously supporting the following protocols: Modbus TCP/IP, IEC61850 GOOSE & Server model, DNP3 or IEC60870-5-104, TFTP, IEEE 1588, SNTP and OPC-UA. The 350 supports popular industry standard protocols enabling easy, direct integration into electrical SCADA and HMI systems. The protocols supported by the 350 include: • IEC 61850

• Modbus TCP/IP

• IEC 61850 GOOSE

• IEC 60870-5-103

• DNP 3.0

• IEC 60870-5-104

• Modbus RTU The 350 relay provides Precision Time Protocol (PTP) based on IEEE 1588 for precise time synchronization throughout a network. OPC-UA is another feature based on IEC 62541 that the 350 relay offers. These protocols make it easy to connect to a Utility or Industrial automation system, eliminating the need for external protocol converter devices.

EnerVista Software The EnerVista suite is an industry leading set of software programs that simplifies every aspect of using the 350 relay. The EnerVista suite provides all the tools to monitor the status of the protected asset, maintain the relay, and integrate the information measured into DCS or SCADA monitoring systems. Convenient COMTRADE and sequence of event viewers are an integral part of the 350 set up software and are included to ensure proper protection and system operation.

Simplified Feeder Setup The 350 Feeder Protection System includes a simplified setup process. This simplified feeder setup consists of minimal settings and can be accessed through the relay front panel or via the EnerVista Setup software. Once the information is entered, the simplified setup will generate a settings file, provide documentation indicating which settings are enabled, and an explanation of the parameters entered.

Viewpoint Monitoring Viewpoint Monitoring is a simple to use and full featured monitoring and data recording software package for small systems. Viewpoint monitoring provides a complete HMI package with the following functionality: • Plug and play device monitoring • System single line monitoring and control • Annunciator alarm screens • Trending reports • Automatic event retrieval • Automatic waveform retrieval

Display A 4 line liquid crystal display (LCD) allows visibility under varied lighting conditions. When the keypad and display are not being used, the metering summary page is displayed to show critical metered values.

LEDs The 350 relay has twelve* LED’s (8 programmable) that provide status indication for various conditions of the relay and the system. The LED indications are color coded to indicate the type of event. * 10 non programmable LEDs for the non draw out design Trace any setting changes with security audit trail

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350 Feeder Protection System

Feeder protection settings in one easy step

Feeder Protection

Fast and accurate configuration in one simple screen.

3 Series setup software protection summary for viewing a summary of Protection & Control configuration.

User Interface SETPOINT GROUP 1, 2: These indicators are continuously on if corresponding group provides settings for protection elements. TRIP: Indicator turns on when relay detects a trip condition. Operates the Trip Relay to open the breaker. ALARM: While relay detects an alarm condition, indicator flashes. PICKUP: Indicator lights steady when any protection feature pickup threshold exceeded.

DISPLAY: 4 line text for easy viewing of key data

LEDs: 10/12 LED indicators for quick diagnostics

KEYPAD: Ten button keypad for access to device interrogation and change of settings.

FRONT PORT: Electrically isolated front USB communication port USER INTERFACE OPTIONS: Draw out and non draw out options available

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Dimensions

Front

DRAW-OUT DESIGN H

Top

NON DRAW-OUT DESIGN

in

mm

in

mm

7.93

201.5

7.98

202.7

W

6.62

168.2

6.23

158.2

D

9.62

244.2

9.35

237.5

W1

3.96

100.6

3.96

100.6

D1

7.89

200.4

7.88

200.2

D2

1.73

43.8

1.47

37.3

H1

6.82

173.2

6.82

173.2

W1

H

D2

D1

W

D

Side

Feeder Protection

Rear

H1

Mounting

5.350” ±0.010” (131.1 mm ±0.25mm) 4.100” ±0.010” (104.1 mm ±0.25 mm)

L

C Φ 0.200” (5.1 mm)

6.900” ±0.010” (175.3 mm ±0.25 mm)

L

C

300

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6.000” ±0.010” (152.4 mm ±0.25 mm) 4.000” ±0.010” (101.6 mm ±0.25 mm)

350 Feeder Protection System

Typical Wiring Diagram DIRECTION OF POWER FLOW FOR POSITIVE WATTS POSITIVE DIRECTION OF LAGGING VARs

A B C

FEEDER Cts

BUS Vts

FEEDER

1A OR 5A

52

WYE VT CONNECTION CONNECT AUX_VT AS REQUIRED

+ CONTROL - POWER E9 D9 E10D10E11D11E12D12

E5 D5 E6 D6 E7 D7 E8 D8 IA

IB

IC

IB

IC

IG

VA V A V B V B V C V C V X V X

IG

B1 A1

B2

+ -

chassis gnd

Feeder Protection

IA

POWER SUPPLY

VOLTAGE INPUTS

CURRENT INPUTS

GROUND BUS

Breaker Aux Contacts GE Multilin

52a

C2 52b (C1 #2) C3 INPUT 3 C4 INPUT 4 C5 INPUT 5 C6 INPUT 6 C7 INPUT 7 C8 INPUT 8 C9 INPUT 9 C10 INPUT 10 C11 COMMON

DIGITAL INPUTS

52b

350 Feeder Protection System

A3

3 AUXILIARY

B6 A6

4 AUXILIARY

A7

CLOSE CIRCUIT

52b

B7 B8 A8 5 AUXILIARY

USB TYPE B

6 AUXILIARY

USB

B9 A9 B10 A10 B11

Rear Pane l ETHERNET RJ45 mTRJ

10/100 BASE-T

+ CLOSE COIL

A4 B5 A5

TRIP CIRCUIT

52a

B4 2 CLOSE V

Front Panel

4 WIRE USB

TRIP COIL

B3 V

C12 CHASSIS GND PERSONAL COMPUTER

+

A2 1 TRIP

C1 52a (C1 #1)

100 BASE-FX

4 WIRE ETHERNET

OPTIONAL

COMMUNICATIONS

IRIG-B

- +

RS485 COM

- +

7 CRITICAL FAILURE RELAY

A11

OUTPUT CONTACTS SHOWN WITH NO CONTROL POWER

B12 A12 OPEN DELTA VT CONNECTION

F2 F1 F5 F4 F3

GROUND BUS SEE COMMUNICATIONS WIRING IN INSTRUCTION MANUAL

COM

E9 D9 E10D10 E11 D11

RS485

898728.CDR

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350 Feeder Protection System

Technical Specifications

Feeder Protection

PHASE/NEUTRAL/GROUND TIME OVERCURRENT (51P/51N/51G) Pickup Level: 0.05 to 20.00 x CT in steps of 0.01 x CT Dropout Level: 97 to 99% of Pickup @ I > 1 x CT Pickup - 0.02 x CT @ I < 1 x CT Curve Shape: ANSI Extremely/Very/Moderately/ Normally Inverse Definite Time (0.05 s base curve) IEC Curve A/B/C/Short IAC Extreme/Very/Inverse/Short User Curve, FlexCurve™ A/B (programmable curves) Curve Multiplier: 0.05 to 50.00 in steps of 0.01 Reset Time: Instantaneous, Linear Time Delay ±3% of expected inverse time or 1 cycle, Accuracy: whichever is greater Level Accuracy: per CT input SENSITIVE GROUND TIME OVERCURRENT (51SG) Pickup Level: 0.005 to 3 x CT in steps of 0.001 x CT Dropout Level: 97 to 99% of Pickup @ I > 0.1 x CT Pickup - 0.002 x CT @ I < 0.1 x CT Curve Shape: ANSI Extremely/Very/Moderately/ Normally Inverse DefiniteTime IEC Curve A/B/C/Short Inverse IAC Extreme/Very/Inverse/Short Inverse User Curve, FlexCurve™ A/B Curve Multiplier: 0.05 to 50.00 in steps of 0.01 Reset Time: Instantaneous, Linear Time Delay ±3% of expected inverse time or 1 cycle, Accuracy: whichever is greater Level Accuracy: per CT input PHASE/NEUTRAL/GROUND NEGATIVE SEQUENCE INSTANTANEOUS OVERCURRENT (50P/50N/50G/50_2) Pickup Level: 0.05 to 20 x CT in steps of 0.01 x CT Dropout Level: 97 to 99% of Pickup @ I > 1 x CT Pickup - 0.02 x CT @ I <1 x CT Time delay: 0.00 to 300.00 sec in steps of 0.01 Operate Time: <30 ms @ 60Hz (I > 2.0 x PKP, No time delay) <35 ms @ 50Hz (I > 2.0 x PKP, No time delay) Time Delay 0 to 1 cycle (Time Delay selected) Accuracy: Level Accuracy: per CT input SENSITIVE GROUND INSTANTANEOUS OVERCURRENT (50SG) Pickup Level: 0.005 to 3 x CT in steps of 0.001 x CT Dropout Level: 97 to 99% of Pickup @ I > 0.1 x CT Pickup - 0.002 x CT @ I < 0.1 x CT Time delay: 0.00 to 300.00 sec in steps of 0.01 Operate Time: <30 ms @ 60Hz (I > 2.0 x PKP, No time delay) <35 ms @ 50Hz (I > 2.0 x PKP, No time delay) Time Delay 0 to 1 cycle (Time Delay selected) Accuracy: Level Accuracy: per CT input PHASE DIRECTIONAL (67P) Directionality: Co-existing forward and reverse Operating: Phase Current (Ia, Ib, Ic) Polarizing Voltage: Quadrature Voltage (ABC phase sequence: Vbc, Vca, Vab) (CBA phase sequence: Vcb, Vac, Vba) Polarizing Voltage 0.05 to 1.25 x VT in steps of 0.01 Threshold MTA From 0º to 359º in steps of 1° Angle Accuracy: ±4º Operation Delay: 20 to 30 ms GROUND DIRECTIONAL (67G) Directionality: Co-existing forward and reverse Operating: Ground Current (Ig) Polarizing Voltage: V calculated using phase voltages (VTs must be connected in “Wye”) - 3V measured from Vaux input . (3V provided by an external open delta connection). MTA: From 0° to 359° in steps of 1° Angle Accuracy: ±4º Operation Delay: 20 to 30 ms 0

0

METERING SPECIFICATIONS Parameter 3-Phase Real Power (MW) 3-Phase Reactive Power (Mvar) 3-Phase Apparent Power (MVA) Power Factor Frequency

302

0

Accuracy ±1% of full scale ±1% of full scale ±1% of full scale ±0.05 ±0.05 Hz

NEUTRAL DIRECTIONAL (67N) Directionality: Co-existing forward and reverse Polarizing: Voltage, Current, Dual Polarizing Voltage: V calculated using phase voltages (VTs must be connected in “Wye”) - 3V measured by Vaux input (3V provided by an external open delta connection). Polarizing Current: Ig MTA: From 0° to 359° in steps of 1° Angle Accuracy: ±4º Operation Delay: 20 to 30 ms 0

0

0

PHASE/AUXILIARY UNDERVOLTAGE (27P/27X) Minimum Voltage: Programmable from 0.00 to 1.25 x VT in steps of 0.01 Pickup Level: 0.00 to 1.25 x VT in steps of 0.01 Dropout Level: 101 to 104% of pickup Curve: Definite Time, Inverse Time Time Delay: 0.0 to 600.0 s in steps of 0.1 Operate Time: Time delay ±30 ms @ 60Hz (V < 0.85 x PKP) Time delay ±40 ms @ 50Hz (V < 0.85 x PKP) Time Delay ±3% of expected inverse time or 1 Accuracy: cycle, whichever is greater Level Accuracy: Per voltage input PHASE/AUXILIARY/NEUTRAL/NEG SEQ OVERVOLTAGE (59P/59X/59N/59_2) Minimum Voltage: Programmable from 0.00 to 1.25 x VT in steps of 0.01 Pickup Level: 0.00 to 1.25 x VT in steps of 0.01 Dropout Level: 96 to 99% of pickup Time Delay: 0.0 to 600.0 s in steps of 0.1 Operate Time: Time delay ±35 ms @ 60Hz (V > 1.1 x PKP) Time delay ±40 ms @ 50Hz (V > 1.1 x PKP) Time Delay 0 to 1 cycle (Time Delay selected) Accuracy: Level Accuracy: Per voltage input UNDERFREQUENCY (81U) Minimum Voltage: 0.00 to 1.25 x VT in steps of 0.01 Pickup Level: 40.00 to 70.00 Hz in steps of 0.01 Dropout Level: Pickup +0.03 Hz Time Delay: 0.0 to 600.0 s in steps of 0.1 Time Delay 0 to 6 cycles (Time Delay selected) Accuracy: Operate Time: Typically 10 cycles @ 0.1Hz/s change Level Accuracy:

±0.01 Hz

OVERFREQUENCY (81O) Pickup Level: 40.00 to 70.00 Hz in steps of 0.01 Dropout Level: Pickup -0.03 Hz Time Delay: 0.0 to 600.0 s in steps of 0.1 Time Delay 0 to 6 cycles (Time Delay selected) Accuracy: Operate Time: Typically 10 cycles @ 0.1Hz/s change Level Accuracy: ±0.01 Hz TRANSIENT RECORDER Buffer size: 3s No. of buffers: 1x192, 3x64, 6x32 No. of channels: 14 Sampling rate: 32 samples per cycle Triggers: Manual Command Contact Input Virtual Input Logic Element Element Pickup/Trip/Dropout/Alarm Data: AC input channels Contact input state Contact output state Virtual input state Logic element state Data storage: RAM - battery backed-up

Resolution 0.1 MW 0.1 Mvar 0.1 MVA 0.01 0.01 Hz

EVENT RECORDER Number of events: Header: Content:

Range ±3000 MW ±3000 Mvar 3000 MVA -0.99 to 1.00 40.00 to 70.00 Hz

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Data Storage: CLOCK Setup: IRIG-B:

LOGIC ELEMENTS Number of logic elements: Trigger source inputs per element: Block inputs per element: Supported operations: Pickup timer: Dropout timer:

256 relay name, order code, firmware revision event number, date of event , cause of event , per-phase current , ground current , sensitive ground current , neutral current, per-phase voltage (VTs connected in “Wye”), or phase-phase voltages (VTs connected in “Delta”), system frequency, power, power factor, thermal capacity Retained for 3 days Date and time Daylight Saving Time Auto-detect (DC shift or Amplitude Modulated) Amplitude modulated: 1 to 10 V pk-pk DC shift: TTL Input impedance: 40kOhm ± 10% RTC Accuracy: ± 1 min / month 8 3 3 AND, OR, NOT, Pickup / Dropout timers 0 to 6000 ms in steps of 1 ms 0 to 6000 ms in steps of 1 ms

BREAKER CONTROL Operation: Asserted Contact Input, Logic Element, Virtual Input, Manual Command Function: Opens / closes the feeder breaker AUTORECLOSE (79) Reclose attempts: Up to 4 shots Time Delay 0 to 3 cycles (AR Dead Time selected) Accuracy: Elements: Inputs, Outputs, Breaker Status (52 status) BREAKER FAILURE (50BF) Pickup Level: 0.05 to 20.00 x CT in steps of 0.01 Dropout Level: 97 to 98% of pickup Time Delay 0 to 1 cycle (Timer 1, Timer 2) Accuracy: Level Accuracy: per CT input BREAKER TRIP COUNTER Trip Counter Limit 1 to 10000 in steps of 1 (Pickup): COLD LOAD PICKUP BLOCKING Operation: Automatically (current level), or by command (asserted input) Function: Block IOC functions, raise TOC pickup, for selected period of time Time Delay 0 to 1 cycle (block Time) Accuracy: ±50 ms (outage time? ≤?5 min) ±1 s (outage time > 5 min) AMBIENT TEMPERATURE High Temperature 20°C to 80°C in steps of 1°C Pickup: Low Temperature -40°C to 20°C in steps of 1°C Pickup: Time Delay: 1 to 60 min in steps of 1 min ±50 ms (outage time? ≤?5 min) ±1 s (outage time > 5 min) Temperature Configurable 90 to 98% of pickup Dropout: Temperature ±10°C Accuracy: Timing Accuracy: ±1 second

350 Feeder Protection System

CONTACT INPUTS Inputs: Selectable thresholds: Recognition time: Debounce time: Continuous current draw: Type: External switch: Maximum input voltage:

8 17, 33, 84, 166 VDC 1/2 cycle 1 to 64 ms, selectable, in steps of 1 ms 2 mA opto-isolated inputs wet contact 300 VDC

SENSITIVE GROUND CURRENT INPUT CT Primary: 1 to 600 A Range: 0.002 to 3 × CT Input type: 1 A or 5 A (must be specified with order) Nominal 50/60 Hz frequency: Burden: <0.1 VA at rated load Accuracy: ±1% of reading at 0.1× CT ±3% of reading from 0.02 to 3 × CT ±20% of reading from 0.002 to 0.019 × CT CT withstand: 1 second at 100 × rated current 2 seconds at 40 × rated current continuous at 3 × rated current PHASE/AUX VOLTAGE INPUTS Source VT: 0.12 to 65 kV / 50 to 220 V VT secondary: 50 to 240 V VT ratio: 1 to 5000 in steps of 1 Nominal 50/60 Hz frequency: Accuracy: ±1.0% of reading Voltage withstand: 260 VAC continuous FORM-A RELAYS Configuration: Contact material: Operate time: Continuous current: Make and carry for 0.2s: Break (DC inductive, L/R=40 ms): Break (DC resistive): Break (AC inductive): Break (AC resistive):

2 (two) electromechanical silver-alloy <8 ms 10 A

HIGH RANGE POWER SUPPLY Nominal: 120 to 240 VAC 125 to 250 VDC Range: 60 to 300 VAC (50 and 60 Hz) 84 to 250 VDC Ride-through time: 35 ms LOW RANGE POWER SUPPLY Nominal: 24 to 48 VDC Range: 20 to 60 VDC ALL RANGES Voltage withstand: 2 × highest nominal voltage for 10 ms Power 15 W nominal, 20 W maximum consumption: 20 VA nominal, 28 VA maximum SERIAL RS485 port: Baud rates: Response time: Parity: Maximum Distance: Isolation: Protocol:

Opto-coupled up to 115 kbps 1 ms typical None, Odd, Even 1200 m (4000 feet) 2 kV Modbus RTU, DNP 3.0, IEC 60870-5-103

ETHERNET (COPPER) Modes: 10/100 MB (auto-detect) Connector: RJ-45 Protocol: Modbus TCP/IP, DNP 3.0, IEC 60870-5-104, IEC 61850 GOOSE ETHERNET (FIBER) Fiber type: Wavelength: Connector: Transmit power: Receiver sensitivity: Power budget: Maximum input power: Typical distance: Duplex: Protocol:

100 MB Multi-mode 1300 nm MTRJ -20 dBm -31 dBm 9 dB -11.8 dBm 2 km (1.25 miles) half/full Modbus TCP/IP, DNP 3.0, IEC 60870-5-104, IEC 61850 GOOSE

30 A per ANSI C37.90

USB Standard Compliant with USB 2.0 specification: Data transfer rate: 115 kbps

24 V / 1 A 48 V / 0.5 A 125 V / 0.3 A 250 V / 0.2 A

CERTIFICATION

24 V / 10 A 48 V / 6 A 125 V / 0.5 A 250 V / 0.3 A 720 VA @ 250 VAC Pilot duty A300

CE:

277 VAC / 10 A

North America: ISO:

Low voltage directive EN60255-5 / EN60255-27 / EN61010-1 EMC Directive EN60255-26/EN50263, EN61000-6-2, UL508 cULus UL1053, C22.2.No 14 Manufactured under a registered quality program ISO9001

FORM-A VOLTAGE MONITOR Applicable voltage: 20 to 250 VDC Trickle current: 1 to 2.5 mA FORM-C RELAYS Configuration: Contact material: Operate time: Continuous current: Make and carry for 0.2s: Break (DC inductive, L/R=40 ms): Break (DC resistive): Break (AC inductive): Break (AC resistive):

5 (five) electromechanical silver-alloy <8 ms 10 A

TYPE TESTS Dielectric voltage withstand: Impulse voltage withstand: Damped Oscillatory: Electrostatic Discharge: RF immunity: Fast Transient Disturbance: Surge Immunity: Conducted RF Immunity: Power Frequency Immunity: Voltage interruptionand Ripple DC: Radiated & Conducted: Emissions Sinusoidal Vibration: Shock & Bump: Siesmic: Power magnetic Immunity: Pulse Magnetic Immunity: Damped Magnetic Immunity: Voltage Dip & interruption:

2.3KV EN60255-5

5KV

IEC 61000-4-18 IEC 60255-22-1 EN61000-4-2/ IEC 60255-22-2 EN61000-4-3/ IEC 60255-22-3 EN61000-4-4/ IEC 60255-22-4 EN61000-4-5/ IEC 60255-22-5 EN61000-4-6/ IEC 60255-22-6 EN61000-4-7/ IEC 60255-22-7 IEC 60255-11

2.5KV CM, 1KV DM

CISPR11 /CISPR22/ IEC 60255-25

Class A

IEC 60255-21-1

Class 1

IEC 60255-21-2 IEC 60255-21-3 IEC 61000-4-8

Class 1 Class 2 Level 5

IEC 61000-4-9

Level 4

IEC 61000-4-10

Level 4

IEC 61000-4-11

Level 4 Level 3 Class A and B Level 3 & 4 Level 3 Class A & B 15% ripple, 200ms interupts

Feeder Protection

PHASE & GROUND CURRENT INPUTS CT Primary: 1 to 6000 A Range: 0.02 to 20 × CT Input type: 1 A or 5 A (must be specified with order) Nominal 50/60 Hz frequency: Burden: <0.1 VA at rated load Accuracy: ±1% of reading at 1× CT ±3% of reading from 0.2 to 20 × CT ±20% of reading from 0.02 to 0.19 × CT CT withstand: 1 second at 100 × rated current 2 seconds at 40 × rated current continuous at 3 × rated current

TRIP / CLOSE SEAL-IN Relay 1 trip seal-in: 0.00 to 9.99 s in steps of 0.01 Relay 2 close 0.00 to 9.99 s in steps of 0.01 seal-in:

Damped Oscillatory: Conducted RF Immunity 0-150khz: Voltage Ripple: Ingress Protection:

IEC 61000-4-12

0, 40, 70, 80% dips, 250/ 300 cycle interrupts 2.5KV CM, 1KV DM

IEC 61000-4-16

Level 4

IEC 61000-4-17 IEC 60529

Environmental (Cold): Environmental (Dry heat): Relative Humidity Cyclic: EFT: Damped Oscillatrory: RF Immunity:

IEC 60068-2-1

15% ripple IP40 front , IP10 Back -40C 16 hrs

IEC 60068-2-2

85C 16hrs

IEC 60068-2-30

6day variant 2

IEEE/ANSIC37.90.2

20V/m 80-1Ghz

ESD:

IEEE/ANSIC37.90.3

8KV CD/ 15KV AD e83849 NKCR

Safety:

UL508 UL C22.2-14 UL1053

DIMENSIONS Size: Weight:

IEEE/ANSI C37.90.1 4KV, 2.5Khz IEEE/ANSI C37.90.1 2.5KV,1Mhz

e83849 NKCR7 e83849 NKCR

Refer to Dimensions Chapter 4.1 kg [9.0 lb]

OPERATING ENVIRONMENT Ambient operating –40°C to +60°C [-40°F to +140°F] temperature: Ambient storage / –40°C to +85°C [-40°F to +185°F] shipping temperature: Humidity: Operating up to 95% (non condensing) @ 55C (As per IEC 60068-2-30 Variant 2, 6days) Pollution degree: II Overvoltage III category: Ingress Protection: IP40 Front , IP10 back

30 A per ANSI C37.90 24 V / 1 A 48 V / 0.5 A 125 V / 0.3 A 250 V / 0.2 A 24 V / 10 A 48 V / 6 A 125 V / 0.5 A 250 V / 0.3 A 720 VA @ 250 VAC Pilot duty A300 277 VAC / 10 A

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Ordering 350 Base Unit Language Phase Currents

*

**

**

*

E

*

*

*

**

*

*

Description

N H

English (without programmable LEDs) English (with programmable LEDs) for Draw out option only 1A three phase current inputs 5A three phase current inputs 1A ground current input 5A ground current input 1A sensitive ground current input 5A sensitive ground current input 24 - 48 Vdc 125 - 250 Vdc/120 - 240Vac Standard faceplate (LCD, full menu, actual values and setpoints) with 10 Inputs, 7 Outputs (2 Form A, 5 Form C) Standard Overcurrent Protection - 50P(1), 50G(1), 50N(1), 51P(1), 51G(1), 51N(1) Extended Overcurrent Protection - 49, 50P(2), 50G(2), 50N(2), 51P(1), 51G(1), 51N(1) Advanced overcurrent protection - 49, 50P(2), 50G(2), 50N(2), 51P(1), 51G(1), 51N(1), 50_2 (46) No Selection CLP, 50BF, Autoreclose (79), Lockout (86) No Selection Directional Neutral Overcurrent Protection 67N(1), 67G(1) Voltage Metering Phase, Neutral and Ground Directional elements 67P(1), 67N(1), 67G(1) + Voltage Metering Voltage Protection, Phase, Neutral and Ground Directional elements - 27P(1), 27X(1), 59P(1), 59N(1), 59X(1), 59_2(1), 81O(2), 81U(2), 67P(1), 67N(1), 67G(1), VTFF(1), 25(1) Standard :Front USB, Rear RS485 : Modbus RTU, DNP3.0, IEC 60870-5-103 Standard + Ethernet (Copper & Fiber - MTRJ) MODBUS TCP/IP, DNP3.0, IEC 60870-5-104 Standard + Ethernet (Copper & Fiber - MTRJ) MODBUS TCP/IP, DNP3.0, IEC 60870-5-104, IEC 61850 GOOSE Standard + Ethernet (Copper & Fiber - MTRJ) MODBUS TCP/IP, DNP3.0, IEC 60870-5-104, IEC 61850 Standard + Ethernet (Copper & Fiber - MTRJ) MODBUS TCP/IP, DNP3.0, IEC 60870-5-104, IEC 61850, OPC-UA Standard + Ethernet PRP/HSR/1588(Fiber- MTRJ) MODBUS TCP/IP, DNP3.0, IEC 60870-5-104, IEC 61850, OPC-UA Draw-out Design Non Draw-out Design None Harsh Environment Conformal coating

350 E L P1 P5

Ground Currents

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Power Supply Faceplate Current Protection

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Control

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Note: 1) G1/G5 and S1/S5 must match corresponding P1/P5 - there cannot be 5A and 1A mixing

Accessories for the 350

Visit GEMultilin.com/350 to:

  •  Multilink Ethernet Switch

ML2400-F-HI-HI-A2-A2-A6-G1

 • Viewpoint Maintenance

VPM-1

  •  Viewpoint Monitoring IEC 61850

VP-1-61850

  •  Download the instruction manual   •  Review applications notes and support documents   •  Buy a 350 online   •  View the 350 brochure

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Multilin™ A60 Advanced Light & Pressure Arc Flash Detection System An arc flash event is the sudden release of electrical energy through the air. The resulting forces can produce temperatures up to 35,000°F, causing copper to turn into plasma expanding by 67,000 times. With these type of extreme events, fast, reliable arc flash detection is critical to avoid significant damage to equipment. The Multilin A60 Arc Flash System utilizes a unique sensing method that detects both light and pressurized sound signals that occur during an arc flash event, enabling more reliable and faster operating times to reduce the total arc energy generated. Utilizing a patented arc flash sensing method, the Multilin A60 is able to reliably detect an arc flash event in as fast as 1 msec (when compared to not having any arc flash detection device).

Key Benefits • GE patented, dual input light and pressure wave sensors for fast, reliable arc flash detection • Continuous health monitoring of optical sensors, fiber cables, and control unit to ensure reliable operation

Advanced Arc Flash Detection • GE patented, high-speed arc flash system utilizing light and pressure wave detection technology • Stand-alone unit providing continuous operation, 24/7 • Continuous self-supervision (health monitoring) of sensors, fiber cables, and arc flash relay with trouble indication • Up to five arc flash sensors per relay for detection in multiple locations within switchgear

• Direct connection to breaker trip circuit using solid state output relays, for increased operating speed • Multi-stage detection for reduced nuisance tripping with optional external current supervision input • Simplified installation and configuration with sensor auto-calibration and no requirement for additional setup software • Multiple unit connectivity and transfer trip capability to ensure optimized coverage for large applications • No requirement to install additional CT’s reducing time and costs associated with installation and commissioning

Applications • Arc flash detection system for medium voltage applications (switchgear and motor control centers) • Applications requiring arc flash mitigation • Suitable for new and existing retrofit applications

Reliable Operation • External current supervision from IOC device • Five solid state output relays for fast trip initiation • Six digital inputs with transfer trip capability for cascading applications • Arc flash sensor auto-calibration • Operating temperature range from -40°C to +60°C

Easy to Use & Install • DIN Rail mounting • Slide switches and rotary dial for device setup • No setup software required • Local and remote reset capability • Three LEDs for indication for Status, Trip, and Trouble

A60 Arc Flash Module

Overview An arc flash event is the sudden release of electrical energy through the air. The resulting forces can produce temperatures up to 35,000°F, in less than one thousandths of a second, causing copper to turn into plasma expanding by 67,000 times. The arc event remains as long as there is enough power to maintain the short circuit. With these type of extreme events, fast, reliable arc flash detection is critical for the power and process industries in order to avoid significant damage to equipment and reduce the repair and replacement costs, as well as downtime of the power system.

The light fiber picks up the flash of light from the bare fiber in the sensor and transmits that to the Multilin A60. On a second fiber an LED emits light. This light is transported through the fiber and is reflected back by the diaphragm, and collected by the same fiber back to the main unit.During an arc flash event, the diaphragm vibrates due to the pressurized sound wave creating a signature which is recognized by the Multilin A60. It is this unique combination of light and pressure wave detection that ensures reliable and fast detection of an arc flash event.

Membrane

Feeder Protection

In an arc flash event, the amount of energy generated is a direct function of time so, when considering arc flash detection or mitigation solutions, every millisecond counts.

Bare fiber

The Multilin A60 Arc Flash System utilizes a unique sensing method that detects both light and pressurized sound signals that occur during an arc flash event, enabling more reliable and faster operating times to reduce the total arc energy generated. Utilizing a patented arc flash sensing method, the Multilin A60 is able to reliably detect an arc flash event in as fast as 1 msec (when compared to not having any arc flash detection device).

Light fiber Sound/pressure fiber Mirror for light test

As an independent arc flash detection device, the Multilin A60 Arc Flash System provides wide-ranging, scalable arc flash detection for medium voltage switchgear and motor control center applications.

Figure 2: GE’s Unique Light & Pressure Sensor Technology

Advanced Sensor Technology Light and pressure wave arc flash detection

To ensure optimal coverage, the Multilin A60 supports up to five sensors per unit providing optimal coverage in a typical two-high medium voltage switchgear section. To cover a larger area or for multi-section applications, Multilin A60’s may be daisy chained together.

The Multilin A60 Arc Flash System utilizes GE’s patented light and pressure signal fiber sensor to ensure fast and reliable protection against arcing events.

Inputs & Outputs

Based on a known time relationship between the speed of light and sound, (pressure wave), GE’s patented sensor is able to detect and issue a trigger signal to clear the fault in under 2 milliseconds – significantly reducing incident energy from an arc flash event.

The Multilin A60 includes six isolated 24V dry inputs. Digital inputs are used for ‘daisy chaining’ multiple relays together or for remote control. The Multilin A60 includes five solid state output relays which may be connected directly to a fast disconnect device, such as a circuit breaker or switch for trip initiation and/or to other devices for signaling purposes. Utilizing solid state output contacts, it ensures very fast response and operating times, reducing total arc flash energy. The Multilin A60 also includes one alarm output that provides remote indication of an arc flash event.

Easy to Install & Configure Well suited for both new and existing applications As a stand-alone unit, the Multilin A60 relay is DIN rail mountable and should be mounted inside the control cabinet of the medium voltage switchgear or motor control center, making it suitable for both new and retrofit applications.

Figure I: Arc Flash Quenching Specifically, the sensor head detects these two key factors (light and pressure wave) using LEDs, bare fiber and a membrane.

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With up to five arc flash sensors per unit, sensors should be mounted and installed in proper locations where there is a high probability of an arc flash occurring. Though application dependent, please refer to Figure 3: sensor placement in a two-high design switchgear, side view for suggested sensor placement. Sensor placement will vary depending on the specific application.

GEDigitalEnergy.com

A60 Arc Flash Module

As the Multilin A60 utilizes both light and pressure to detect an arc flash condition, installation and wiring of external CT’s is not required. An external current supervision from a separate Instantaneous Over Current (IOC) device may be used and connected as a contact input on the Multilin A60 for enhanced security and mitigation of nuisance tripping.

Calibration & Testing The Multilin A60 provides an auto-calibration function for the sensors, reducing total commissioning and testing time. Once installed and powered, the device will first run in calibration mode. This mode sets the thresholds for both the light and pressurized sound, based on surrounding ambient conditions. As surrounding conditions may change, the Multilin A60 may be re-calibrated at anytime. 2

Enhanced Diagnostics

The Multilin A60 has a built-in self-test feature that runs every second during normal operating mode. This unique feature monitors the health of the sensors, the full length of the fiber cables, and the unit itself, eliminating the need for periodic testing and additional test equipment.

Feeder Protection

5

Constant self-monitoring and diagnostics to ensure reliable operation

Figure 3: The above is a representation of a Two-High design with Arc-Flash Sensors Legend:

1. Breaker 1 compartment An LED on the unit is used to indicate the health of the sensor and its 2. Breaker 2 compartment connection to the unit. Using the alarm output relay, remote health status 3. Main bus bar section indication is also provided. GE PROPRIETARY AND CONFIDENTIAL INFORMATION 4. Upper cable exit section

REVISIONS

This document is the property of General Electric Company ("GE") and contains proprietary information of GE. This document is loaned on the express condition that neither it nor the information contained therein shall be disclosed to others without the express written consent of GE Digital Energy, and that the information shall be used by the recipient only as approved expressly by GE Digital Energy. This document shall be returned to GE upon its request. This document may be subject to certain restrictions under U.S. export control laws and regulations.

REV DATE 5. Lower cable exit section

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DESCRIPTION

FIRST RELEASE

Multilin A60 Arc Flash System Dimensional Information Base unit is DIN rail mountable inside control cabinet/compartment for simplified installation

8.22" [209mm]

3.45" [88mm]

7.10" [180mm]

3.83" [97mm]

6.41" [163mm] 6.70" [170mm]

877700A1

GEDigitalEnergy.com NOTE:

FOR ADDITIONAL INFO REFER TO: APPLIED PRACTICES

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SIGNATURES

DATE

A.Z

06/01/12

MODEL

Digital Energy

A60 Arc Flash Module

Control Panel Interface The Multilin A60 faceplate provides easy device configuration and operating status though bright LED indicators, a pushbutton, slide switches and a rotary switch. Three LEDs provide indication of Status (operating mode), Trip and Trouble.

Optical Arc Flash Sensor Utilizing light and pressure detection technology in one sensor head

Simple slide switches and a rotary switch provide all the required configuration for the Multilin A60, eliminating the need for separate setup software, simplifying and reducing total setup and commissioning time.

Feeder Protection

Arc Flash Sensor Inputs – Total of five per unit

LED Indicators Status: Provides status indication of the mode of operation of the unit Trip: Indication of a trip condition Trouble: Provide indication of the health of the unit and all the sensors connected to the arc flash unit Reset: Resets the arc flash relay and the state of the solid state output relays Configuration Switches & Rotary Dial External Supervision: Enabled when an external supervision input is desired Transfer Trip: Enabled when multiple arc flash units are connected together Trip Output Disable: Used to enable or disable the output relays Aux Output Disable: Used for transfer trip to adjacent arc flash units

Power Supply connection Input and Output terminals

Outputs 1 Power Supply 110 - 250 Vdc/110 - 230 Vac

2

3

Trip from SSR 1/2/3/4/5

4

5

Remote trip output disable Transfer trip to other A60’s

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Inputs 1

2

3

4

5

6

Transfer trip from other A60s Optional IOC Supervision

Remote reset

A60 Arc Flash Module

Typical Wiring Diagrams & Application Examples The figure below shows the typical wiring diagram of the Multilin A60 Arc Flash System. The typical wiring diagram shows the connection of the input and output relays and the connected sources. The wiring diagram also shows the connection of the supervisory circuit (option) to the A60 unit.

The figure below illustrates an application of the Multilin A60 Arc Flash System. It shows how the unit is set up to detect an arc flash event in a MV (medium voltage) switchgear application. Arc flash sensors from the Multilin A60 can be installed in either different compartments or in a single compartment, depending on the size of the compartment to be monitored. If an arc flash condition is detected in a location where an arc flash sensor is installed, the unit will trip the corresponding breaker to which the output relay on the Multilin A60 is connected.

Feeder Protection

This figure describes how a cascading of multiple Multilin arc flash systems (AFS) using the transfer trip feature can be implemented. In the figure, the AFS 1 unit protects a large incoming circuit breaker compartment, and the AFS 2 sensors are connected to the outgoing feeder compartments. The Solid State Relay (SSR) 4 or 5 of the AFS 2 unit is connected to contact input 4 or 5 in order to transfer trip from the AFS 2 unit to the main circuit breaker through the AFS 1 unit. With this implementation, there is no need to extend many trip signals to the main circuit breaker. The trip signal from AFS 2 is connected to the transfer trip inputs (contact inputs 4 or 5) of the AFS 1 unit, so the transfer trip slide switch should be set to “ON” in the AFS 1 unit. This allows transferal of the AFS 2 trip to the main circuit breaker.

The figure below is an application example that describes the ability of the Multilin A60 AFS to be deployed in a cascading configuration across multiple MV switchgear sections and compartments, including through a substation bus bar vault. The Multilin A60 sensors should be installed at a certain distance from each other to ensure coverage of the entire bus bar. Refer to the Sensor coverage section in the Multilin A60 Instruction Manual for further information about the number of sensors required per compartment, and to cover the entire bus bar vault. By connecting devices together using the transfer trip input/output, individual Multilin A60 devices may receive a transfer trip signal from an upstream or downstream device, ensuring fast, reliable detection of an arc flash event in large MV switchgear applications.

CB

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SSR 1

AFS 1

SSR 1

AFS 1

Contact Input 1

Contact Input 1

Power Supply

Contact Input 6

Power Supply

Contact Input 6

Contact Input 4 or 5

Contact Input 4 or 5

Transformer

Transformer

SSR 4

AFS 2

Contact Input 1

AFS 2

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Contact Input 4 or 5

Power Supply

Contact Input 6

Power Supply

Contact Input 6

Contact Input 1

SSR 4

AFS 3

CB Contact Input 1 Contact Input 6

Power Supply

CB

AFS = Arc flash system SSR = Solid-state relay CB = Circuit breaker = Sensor

CB

CB

CB CB

GEDigitalEnergy.com

CB

AFS = Arc flash system SSR = Solid-state relay CB = Circuit breaker = Sensor

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Technical Specifications DIGITAL INPUTS

POWER SUPPLY

Total six 24 V dry inputs Isolated Current Draw @ Rated Voltage: 10 mA @ 24 V Input Impedance: 1 MΩ Type: Dry contacts

NOMINAL • 100 VAC to 240 VAC 50/60 Hz • 125 VDC to 250 VDC RANGE • 100 VDC to 300 VDC 50/60 Hz POWER CONSUMPTION Maximum Consumption: 10 W

SENSOR INPUTS Five self-monitored inputs SMI to SMI (Small Media Interface), Duplex, 2.20 mm, Plastic Optical Fiber Bend radius of 25mm max

RELAY OUTPUTS SOLID STATE RELAY OUTPUTS Maximum continuous current: 6 A Operate time : 60 μs Make and carry for 0.2s: 30 A per ANSI C37.90 SSR BREAKING CAPACITY AC Resistive, 120 VAC: 6A AC Resistive, 240 VAC: 6A AC Inductive, PF=0.4 pilot duty: 2A DC Resistive, 30 VDC: 6A FORM-C (ALARM OUTPUT) AC Resistive, 120 V AC: 6A normally open, 5A normally closed AC Resistive, 240 V AC: 6A normally open, 6A normally closed AC Inductive, PF = 0.4 pilot duty: 2.5 A DC Resistive, 30 V dc 6A

ENVIRONMENTAL SPECIFICATIONS Operating Temperature -40 °C to +60 °C Humidity Operating up to 95% (non condensing) @ 55 °C (per IEC60068-2-30 Variant 2, 6 days) Altitude 2000 m (max.) Overvoltage Category II Ingress Protection IP40 Environmental rating 60 °C surrounding air Pollution Degree II Type 1 NOTE: Final installation must not exceed IP40.

Industrial Test Certifications Compliance TEST Dielectric Voltage Withstand Impulse Voltage Withstand Insulation Resistance Test Damped Oscillatory

REFERENCE STANDARD EN60255-5

TEST LEVEL 2.3KV

EN60255-5

5KV

EN60255-5 IEC61000-4-18IEC60255-22-1

Electrostatic Discharge RF Immunity Fast Transient Disturbance Surge Immunity Conducted RF Immunity Radiated & Conducted Emissions

EN61000-4-2/IEC60255-22-2 EN61000-4-3/IEC60255-22-3 EN61000-4-4/IEC60255-22-4

500 VDC 2.5KV CM, 1KV DM Level 4 Level 3 Class A and B

EN61000-4-5/IEC60255-22-5 EN61000-4-6/IEC60255-22-6 CISPR11/CISPR22/IEC60255-25

Level 3 & 4 Level 3 Class A

TEST Sinusoidal Vibration Shock & Bump Siesmic Power Magnetic Immunity Voltage Dip & interruption

REFERENCE STANDARD IEC60255-21-1 IEC60255-21-2 IEC60255-21-3 IEC61000-4-8 IEC61000-4-11

Environmental (Cold) Environmental (Cold Storage) Environmental (Dry heat) Relative Humidity Cyclic RF Immunity

IEC60068-2-1 IEC60068-2-1

TEST LEVEL Class 1 Class 1 Class 2 Level 5 0, 40, 70, 80% dips, 250/300 cycle interrupts -20C 16 hrs -40C 16 hrs

IEC60068-2-2 IEC60068-2-30 IEEE/ANSIC37.90.2

85C 16hrs 6day variant 2 20V/m 80-1Ghz

Approvals APPLICABLECOUNCIL DIRECTIVE Low voltage directive EMC Directive Manufactured under a registered quality program

CE compliance ISO

ACCORDING TO EN60255-5/EN60255-27 EN61000-6-2/6-4 ISO9001

Ordering A60 Language Power Supply Sensors

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Description English 125 - 250V DC / 100 - 240V AC, 50/60 Hz Qty 0 to 5 - 6ft Sensors Qty 0 to 5 - 12ft Sensors Qty 0 to 5 - 18ft Sensors

NOTE: Qty 5 sensors maximum per Multilin A60, minimum 1 sensor required

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Passport.GEDigitalEnergy.com GEA-12706B(E) English 150121

Distribution Automation Distribution Automation Overview Advanced visualization technologies enable the efficient recovery of distribution systems utilizing fault isolation, sectionalization and power system restoration capacities within our wide range of distribution assets, controllers, and high accuracy measurement devices.

Featured Products Product brochures for featured Multilin distribution automation systems offered by GE.

Product Listing

Distribution Automation – Featured Products DGCM

Multilin DGCM Field RTU

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Part of a platform of Distribution Automation Controllers, the Multilin DGCM Field RTU provides advanced monitoring of low and medium voltage distribution feeders and is suitable for both pole top and pad mounted switch devices or transformer feeders. As an integrated component to a FDIR system, the Multilin Field RTU provides the asset visibility utilities need to maximize system reliability.

ILMS

Multilin Intelligent Line Monitoring System

325

Distribution Automation

The Multilin™ Intelligent Line Monitoring System is a complete solution for improving the reliability and efficiency of overhead networks. The Line Monitoring System is modular, accurate, reliable, cost effective and easy to install. It enables Utilities to remotely manage and optimize their distribution assets while minimizing outages and disruption to customer supply.

DGCS

Multilin DGCS Switch Controller

317

Part of a platform of Distribution Automation Controllers that includes a Capacitor Bank Controller and Voltage Regulator, the Multilin DGCS provides integrated fault detection, control, and Auto-Sectionalizing functionality that senses downstream faults and isolates these faulted sections based on the set auto-sectionalized shots or elapsed time. The Multilin DGCS is compatible with many switches to provide application flexibility when integrating with FDIR systems.

Go online for the full listing of Multilin Protection & Control products

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Multilin DGCM Field RTU ™

Cost-Effective Monitoring for Distribution Network Visibility

Versatile Configuration

Most distribution assets are not being monitored, mainly due to space limitations, installation cost and the cost of the monitoring device itself. The Multilin DGCM is a versatile Field RTU (Remote Terminal Unit) that can monitor and control a wide range of pole top, pad mount, and underground distribution assets. This compact solution is designed for easy installation on new equipment and retrofit on installed assets, making distribution modernization a cost-effective endeavor. The Multilin DGCM supports most wired and wireless communication architectures along with multiple simultaneous industry standard communication protocols, resulting in a seamless and straightforward integration into DMS, OMS and SCADA systems.

• Remote downloading of settings and firmware upgrades reduces trips for field crews

Key Benefits

Reliable Hardware

• Improve efficiency and reliability by integrating remote feeders into DMS/OMS/SCADA

• Wide operating temperature range (-40°C to +65°C ) for harsh environmental conditions

• Track non-technical losses with real-time energy monitoring • Receive early warning signs of asset failure and approaching capacity limits • Eliminate the need for fault passage indicators with built-in per-phase fault detection • Develop customized control schemes with an advanced logic engine and expandable I/O • Enhance fault location and load flow studies using sequence of event records & trending • Reduce setup and commissioning time with easy-to-use software tools • Suitable for use outdoors and in harsh environments (-40°C to +65°C)

Monitoring and Control Applications RMU/Pad Mounted Switchgear Local Automation, Switch Management

Pole Top/Pad Mount Transformer Transformer Monitoring, Load Flow Analysis

Cables in Vaults and Cable Joint Boxes Fault Monitoring & Early Overload Warning

Pole Top Applications Monitoring & Control

Distribution Substation, LV Systems Load Monitoring, Theft Detection

End of Line Monitoring Voltage Optimization Support Theft Detection

• Up to 18 CT and 3 VT inputs for multi-feeder monitoring and control • Up to 32 digital inputs and 16 digital outputs for connection adaptability • Support for traditional CTs/VTs and sensor inputs provides application flexibility

• Designed and tested to protection relay standards • Rugged NEMA 3, IP 44 housing

Cost-Effective Integration • Unsolicited messaging for immediate issue notification • Rogowski coil option reduces installation time • Integrated cellular modem delivers accessible communication

Compact Footprint • Scalable solution supports multiple application needs • Variable options (stand-alone, with or without HMI, with or without an enclosure) for situational requirements

DGCM Field RTU

Application Overview Overcurrent and under/over voltage conditions detected by the Multilin DGCM enable early warning signals of system issues. The Multilin DGCM also monitors for voltage, current, energy, power quality, and breaker/switch states, which facilitates efficient load planning. Using the Multilin DGCM, utilities can optimize operational planning, forecast short and long term loads, perform asset management, and achieve power quality. Additionally, the Multilin DGCM monitors asset variables, such as oil and winding temperature, oil pressure, energy release, and number of operations.

Distribution systems have grown rapidly in the past few decades, including the addition of low carbon technologies, causing increased instances of system losses and poor supply quality. In order to improve operational planning, grid efficiency, and reliability, utilities need network or topographic information, real-time load data, as well as the status of distribution assets, like transformers and feeders.

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The Multilin DGCM provides information from various field-based and substation-based assets, helping utilities achieve voltage optimization, quick fault detection, fault isolation, and prompt service restoration.

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DGCM Field RTU

Application 1: RMU/Pad Mounted Switchgear Enhancing RMUs (Ring Main Units) and pad mounted switchgear with detection functionality has its own challenges regarding the mounting of conventional MV transformers. The Multilin DGCM enables the utility to overcome these challenges by offering Rogowski coil and Low Energy Analog (LEA) compatibility for current and voltage inputs. These features enable utilities in reducing their overall cost of installation and outage time.

RMU/Pad Mounted Switchgear

M

M

M

M

M

Key Benefits Up to 64 DI & 32 DO

• Real-time load monitoring and profiling of up to 6 feeders (18 individual phases)

Up to 6 Voltage Inputs

1 to 6 Feeders

• Overcurrent detection per phase (50, 51) for each feeder to identify faulted circuits and loads approaching overload levels

Up to 6 Current Inputs

DGCM

• Expandable digital inputs and outputs enable remote switching of main incomers or outgoing switches Distribution Automation

• Support of multiple voltage sensors, such as LEA sensors and PT’s, for cost-effective power quality monitoring • Advanced FlexLogic™ engine to enable automated switching schemes • Supports traditional CT’s and Rogowski coils for quick retrofit solutions

Automation of RMU/pad mounted switchgear with the Multilin DGCM improves grid reliability by reducing outage time.

Application 2: Cables in Vaults and Cable Joint Boxes The challenge faced in underground networks is the quick identification of faults. Deployment of the Multilin DGCM at strategic locations along cable paths enables faster fault detection as well as early warning signals in case of overload.

DGCM 1 to 6 Feeders Up to 18 Current Inputs

Key Benefits • Compact, cost-effective fault detector for underground cable networks • Rogowski coil option to enable retrofit installation in space-limited locations and to reduce the need for outages

Up to 6 sets of 3-Phase cables

• Early warning and fault detection per phase (50, 51) for each feeder to reduce fault location and feeder downtime • Multiple communication (cellular and radio) and protocol options for easy integration into DMS and SCADA systems

Using the Multilin DGCM on cables enables faster fault detection and isolation, reducing outages and crew deployment time.

GEDigitalEnergy.com

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DGCM Field RTU

Application 3: Distribution Substation, LV Systems Most distribution substations and indoor/outdoor LV systems lack asset monitoring and control. The Multilin DGCM can be used to effectively monitor power quality, as well as control, when necessary. Rogowski coil support provides current sensing in hard-to-find spaces and allows for modifications without an actual outage. The provision of overcurrent detection provides a vital warning signal well in advance of an actual failure.

DGCM

Up to 6 Voltage Inputs 1 to 6 Feeders Up to 18 Current Inputs

Key Benefits • Real-time load and energy monitoring and profiling of up to 6 feeders (18 individual phases) • Quick retrofit installation especially in tight spaces through Rogowski coil current sensors or traditional CT’s

Distribution Automation

• Cost-effective energy monitoring through direct voltage measurements up to 400V or via LEA voltage sensors LV Substation

• Ability to compensate for amplitude and phase shifting associated with different sensor types • Identification of faulted circuits and loads approaching overload levels through overcurrent detection per phase (50, 51) for each feeder • Per feeder energy monitoring and logging to help identify locations of theft detection • Unsolicited messaging to ensure faster response time to SCADA/DMS systems, making utilities aware of impending abnormalities

Monitoring at key LV consumer substations with the Multilin DGCM can help in faster fault isolation and energy theft detection.

Application 4: Pole Top/Pad Mounted Transformers Transformers may be loaded to their maximum capacity without the utility even realizing it, resulting in reduced transformer life. The Multilin DGCM enables the monitoring of transformer conditions, identifying transformers likely to fail. Keeping the utility updated of changing load demands enables proper planning for current peak loads and future demand.

DGCM mA Inputs

Key Benefits

Voltage Inputs

• Quick retrofit installation especially in tight spaces through Rogowski coil current sensors or traditional CT’s

Current Inputs

• Energy monitoring and logging to help theft detection • Remote configuration and firmware updates to simplify fleet management • Real-time transformer load monitoring to improve load flow studies and planning • Multiple communication (cellular, radio) and protocol options to ensure compatibility with existing infrastructure

Transformer monitoring with the Multilin DGCM enables overload identification, which is key for load planning and asset management.

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DGCM Field RTU

Application 5: Pole Top Applications The Multilin DGCM can be used for a wide range of pole top applications, such as remote controls for reclosers, switches, sectionalizers, interchange tie closures, tap changers and capacitor bank controllers. The Multilin DGCM’s hardware and communication flexibility can be applied to a wide variety of field applications where monitoring and/or remote control is required.

SWITCHING DEVICE

LINE

A B C

A B C

LOAD

Key Benefits • Cost-effective automation of installed field equipment (reclosers, switches, sectionalizers, interchange tie closures, tap changers and capacitor bank controllers)

DGCM

• Overcurrent detection per phase (50, 51) for each feeder to identify faulted circuits and loads approaching overload levels • Energy monitoring and logging to help theft detection Distribution Automation

• Remote configuration and firmware updates to simplify fleet management • FlexLogic to allow for the creation of customized control schemes that can be used in many pole top applications • Supports direct voltage measurements up to 400V or LEA voltage sensors for cost-effective monitoring

Detection functions and FlexLogic enable the Multilin DGCM to be used for most pole top applications.

Application 6: End of Line Monitoring Utility and industrial end of line monitoring for Volt/VAr control schemes play an important role in voltage optimization by ensuring the end customer is being provided with the proper voltage level. The Multilin DGCM can be used in applications where only voltage and/or current monitoring is required by high-end SCADA or DMS systems.

DGCM mA Inputs Voltage Inputs

Key Benefits

Current Inputs

• End of line voltage and current measurements to help in short term and long term operational planning • Energy monitoring and logging to help theft detection • Real-time monitoring of voltage for integrating in Volt/VAr control schemes • Overcurrent detection with alarm/trip to provide early warning signals of potential failures • Support for multiple communications technologies including cellular and private radio networks

Volt/VAr control schemes are better optimized using the Multilin DGCM, as changes in voltage (real-time) are reported almost immediately (unsolicited messaging) over most utility protocols.

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Hardware Options

140mm/5.51”

The Multilin DGCM is a cost-effective monitoring and control solution for most pole top, transformer, end of line, RMU and pad mounted switchgear applications, especially where ease of installation is desired and space constraints exist . Modular design and expandable I/O support most customer needs.

Base Unit (Supports Maximum 2 Modules) • 3 Voltage Inputs • Up to 18 Current Inputs (2 Cards) • Up to 32 Digital Inputs and 16 Digital Outputs (2 Cards)

Distribution Automation

• Note : Maximum 2 Cards

150mm/5.91” * Base Unit

Analog Inputs The Multilin DGCM utilizes many traditional and non-traditional sensors: • Traditional CT’s • Traditional PT’s • Rogowski Coils • LEA Sensors – 0 to 12V Output

Rogowski Coils Rogowski coils can be used on bare conductors for voltages of up to 600V and on insulated cables for higher voltages. The use of Rogowski coils shortens the installation time, reducing outage periods and installation costs.

Rogowski Coil

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Advanced Integration The Multilin DGCM employs industry standard communications technologies, making it one of the easiest and most flexible controllers to use and integrate into new and existing SCADA and DMS infrastructures.

Remote Communication

Multiple Protocol Support

The Multilin DGCM can communicate to FDIR/FLISR/SCADA systems via wireless communications media including:

Multiple communication ports and protocols allow for remote control and easy access to device and system information.

The Multilin DGCM’s integrated cellular modem eliminates the need for external wireless devices, reducing infrastructure costs.

• Wireless radio (MDS™ or customer specific)

Simultaneous industry standard protocols(slave) supported:

• GSM/GPRS

• DNP 3.0 – Serial and Ethernet

• Pre-wired for future radio

• Modbus® Serial and Ethernet

Options for MDS radios when purchased with enclosure:

• IEC® 60870-5-104, (IEC 60870-5-101 available Q4 2015)

• MDS iNET-II • MDS TransNet

Distribution Automation

The Multilin DGCM can be used as an I/O extension for relays or for current and voltage measurements into new and existing SCADA and DMS infrastructures.

Indication LED RJ45 Ethernet Port Power Supply

USB Serial Port

Low Volt (24 to 60 VDC) High Volt (85 to 265 VAC/DC)

RS485 Serial Port Integrated Cellular Card

3-Phase Voltage Input Traditional: 60 to 440 VAC LEA: 0 to 12 VAC

Cellular Antenna

Package Solution Option The Multilin DGCM can be purchased as a stand-alone unit or installed inside a cabinet. Refer to the order code section for order options.

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Automation and Control

Fault/Level Detections

The Multilin DGCM offers powerful I/O and programmable logic (FlexLogic) options for advanced automation and control, reducing the need for and costs associated with additional programmable controllers and discrete control devices.

Effective fault isolation is a key feature for grid reliability. The Multilin DGCM provides early warning of downstream overcurrent and earth faults. It can be programmed to isolate a faulted segment, either independently or from remote SCADA systems. The Multilin DGCM also offers control, monitoring and diagnostics in one integrated and efficient design.

Remote Control For both operational efficiency and reliability, the Multilin DGCM provides remote control for operating overhead switches and pad mount switchgear. The Multilin DGCM can be locally locked to prevent remote control operations during field maintenance. Capable of providing both local and manual control of switchgear, the compact size of the Multilin DGCM enables it to fit into existing outdoor distribution substations where space constraints exist.

Overcurrent Protection

Set Point Group Control

The Multilin DGCM can be programmed to block instantaneous overcurrent elements, and raise the pick-up time of overcurrent elements, when a cold load condition is detected. Cold load conditions are sensed during the closing of the breaker on a feeder that has been de-energized for a long time. The feeder in-rush and motor accelerating currents during breaker closing may be above some overcurrent protection settings.

Virtual Inputs and Outputs The Multilin DGCM provides 32 virtual inputs and 32 virtual outputs that provide users with the ability to send commands to the device. The Multilin DGCM can accept commands from SCADA, through the front HMI, or front USB port, and issue commands, such as close or open.

FlexLogic

Cold Load Pick-Up

Over Voltage (OV) Detection The phase OV detection alerts utilities of sustained OV conditions. The OV detector generates an alarm when the voltage exceeds the selected voltage level after a specified time delay.

FlexLogic in the Multilin DGCM helps reduce costs by providing the ability to create customized control schemes, minimizing the need for auxiliary components and wiring. Schemes can be configured with FlexLogic, specifying what actions need be taken, based on the status of fault detections or control elements, and inputs driven by connected sensors and equipment .

1 Save

Restore

Default

2

3

4

1

VIRTUAL IP 1 ON (SCADA CLOSE) PHASE OVERVOLTAGE BNK1 OP PHASE UNDEROVERVOLTAGE BNK2 OP

AND (2) AND (3)

AND (2) BNK1 PH HI IOC OP CONT IP 1 ON (SWITCH 1 OPEN) AND (2)

= CLOSE INCOMER A (VO1)

AND (2)

TIME

Distribution Automation

The Multilin DGCM has three set point groups. The activation of the groups can be done either from SCADA, HMI or via a digital input.

Instantaneous and time overcurrent functions are available for phase, and neutral currents. A variety of time curves are provided, including IEEE®/ ANSI®, IEC A/B/C long time inverse and short time inverse definite time and user-programmable curves.

OR (2)

BNK1 PH HI IOC DPO OR (2)

2 4

AND (3) = VIRTUAL OP 1 (VO1)

Using FlexLogic, customers can develop customized control schemes for multiple applications.

3 CURRENT

Custom FlexCurves can be constructed to coordinate with other upstream and downstream protection devices.

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Under Voltage (UV) Detection

Trending and Data Logging

The phase UV detection alerts utilities against sustained UV conditions. The UV detector generates an alarm when the voltage drops below the selected voltage level after a specified time delay.

The Multilin DGCM provides a 200 channel RMS recorder for advanced disturbance diagnostic features. Data recording can be set to record from 1 minute to 60 minute intervals. This significantly reduces the time and cost associated with troubleshooting power system events and reconstructions. The data can be immediately analyzed for trends, or stored for archival purposes.

Power Loss The Multilin DGCM can detect a power loss condition in each phase of the power distribution line. Open/close commands are blocked, unless currents and voltages of each phase fall below minimum set values. When the switch is closed, the power loss detection of the source side is used to control the open command execution.

Measurements The Multilin DGCM provides high accuracy metering and recording of AC signals, measuring the following key parameters:

Basic Measurements

EVENT

DATE

TIME

53

02/03/2012

16:22:44:103

TOC pickup

52

02/03/2012

16:22:44:220

Loss 01 Power

51

02/03/2012

16:22:45:115

TOC drop off

50

02/03/2012

16:22:45:175

AS first shot

49

02/03/2012

16:22:47:680

TOC pickup

48

02/03/2012

16:22:47:710

Loss of Power

47

02/03/2012

16:22:48:132

TOC drop off

46

02/03/2012

16:22:48:192

A5 second shot

45

02/03/2012

16:22:48:412

Switch Open

• Phase-to-phase and phase-to-ground voltages for bus and line: Van, Vbn, Vcn, Vbb, Vab, Vbc, Vca • Active power (per-phase and total): Wa, Wb, Wc, W

Distribution Automation

• Current: Ia, Ib, Ic, In

CAUSE OF EVENT

The Multilin DGCM event recorder enables users to analyze the sequence of events after each triggered event. Each event is stored with the event number, date, time and analog data of interest.

• Reactive power (per-phase and total): VARa, VARb, VARc, VAR • Total active, reactive and apparent energy: MWh, MVARh, MVAh

02/25/2013 13:05:21.626000

5hr 0 m

15 hr 0 m

02/25/201313:05:21.626000

02/25/201313:05:21.626000

10 hr 0 s

• Power factor (per-phase and total) Phase A Current Bank1

280.000 (Amps) 160.000 (Amps) -120.000 (Amps)

• Frequency

Phase B Current Bank1

270.000 (Amps) 190.000 (Amps) -80.000 (Amps)

Power Quality Measurements

Phase C Current Bank1

230.000 (Amps) 130.000 (Amps) -100.000 (Amps)

• Voltage sag/swell

Phase A RMS Current Bank1

• Current unbalance

198.02.000 (Amps) 113.154.000 (Amps) -84.866.000 (Amps) Phase B RMS Current Bank1

• Demand: voltage, current, active power, apparent power, energy, temperature

190.948.000 (Amps) 134.371.000 (Amps) -56.577.000 (Amps) Phase C RMS Current Bank1

162.659.000 (Amps) 91.938.000 (Amps) -70.721.000 (Amps)

• 2nd to 15th harmonic for current • 2nd to 15th harmonic for voltage

1

• THD in 20% for current

2

3

4

5

6

7

8

9

10

11

12

13

14

15

16

17

18

19

20

21

22

23

24

The Multilin DGCM data logger helps in better understanding the analog channel behavior, by sampling at a selectable time interval rate of 1 to 60 minutes.

• THD in 20% for voltage These data points can be easily integrated into a customer’s database for seamless viewing through SCADA or a DMS system, such as GE’s PowerOnTM Control or GENe.

Data Management and Diagnostics Event Recorder To enable more effective post event analysis and troubleshooting, the Multilin DGCM provides an integrated event recorder and detailed diagnostic features. The event recorder offers: • Storage for up to 1024 time stamped events • Pick-up & drop-off of detection elements • Instantaneous values of voltage/current at the time each event occurred

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Software and Configuration The EnerVista™ suite is an industry leading set of software programs that simplifies every aspect of using the Multilin DGCM.

Distribution Automation

EnerVista provides all the tools to monitor the status of the protected asset, maintain the controller, and integrate information, measured by the Multilin DGCM, into SCADA or DMS monitoring systems.

Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed. Documents available include: • Manuals

The ability to easily view sequence of events is an integral part of the setup software, as postmortem event analysis is critical to proper system operation.

• Application Notes

EnerVista Launchpad

• Wiring Diagrams

EnerVista Launchpad is a powerful software program that provides users with all of the setup and support tools needed for configuring and maintaining GE’s Multilin products. The setup tools within Launchpad allow for the configuration of devices in real-time, by communicating via serial, Ethernet or modem connections, or offline, by creating device setting files to be sent to devices at a later time.

• FAQs

• Guide Form Specifications • Brochures

• Service Bulletins

Setup with EnerVista Software EnerVista setup software can reduce device setup and configuration time.

Single Click Device Communications Quick Link Diagnostic Information

Online Device Configuration and Monitoring

Menu Driven Device Configuration

Offline Device Setting File Configuration

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Technical Specifications POWER SUPPLY

PHASE VOLTAGE INPUTS

COMMUNICATIONS

HIGH RANGE POWER SUPPLY

PHASE VOLTAGE INPUTS (Direct Connection)

SERIAL

Nominal: 110 to 240 VAC 125 to 250 VDC Range: 85 to 265 VAC (50 and 60 Hz) 85 to 265 VDC

Range: 60 to 440 VAC Nominal Frequency: 50/60 Hz Burden: <0.25 VA at 120 V Accuracy: ±0.5% Throughout Range Voltage Withstand: 2xVn Continuously, 3xVn 10s

RS485 Port: Baud Rates: Protocol:

LOW RANGE POWER SUPPLY Nominal: Range:

24 to 48 VDC 20 to 60 VDC

PHASE CURRENT INPUTS PHASE CURRENT INPUTS (CTS)

PHASE CURRENT INPUTS (Rogowski Coils)

ETHERNET (COPPER)

PHASE VOLTAGE INPUTS (LEA)

Modes: 10/100 MB (Auto-Detect) Connector: RJ45 Protocol: IEC® 60870-5-104

Range: 0 to 10 VAC Nominal Frequency: 50/60 Hz Input Impedance: > 10 MΩ Accuracy: ±0.5% Throughout Range Voltage Withstand: 2xVn Continuously, 3xVn 10s

USB Standard Specification: Data Transfer Rate:

GPRS Quad-Band EGSM 850/900/1800/1900 MHz GSM/GPRS Protocol Stack 3GPP Release 4 Compliant Sensitivity:  ≤-107 dBm (typ.) @ 850 / 900 MHz ≤-107 dBm (typ.) @ 1800 /1900 MHz Extended temperature range: -40°C to +85°C

DIGITAL I/O DIGITAL INPUTS Thresholds: 20 to 64 VDC for Low Range 100 to 240 VAC for High Range Recognition Time: 1/2 Cycle Debounce Time: 10 to 100 ms, Selectable, in Steps of 5 ms

DIMENSIONS

DIGITAL OUTPUTS IP67

Contact Material: Operate Time: Continuous Current: Make and Carry for 4s:

Compliant with USB 2.0 115 kbps

Base Size: 150 mm (W) x 140 mm (H) x 110 mm (D); 5.91” (W) x 5.51” (H) x 4.33” (D) Weight (Base): 2 kg; 4.41 lbs

Silver-Alloy 10 ms 6A 15 A per ANSI C37.90

Type Tests TEST DESCRIPTION

LEVELS

STANDARD

TEST DESCRIPTION

IMMUNITY ESD

LEVELS

STANDARD

ELECTRICAL (Category IV, 300V) 8 kV contact/ 15 kV air discharge

IEC 61000-4-2, EN60255-22-2

Dielectric Strength

EN60255-5

Radiated RF Immunity

10 V/m (80 MHz to 1 GHz) 3 V/m (1.4 GHz to 2.0 GHz) 1 V/m (2.0 GHz to 2.7 GHz)

IEC 61000-4-3:2002, EN6025522-3

Basic & Supplementary Insulation: 3.3 kV at least 1 min

Impulse

Reinforced Insulation: 5.4 kV at least 1 min

IEC 61010-1:2010

Radiated RF Immunity

80 MHz-1 GHz 20 V/m included Frequency Sweep, Keying Test and Spot Frequencies (except GSM)

IEEE C37.90.2:2004

Clearance & Creepage

Category IV, 300 V, Table K 4 IEC 61010-1:2010/

Fast Transient

4 kV at 5 kHz

IEC 61000-4-4:2012/ IEC 60255-22-4

Surge

2 kV

IEC 60255-22-5

Conducted RF Immunity

10 Vrms (150 kHz to 80 MHz)

IEC 61000-4-6, IEC 60255-22-6

Power Frequency Magnetic Field Immunity

Level 5: 100 A/m continuous 1000 A/m 1 to 3 s

IEC 61000-4-8:2001

Voltage Dip

0% during 1 cycle 40% during 10/12 cycles 70% during 25/30 cycles 80% during 250/300 cycles

IEC 61000-4-11:2004

Voltage Interruption

0% during 250/300 cycles

IEC 61000-4-11:2004

Radiated RF Emission

Group 1 & Class B

CISPR 11, IEC 60255-25

Conducted RF Emission

Group 1 & Class B

CISPR 11, IEC 60255-25

ENVIRONMENTAL • Operating temperature: –40°C to + 65°C as per IEC 60068 • Relative humidity cyclic: IEC 60068-2-30; 55°C 95% humidity

MECHANICAL • Sinusoidal vibration: IEC 60068-2-6:2007 Class 1 • Shock and bump: IEC 60068-2-27:2008 Class 1 • Seismic: IEC 60068-3-3:1991 Class 2

MISCELLANEOUS

EMISSIONEN

• Ingress of solid objects and water: IEC 60529:2007 IP44 (with external enclosure) NEMA 3/4 for cabinet • Resistance to mechanical stresses: IEC 61010-1:2010 (Paragraph 8) • Protection against the spread of fire: IEC 61010-1:2010 (Paragraph 9) • IEC 61000-3-2 (2008): Limits for harmonic current emmissions • IEC 61000-3-3 (2008): Limitation of voltage changes, voltage fluctuations and flicker in public low-voltage supply systems

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Distribution Automation

Range: 0.05 to 2.50 × CT Input Type: 1 A or 5 A (SW Selectable) Nominal Frequency: 50/60 Hz Burden: <0.1 VA at Rated Load Accuracy: ±1% of Reading ±0.2% Full Scale CT Withstand: 1 Second at 20 × Rated Current, Continuous at 4x Rated Current

Opto-Coupled Up to 115 kbps Modbus RTU, DNP 3.0, (IEC® 60870-5-101 available Q4 2015)

Ordering Codes DGCM FIELD RTU DGCM Base type

*

E

*

-

S

S

-

*

-

*

-

X

-

X

-

X

-

X

*

1

*

DGCM

Description Field RTU

A

Base Unit Includes : 3 x Voltage Inputs (60 to 440 VAC)

B

Base Unit Includes : 3 x Voltage Inputs (0 to 12 VAC, LEA)

Power Supply

H

High Volt AC Power Supply (85 V to 265 VAC/DC)

L

Low Volt DC Power Supply (24 to 60 VDC)

Modules

Controller

C

C

F

F

9 x CT Inputs 5 Amp/1 Amp Secondary 9 x Rogowski Coil Inputs

P

P

16 x Digital Inputs, 8 x Digital Outputs (64 DI & 32 DO Maximum, 100 to 240 VAC/DC)

Q

Q

16 x Digital Inputs, 8 x Digital Outputs (64 DI & 32 DO Maximum, 24 to 60 VDC)

X

X

X

X

X

X

None 1

Controller Only (No Display)

2 Wireless Radios

Controller in Enclosure (No Display) X

No External Communications

1

Long Range High-Speed Serial Communication MDS TransNet (EL805-MD9X1AFCD1WN) - Available with controller in enclosure

2

Long Range Ethernet & Serial Communication MDS iNET-II (iNETII-MD9A1AVFCD1NN0) - Available with controller in enclosure

Rogowski Coil ROGS Rogowski Coil Sensors

ROGS

-

*

*

*

A

A

3 

Rogowski Coil Sensor, 3 m termination length required to be ordered when F option for current input is chosen

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12715C(E) English 150121

Multilin™ Intelligent Line Monitoring System Delivering actionable intelligence for improved reliability and efficiency Distribution utilities are faced with regulatory requirements to improve reliability, while operating and maintaining aging infrastructure with limited maintenance and capital improvement budgets. GE’s Intelligent Line Monitoring System equips distribution utilities with tools and applications to meet these challenges. GE’s innovative Multilin Intelligent Line Monitoring System provides situational awareness along distribution feeders enabling distribution utilities to operate and respond based on prevailing conditions. The system provides utilities with high quality, time coherent data throughout their distribution networks, allowing them to improve performance, reliability and efficiency. GE’s expertise in distribution networks and system development provides the experience needed to address the utilities challenges and deliver proven and sustainable network performance improvement.

• Provides increased situational awareness along distribution feeders • Enables utilities to operate and respond based on prevailing feeder conditions, not static or seasonal estimates

Reduced Outage Duration • Enables faster response reducing SAIDI and CAIDI indices

Key Benefits • End-to-end solution delivers extended visibility into the distribution network • Reduced cost of ownership with GE’s sensors designed for easy installation on live networks • Designed to meet the challenges of capturing faults in both low and high impedance grounding treatments • Advanced analytical applications enabled by GE’s patented time synchronized data • Remote firmware upgrades enable further application development and compliance with regulatory and operational requirements

Applications Fault detection, location & analysis

Enhanced Network Visibility

Feeder visualization

• Identifies fault location alerting operators visually and notifying repair crews via email and SMS messaging • Promotes targeted spend of maintenance funds based on performance instead of age of asset

Increased Network Capacity • Provides the visibility to compute dynamic line ratings based on prevailing conditions • Enables distribution utilities to better manage their feeders, avoid conductor degradation and knowledgeably deploy sustainable generation

Dynamic line rating

System diagnostics & maintenance

Intelligent Line Monitoring System

System Overview

System Components

The modular design of GE’s monitoring system enables customers to tailor their own monitoring platform so that it aligns with their key strategies for performance improvement of the network, whether this is fault location, increased capacity through dynamic line rating or enhanced network visibility. The system consists of three key components:

Line Sensors

• Multilin FMC line sensors that provide accurate data inputs on line load and conductor temperature • Multilin SNG™ (Sensor Network Gateway) that provides two way communications between the line sensors, weather stations, and to the server based applications • Server-Based Applications: -- Feeder visualizer application -- Fault detection, location and analysis application (Multilin X-NET™) -- Dynamic line rating calculation and analysis application (Multilin T-NET™) Distribution Automation

-- System diagnostics application

Data Synchronization GE’s Intelligent Line Monitoring system is time synchronized enabling data from multiple locations along the distribution network to be aligned to within 40µS creating an accurate snapshot of the network suitable for advanced analytics. GE’s applications use this technique to align the values captured at the substation and along the feeder to provide a coherent image of the network performance under normal operations as well as under faulted conditions.

As part of the Intelligent Line Monitoring System, the sensors play a key role in providing visibility along the distribution network. The sensor measures and records the current, both amplitude and phase, at 32 samples per cycle, and supports two way communications with the SNG via an on-board 2.4 GHz radio. The sensor is configured to detect fault conditions facilitating rapid identification and notification. In addition, the sensors can be configured to provide periodic measurements to facilitate improved situational awareness and operations. The sensor can be supplied with a temperature probe fitted on a flying lead that measures the surface temperature of the conductor facilitating dynamic line rating analysis and conductor temperature monitoring.

Weather Monitoring Equipment Weather information is a critical data source for dynamic line rating and ice load warning applications. These applications depend on wind speed and direction, ambient temperature, dew point and solar radiation. The Intelligent Line Monitoring System employs a weather station with an ultrasonic anemometer option to deliver enhanced dynamic line rating analytics. Wind speed and direction averaging techniques enable utilities to set increased circuit ratings based on a greater understanding of prevailing conditions. The optional weather station and ultrasonic anemometer communicate with the SNG via a hardwired link.

GE’s Intelligent Line Monitoring System

Software Applications (Server-Based)

Multilin FMC-T6 (Line Sensor)

Multilin SNG (Sensor Network Gateway)

The components of GE’s monitoring system enable utilities to improve network performance through fault location, dynamic line rating and enhanced network visibility

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Intelligent Line Monitoring System

Sensor Network Gateway The Multilin Sensor Network Gateway (SNG) provides connectivity between the applications and the field, ensuring visibility along the distribution network. The SNG is a communications gateway for the distribution network and weather information required for advanced applications such as fault detection, location and analysis, dynamic line rating, maintenance planning and feeder visualization. The SNG provides two way communications to the line sensors by 2.4 GHz radio and to the weather monitoring equipment by a hardwired link. The SNG also performs another important function by recording voltage, both amplitude and phase, at 32 samples per cycle via substation or feeder voltage transformers (VT’s). The SNG is equipped with several backhaul options for communicating with the advanced applications including 2G/3G GRPS/UMTS as well as Serial and Ethernet communication ports. Each SNG is equipped with a GPS transceiver that synchronizes the entire system, enabling GE’s advanced analytics.

• Multilin T-NET Software Applications for dynamic line rating:

Server Based Applications

-- Dynamic line rating calculation (CIGRE model)

The Intelligent Line Monitoring System has a suite of server based applications that include:

-- Site specific ice load warning (Rime)

• Multilin X-NET Software Application for fault detection, location and analysis:

Distribution Automation

The SNG is versatile and can be installed along the distribution feeder communicating with the line sensors or in a substation for voltage monitoring. Typical feeder installation scenarios include a single SNG with three sensors (one sensor per phase) or a single SNG with six sensors located at a branch port or feeder tap enabling it to effectively monitor two circuits at one site.

-- Local sag/clearance calculator -- Weather data monitoring -- Data download facility - monitored network data, in user defined time periods (available in Microsoft Excel format) • System diagnostics and maintenance application

-- Fault location -- Fault signature as RMS values on a cycle by cycle basis

-- System diagnostics

-- Fault notification (SMS and email)

-- Remote SNG firmware updates

-- Graphical depiction of outage history

-- Remote line sensor firmware updates

-- Data download facility - monitored network data, in user defined time periods (available in Microsoft® Excel format)

-- Directory for email and SMS recipients -- Fault threshold settings -- Monitoring frequency configuration

Server Based Applications: Weather Data Monitoring

Tracking of weather conditions allow for determining the effect of local weather conditions on capacity of the feeders

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Intelligent Line Monitoring System

Application Overview: Dynamic Line Rating Analysis GE’s Multilin T-NET advanced analytics compute dynamic line ratings based on prevailing conditions enabling distribution utilities to: • Better manage their feeders, • Avoid conductor degradation, and • Knowledgeably deploy sustainable generation

Dynamic Line Rating (T-NET)

Advanced Line Sensor

The dynamic line rating application provides actionable information enabling utilities to:

GE’s advanced line sensors provide time synchronized measurements to facilitate improved situational awareness and operations including:

Distribution Automation

• Understand the current loading on the feeder

Weather Data

• Recognize feeders nearing their rated capacity

• Electrical current, both amplitude and phase

• Identify additional available line capacity based on prevailing conditions

• Conductor surface temperature

The Intelligent Line Monitoring System employs a weather station with an ultrasonic anemometer option to deliver enhanced dynamic line rating analytics using wind speed and direction averaging techniques that enable utilities to set increased circuit ratings based on a greater understanding of prevailing conditions.

• Detect local icing conditions to enhance storm operation decisions and response Max. Capacity

• Calculate site specific line sag based on prevailing conditions

92

Max. Capacity

86

Substation

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88

Substation

Radiant heat from roads reduces line capacity

The cooling effect of wind blowing across the conductor allows greater capacity

Max. Capacity

Intelligent Line Monitoring System

Application Overview: Fault Detection, Location and Analysis The Intelligent Line Monitoring System delivers the necessary field visibility and advanced analytics to: • Capture faults in low and high impedance grounding treatments, • Identify fault location alerting operators visually and notifying repair crews

Communications Gateway

The sensor is configured to detect fault conditions facilitating rapid identification and notification. This line mounted device measures and records the current, both amplitude and phase, at 32 samples per cycle, and communicates to the SNG via an on-board 2.4 GHz radio.

The Sensor Network Gateway (SNG) provides a communications gateway for distribution network and weather information that is critical for advanced applications. The SNG communicates with the line sensors, weather monitoring equipment and records voltage, both amplitude and phase. The gateway is equipped with several backhaul options for communicating with the advanced applications including an embedded 2G/3G/ GPRS/UMTS modem, and Serial and Ethernet communication ports.

GEDigitalEnergy.com

Fault Detection, Location and Analysis (X-NET) • Monitors the distribution network 24/7 for events and faults • Automatically filters events from faults based on utility defined configuration to avoid nuisance reports • Identifies fault location alerting operators visually and notifying repair crews via email and SMS messaging. • Provides a cycle by cycle plot of fault activity.

329

Distribution Automation

Advanced Line Sensor

Intelligent Line Monitoring System

Application Overview: Feeder Visualization The Intelligent Line Monitoring System increases situational awareness along distribution feeders and enables utilities to operate and respond based on prevailing conditions, not static or seasonal estimates. The extended visibility delivered by the Intelligent Line Monitoring System provides actionable information enabling utilities to meet the changing dynamics of the distribution network, and be able to: • Analyze 3 phase current along the feeder • Balance phases to extend circuit capabilities and delay capital expenditures • Identify conductor loading issues due to phase imbalance and take corrective action

Distribution Automation

• Identify line regulator loading issues and take corrective action To meet the new demands posed by distributed generation and the proliferation of electric vehicles on an aging infrastructure, distribution networks have to become more efficient, robust and reliable. In order to meet these challenges, greater visibility of distribution networks is essential for operations, planning and developing new construction and protection design guidelines. The ‘Smart’ use of distributed intelligence has emerged as a major factor in meeting the needs of the new distribution network model, while at the same time driving enhancements in network safety and security.

Improving Network Efficiency and Capacity

Improving Situational Awareness GE’s Intelligent Line Monitoring system is time synchronized enabling data from multiple locations along the distribution network to be aligned to within 40µS. GE’s applications use this technique to align the values captured at the substation and along the feeder to provide a coherent image of the network performance.

Many distribution networks are asymmetrical due to the use of single or two phase laterals. This type of network design tends to lead to unbalanced loads with negative implications for efficiency and capacity. A balanced load seen at the substation may not be indicative of balanced circuits down the feeder. The distributed load monitoring feature of the Intelligent Line Monitoring System provides added visibility necessary to correct and improve load balance. Similarly the onset of distributed generation complicates the network further, where load and power flow direction are no longer obvious. In addition to understanding the impact of asymmetry of the network, periodic data recorded by the system brings enhanced visibility supporting more in depth network analysis. Accurate time synchronization enables the delivery of positive, negative and zero sequence currents at each measuring location along with substation voltage. The use of load profiling is very useful as an indicator of consumption changes or patterns, giving an early indication of non-technical losses. Reporting intervals are user configurable. This enhanced network visibility delivers actionable information to enable: • Field personnel to identify the optimum phases for laterals, • Network planners to identify maximum loadings and assist in new load or distributed generation planning,

3 phase current profiling identifies magnitude of line imbalance at each measurement point

• Protection engineers to support more advanced relay setting techniques based on distributed information and • Network engineers to identify where the network losses are occurring.

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Application Overview: System Diagnostics and Maintenance The system diagnostics and maintenance applications play an important role in maintaining a high level of system performance in delivering actionable intelligence.

System Diagnostics

System Maintenance

The Intelligent Line Monitoring System and its ability to deliver valuable network data becomes an important component in the drive for increased network performance and efficiency. To maximize system up-time, the Intelligent Line Monitoring System constantly monitors for equipment and communication failures. The system diagnostics records equipment performance and notifies the administrator by email of any detected performance issues.

The system maintenance application provides a unified dashboard for managing and tracking key system assets. This application manages the remote firmware upgrade process for SNG’s and line sensors, and displays the current firmware version installed in an SNG or line sensor. It also enables the system administrator to manage the list of recipients for SMS messages and emails relating to fault notification.

System diagnostics application reports for communications: • Time of SNG’s last activity • CSQ (2G/3G GPRS/UMTS signal strength) Distribution Automation

• 2G/3G GPRS/UMTS modem resets • GPS timing lock status • Communication with weather monitoring equipment • Communication with line sensors System diagnostics application reports for asset health: • Battery voltage on the SNG • Battery voltage on the line sensors • Charge/discharge current on the SNG • Charge/discharge current on the line sensors

The notification management tool enables the system administrator to maintain recipients for fault notifications

System Diagnostic Management Tool

System diagnostic management tool monitors asset health

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Intelligent Line Monitoring System

Multilin T-NET Software: Dynamic Line Rating Analysis Application The dynamic line rating application provides actionable information enabling utilities to: • Understand the current loading on the feeder • Recognize feeders nearing their rated capacity • Identify additional available line capacity based on prevailing conditions • Detect site specific icing conditions to enhance storm operation decisions and response • Calculate line sag based on prevailing conditions

Distribution Automation

GE’s Multilin T-NET advanced analytics compute dynamic line ratings based on prevailing conditions enabling distribution utilities to better manage their feeders, avoid conductor degradation, and knowledgeably deploy sustainable generation. The Intelligent Line Monitoring System employs weather data including a weather station and/or an ultrasonic anemometer input and uses wind speed and direction averaging techniques to deliver enhanced dynamic line rating analytics enabling utilities to set increased circuit ratings based on a greater understanding of prevailing conditions.

Application displays current line loading and available capacity based on the CIGRE algorithm

Application delivers site specific line sag and clearance for safety constraint verification and maximum line utilization

Static Circuit Rating Utilities have traditionally employed a single, static circuit capacity rating or seasonal rating. Yet this method does not take into account the prevailing conditions. Without this insight, circuit capacity may be underestimated, resulting in assets that are underutilized, loss of return on investment or even inability to serve a load. Conversely capacity may be overestimated, yielding potentially unsafe ground clearance conditions and/or conductor degradation.

Calculating Dynamic Line Rating GE’s Multilin T-NET advanced analytics compute dynamic line ratings based on prevailing conditions using the CIGRE model calculation. This algorithm considers parameters such as:

• Diameter of conductor and outer wire • DC resistance at 20°C • Solar radiation • AC resistance • Latitude and elevation above sea level The Multilin T-NET software automatically calculates the available and maximum capacity based upon the prevailing conditions reported from the Multilin FMC line sensors, weather stations and/or ultrasonic anemometers. The dynamic line rating application displays three critical values for each node, namely: • Present load

• Maximum conductor temperature

• Present maximum capacity

• Temperature coefficient of resistance

• Present available capacity

• Conductor type

The Multilin T-NET software calculates local line sag and site specific icing conditions based upon the prevailing conditions as shown in the image above.

• Ambient temperature • Speed and angle of attack of the wind

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The Multilin T-NET software can exchange key rating values and conductor temperatures with the utility SCADA system using DNP3 or IEC 870-5-101/104.

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Intelligent Line Monitoring System

Multilin X-NET Software: Fault Detection, Location and Analysis Application The advanced analytics delivered by the X-NET application are designed to meet the challenges of capturing faults in both low and high impedance grounding treatments. The Intelligent Line Monitoring System delivers the necessary field visibility and advanced analytics to capture and report the location of ground and phase to phase faults in directly grounded treatments, and ground and cross country faults in high impedance grounding schemes.

Fault Detection, Location & Analysis • Monitors the distribution network 24/7 for events and faults • Automatically filters events from faults based on utility defined configuration to avoid nuisance reports • Identifies fault location alerting operators visually and notifying repair crews via email and SMS messaging

Fault Analysis Notification of a fault in the network is triggered in one of three ways: when a line sensor detects that the load has exceeded the maximum user configured threshold or fallen below its minimum user configured threshold or when a substation SNG monitoring open delta voltage exceeds its maximum user configured threshold (applicable in high impedance grounding scenarios). Upon notification the X-NET software selects the substation identified as the source of supply to the fault and polls the sensors installed along the feeders obtaining 10 cycles of current data on either side of the event time stamp in order to provide a complete picture of the faulted network. The X-NET software analyzes the data received and displays the section where the fault has occurred. When the fault condition is resolved and power is restored, the sequence is reversed and the graphical display is cleared.

• Provides a cycle by cycle plot of fault activity Distribution Automation

Maintenance Prioritization The X-NET Software enables the utility to effectively prioritize maintenance expenditure by: • Maintaining a database of events to facilitate identification of repetitive incidences, comparison of feeder performance and definition of preventive maintenance programs • Graphically depicting outage history for each feeder section The X-NET Application enables utilities to: • Target where to spend maintenance funds based on performance instead of age of assets • Direct field crews to feeder sections where maintenance is needed • Guide maintenance work required by the nature and frequency of feeder faults indicated by frequent re-closer activity

Fault notifications are sent directly to field crews mobile devices

• Categorize maintenance required based upon repetitive transients indicative of: -- The need for tree trimming -- Salt build-up -- Equipment degradation

Fault Identification The system monitors the distribution network 24/7 for events and faults. Any network event activity that exceeds a user defined threshold and is longer than 2 cycles in duration is stored into the database and processed by the Multilin X-NET software as a network event. The system automatically filters events from faults based on utility defined configuration to avoid nuisance reports. If the outage exceeds a user defined duration, it is classified as a fault and the system proceeds to notify personnel by SMS or email. Both faults and events captured are stored in the database for future review and analysis. The Multilin X-NET software provides data mining capabilities allowing the user to define a time period and review the captured fault and event activity during this period. Results are presented graphically so that locations experiencing network problems are easily identified, supporting preventive maintenance by highlighting the most critical or problematic sections of the network.

Support maintenance prioritization based on fault history activity for feeder segments

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Intelligent Line Monitoring System

Distribution Automation

Installation Multilin FMC Line Sensor

Communications

Installation of the Multilin FMC line sensor can be completed in just minutes on a live line using either hot-stick or hot-glove. Sensors can be installed on 480V to 140kV feeders and will sit on conductors ranging from 10 mm to 28 mm in diameter. The sensor commences operation as soon as it is closed around the conductor and a small flashing LED mounted in the sensor housing indicates that it is operational. The magnetic field of the line provides the power for the sensor and also charges a 48 hour battery back-up that keeps the sensor operational in the event of an outage.

The SNG supports several backhaul options for communicating with the advanced applications, including cellular as well as serial and Ethernet communication ports. Equipped with a SIM card holder, the SNG enables 2G/3G GPRS/UMTS backhaul communications. The serial cables from the weather station and/or ultrasonic anemometer can be connected to the SNG to enable transmission of weather data. The gateway supports two way communications with the line sensors by 2.4 GHz radio and no special installation is required.

The sensor can be supplied with a temperature probe fitted on a flying lead that measures the surface temperature of the conductor. The lead is wrapped around the conductor with its temperature sensing tip at the end of the lead tied to the conductor surface. To ensure that the probe is thermally coupled to the conductor, GE recommends that a thermal compound is used between the conductor and the probe tip (please refer to the sensor installation instruction manual).

System Overview

GPS provides accurate timing pulse to SNGs

Multilin SNG Sensor Network Gateway The SNG can be installed along the distribution feeder communicating with the line sensors or in a substation for voltage monitoring. Radio range between the line sensors and the SNG is typically 30 meters/100 feet, and the SNG is normally mounted on the same pole or structure underneath the sensors. The SNG is a low power device and can be powered by a solar panel or by a 100V/250V AC power supply. GE offers a solar kit option (see Ordering Codes section).

1

2 SNGs align the FMC-T6 sensors to the same timing reference

Sensors and SNGs distributed throughout the network are time aligned and viewable on the System Console

Software The Intelligent Line Monitoring System Software resides on a server running a Microsoft Windows.NET platform and utilizes a Microsoft SQL Server database. 3

Typical feeder measurement installation

System Network Model

The system network model enables utilities to collect, view and report asset information graphically, creating feeder visualization

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Intelligent Line Monitoring System

Application Data Specifications

System Management Specifications

MULTILIN FMC-T6

PERFORMANCE

Current Range

2 Versions 300A or 600A

Current Measurement Accuracy

+/- 1% of Amplitude Plus 0.3A

Phase Accuracy

+/- 0.6°

Conductor Temp Measurement Range

-10°C to +85°C

Accuracy of Conductor Temperature Probe

+/- 2°C

Measurement Sampling Rate

32 Samples per Cycle

Minimum Line Current to Power the Sensor

10A 300A Version / 30A 600A Version

Line Voltage Range

480V to 140kV

Sensor Radio Frequency

2.4GHz

Sensor Radio Range

30m/100ft Line of Sight

Flash Memory

80 Minutes of Data

Battery Back-Up

Maximum 48 Hours With a Fully Charged Battery

SOFTWARE SPECIFICATIONS

Operating Temperature Range

-40°C to +65°C

Weight

6kg/13lb

Feeder Visualizer (Standard)

Reports: • Individual Phase, Positive and Negative Sequence Currents • Substation Bus Phase Voltage • Open Delta Voltage • Conductor Temperature* • Wind Speed, Direction, Dew Point and Solar Gain**

Multilin X-NET Application

Detects and Reports at Each Node: • Earth Faults in High Impedance Grounding Treatments • Over Currents, (Earth Faults in Low Impedance Grounding Treatments and Phase to Phase Faults) • Under Currents (Dropped Phase or Phases and Outages)

Multlin T-NET Application

Calculates and Reports at Each Node: • Dynamic Rating of Conductor (Cigre Model)** • Sag/Clearance* • ICE Load Warning (Rime)***

SNG Firmware

Remotely Upgradeable

Sensor Firmware

Remotely Upgradeable

Monitoring Frequency

Remotely Upgradeable

Fault Detection Threshold

Remotely Upgradeable

SCADA Integration

Server based (DNP3/IEC101/104)

Fault Notification

Remotely Configurable (SMS & Email)

Network Modeling

Server based Tool

0.5% of Reading+/-0.5% of Full Scale

Voltage Phase Accuracy

1°

Radio Range to Line Sensor

30m/100ft Line of Sight

Battery Backup

48hrs at 25°C

Operating Temperature Range

-40°C to +65°C

Data Size

150 MB per month (Typical)

Data Storage

48 Hours (At a Monitoring Interval of 5 Minutes)

DESCRIPTION

OPTIONAL

GPS Location and Timing

•

*

2.4 GHz Radio

•

** Requires weather monitoring equipment.

Davis Weather Station Port

•

Ultrasonic Anemometer Port

•

2G/3G (GPRS/UMTS) Backhaul Communications

•

RS232 Serial Port for Backhaul Communications

•

Ethernet Port for Backhaul Communications

•

Open Delta Voltage Input (High Impedance Grounding Treatment)

•

Three Phase Voltage Input

•

Standard Pole Mounting Bracket

•

LV AC Supply (Input 85-250Vac 50/60 Hz)

•

DC Power Supply (Input 22.5-28V DC)

•

Feeder Visualizer Software

•

Requires Multilin FMC sensors with temperature probes.

*** Requires Multilin FMC-T6 sensors with temperature probes and weather monitoring equipment.

Certifications ISO

Manufactured under an ISO9001 registered program

CE

Conforms to: 2004/108/EEC EMC Directive December 2004 2006/95/EC Low Voltage Directive December 2006 1999/5/EC Radio equipment and telecommunications terminal equipment Directive R&TTE March 1999

Multilin X-NET Software Application

•

Multilin T-NET Software Application

•

Solar Panel & Battery Kit

•

Standard Weather Station Kit

•

Ultrasonic Anemometer

•

Type Tests Document No.

Title

Edition / Issue

2004/108/EC

EMC Directive

Dec 2004

2006/95/EC

Low Voltage Directive

Dec 2006

1999/5/EC

Radio Equipment and Telecommunications Terminal Equipment Directive R&TTE

March 1999

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Distribution Automation

PERFORMANCE

Voltage Measurement Accuracy

STANDARD

DESCRIPTION

Software Specifications

MULTILIN SNG

SYSTEM OPTIONS

SYSTEM CONFIGURATION AND MANAGEMENT TOOLS

Ordering Codes SENSOR FMC-T6 -

*

Type

0

*

*

Without Temperature Probe

1 Frequency

With Temperature Probe 0

50Hz

1

60Hz

2

50/60Hz1

Current Range

1

Description

0

300A

1

600A

Option available for SNG2 models only.

SNG

SNG SOLAR SUPPLY KIT

SNG-2-

*

Description

SKIT-

*

Description

Type

0

Standard

Type

0

Standard 30W Solar Supply Kit

WKIT -

*

Description

TM-

*

Description

Type

B

Standard Weather Station Kit

Type

0

Module 1 Installation

C

Ultrasonic Anemometer

1

Module 2 System Set-Up

2

Module 3 Controller Set-Up

3

Module 4 Server Installation

4

Module 5 SCADA Integration

WEATHER STATION

ON LINE TRAINING MODULES

2

Please Note: For T-NET application a Standard Weather Station is required in addition to the Ultrasonic anemometer.

2 

MULTILIN T-NET HOSTED SOFTWARE T-NET -

*

Number of Nodes

REMOTE COMMISSIONING SUPPORT

Type

1

1 Node

CS-

*

Description

2

5 Nodes

Type

0

1 Day Support

3

10 Nodes

1

2 Days Support

4

25 Nodes

5

50 Nodes

MULTILIN X-NET HOSTED SOFTWARE X-NET -

*

Number of Nodes

Type

1

1 Node

2

5 Nodes

3

10 Nodes

4

25 Nodes

5

50 Nodes

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

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GEA-12689C(E) English 150121

Multilin™ DGCS Switch Controller The Multilin DGCS is an advanced Switch Controller for the detection of faults and control of overhead and pad mounted switches. The DGCS is compatible with many switches and provides the flexibility to integrate with FDIR systems. The Multilin DGCS provides integrated fault detection, control, and Auto-Sectionalizing functionality that senses downstream faults and isolates faulted sections based on the set auto-sectionalized shots or elapsed time. The Multilin DGCS greatly improves distribution reliability whether it is being used independently or in tandem with an FDIR scheme. The DGCS is part of a family of Distribution Automation controllers that also includes the DGCV Voltage Regulator Controller and DGCC Capacitor Bank Controller

Key Benefits • 20+ years with a field proven auto-sectionalizing algorithm • 5 shot auto-sectionalizing enabling more switches per section • 3 setting groups for application flexibility and sensitivity based on switched conditions • Advanced logic engine and multiple I/Os for creating customized control schemes • Improve performance and reliability by integrating remote feeders into DMS/OMS/ADMS or SCADA system • Real-time monitoring of energy to track non-technical losses

Fault / Level Detection & Hardware • AC Parameters level detections (Phase & Neutral Overcurrent • Over & Undervoltage, Voltage Unbalance • Reverse Power and Power Loss detection • 5 shots to lockout, 3 setting groups • 3 CTs: supporting traditional & line post sensors • 6 VTs: supporting traditional & LEA inputs • Expandable inputs & outputs for advanced applications

Communications • Support for multiple protocols: Modbus®, DNP3.0 and optional wireless communications (radio or cellular) • User Interface: Front panel USB, 4 Line HMI display, 20 system status LEDs

• Improves asset monitoring and maintenance schedules based on measured energy discharge

Automation & Control

• Compatible with low energy analog voltage sensors

• Auto-sectionalizing, CLP Cold Load Pickup

• Offers enhanced troubleshooting tools including sequence of events records and data logger • Reduce setup and commissioning time and effort with industry leading, easy-to-use EnerVista Setup Software and front panel quick setup keys

• Auto/Manual, Local/Remote Control • Customized automation schemes using FlexLogic™

• Common hardware, firmware and software with other Multilin Distribution Automation Controllers, simplifying training requirements

Monitoring & Metering

• Rugged construction, designed for outdoor use in harsh environments

• Metering: Current, voltage, power, energy, frequency, and PF

Applications

• Event Recorder: up to 256 time tagged events with 1ms resolution

• Automatic control of load break and non-load break switches (LBS/NLS) for fault detection and isolation (FDIR) • Automatic control of pad mounted switchgear • Interfacing with FDIR/FLISR for auto-sectionalizing and auto-restoration

Security & Software • 4-level device security to maintain authorized access only • Simplified device configuration with EnerVista™ Setup Software

DGCS Switch Controller

Reliability in Networks

Overview

Modes of Operation

A key driver and measurement of utility effectiveness is in the reliability of power to its customers. As many faults on overhead distribution lines are transient in nature, reclosing at the substation and installation of mid-line reclosers./switches can improve a utilities SAIDI reliability index by up to 24%.

The Multilin DGCS is capable of monitoring 3 currents and up to 6 voltages allowing for 3-phase voltage measurement on each side of the switch. The Multilin DGCS support traditional CTs and PTs sensors as well as line post sensors such as (Lindsey, Fisher Pierce).

The Multilin DGCS Switch Controller provides two modes of operation:

Distribution Automation

When permanent faults occur on overhead lines, having feeders with increasing degrees or automation can greatly enhance distribution grid reliability and reduce restoration of unfaulted segments from several hours to a few seconds or minutes. A key component of these automation schemes is intelligent controllers that can integrate with FDIR systems through sharing local information and accepting control commands.

Fault Isolation and Restoration With adequate deployment of Reclosers and switches, faults on distribution networks can often be isolated allowing unaffected parts of the system to be restored. Two main modes of operation of isolation and restoration commonly deployed are: A. Manual: Fault Isolation & restoration is done manually by the crew visiting the site. B. Automatic: Intelligence at the switching locations detect faults and based on the level of automation available, the following three options are possible. 1. Localized Control: Local intelligence for detecting and isolating a faulted section of the feeder allowing for automatic reclosing and restoration to unfaulted upstream sections of the feeder.

With this measurement capability, Multilin’s DGCS can measure and communicate critical information including voltage and current magnitudes to SCADA and DMS systems. The Multilin DGCS calculates power factor, phase angle, power flow direction, power and energy. Multilin’s DGCS performs real time tracking of recloser operations, parameters and the recloser wear thereby enabling the utility to manage their assets effectively and efficiently

Robust Design Based on GE’s proven Switch Controller platform with tens of thousands of units installed globally, the Multilin DGCS undergoes extensive Accelerated Life Testing (ALT) and Highly Accelerated Life Testing (HALT) to validate accurate functionality under specified conditions and to ensure accurate performance in extreme operating conditions and harsh environments. As a complete package, the Multilin DGCS is offered in a NEMA-4 certified cabinet that is suitable for operation of harsh environments with an operating range of -40°C to +60°C (-40°F to +140°F).

• Remote mode • Local mode The Multilin DGCS Switch Controller measures three phase voltages and currents, and based on the measurements, manages AutoSectionalizing functionality.

Fault / Level Detections The Multilin DGCS provides early warning for downstream over current and earth faults. The Multilin DGCS can be programmed to isolate a faulted segment either independently or from the remote. Effective fault isolation is a key feature for grid reliability. The DGCS also offers control, monitoring and diagnostics in one integrated efficient design.

Cold Load pickup The Multilin DGCS can be programmed to block the instantaneous over-current elements, and raise the pickup level of the time over-current elements, when a cold load condition is detected. The cold load condition is detected during closing of the breaker on a feeder that has been de-energized for a long time. The feeder inrush current and the motor accelerating current during breaker closing maybe above some overcurrent protection settings.

Typical Loop Feeder Arrangement

2. Operator Control: Operator Control requires a DMS application like GE’s PowerOn or GeNe solutions running in the control center. This is a combination of local intelligence communicating to the control center with an Operator executing switching plans to isolate the fault and restore service to non-faulted sections. 3. Automated Control: Automated Control requires a DMS application like like GE’s PowerOn or GeNe running in the control center or a decentralize system running in the substation like GE’s D400-FDIR. FDIR algorithms determines fault location and automatically reconfigure the feeder to isolate the fault & restoring power to nonfaulted sections. The DGCS can play an important part of FDIR/FLISR solutions for improving distribution grid reliability.

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DGCS Switch Controller

Automating the reconfiguration of faulted distribution circuits reduce customer outage time on unfaulted sections of the network from hours to seconds Manual Mode

Automatic Mode Localized Control

Alert Operator

Restore Upstream

5-10 min

0.5-1 hr

Restore Upstream

Alert Operator

Restore Downstream

5-10 min

0.5-1 hr

0.5-5 sec*

Automatic Mode Operator Control

Restore Upstream

Automatic Mode Automated Control

Restore Downstream

<10 sec

<3 min

Alert Operator

Fix Fault

Fix Fault

1-1.5 hr

Fix Fault

Fix Fault

Distribution Automation

0.5-5 sec*

Alert Operator

Restore Downstream

Restore Upstream Restore Downstream 0.5-5 sec*

<10 sec

Comparison of time taken for different fault isolation and restoration options. Detects Fault – Dispatch crew on receipt of fault information Restore Upstream – Restore power back from S/S A to first switching device (SW1). Crew travel time, Isolate fault (Open SW1) Restore Downstream– Restore power to segment between SW2 and Tie SW. Crew travel time, Isolate fault (Open SW2) & reroute power (Close tie SW) Fix Fault – Rectify the fault & revert back to normal * Actual restoration time varies based on the circuit configuration.

Network Reconfiguration Improving Reliability Efficient fault detection, isolation and restoration greatly enhances distribution grid reliability, reducing restoration time drastically from several hours to a few seconds or minutes. Distribution reliability performances are greatly enhanced, as are the indexes of CAIDI, SAIFI and SAIDI, which are commonly used as a reliability indicator by electric power utilities.

SAIDI:

CAIDI:

The System Average Interruption Duration Index is the average outage duration for each customer served.

The Customer Average Interruption Duration Index is SAIDI — SAIFI. CAIDI gives the average outage duration that any given customer would experience. CAIDI can also be viewed as the average restoration time.

SAIFI: The System Average Interruption Frequency Index is the average number of interruptions that a customer would experience.

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DGCS Switch Controller

Phase IOC

Phase Under voltage detection

The Multilin DGCS has one instantaneous overcurrent detection function Phase IOC. It consists of three separate instantaneous overcurrent elements; one per phase, with identical settings.

The phase UV protection protects voltage sensitive feeder loads and circuits against sustained under voltage conditions. The phase UV protection generates alarms when the voltage drops below the selected voltage level for the specified time delay.

Phase TOC The TOC in the Multilin DGCS comes with the following user selectable curves:

The TOC settings are applied to each of the three phases to produce pickup and alarm conditions per phase

The Voltage Unbalance feature in the Multilin DGCS detects voltage unbalances on a feeder. Voltage unbalance is defined as the ratio of negative-sequence to positive-sequence voltage. On unbalance an alarm is issued so the master station can take action to isolate and repair the damaged section. This could provide an indication to the system operator of a broken conductor causing a high impedance fault.

Neutral current detection

Power Loss

The Multilin DGCS has one Neutral Overcurrent detection function. The settings of this function are applied to the calculated neutral current for pickup and trip flags.

The Multilin DGCS can detects a power loss condition in each phase of the power distribution line.

Extremely/Very/Moderately/Normally Inverse, Definite Time, IEC Curve A/B/C and Short Inverse, IAC Extremely / Very / Inverse / Short, User Curve, FlexCurve A, FlexCurve B.

Distribution Automation

Voltage Unbalance detection

Overvoltage detection The phase OV protection protects voltage sensitive feeder loads and circuits against sustained overvoltage conditions. The phase OV protection generates alarms when the voltage exceeds the selected voltage level for the specified time delay.

Open/Close commands are blocked unless currents and voltages of each phase fall below minimum set values. When the switch is closed, the power loss detection of the source side is used to control the opening commands execution.

Reverse Power Detection On detection of Reverse Power, the Multilin DGCS prevents the Switch Open command from being executed during the Auto Sectionalizing sequence.

Functional Block Diagram

Auto Sectionalizing The Auto sectionalizing element provides a mechanism to localize a fault by coordinating this function with the reclosing operations of the feeder breaker within a timing schedule. 27P

59P

OPEN

CLOSE

Monitoring

50P

50N

51P

CLP

METERING

AUTO-SECTIONALIZING

ANSI Device Numbers & Functions Device Number 50P 50N 51P CLP 27P 59P

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Function Phase Instantaneous Overcurrent Neutral Instantaneous Overcurrent Phase Time Overcurrent Cold Load Pick Up Phase Time Overcurrent Over Voltage

The logic implemented in this element provides a way to detect several reclosing actions from the main circuit breaker and accordingly open the local switch, in periods when the voltage is absent. The logic uses the information of the overcurrent condition followed by a loss of voltage, loss of current, power flow direction and voltage detection functions to execute the transition into internal states.

Custom FlexCurves can be constructed to coordinate with other Up/down stream protection devices on a lateral

Automation & Control The Multilin DGCS offers powerful I/O and programmable logic (FlexLogic™) options for advanced automation and control, reducing the need and costs associated with additional programmable controllers or discrete control devices.

Remote Control For both operational efficiency and reliability reasons, the Multilin DGCS provides remote control for operating over-head recloser as well as Pad mounted switchgear. The Multilin DGCS has the capability to lock remote control operations locally to prevent remote control functionality. The Multilin DGCS is capable of providing both local and manual control of the switchgear. The compact size of the Multilin DGCS enables it to fit in existing out door Distribution Substations without the need for additional space.

Set Point Group Control The Multilin DGCS has three identical set point groups. The activation of the group can be done either from the HMI or via a digital input.

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DGCS Switch Controller

Virtual Inputs and Outputs

• Low Charge Limit Switch (LCL)

• Phase A, B, and C Currents (A)

The Multilin DGCS provides 32 virtual inputs and 32 virtual outputs that provide users with the ability to send commands to the device. The Multilin DGCS can accept commands from SCADA, through the front HMI, or front USB port to issue commands such as close or open.

• Spring Charge Limit (SCL)

• Positive, Negative, Zero Sequence Current

• Disconnect Closed & Latched (DCL)

• Ground Current (A)

• Open Visual Disconnect Contact

• 3-Phase Active Power (KW)

These inputs can be used to inhibit any possible local and remote closing and opening commands to the feeder switch.

• 3-Phase Reactive Power (KVar)

The Multilin DGCS is able to monitor other external states such as low battery conditions, ambient temperature.

• Pos. & Neg. (Import & Export) Real Energy (kWh)

Power Quality Measurements

• 2nd to 8th Harmonic up to 20% – for Current

The Multilin DGCS provides high accuracy metering and recording of all AC signals, measuring the following key parameters:

• 2nd to 8th Harmonic up to 20% – for Voltage

• Phase-Ground Voltages (kV)

These data points can be easily integrated into a customer’s database for seamless viewing through a SCADA or DMS system like GE’s PowerOn or GeNe.

Command Setting The Multilin DGCS has the ability to force commands from the menu structure. This can also be achieved via the EnerVista™ software that runs on a PC. This simulation ensures that the close and open commands can be safely issued from a distance without using the HMI.

FlexLogic™

• Phase to Phase Voltages (kV) • Positive, Negative, Zero Sequence Voltage

• Power Factor (Lag or Lead) • Pos. & Neg. (Import & Export) Reactive Energy (kVarh)

• THD in 20% – for Current • THD in 20% – for Voltage

Battery Management System The Multilin DGCS is capable of controlling the Feeder Switch in different conditions including power loss. The power loss can occur if the Line Recloser opens up or there is a distribution grid blackout. During all power loss conditions, the Multilin DGCS is supplied from a backup battery. The battery is a 24V Sealed Valve Regulated Lead Acid (SVRLA) battery. It is sized to keep the Multilin DGCS running for 8 hours.

Event record enables to analyze the sequence of events after each recloser action. Each event is stored with event number, date, time, and analog data of interest

During normal running conditions, the battery is connected to the charger. Switching to different modes of operation is controlled by the DGCS. The battery management system has the following modes of operations. • Run • Backup • Battery test • Fuse test A battery alarm LED is provided for alarms, and the event will be logged into the event recorder.

Metering & Monitoring The DGCS switch controller is able to monitor the switch state based on the auxiliary input 52a / 52b provided by the feeder switch. It can also be configured for several external inputs for monitoring possible errors provided by the switch.

Data logger helps in better understanding the analogue channel behavior. Sampling at a selectable time interval rate of 1 min to 60 minutes

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Distribution Automation

FlexLogic in the Multilin DGCS provides the ability to create customized control schemes. This minimizes the need and costs associated with auxiliary components and wiring. Schemes can be configured with FlexLogic specifying what actions need be taken based on the status of fault detections or control elements, as well as inputs driven by connected sensors and equipment.

• 3-Phase Apparent Power (KVA)

DGCS Switch Controller

Statistics & Counters

• Up to 256 consecutive events stored

Communications

• Open Counter

• Enable or disable, operate and dropout events by set points

The Multilin DGCS utilizes industry standard communications technologies making it one of easiest and most flexible controllers to use and integrate into new and existing SCADA or DMS infrastructures. Supported communication protocols include:

• Close Counter • KI2T Phase A Counter • KI2T Phase B Counter • KI2T Phase C Counter • Total Close/Open Operation

Maintenance Elements The maintenance elements in the Multilin DGCS provides alarms to the system based on the maximum number of closing/opening executed commands per period of time and I2t measurements per feeder.

Distribution Automation

Event Recorder To significantly reduce time and enable more effective distribution, post fault analysis and troubleshooting, the Multilin DGCS provides an integrated event recorder and detailed diagnostic features. The sequence of events recorder offers the following features:

• Phase voltage/current and power metering shot is also included and stored at each event

Data Management & Diagnostics The Multilin DGCS provides advanced disturbance diagnostic features that significantly reduce the time and costs associated with troubleshooting power system events and reconstruction. Recording functions include enhanced diagnostics with a 10 channel RMS recorder data logger.

• DNP 3.0

Advanced Device Health Diagnostics

The Multilin DGCS can also communicate to FDIR/FLISR/SCADA systems via wireless communications media. The supported wireless media includes:

Comprehensive device health diagnostic tests are performed by the Multilin DGCS during startup and continuously at runtime to test its own major functions and critical hardware. These diagnostic tests monitor for conditions that could impact the Multilin DGCS Controller’s performance, evaluates the potential impact and criticality of this condition, and presents the device status to operators via SCADA and/or through the front panel display.

• Modbus RTU (RS485) Multiple communication ports and protocols allow for remote control and easy access to device and system information. All communication ports are capable of simultaneous communications.

• Wireless radio (MDS or customer specific) • GSM/GPRS • Pre-wired for future radio

Front panel

Display: 4x20 character LCD display

USB 2.0 Port

Status LEDs

Status LEDs Quick access pushbuttons

Control Panel: Auto/Manual pushbutton Local/Remote pushbutton Manual Open/Close pushbuttons Multi-functional menu navigation keypad Target Reset

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DGCS Switch Controller

Security

Software & configuration

The Multilin DGCS Controller and associated software tools provide a suite of security features that ensure only approved personnel can make changes to the configuration of the system or execute commands. These functions enable a utility to meet NERC/CIP requirements.

The EnerVista™ Suite is an industry-leading set of software programs that simplifies every aspect of using the Multilin DGCS.

Password Security The Multilin DGCS offers multiple levels of password security to limit access control based on settings or command levels. There are four levels of password security provided: • Local settings access

EnerVista provides all the tools to monitor the status of the protected asset , maintain the controller and integrate information measured by the Multilin DGCS into SCADA or the DMS monitoring systems. The ability to easily view sequence of events is an integral part of the setup software, as postmortem event analysis is critical to proper system operation.

EnerVista Launchpad

• Remote settings access

EnerVista Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining GE’s Multilin products. The setup software within Launchpad allows configuring devices in real-time by communicating using serial, Ethernet or modem connections, or offline by creating setting files to be sent to devices at a later time.

• Remote control access Local access refers to users making changes using the front USB serial port and the HMI. Remote access refers to users making changes using the rear RS485 port one 24 hour day period.

• Manuals • Application notes • Guide form specifications • Brochures • Wiring diagrams • FAQs • Service bulletins

Distribution Automation

• Local control access

Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed. Documents made available include:

Set up with EnerVista™ Software

EnerVista setup software can reduce device set-up and configuration time with the help of easy to use drag & drop configuration menu.

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Technical Specifications POWER SUPPLY Nominal: Range: Power Consumption:

COMMUNICATION SERIAL RS485 port: Opto-coupled Baud rates: up to 115 kbps Response time: 1 ms typical Parity: None, Odd, Even Maximum distance: 1200 m (4000 ft) Isolation: 2 kV Protocol: Modbus RTU, DNP 3.0 USB Standard specification: Compliant with USB 2.0 Connector: 115 kbps TESTING AND CERTIFICATION ISO: Manufactured under an ISO9001 registered program PHYSICAL SPECIFICATIONS Enclosure Size: 356 mm (W) x 406 mm (H) x 254 mm (D); 14.0” (W) x 16.0” (H) x 10.0” (D) Weight (Base): 18 kg (excluding batteries)

24 to 48 V DC 20 to 60 V DC 16 W typical, 25 W maximum

AC CURRENT (OPTION A) Input type: Combined IA/SA Frequency: 50 or 60 Hz AC VOLTAGE: (OPTION B) Input type: 60 to 300 V AC Nominal frequency: 50 or 60 Hz AC VOLTAGE: (OPTION J) Input range: 0-12 V AC Nominal frequency: 50 or 60 Hz DIGITAL INPUTS: Type: opto-isolated inputs External switch: wet contact Maximum input 36 V AC voltage: DIGITAL OUTPUTS: Operate time: 10 ms Minimum contact load: 10 mA at 5 V DC Continuous current: 10 A Make & carry for 0.2s: 30 A per ANSI C37.90

ENVIRONMENT Ambient operating temperature: Ambient storage / shipping Temperature: Humidity: Pollution degree: Installation category: Overvoltage category: IP rating:

-40°C to +60°C [-40°F to +140°F] –40°C to +85°C [-40°F to +185°F] up to 90% non-condensing 2 Class I Class III NEMA 4/ IP65

Provides ingress protection rating of NEMA 4 (and equivalent IP rating – IP65) as defined by NEMA IEC 60529 for pole top installation.

Ordering DGC Application Language Power Supply Communication Options I/O

S S

E

L

S

S

A

*

*

B J

B J

*

*

1

*

E L S S A

E

Wireless Radio Option

E

E

E

E

D G

D G X 1 2 4 5

X

X

X

Description Switch Controller English (Standard) Low (20 to 60vdc) RS485 Modbus RTU / DNP3.0 (Standard) Standard Current Input Card (1A/5A) Voltage Input Card (60 - 300VAC) Sensor Input Card (0-12V) Two (2) 10 A Form-A relays and six (6) 20 to 60V DC digital Inputs (2xIO_E Standard), Max 3xIO_E Four (4) 10A form-C relays (Optional, Max 1 IO_D) 3 RTD (Optional, Max 1 IO_G) None MDS TransNet MDS iNET-II Prewired for future radio with 12VDC Power Supply installed Prewired for future radio with 24VDC Power Supply installed

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12915(E) English 150123

Motor Protection Motor Principles & Protection

345

Motor sizing and applications and the differences between inductions and synchronous motors. Key principles for understanding motor protection and using system diagnostics to maintain proper operation.

Typical Applications

355

Typical Motor protection applications are shown detailing several protection schemes including Differential Protection and Medium and Low Voltage Protection. Each application identifies the corresponding protection system.

Spotlight Application

358

Process applications depend on critical communications and controls systems. Utilizing both advanced motor protection techniques and dedicated communications networks ensures maximum process uptime.

Technical Resources

360

Access an extensive library of interactive tools and videos showcasing innovative solutions, as well as online publications, technical resources, how-to videos and motor protection configurators.

Selector Guide

361

A reference table highlighting the feature set for each motor protection system, allowing for quick and easy identification of products to assist in choosing the correct product for the specific application.

Featured Products Featured Product brochures for Multilin motor protection systems.

362

Motor Protection Principles

Motor Principles Introduction A motor is an electric machine that converts Electrical energy to Mechanical energy with typical 98% efficiency. An electric motor is powered from an external electric AC or DC power source. The energy generated by the motor, also known as mechanical energy, can be used to drive several different types of equipment such as pumps, compressors, fans, etc. The power a motor generates determines how it is rated, and is measured in either kilowatts (kW) or horsepower (Hp). Horsepower and kilowatts the

standard unit of measure for electric motors. One horsepower is equivalent to 746 watts. Hp = kW / 0.746 kW = HP x 0.746 Ratings of AC and DC motors can range from as little as a micro horsepower up to and over 100,000 horsepower. The motor’s application will determine the necessary size.

1 - 500

800

4,000

15,000

100,000

KW

1 - 373

597

2,984

11,190

74,600

Motor Protection

HP

Small to Medium Motor

Medium to Large Motor

Large to Extra Large Motor

Figure 1. Motor power range

Induction Motors Three-phase induction motors are the motors that are most commonly used in the industry. They are inherently simple, rugged, cost effective and easy to maintain. Induction motors range in horsepower from fraction horsepower to several thousand horsepower. A three-phase induction motor consists of two main parts: the stationary stator and the rotating rotor. The rotor is separated from the stator by a small air gap which ranges from 0.4 mm to 4 mm depending on the size of the motor. The stator consists of a steel frame which supports a hollow, cylindrical core made up of stacked laminations. A number of evenly spaced slots, punched out of the internal circumference of the laminations, provide the space for the stator windings. The rotor is also composed of punched laminations. These are stacked to create a series of rotor slots to provide space for the rotor winding.

Figure 2. Induction motor

Power is applied from the stator to the rotor by means of electromagnetic induction, which causes the rotor to rotate when power is applied to the stator.

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Motor Protection Principles

Synchronous Motors Synchronous motors are used mainly when an application requires the motor speed to be consistent without load fluctuations, and also to assist in regulating power quality and power factor.

The major difference between a synchronous and an induction motor is in their respective rotors. Unlike an induction rotor, which consists of laminations and rotor bars, the synchronous rotor has field windings wrapped around protruding poles that create a DC field. A synchronous motor will start similar to an induction motor. When a predetermined amount of slip is reached a DC field will be applied to the rotor. Once the DC field is applied, the rotor will lock in with the stator creating synchronous operation.

Field windings wrapped around Rotor

Figure 3. Medium voltage synchronous motor

Motor Protection

Figure 4. Rotor of a synchronous motor

Figure 5. Medium voltage motor core

Motor Application Considerations Induction • Pumps

• Conveyors

• Shredders

• Fans

• Crushers

• Extruders

• Compressors

• Mixers

Synchronous • Compressors (High & Low Speed)

• Vacuum Pumps

• Fans (High & Low Speed)

• Chippers

• Extruders

• Special Apps. with Large AFDs

• Refiners

• Mining Mills

Figure 6. Typical applications for Induction and Synchronous motors

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Motor Protection Principles

Motor Applications Variable Speed Drives Motor Applications

Cyclic or Reciprocating Load Motor Applications

Variable frequency drive (also known as variable speed drive, adjustable frequency drive or AC Drive) is widely known by the industry to achieve improved process control and increase plant efficiency, resulting in reduced energy consumption and cost, and increased production.

In every part of small or large industry, cyclic or fluctuating mechanical loading of the motor can be very easily found in applications such as crushers, pumps, cranes, compressors, movers etc. Load variation can be typically from very light to overload capability of the motor during a load cycle.

Controlling the motor with a variable frequency drive (VFD) can be found in applications such as compressors, fans, and centrifugal pumps, blowers where varying speed and torque is required.

Many motor protection functions including Thermal protection cannot operate correctly if the protective relay does not have provision to adjust to such continuously changing load current. Standard overcurrent relays will occasionally trip even before the thermal capacity of the motor is exceeded.

VFD driven motor applications require special considerations when applying the standard motor protection. To ensure reliable protection of the motor driven by VFD, dynamic change in the motor characteristics must be taken into account in order to provide adequate motor protection.

Motor Protection

Motors in a Typical Mining Application Electric motors are the workhorse and backbone of industrial process applications. Motors ranging from medium voltage large motors to low voltage small motors can be found in applications such as oil & gas, water treatment, and as shown below, the mining industry. Medium voltage motors can be used in applications such as crushers, grinding, and large pumps and fans where high horsepower ratings are required to process or move material. Low voltage motors are typically used in secondary process applications in the mid to final stages of the process of the material. These motors are vital to ensure the process remains running in order to finalize the process of the material. With motors found in many different processes in each application, it is vital to ensure each motor is adequately protected so that process uptime is not interrupted. Before motor protection can be implemented, vital information, known as motor performance data, is required to ensure correct configuration.

Figure 7. Motor applications in the mining process

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Motor Performance Data Correct motor protection setup and configuration is essential to ensuring proper operation, performance, and efficiency of a motor.

This information can be used to configure the Motor Protection Device to ensure overall performance of the motor is maximized.

Key elements to ensuring correct protection setup of the motor relies on the Motor Performance Data, or Motor Nameplate Data, which is supplied by the motor manufacturer.

The Motor Performance Data as shown in Figure 8, identifies key information required to set up the Motor Protection Device.

1. Thermal Overload Pickup • The thermal overload pickup is set to the maximum allowed by the service factor of the motor. In this case it would be set to 1.10 x FLC for the motor service factor of 1.00. If the service factor is unknown we must assume 1.00.

2. Voltage Sensing • The connection type (wye or delta) is required for the relay to perform proper calculations. In this example a 4160/120 PT will be required with a ratio of 35:1.

3. Motor FLA and Phase CT’s Motor Protection

• Motor FLA is applied to the motor protection device, and in this case is 413 amps. FLA also dictates the CT’s required size. • FLA should be 50% - 100% of chosen CT primary. This logic will provide accurate protection pick-up and metering.

4. Starting Time • The starting time is the maximum amount of time the motor takes to achieve full load speed. The motor nameplate data will typically list the starting times at 100% and 80% rated voltage, in this case 3.4 seconds for 100% and 6.1 seconds for 80%. Should the starting time at the respective voltage level exceed the designated start time the relay will trip the motor offline.

5. Number of Consecutive Starts • Relates to the thermal heating effects experienced by the motor during starting conditions. Since the motor will experience a high inrush of current during starting, which increases the Thermal Capacity used, the motor can only safely start a certain number of times within an hour.

Figure 8. Typical motor performance data sheet

• In this example the motor can safely be started 3 times when the motor is cold or at ambient temperature, or 2 times hot.

Additional Essential Data Sensitive Ground CT

Overload Curve

For high resistance grounded systems, sensitive ground detection is possible with the 50:0.025 CT. On solidly grounded or low resistance grounded systems where the fault current is much higher, a 1A or 5A secondary CT should be used. If residual ground fault connection is to be used, the ground fault CT ratio must equal the phase CT ratio. If residual connection is used, pickup levels and timers must be set with respect to the acceleration time. The zero sequence CT chosen needs to be able to handle all potential fault levels without saturating.

The overload curve should be chosen so that the curve falls in between the Cold Thermal Limit Curve and the Hot Thermal Limit Curve. The correct overload curve will provide the most accurate protection of the motor and allow for maximum process uptime.

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Motor Protection

Motor Protection There are two main risks for an overheated motor: Stator windings insulation degradation and rotor conductors deforming or melting. Insulation lifetime decreases by half if the motor operating temperature exceeds its thermal limit by 10ºC. There are a number of conditions that can result in damage to three-phase motors. These damages are a result of operating conditions or internal or external faults. External faults and operating conditions include: undervoltage, asymmetrical loading, phase and ground faults on the motor feeder and overloading during starting and running operation. Internal faults include: ground faults, faults between windings and inter-turn faults.

FAULT TYPE

PROTECTION PHILOSOPHY

INTERNAL FAULT Stator ground faults

Ground/Neutral IOC/TOC (50/51G/N), Neutral Directional TOC (67N)

Stator phase faults

Phase differential protection (87), Phase IOC/TOC (50/51P), Phase short circuit (50 P)

EXTERNAL FAULT Motor Protection

Overheating

Overload - Thermal model with Programmable Curves and biased with RTD and/or Unbalance (49/51) Voltage Dependant Curve for Large Inertia Loads Overtemperature via thermistors and/or RTDs (38,49) Locked rotor / mechanical jam, Stall Protection (39, 51R) Jogging, Starts/hour, time between starts, restart time delay (66), Acceleration Time Logic

Overload Protection Three-phase motors are designed in such a way that overloads must be kept below the machine thermal damage limit. The motor thermal limits curves, Figure 9, consist of three distinct segments, which are based on the three running conditions of the motor: the locked rotor or stall condition, motor acceleration and motor running overload. Ideally, curves should be provided for both hot and cold motor conditions. For most motors, the motor thermal limits are formed into one smooth homogeneous curve. The protective relay integrates stator and rotor heating into a single model, by measuring the terminal currents. The Thermal capacity Used (TCU) value is maintained in a register and when the motor is on overload, the motor temperature and the TCU will rise. When the TCU reaches 100% a trip occurs. When the motor is stopped and is cooling to ambient, the TCU decays to zero. The thermal model curve determines the thermal limit overload conditions that can damage the motor. This curve accounts for motor heating in both the stator and rotor during stall, acceleration, and running conditions. The overload curve that matches the thermal limit of the motor can be applied using one of the three formats: Standard Motor Curves, IEC Hot and Cold Curves and Custom Curves (FlexCurves). The acceleration curves, Figure 9, are an indication of the amount of current and associated time for the motor to accelerate from a stop condition to a normal running condition.

Reduced voltage start (19) Incomplete sequence (48) Overload lock-out (86) Overload - Thermal model with Programmable K factor setting

Phase reversal

Negative Sequence Overvoltage (47)

Abnormal voltage

Overvoltage (59), Undervoltage (27)

Abnormal frequency

Overfrequency (81O), Underfrequency (81U), Speed switch (14)

Loss of load

Undercurrent/minimum load (37), Underpower, Sensitive Directional Power (32)

Back-Spin

Back-Spin Detection

Breaker failure

Breaker failure (50BF)

Power factor

Power factor (55)

Feeder Ground Fault

Ground/Neutral IOC/TOC (50/51G/N) Neutral Directional TOC (67N)

Feeder Phase Fault

Phase differential protection (87), Phase IOC/TOC (50/51P), Phase short circuit (50 P)

Time (Seconds)

Phase unbalance

Table 1. Motor faults

Motor Rated Current A. Cold Running Overload B. Hot Running Overload C. Cold Locked Rotor Curve D. Hot Locked Rotor Curve E. Acceleration curve @ 80% rated voltage F. Acceleration curve @ 100% voltage

Figure 9. Motor thermal limits curves

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Motor Protection

Typical Estimate: K=

• Motor start inhibit • Standard, custom and voltage dependent overload curves • Thermal model biasing by measured current unbalance and RTD’s • Separate thermal time constants for running and stopped motor conditions • Independent current unbalance detector • Acceleration limit timer • Mechanical jam detector • Start and restart supervision

Motor Protection

The primary protective element of the motor protection relay is the thermal overload element and this is accomplished through motor thermal image modeling. This model must account for all thermal processes in the motor while the motor is starting, running at normal load, running overloaded and if the motor is stopped. The algorithm of the thermal model integrates both stator and rotor heating into a single model. If the motor starting current begins to infringe on the thermal damage curves or if the motor is called upon to drive a high inertia load such that the acceleration time exceeds the safe stall time, custom or voltage dependent overload curves may be required. Negative sequence currents (or unbalanced phase currents) will cause additional rotor heating that will not be accounted for by electromechanical relays and may not be accounted for in some electronic protective relays. The main causes of current unbalance are: blown fuses, loose connections, stator turn-to-turn faults, system voltage distortion and unbalance, as well as external faults.

Thermal models can have the following enhancements and additions:

Time

Usually, for large motors, there are two acceleration curves: Curve F is the acceleration curve at rated stator voltage while curve E is the acceleration at 80% of rated stator voltage (soft starters are commonly used to reduce the amount of inrush current during starting). Starting the motor on a weak system can result in voltage depression, providing the same effect as a soft-start.

175 I2LR

100% Full Load Amps

Conservative Estimate:

K=

Time

NEMA 230 I2LR

80% Full Load Amps

Acceleration Curve Voltage Dependant Overload Curve Figure 11. Voltage dependant overload curves

Multilin Figure 10. Motor derating curves

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Motor Protection

The current unbalance cause rotor heating in addition to the normal heating caused by positive sequence currents. The curves on Figure 10 shows recommended NEMA derating as a function of voltage unbalance. Multilin motor protection relays allows the biasing of the Thermal model to comply with the NEMA standards. The Thermal Model is also biased by the RTD’s temperature feedback, as shown in Figure 10. This feature allows the relay to protect the motor against unusual high ambient temperatures or abnormal heating due to overvoltage or damaged bearings. The RTD biasing feature can correct for this temperature rising by forcing the TCU register up to the value appropriate to the temperature of the hottest stator RTD.

Motor Protection

Cyclic Load Motor Applications Input currents of a motor driving cyclic load can vary between very low to above the maximum allowable current during a load cycle. Variation in current magnitude results in motor heating and cooling depending on the heat and cooling time constants. Thermal overload protection response is made adaptive to the cyclic load based on the cooling time constants. In addition, to provide more accurate overload thermal model response to cyclic load, the input currents to the thermal model are averaged over the duty cycle interval. With a reciprocating load application, the number of cycles to average can be determined from current waveform capture using the Oscillography/Datalogger features in the GE motor protection relays.

Variable Frequency Drive Motor Applications Variable frequency drives (VFD) generate significant distortion in voltages introducing harmonics. However, distortion due to these harmonics is not as significant in currents as in voltages. Moreover, VFD motor application can have various possible system configurations such as motor start and run through the VFD only or motor run through the bypass switch without VFD but the VFD is required for starting. The capability of the motor relay is to ensure the secure operation of the relay due to distorted motor ac signals and system configurations while maintaining the high sensitivity to the abnormal system/motor conditions. Thermal protection takes into account the extra heating generated by the higher harmonics due to VFD in order to achieve the accurate response to the actual motor heating. RMS currents fed to the various motor protection elements are further processed through the averaging filter in order to eliminate oscillations in current signals to ensure the security. Sensitivity to faults detection such as short circuit, ground fault and differential protection is maintained by using the RMS currents.

The relay protecting the motor must be able to distinguish between a locked rotor condition and an accelerating condition for different levels of the system voltage e.g 80% and 100% of the rated voltage. Voltage is continually monitored during motor starting and the acceleration thermal limit portion of the relay overload curve is dynamically adjusted based on motor voltage variations. The acceleration thermal limit is a function of motor speed during the start. The dynamically shifted voltage dependent overload curve inherently accounts for the change in motor speed as a function of motor impedance. The change in impedance is reflected by motor terminal voltage and line current. This method aids to set dynamically the appropriate value of the thermal limit time for any given line current at any given terminal voltage.

Two-Speed Motor Protection The two-speed motor protection is provided for motors having two windings wound into one stator. One winding, when energized, provides one of the speeds. When the second winding is energized, the motor takes on the speed determined by the second winding. The two-speed motor feature provides proper protection for a two-speed motor where there will be two different full load values. Overload protection integrates the heating at each speed into one thermal model using a common thermal capacity used register value for both speeds.

Differential Protection This protection function is mostly used to protect induction and synchronous motors against phase-to-phase faults. Differential protection may be considered the first line of protection for internal phase to phase or phase to ground faults. In the event of such faults, the quick response of the differential element may limit the damage that may have otherwise occurred to the motor. The differential protection function can only be used if both sides of each stator phase are brought out of the motor for external connection such that the phase current going into and out of each phase can be measured. The differential element subtracts the current coming out of each phase from the current going into each phase and compares the result or difference with the differential pickup level. If this difference is equal to or greater than the pickup level a trip will occur. GE Multilin motor protective relays support both three and six CT configurations. For three CT configuration (Figure 12) both sides of each of the motors stator phases are being passed through a single CT. This is known as the core balance method and is the most desirable owing to its sensitivity and noise immunity.

High Inertia Load The thermal model has an additional enhancement that allows the coordination of protection with high-inertia long starts. It is quite possible and acceptable for the acceleration time to exceed the safe stall time (keeping in mind that a locked rotor condition is different than an acceleration condition). The voltage dependent overload curve feature is tailored to protect these types of motors by employing the varying thermal limits corresponding to the acceleration current levels. This curve is composed of the three characteristic of thermal limit curve shapes as determined by the stall or locked rotor condition, acceleration, and running overload. Figure 12. Differential protection of phase to phase faults

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Motor Protection

If six CT’s are used in a summing configuration, during motor starting, the values from the two CT’s on each phase may not be equal as the CT’s are not perfectly identical and asymmetrical currents may cause the CT’s on each phase to have different outputs. To prevent nuisance tripping in this configuration, the differential level may have to be set less sensitive, or the differential time delay may have to be extended to ride through the problem period during motor starting. The running differential delay can then be fine tuned to an application such that it responds very fast and is sensitive to low differential current levels. The Biased Differential protection method allows for different ratios for system/line and neutral CT’s. This method has a dual slope characteristic to prevent a maloperation caused by unbalances between CT’s during external faults. CT unbalances arise as a result of CT accuracy errors or CT saturation.

Ground Fault Protection Damage to a phase conductor’s insulation and internal shorts due to moisture within the motor are common causes of ground faults. A strategy that is typically used to limit the level of the ground fault current is to connect an impedance between the neutral point of the motor and ground. This impedance can be in the form of a resistor or grounding transformer sized to ensure that the maximum ground fault current is limited to a level that will reduce the chances of damage to the motor.

Unbalance Protection Unbalanced load in the case of AC motors is mainly the result of an unbalance of the power supply voltages. The negative-sequence reactance of the three-phase motor is 5 to 7 times smaller than positive-sequence reactance, and even a small unbalance in the power supply will cause high negative sequence currents. For example for an induction motor with a starting current six times the full load current, a negative sequence voltage component of 1% corresponds to a negative sequence current component of 6%. The negative-sequence current induces a field in the rotor, which rotates in the opposite direction to the mechanical direction and causes additional temperature rise. Main causes of current unbalance are: system voltage distortion and unbalance, stator turn-to-turn faults, blown fuses, loose connections, and other internal motor faults.

Single Phasing During motor running condition, loss of current in one of the three phases results in the increase in other two phases currents by 1.73 times rated full load current. Single phasing element provides a special form of protection for an unbalance condition when current in any one of the three phases is less than the cutoff level while average of the three currents is more than 25% of the rated full load current.

Short Circuit

Power Lead

The short circuit element provides protection for excessively high overcurrent faults. When a motor starts, the starting current (which is typically 6 times the Full Load Current) has asymmetrical components. These asymmetrical currents may cause one phase to see as much as 1.7 times the RMS starting current. As a result the pickup of the short circuit element must be set higher than the maximum asymmetrical starting currents seen by the phase CTs to avoid nuisance tripping. The breaker or contactor that the relay is to control under such conditions must have an interrupting capacity equal to or greater then the maximum available fault current.

Zero Sequence CT -20 + 20 + 0 = 0 Current

Figure 13. Ground fault CT configuration

Figure 14. Phase to ground fault

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Motor Protection

There are several ways by which a ground fault can be detected. The most desirable method is to use the zero sequence CT approach, which is considered the best method of ground fault detection methods due to its sensitivity and inherent noise immunity. All phase conductors are passed through the window of a single CT referred to as a zero sequence CT. Under normal circumstances, the three phase currents will sum to zero resulting in an output of zero from the zero sequence CT’s secondary. If one of the motor’s phases were shorted to ground, the sum of the phase currents would no longer equal zero causing a current to flow in the secondary of the zero sequence CT. This current would be detected by the motor relay as a ground fault.

If the cables are too large to fit through the zero sequence CT’s window or the trench is too narrow to fit the zero sequence CT, the residual ground fault configuration can be used. This configuration is inherently less sensitive than that of the zero sequence configuration, owing to the fact that the CT’s are not perfectly matched. During the motor start, the motor’s phase currents typically rise to magnitudes greater than 6 times the motors full load current. The slight mismatch of the CT’s combined with the relatively large phase current magnitudes produce a false residual current, which will be seen by the relay. This current can be misinterpreted by the motor relay as a ground fault unless the ground fault element’s pickup is set high enough to disregard this error.

Motor Protection

Undervoltage

Load Loss Detection

If an induction motor operating at full load is subjected to an under voltage condition, full load speed and efficiency will decrease and the power factor, full load current and temperature will increase. The undervoltage element can be considered as backup protection for the thermal overload element. If the voltage decreases, the current will increase, causing an overload trip. In some cases, if an undervoltage condition exists it may be desirable to trip the motor faster than the overload element.

Undercurrent protection is useful for indicating the loss of suction in a pump application or a broken belt in a conveyor application. The second method of load loss detection is the use of the underpower protection element. A loss of load condition will not always cause a significant loss of power. Power is a more accurate representation of loading and may be used for more sensitive detection of load or pump cavitations.

The overall result of an undervoltage condition is an increase in current and motor heating and a reduction in overall motor performance.

Motor Protection

Overvoltage When the motor is running in an overvoltage condition, slip will decrease as it is inversely proportional to the square of the voltage and efficiency will increase slightly. Overvoltage causes an increase in magnetization current due to an increase in iron losses, and could cause the motor to overheat, but at a given shaft load, the overvoltage also causes a decrease in load current and the resulting total current will be less than the motor current at rated voltage. Therefore, higher stator winding temperatures at higher voltages are unlikely. However, if the magnetization current increases due to overvoltage while the load current were to remain constant, the motor operating temperature would increase. The only way to protect a motor against overvoltage conditions is by utilizing a device that senses winding temperature. Multilin relays include options to sense motor’s temperature with RTD’s and also includes overvoltage alarm and trip features to allow alarming or tripping of the motor under extended overvoltage conditions.

Mechanical Jam An induction motor stalls when the load torque exceeds the breakdown torque and causes its speed to decrease to zero, or to a point below rated speed. The mechanical jam element is designed to operate for running load jams due to worn motor bearings, load mechanical breakage and driven load process failure. This element is used to disconnect the motor on abnormal overload conditions before the motor stalls. In terms of relay operation, the Mechanical Jam element prevents the motor from reaching 100% of its thermal capacity while a mechanical jam is detected. After a motor start, once the magnitude of any one of either phase A, B, or C exceeds the Trip/ Alarm pickup level x FLA for a period of time specified by the delay, a trip/ alarm will occur. It helps to avoid mechanical breakage of the driven load and reduce start inhibit waiting time by taking the motor off-line quicker than the thermal model or overload curve.

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Start Inhibit/Start Supervision Start inhibit functions supervise and prevent the motor restarting once stopped, until this condition clears and/or a set time expires. Start supervision comprises of four elements: Thermal Start Inhibit, Maximum Starting Rate, Time Between Starts and Restart Delay. Each of these function are meant to inhibit the motor start and do not trip a motor that is already running. Thermal Inhibit function is provided to inhibit starting of a motor if there is insufficient thermal capacity available for a next successful start. Maximum Starting Rate function defines the configurable number of start attempts allowed in a pre-defined time interval. Motor is not allowed to start if number of starts within an interval exceeds the maximum number of allowable starts usually available from the motor nameplate. The Time Between Starts function enforces a configurable minimum time duration between two successive start attempts. A time delay is initiated with every start attempt, and a new start is not allowed until the specified interval has elapsed. The timer feature is useful in enforcing the duty limits of starting resistors or starting autotransformers. The Restart Delay feature is used to ensure that a certain amount of time passes between time a motor is stopped and a new start of that motor. This timer feature can be very useful for some process applications or motor considerations. If a motor is on a down-hole pump, after the motor stops, the liquid can fall back down the pipe and spin the rotor backwards. It is very undesirable to start the motor at this time.

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Typical Applications

Motor Protection ­‑ Typical Applications Large MV motor - Two sets of CT’s for differential protection Typical Functions

46

Current Unbalance

87S

Stator Differential

47

Phase Reversal

49

Thermal Overload

27P

Undervoltage

49RTD

RTD Biased Thermal Overload

59P/N

Overvoltage

49S

Stator RTD

67P/N

Directional Overcurrent

38

Bearing RTD

32

Directional Power

51R

Mechanical Jam

81U

Underfrequency

50P/G

Instantaneous Overcurrent

81O

Overfrequency

51P/G

Time Overcurrent

50BF

Breaker Failure

66

Starts per hour

Functions

Typical Product Order Code

Typical Functions

869-E-P5-P5-B5-H-R-R-A-N-N-G-M-P-B-B-SE-N-N-B-N M60-U00-HKH-F8L-H6P-M8N-P5C-UXX-WXX Copper

869-E-P5-P5-B5-H-R-R-A-N-N-G-M-P-B-B-SE-N-N-B-N M60-U00-HKH-F8L-H6P-M8N-P5C-UXX-WXX

Fiber

869-E-P5-P5-B5-H-R-R-A-N-N-G-M-P-B-B-1E-S-N-B-N M60-U00-HKH-F8L-H6P-M8N-P5C-UXX-WXX

Standalone

HEA61-A-RU-220-X2

Lockout

Integrated

869-E-P5-P5-B5-H-R-R-A-N-N-G-M-P-B-B-SE-N-N-B-N M60-U00-HKH-F8L-H6P-M8N-P5C-U4L-WX

Remote RTD

RRTD

RRTD-HI-IO-F-O

Motor Protection

Ethernet Communications

Large MV motor - One set of CT’s for differential protection Typical Functions

51P/G

Time Overcurrent

87S

50BF

Breaker Failure

66

Starts per hour

Stator Differential

49

Thermal Overload

46

Current Unbalance

49RTD

RTD Biased Thermal Overload

47

Phase Reversal

49S

Stator RTD

27P

Undervoltage

38

Bearing RTD

59P/N

Overvoltage

51R

Mechanical Jam

14

Speed Switch

50P/G

Instantaneous Overcurrent

55

Power Factor

Functions

Typical Product Order Code

Typical Functions

869-E-P5-P5-B5-H-R-R-A-N-N-G-S-P-B-B-SE-N-N-B-N M60-U00-HKH-F8L-H6P-M8N-P5C-UXX-WXX

Communications

Lockout Remote RTD

GEDigitalEnergy.com

Ethernet & Serial

869-E-P5-P5-B5-H-R-R-A-N-N-G-S-P-B-B-SE-N-N-B-N

DeviceNet

469-P5-HI-A20-D

Standalone

HEA61-A-RU-220-X2

Integrated

869-E-P5-P5-B5-H-R-R-A-N-N-G-S-P-B-B-SE-N-N-B-N M60-U00-HKH-F8L-H6P-M8N-P5C-U4L-WXX

RRTD

RRTD-HI-IO-F-O

355

Typical Applications

Large or medium size MV motor

Typical Functions

51G

Time Overcurrent

49

Thermal Overload

66

Starts per hour

49RTD

RTD Biased Thermal Overload

46

Current Unbalance

49S

Stator RTD

47

Phase Reversal

38

Bearing RTD

27P

Undervoltage

51R

Mechanical Jam

59P/N

Overvoltage

50P/G

Instantaneous Overcurrent

37

Undercurrent

Functions

Typical Product Order Code

Typical Functions

869-E-P5-NN-G5-H-R-R-A-N-N-G-S-P-B-B-SE-N-N-B-N M60-U00-HKH-F8L-H6P-M8N-P5C-UXX-WXX 469-P5-HI-A20-E 369-HI-R-M-0-0-0 Ethernet & Serial

869-E-P5-NN-G5-H-R-R-A-N-N-G-S-P-B-B-SE-N-N-B-N M60-U00-HKH-F8L-H6P-M8N-P5C-UXX-WXX 469-P5-HI-A20-T 369-HI-R-M-0-E-0

DeviceNet

469-P5-HI-A20-D 369-HI-R-M-0-D-0

Profibus

369-HI-R-M-0-P-0

Standalone

HEA61-A-RU-220-X2

Integrated

869-E-P5-NN-G5-H-R-R-A-N-N-G-S-P-B-B-SE-N-N-B-N M60-U00-HKH-F8L-H6P-M8N-P5C-U4L-WXX

Communications

Lockout

869-E-P5-NN-G5-H-R-R-A-N-N-G-S-P-B-B-SE-N-N-B-N 469-P5-HI-A20-E-H 369-HI-R-M-0-0-H

Motor Protection

Harsh Environment

Medium size MV motor

Typical Functions

51G

Time Overcurrent

49

Thermal Overload

46

Current Unbalance

49RTD

RTD Biased Thermal Overload

66

Starts per hour

49S

Stator RTD

37

Undercurrent

38

Bearing RTD

51R

Mechanical Jam

50P/G

Instantaneous Overcurrent

Functions

Typical Product Order Code

Typical Functions

869-E-P5-NN-G5-H-R-R-A-N-N-G-S-P-B-B-SE-N-N-B-N 369-HI-R-M-0-0-0 339-E-P1-G1-H-S-S-N-1E-D

Communications

Lockout

Ethernet & Serial 869-E-P5-NN-G5-H-R-R-A-N-N-G-S-P-B-B-SE-N-N-B-N 369-HI-R-M-0-E-0 DeviceNet

369-HI-R-M-0-P-0

Standalone

HEA61-A-RU-220-X2 869-E-P5-NN-G5-H-R-R-A-N-N-G-S-P-B-B-SE-N-N-B-N 369-HI-R-M-0-0-H 339-E-P1-G1-H-S-S-N-1E-D-H

Harsh Environment Remote RTD

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GEDigitalEnergy.com

369-HI-R-M-0-D-0

Profibus

RRTD

RRTD-HI-IO-F-O

Typical Applications

Small size, MV or LV motor

Typical Functions

51R

Mechanical Jam

49

Thermal Overload

50G

Instantaneous Overcurrent

49RTD

RTD Biased Thermal Overload

46

Current Unbalance

49S

Stator RTD

27P

Phase Undervoltage

38

Bearing RTD

37

Undercurrent

Functions

Typical Product Order Code

Typical Functions

MM300-B-E-H-S-S-C-A-G MM200-B-X-H-2-S 339-E-P1-G1-H-S-S-N-1E-D

Lockout Harsh Environment

Standalone

HEA61-A-RU-220-X2 339-E-P1-G1-H-S-S-N-1E-D-H

Motor Protection

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Application Spotlight

Advanced, Flexible Motor Protection In typical refinery applications, there is traditionally one communication network communicating data to both the Electrical Engineering and the Process Control groups. Since this network is designed with the Process Control groups’ requirements in mind, limited electrical information is available to the Electrical Engineering group.

The Process Control group is responsible for set-up and maintenance of the overall process of the facility. The Electrical Engineering group is responsible for troubleshooting problems, maintenance, and fixing the electrical equipment. Each group has their own management and control system, each with very different requirements.

As a result, the Electrical Engineering group does not have the visibility and remote access to connected loads for essential operational information and statistics required for efficiency.

Motor Protection

Industrial applications depend on a communications highway within the facility to ensure proper operation of both the process and electrical systems. In traditional industrial applications there are two different groups of people that are responsible to ensure the facility maintains continual operation, the Process Control Group, and the Electrical Engineering Group.

Electrical Engineers Remote read/write access to: Waveform Data Event Record Settings Files

Process Control Operators (DCS) Increased response time Increased Efficiency Decreased Downtime

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PLC

Application Spotlight

Using Simultaneous Communications Without remote access to this critical information, remote troubleshooting of electrical system problems are not possible, increasing system downtime. With the implementation of the Multilin MM300 for LV motors or Multilin 869 for MV motors, dedicated individual networks for both the Process and Control group and the Electrical Engineering group, is possible.

This also provides the Process and Control group a network designed specifically for the process application ensuring maximum system response and efficiency. With the Multilin MM300 and Multilin 869 motor management systems, simultaneous high-speed communications allow critical information to be transmit remotely, ensuring a higher level of system stability and efficiency, without compromising data integrity.

By having individual networks at field level devices, the Multilin MM300 and Multilin 869 provide dedicated communications to the Electrical Engineering Group. This allows remote access to critical electrical operation information such as; event records, data log files, motor learned data, waveform captures, operational status, full settings files, and troubleshooting.

Motor Protection

Dedicated Electrical Engineering Network

MM300

869

• Programmable Automation

• Advanced Motor Health Diagnostics

• Advanced Diagnostics

• Flexible, High-Density I/O

• Multiple I/O options

• Redundant communications

• Comprehensive communications

• Programmable Logic Engine

Dedicated Process Control Network

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Extensive library of interactive tools & videos 

Broad range of publications & technical resources

SOLUTIONS

SELECTOR GUIDES for motor products

Motor Protection

to motor challenges

Discover ways to get the most out of your motor protection, through simplified management , flexible communications and advanced diagnostics.

“How To” videos &

Compare, filter and select your product by protection, control, automation, and communications features o fit your application needs.

online product

TRAINING

CONFIGURATORS

Access over 60 step-by-step product videos and technical training to help you get the most out of your products.

Configure, price and easily order your motor protection products and accessories on the Digital Energy online store.

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Product Selector Guide

Motor Protection – Selector Guide Features

Device

MM200

MM300

•

•

339

369

469

869

M60

•

•

• • • • • •*

• • • • • •*

• •

• • • • • •

• • • • • • •1 •

•

49

•

•

•

• •

66 48 19

•

• • •

• •

• •

• • •

•

• • • • •

50LR 50P/G/SG/N 51P/G/SG/ 87S 67P/G/N 46 37 59P/N/X 27P/X 59_2 VTFF 47 81U/O 32R 55 49 49 50BF

• G/SG G/SG

• G/SG G/SG

• •

• • P P/X

86

•

• • P/G/SG G/N

• • P/G/SG

• • • P/G/SG

• • •

• • P P

• • P P

•

• • •

• • • • • • •

•

•

•

•

7 DC/6 AC 3

30 18

8 7

5 4

•

6 • •

X

• •

•

• • •

•

• • • • • •

• • • • •

• • • • • • • •* •

• •* •

• • •

7 (9 w/ SPM) 6 (9 w/SPM) 4 4 12

14 10 •1 •1 12

80 64 24 4 24

•

• • • •

• • • • •

• • • • • • • • • • 1024 128 • • • • • •

• • • • • • • • •

•

• •

256 32 • • •

512 32 • • • • •

512 16 • • • • •

256 12 • • •

• •

• •

• •

• •

• •

•

•

• • • • • • • • •

•

1 • • •

• • •

•

• • • • • • • • • •

• • •

• • • P/G/SG/N G/SG • P/N • • P/N/X P/X • • • • • Logic •

• • • • • • • • •

• •

•

• • • • • •

• • • P(2)/N(2)/G/SG P/N/G • P/N • • P(2)/N/X P • • • • • • •

•

4 12

•

• •

• • • • 2 • • • • • • • • •

•

1024 16 • • • • • • • • 3 • • • • • • • • • •

•

* Excitation control requires either field protection provided by a motor excitation system or a SPM module used with the 469 relay 1 Functionality to be commercially available in 2015

For the most up-to-date selector guides, please visit

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361

Motor Protection

APPLICATIONS & FUNCTIONALITY LV small size induction motor MV small or medium size induction motor MV medium or large size induction motor MV induction motor via VFD MV induction motor with cyclic load MV synchronous motor protection MV synchronous motor protection and excitation control PROTECTION & CONTROL Thermal Model (with RTD and unbalance biasing) Custom Overload Curves Voltage Dependant Overload Curves Jogging Start / Starts-Per-Hour Acceleration Time Reduced Voltage Starting Backspin Detection Two Speed Motor Reversing (DOLR) Variable frequency drive Emergency Restart Mechanical Jam / Stall IOC, Phase, Ground, Sensitive Grnd, Neutral TOC, Phase, Ground, Sensitive Grnd Differential Current Directional, Phase, Ground, Neutral Current Unbalance Undercurrent / Underpower Phase, Auxiliary, Neutral Overvoltage Phase, Auxiliary Undervoltage Negative Sequence Overvoltage Voltage Transformer Fuse Failure Phase Reversal Under / Overfrequency Reverse Power Power Factor RTD Overtemperature Remote RTD (RRTD) Breaker Failure Synchronous motor* Start Inhibit/Lockout AUTOMATION Contact Inputs (max) Contact Outputs (max) Analog Inputs (max) Analog Outputs (max) RTD Inputs (max) Thermistor Input Programmable Logic Trip / Close Coil Supervision Digital Counters Timers Undervoltage Auto-restart MONITORING & METERING Current Voltage Frequency Power - Real Power - Apparent / Reactive Power Factor Demand - Current, MW, MVA, Mvar Energy Temperature Environmental monitor (T, H, V, S) Event Recorder (number of events) Oscillography (max samples per cycle) Data logger Motor Learned Information Thermal Capacity Used Motor Start Data Logger Motor Start / Stop Health Report Broken Rotor Bar COMMUNICATIONS RS232 Serial Communications RS485 Serial Communications 802.11 WiFi USB Front panel Radius Authentication Fiber Optic Ethernet IEC 62439 PRP IEEEE 1588 Modbus protocol DeviceNet protocol Profibus protocol DNP 3.0 protocol IEC61870-5-103/4 protocol IEC61850 protocol Peer-to-Peer Communications (GSSE/GOOSE) Simple network Timesync protocol IRIG-B input Process Bus (IEC 61850-9-2) FORM FACTOR Withdrawable

Featured Products

Motor Protection – Featured Products 869

Comprehensive Motor Protection and Management for Medium and Large Motors

363

The Multilin 869 relay is a member of the Multilin 8 Series protective relay platform and has been designed for the protection, control and management of medium and large induction and synchronous motors. The Multilin 869 provides advanced functionality for various types of applications such as high-speed protection, extensively customizable programmable logic, advanced motor monitoring and diagnostics, and flexible configuration capabilities. The advanced communications of the 8 Series platform allows an easy integration into the process and electrical control systems for smoother asset monitoring and control.

M60

Unparalleled Protection, Control, Diagnostics and Management of medium and large motors

383

Motor Protection

Built on the industry-leading UR platform, the M60 offers superior protection with an enhanced thermal model that can be customized to match the operating characteristics of the motor. Advanced motor health diagnostics, allowing operators the ability to easily identify potential motor issues before they result in costly system downtime. Simplified setup configuration through the use of the Motor Settings Auto-Configurator. Connectivity of remote RTD’s reducing installation cost. The M60 provides advanced communication with the integration of a fully managed Ethernet switch reducing network installation costs while also supporting most industry standard communication protocols. It may be used as part of an automation control system with peer-to-peer communications or as a stand-alone protection device.

339

Complete protection, control, diagnostics and communications for small and medium sized AC motors

391

Designed for medium voltage motors in industrial applications, the 339 delivers unparalleled protection, control, diagnostics and communications in an industry leading draw-out construction. Providing simplified setup configuration through the use of the Motor Settings Auto-Configurator, advanced graphical diagnostics with the Motor Health Report and support for multiple communication protocols including IEC 61850, the 339 Motor Protection System provides unparalleled motor protection for most small and medium sized AC motors.

MM300

Advanced Low Voltage Motor Management Integrating Protection, Control & Automation

403

The MM300 integrates protection, control, automation, metering, diagnostics and multiple communication protocols in a rugged compact device for low voltage motor applications. Designed for NEMA and IEC Motor Control Centers, the MM300 delivers superior protection and control to extend equipment life and maximize process uptime.

MM200

Comprehensive Low Voltage Motor Protection The MM200 integrates protection, control and multiple communication protocols in a rugged compact device for low voltage motor applications. Easily integrated into new and existing control system architectures, the MM200 provides comprehensive low voltage motor protection and communications for all types of motor protection applications.

Go online for the full listing of Multilin Protection & Control products

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10 YEAR WORLDWIDE

Multilin™ 869 Comprehensive Motor Protection and Management for Medium and Large Motors The Multilin 869 relay is a member of the Multilin 8 Series protective relay platform and has been designed for the protection, control and management of medium and large induction and synchronous motors. The Multilin 869 provides advanced functionality for various types of applications such as high-speed protection, extensively customizable programmable logic, advanced motor monitoring and diagnostics, and flexible configuration capabilities.

WARRANTY

Innovative Technology & Design • Advanced motor protection, control and diagnostics capability

Advanced communications of the 8 Series platform allows easy integration into process and electrical control systems for smoother asset monitoring and control.

• Patented environmental monitoring and diagnostics

Key Benefits

• Advanced, flexible and embedded communications: IEC® 61850 Ed2, IEC 62439/PRP, Modbus® RTU & TCP/IP, DNP3.0, IEC 60870-5-104

• Comprehensive motor protection for medium and large induction motors • Advanced motor diagnostics with high-end fault and disturbance recording • High-end cyber security such as AAA, Radius, RBAC, and Syslog helps enable NERC® CIP requirements

• Single setup and configuration across the platform

• Draw-out design simplifies testing and increases process uptime

• Elimination of electrolytic capacitors

• Wi-Fi connectivity minimizes system configuration and facilitates safe relay programming and diagnostic retrieval

• Field swappable power supply • Enhanced relay draw-out construction

• Monitored environmental conditions helps reduce system downtime

Applications • Wide range of motor applications for oil & gas, mining & metals, cement, and wastewater • Comprehensive protection and management of medium to large motors; two-speed, VFD-driven, cyclic loading and synchronous motors

Exceptional Quality & Reliability • IPC A-610-E Class 3 manufacturing standards

• Specific and advanced features for high inertia loads and reduced-voltage starting motors

• Highest reliability standards for electronics testing

• Stator protection of medium to large synchronous motors where field functions are provided by excitation panels

• 100% Environmental Stress Screening and full functional testing

• Advanced predictive motor diagnostics and motor health visualization

• Rated for IP54 (front) applications • Standard Harsh Environment Conformal Coating

Uncompromising Service & Support • Covered under GE’s 10 year warranty plan • Designed, tested and manufactured by GE

869 Motor Protection System

Multilin 8 Series Platform Overview From oil pumping and refining facilities, to open pit or underground mining and processing operations, to large or small utilities, customers demand solutions that ensure maximum process uptime, minimum operational and maintenance efforts, and have the durability to withstand harsh environmental conditions. The Multilin 8 Series is GE’s next-generation protection and control relay platform provides comprehensive protection and asset monitoring for critical feeders, motors, generators, and transformers.

The 8 Series is designed to solve the challenges that customers face in running their day-to-day operations including maximizing system and process uptime, simplifying system integration and maintenance, and extending the life of critical assets. Utilizing advanced design practices, superior technology (elimination of all electrolytic capacitors), and state-ofthe art test and manufacturing facilities, GE is raising the bar on system performance and reliability. With advanced communications the 8 Series integrates easily and seamlessly into new or existing DCS/SCADA system, along with other Multilin protection devices, providing a comprehensive solution for the end-to-end electrical system within the operations.

Motor Protection

Multilin 8 Series Platform - Application Example

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869 Motor Protection System

Exceptional Quality & Reliability

Pioneering Technology & Design

Industry-leading quality, reliability and design processes are at the core of GE’s next generation protective relay platform. With significant investments in state-of-the-art type test facilities that simulate a complete range of operating environments and manufactured to the IPC A-610 Class 3 standard, adhering to the highest reliability standards and ensuring rugged performance, each device completes Environmental Stress Screening prior to shipping from GE’s facility.

The Multilin 869 is part of the 8 Series platform that provides comprehensive, high performance protection and control for critical assets in Industrial and utility environment.

The Multilin 8 Series Protection Relays are manufactured in an ISO® 9001:2008 certified manufacturing facility.

The Multilin 869 Motor Protection System offers a powerful solution for critical motor protection applications with advanced thermal model and voltage dependant curves for high inertial loads. Utilizing decades of experience in motor protection, GE has implemented ease-of-use features, such as single screen set-ups delivering faster motor configuration and startup and motor health reports providing detailed motor diagnostic enabling quick and easy identification of motor issues. The Mutilin 8 Series products have an integrated protection integrity engine that utilizes customized algorithms, providing advanced diagnostics to ensure asset protection is not compromised.

Motor Protection

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869 Motor Protection System

Multilin 869 Overview

Maintaining and safeguarding the electrical supply of an operation is critical to ensuring maximum process availability and performance.

Motors are the workhorses of any industrial plant. Industrial facilities depend on reliable and secure motor operation to keep their processes running. Regardless of the type of motor, the load it runs or the process requirements, a fully integrated protection and control scheme is critical to maintaining uninterrupted service to the entire facility.

The 8 Series incorporates the latest cyber security features, including password complexity, RADIUS authentication and role-based access control (RBAC), enabling customers to comply with NERC CIP and NISTIR 7628 requirements. Understanding that customers need protection and control devices that must reliably operate in harsh and challenging environments, GE delivers the Multilin 8 Series with harsh conformal coating on all printed circuit boards and a patented environmental awareness module that provides real-time detection of environmental factors that affect product life, as part of its standard offering, delivering higher reliability and extended relay life.

The Multilin 869 Motor Protection System is a protection device designed for the management, protection and control of medium to large horsepower motors. The 869 provides comprehensive protection and control of various types of motors with different loads they run. The 869 relay offers the ideal solution for protecting, monitoring and controlling motors from disturbances or faults. With a fast protection pass, running every 1/8th of a cycle, the 869 relay provides faster current, voltage, power and frequency protection elements. Supporting the latest in industry standard communication protocols, including IEC 62439/PRP and IEC 61850 Ed2, the Multilin 869 relay easily integrates into new or existing networks.

Uncompromised Reliability & Service Designed, manufactured and tested to industry standards at our state-ofthe-art facilities, the Multilin 8 Series delivers maximum performance for today’s most demanding environments.

The 869 is an advanced motor protection relay that provides high performance protection, extensive programmable logic and flexible configuration capabilities. With protection and control logic, the 869 allows for simplified coordination with upstream and downstream disconnect devices. The 869 also offers enhanced features, such as diagnostics, preventative maintenance, condition monitoring, security, and advanced communications options.

Motor Protection

In addition to the superior technology and innovative design advancements that enable delivery of uncompromised performance and reliability, the Multilin 8 Series is also backed by GE’s 10 year warranty plan.

1

2

4

3

1

Field Swappable Power Supply

2

Harsh Environment Conformal Coating

3

No Electrolytic Capacitors

366

Extends the usable life of the protection relay and minimizes costly, time consuming replacement and re-configuration.

Standard on all printed circuit boards delivering higher reliability and extended relay life

5

4

IPC A-610 Class 3 Manufacturing

5

Robust Extruded Aluminum Chassis

6

Draw-Out

Increasing quality and reliability for continuous plant operations

GEDigitalEnergy.com

6

Drives to the highest level of reliability standards delivering rugged performance

Custom-designed extruded aluminum chassis delivering optimal thermal management to extend component life

Providing simplified device fleet management

869 Motor Protection System

Protection & Control

Stator Differential

As part of the 8 Series family, the Multilin 869 provides superior protection and control. The 869 offers comprehensive protection and control solutions for medium and large motors for various applications. It contains a full range of selectively enabled, self contained protection and control elements.

Differential protection is considered as the first line of protection for internal phase-to-phase or phase-to-ground faults for medium and large motors to provide sensitive and fast clearing protection against winding faults including turn-to-turn faults. The Multilin 869 provides two flavors of the stator current differential protection:

Motor Thermal Model Many motor failures are directly or indirectly related to, or caused by, extensive heating of the different motor parts involved in electromechanical operation. Proven through several generations of GE’s Multilin motor relays, an enhanced thermal model is used in the 869 relay with seven major features: Motor thermal limit curves - NEMA® standard, voltage dependent and customized motor curves • IEC 60255-8 thermal overload curves

Traditional dual slope percent differential enhanced with CT saturation detection and directional check for both AC and DC saturation providing exceptional security without sacrificing sensitivity. Core balanced differential protection enhanced with biasing during motor starting to inhibit differential protection during motor starting when inrush currents may upset differential protection. All differential values are available in metering and oscillography allowing easy testing and troubleshooting.

• Smoothing filter for cyclic loads • Current unbalance biasing • Independent running and stopped exponential cooling curves • Optional RTD biasing of the thermal model to adapt to real-time temperature measurements Motor Protection

• Compensation for hot/cold motor condition The flexibility of the Multilin 869 thermal models will allow proper set up and performance for applications, including high inertia and cyclic loads.

Multilin 869 Stator Differential Two-CT set and Core-Balanced configurations

Multilin 869 – Advanced Thermal Model High inertia overload curves sample, 8500HP, 13.2kV, Reactor coolant Pump

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869 Motor Protection System

VFD-Driven Motors The Multilin 869 provides protection for motors fed through VFDs (Variable Frequency Drives). A wide range of the frequency tracking (3-72Hz) allows the 869 to track the motor frequency and adjust its sampling rate to accurately measure phasors. An advanced algorithm allows switchable current and voltage tracking in case VFD is bypassed. To provide even more accurate phasor measurement, there is an option that filters ripples in phasors due to harmonics for major motor functions. Additionally, users may indicate a starting VFD frequency that helps the device to track the motor frequency faster and eliminate unnecessary delay in the averaging filter during motor startup that can cause delayed protection operation during motor failures.

Reduced Voltage Starting The Multilin 869 can control the transition of a reduced voltage starter from reduced to full voltage based on “Current Only”, “Current and Time”, or “Current or Timer”. During this process, the relay continuously monitors the motor current to ensure an effective transition.

Motor Protection

Multilin 869 – VFD Driven Motor Protection with or without bypass switch

Functional Block Diagram

DEVICE #

FUNCTION

DEVICE #

FUNCTION

14

Under speed

50P

Mechanical Jam

19

Motor Starter

50P

Motor Overload Alarm

27P

Phase Undervoltage

50P

Motor Short Circuit

32P

Directional Power

37

Undercurrent

50 P/N/G

37P

Underpower

50_2

38

Bearing Temperature

46

Current Unbalance

47 49

368

DEVICE # 51V

FUNCTION

DEVICE #

FUNCTION

Voltage Restrained Phase Time Overcurrent

67P

Phase Directional Overcurrent

55

Power Factor

67N

Neutral Directional Overcurrent

Phase Overvoltage

Over/Under frequency

Phase/Neutral/Ground Instantaneous Overcurrent

59P

81 O/U

59N

Neutral Overvoltage

86

Lock-out

Negative Sequence Instantaneous Overcurrent

59_2

Negative Sequence Overvoltage

87S

Percent Differential

59X

Auxiliary Overvoltage

VTFF

Fuse Failure

66

Maximum starting rate

66

Time Between Starts

50LR

Acceleration Time

Voltage Reversal

51 P/N/G

Phase/Neutral/Ground Time Overcurrent

Thermal Model

51G

Motor Ground Fault

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RTD Protection Thermal Inhibit

869 Motor Protection System

Two-Speed Thermal Model

Underpower Protection

The two-speed motor protection feature allows for the protection of motors that can operate at two different speeds. The algorithm integrates the heating at each speed into one thermal model.

The Underpower element in the 869 is based on the three-phase real power (kW) measured from the phase currents and voltages. Underpower may be used to detect loss of load conditions. This may be used for more sensitive detection of load loss or pump cavitation or detecting process related issues.

The Multilin 869 automatically determines which settings should be active at any given time considering a transition from speed one to speed two within a period of time. The device has all required logic and time delays to safely transfer speeds.

Voltage and Frequency Protection The voltage and frequency protection functions detect abnormal system conditions like over/under voltage, over/under frequency and/or phase reversal that are potentially hazardous to the motor.

Undercurrent Protection The undercurrent protection element provides the ability to trip the motor due to external conditions that can cause the load being driven by the motor to drop below a pre-set level. This function is used to protect pumps from loss of suction, fans from loss of airflow due to a closed damper or a conveyor system due to a broken belt.

Motor Start Supervision

The voltage dependent overload curve feature is tailored to protect motors which are used in high inertia load applications. Voltage is continually monitored when the motor is started and during acceleration. The thermal limit curve is then adjusted accordingly. This enables the Multilin 869 to distinguish between a locked rotor condition, an accelerating condition and a running condition.

The start inhibit function prevents the starting of a motor when the motor is too hot and does not have a sufficient amount of thermal capacity available to allow a start without being tripped offline. In case of emergency, the thermal capacity used and motor start supervision timers can be reset to allow a hot motor to start.

RTD Protection The Multilin 869 supports up to 12 programmable RTD inputs that can be configured for an Alarm or Trip. The RTD voting option gives additional reliability to ignore any RTD failures. The RTDs can be assigned to a group for monitoring the stator, bearing and ambient temperatures.

RTD Bias Maximum

RTD Thermal Capacity Used (%)

100 90 80 70 60 50 40 30 20

RTD Bias Center Point

RTD Bias Minimum

10 0 -50

0

50

100

150

200

250

Maximum Stator RTD Temperature ( C) RTD bias curve

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Motor Protection

Protection of Motors with High-Inertia Loads

Motor start supervision consists of the following features: Time-BetweenStarts, Start-per-Hour, Restart Time and Start Inhibit . These elements are intended to guard the motor against excessive starting duty, which is normally defined by the motor manufacturer in addition to the thermal damage curves. The Emergency Restart enables the user to reset the Motor start supervisions in case of process needs.

869 Motor Protection System

Breaker Failure Protection The breaker failure protection element monitors for timely operation of the connected breaker. If a trip command is not successful in operating the breaker and clearing the fault, the breaker failure element can be used to send trip signals to upstream breakers to clear the fault.

10000

TYPICAL CUSTOM CURVE - 6500 HP, 13800 VOLT INDUCED DRAFT FAN MOTOR

Mechanical Jam and Acceleration Time These two elements are used to prevent motor damage during abnormal operational conditions such as excessively long acceleration time or stalled rotors. The mechanical jam element senses increased loading associated with process or load related faults such as an overloaded conveyor.

1000

1 TIME TO TRIP IN SECONDS

The Multilin 869 protects the motor from overheating in cases of abnormal loading during motor starts. The motor can be tripped if the motor does not reach a running condition within the programmable motor acceleration time.

Synchronous Motor Protection

Motor Protection

For synchronous motors with excitation system control that offers field winding protection, the Multilin 869 offers comprehensive stator protection functions in addition to features such as power factor based pull out protection and reactive power based alarm and trip functions.

2 100

3 10

Adaptive Protection

4

The Multilin 869 offers effective, reliable management of motors. With dynamic, sensitive settings, the 869 provides secure and dependable protection. With six setting groups, the 869 provides the sensitive settings range and groups required to ensure no compromise is made to meet changing system conditions. These setting groups can be enabled automatically or manually via digital Inputs, virtual inputs or remote communications to address system needs, ensuring greater system reliability and efficiency.

5 1.0

0.1 0.5

1.0

10

100

MULTIPLE OF PER UNIT CURRENT

FlexCurves™ For applications that require greater flexibility, FlexCurves can be used to define custom curve shapes. These curves can be used to protect motors with different rotor and stator damage curves, allowing complete protection over the total motor capacity.

1

PROGRAMMED FLEXCURVE

2

RUNNING SAFETIME (STATOR LIMIT)

3

ACCELERATION SAFETIME (ROTOR LIMIT)

4

MOTOR CURRENT @ 100% VOLTAGE

5

MOTOR CURRENT @ 80% VOLTAGE

Typical FlexCurve overload curve.

Advanced Automation The Multilin 869 incorporates advanced automation capabilities that exceeds what is found in most motor protection relays. This reduces the need for additional programmable controllers or discrete control relays including programmable logic, communication, and SCADA devices. Advanced automation also facilitates the Multilin 869 to integrate seamlessly with other protection/process systems.

FlexLogic™ FlexLogic is the powerful programming logic engine that provides the ability to create customized protection and control schemes, minimizing the need and associated costs of auxiliary components and wiring. Using FlexLogic, the 869 can be programmed to provide the required tripping logic along with custom scheme logic for motor breaker control (including interlocking with internal motor start supervision), interlocking schemes with adjacent protections (for example, preventing sympathetic tripping of healthy feeders), and dynamic setting group changes. 370

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869 Motor Protection System

With fully programmable alarms, the broken rotor bar function will provide early detection of rotor bar problems enabling maintenance personnel to schedule for predictive maintenance of the motor thereby preventing catastrophic motor failures. BROKEN ROTOR BAR

DETECTION

FlexLogic allows the Multilin 869 to operate and control breakers and other auxiliary devices needed to fit most motor protection schemes and applications.

Monitoring & Diagnostics

Advanced Motor Diagnostics The Multilin 869 provides advanced motor diagnostics including a broken rotor bar detection function. The broken rotor bar detection is a condition monitoring function that continuously monitors the motor’s health while in operation. The advanced Motor Current Signature Analysis (MCSA) continuously analyzes the motor current signature and based on preset algorithms will determine when a broken rotor bar is present in the motor.

Advanced Motor Health Report The 869 motor health report provides a quick snapshot of the motor operating and diagnostic information in an easy way to allow users to make decisions about health of the motor. Based on the graphical representation and trend values of the motor historical data gathered by the 869, users can quickly identify process issues and maintenance requirements before damage occurs and costly repairs are required.

Multilin 869 Motor Health Report Motor Start Records

Overview of the 869 Motor Health Report

Motor Status Summary

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Motor Protection

The Multilin 869 includes high accuracy metering and recording for all AC signals. Voltage, current, and power metering are built into the relay as a standard feature. Current and voltage parameters are available as total RMS magnitude, and as fundamental frequency magnitude and angle.

By providing early indication of potential rotor problems, serious system issues can be avoided, such as reduced starting torque, overloads, torque and speed oscillation and bearing wear. With the broken rotor bar detection system, advanced warning of impending problems reduces catastrophic failures, maximizing motor life and system uptime.

869 Motor Protection System

The motor health report quickly provides a motor operation summary with detailed information in seven categories. • Device Overview: gives general information on the motor, including requested period, user name, device name, order code, firmware version, motor and system settings, and motor total running time. • Status Overview: summarizes the historical learned data and gives an evaluation of the status of the motor, including the oldest and latest values of acceleration time, starting current, start thermal capacity used, average motor load, and average running time. • Trip Summary: presents a summary of the events that have tripped the motor. • Motor Operating History: counts the amount of events in terms of Motor Starting/Running, Manual Stop Commands, Trip Commands, Lockouts, Alarm Conditions, and Emergency Restarts. • Motor Starting Learned Data: collects the learned data, including acceleration time, starting current, start thermal capacity used, average motor load, and average running time.

Motor Protection

• Motor Start Records: displays the start data, including average of threephase RMS currents, current unbalance, ground current, average of threephase RMS voltages, thermal capacity used, frequency and motor status.

Environmental Monitoring The 869 implements a patented environmental monitoring system that measures and provides operating condition information. Reliable and secure operation of the 869 relay and other electronic devices in the vicinity may be affected by environmental factors. The 869 relay has been designed to meet or exceed required industry standards. Some operating conditions may be beyond those standards and reduce total lifespan of the device. Typical environmental conditions that may affect electronic device reliability include voltage, current , temperature, humidity, dust , contaminants, mechanical stress, shock, radiation and intensity of electrical and magnetic fields. These environmental factors are different from natural weather conditions at particular installation conditions and are beneficial to monitor. The 869 relay’s built-in environmental awareness feature (patent “Systems and methods for predicting maintenance of intelligent electronic devices”) collects the histograms of operating conditions from the point the device is put into service. Monitored environmental conditions include temperature, humidity and transient voltage. The histogram of each environmental factor may be retrieved from the diagnostic page accessed through a PC running the EnerVista Multilin 8 Series Setup program.

• Motor Stopping/Tripping: gives details on the events that are specifically related to the stopping and tripping of the motor.

Breaker Health Monitoring The breaker is monitored by the relay not only for detection of breaker failure, but also for the overall “breaker health” which includes: • Breaker close and breaker open times • Trip circuit monitoring • Spring charging time • Per-phase arcing current • Trip counters All algorithms provide the user with the flexibility to set up initial breaker trip counter conditions and define the criteria for breaker wear throughout a number of setpoints.

Environmental health report is available via Multilin PC Software

Multilin 8 Series Breaker Health Report available on the display or via the setup software

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869 Motor Protection System

Metering The Multilin 869 offers high accuracy power quality monitoring for fault and system disturbance analysis. The Multilin 8 Series delivers unmatched power system analytics through the following advanced features and monitoring and recording tools: • Harmonics measurement up to 25th harmonic for both currents and voltages including THD.

• Detailed Fault Report allows the user to identify the fault location, fault type and element(s) that triggered the 869 to trip. It carries other useful information, such as pre-fault and fault phasors, relay name and model, firmware revision and other details. The 869 stores fault reports for the last 16 events. • 1024 Event Recorder chronologically lists all triggered elements with an accurate time stamp over a long period of time. The 869 stores the last 1024 events locally in the relay.

• The length of the transient recorder record ranges from 31 cycles to 1549 cycles, depending on the user specified configuration. This gives the user the ability to capture long disturbance records which is critical for some applications.

Motor Protection

Multilin 869 Event Recorder Multilin 869 Phasor viewer • 32 digital points and 16 analog values, assigned by the user, can be captured in the COMTRADE format by the transient recorder. • Comprehensive data logger provides the recording of 16 analog values selected from any analog values calculated by the relay. Capture rates range from 16 ms, 20ms, 1 second, 30 seconds, 1 minute, 30 minutes, or 1 hour rate. This data capture flexibility allows the operator to measure power factor or reactive power flow (for example), for several hours or even days, enabling detailed analysis and corrective action to be taken, if required.

The 869 monitoring system performance with harmonic analysis

The 869 monitoring system performance with oscillography and event records

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869 Motor Protection System

Communications

Cyber Security

The 869 provides advanced communications technologies for remote data and engineering access, making it easy and flexible to use and integrate into new and existing infrastructures. Direct support for fiber optic Ethernet provides high-bandwidth communications, allowing for low-latency controls and high-speed file transfers of relay fault and event record information. The 869 also supports two independent IP addresses, providing high flexibility for the most challenging of communication networks.

The 869 cyber security enables the device to deliver full cyber security features that help operators to comply with NERC CIP guidelines and regulations.

Providing several Ethernet and serial port options and supporting a wide range of industry standard protocols, the 869 enables easy, direct integration into DCS and SCADA systems. The 869 supports the following protocols:

Enables integration with centrally managed authentication and accounting of all user activities and uses modern industry best practices and standards that meet and exceed NERC CIP requirements for authentication and password management.

Role Based Access Control (RBAC) Efficiently administrate users and roles within UR devices. The new and advanced access functions allow users to configure up to five roles for up to eight configurable users with independent passwords. The standard “Remote Authentication Dial In User Service” (Radius) is used for authentication.

• IEC 61850 Ed2, IEC 62439 / PRP • DNP 3.0 serial, DNP 3.0 TCP/IP, IEC 60870-5-103, IEC 60870-5-104 • Modbus RTU, Modbus TCP/IP The 869 has USB front port and Wi-Fi interfaces for ease of access to the relay. Wi-Fi Connectivity:

Event Recorder (Syslog for SEM) Capture all cyber security related events within a SOE element (login, logout, invalid password attempts, remote/local access, user in session, settings change, FW update, etc), and then serve and classify data by security level using standard Syslog data format. This will enable integration with established SEM (Security Event Management) systems.

• Simplify set-up and configuration • Simplify diagnostic retrieval Motor Protection

AAA Server Support (Radius/LDAP)

• Eliminate personnel in front of switchgear • WPA-2 security

Security Server

Local HMI / Single Line

SCADA

EMS

Data Historian

DMS

Access Request: Role, User, Password

D400

Role, User, Password Encrypted (SSH)

D400

0 00C H ML3 SWIT

000 ML3 ITCH SW

LOCAL AREA NETWORK

LOCAL AREA NETWORK

A

B

000 ML3 ITCH SW

Authentication Request:

Authentication Request:

000 ML3 ITCH SW

000 ML3 ITCH SW

Role, User, Password Encrypted (SSH)

000 ML3 ITCH SW

Cyber Security with Radius Authentication

Software & Configuration F650

350

469

850

869

889

845

UR

The EnerVista™ suite is an industry-leading set of software programs that simplifies every aspect of using the Multilin 869. EnerVista provides all the tools to monitor the status of the protected asset, maintain the device and integrate the information measured by the Multilin 8 Series into SCADA or DCS process control systems. The ability to easily view sequence of events is an integral part of the setup software, as postmortem event analysis is critical to proper system management.

EnerVista Launchpad EnerVista Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining Multilin products.

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869 Motor Protection System

Single Click Device Communications Quick Link Diagnostic Information

Online Device Configuration and Monitoring

Quick Setup

Offline Device Setting File Configuration

8 Series Setup Software 8 Series Setup Software is a single setup and configuration tool across the platform and can reduce device setup and configuration time.

1

Easy to Use - Draw-out case

2

Motor Protection

The setup tools within Launchpad allow for the configuration of devices in real-time, by communicating via serial, Ethernet or modem connections, or offline by creating device setting files to be sent to devices at a later time. Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed.

Simplified Setup & On-Going Maintenance The robust 869 streamlines user workflow processes and simplifies engineering tasks, such as configuration, wiring, testing, commissioning, and maintenance. Building on the history of simplified setup and configuration, the 869 relay has implemented simplified setup screens to assist in minimizing relay setup time. In addition, for local programming, the 869 comes with a fully functional Graphical Control Panel (GCP), which allows users to locally monitor the asset.

Easy to Configure - 1 simple step

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Detailed Diagnostics

375

869 Motor Protection System

Ease-of-Use

LED Indicators for Quick Status Indication

Continuing its legacy in providing easy-to-use protective relay solutions, the 869 is designed to minimize product and system configurability requirements for quicker physical installation and for easier and simplified setup and configuration.

G = Green: General Condition

Full Color Graphical HMI Front Display

A = Amber: Alert Condition

A large, full color Graphic Control Panel (GCP) ensures clear representation of critical status and measurements. When the keypad and display are not being used, the GCP will automatically revert to screen saver mode, which will turn off the display until one of the local pushbuttons is pushed.

R = Red: Serious Alarm or Important Status

The GCP can be used to view device and system status, alarms and event logs, and metering information. The GCP and navigation keys simplify relay configuration and setup, allowing users to make setting changes directly through the front panel.

Motor Protection

The front panel includes user configurable LED’s. Each LED can be completely configured and named based on the application and user requirements. The color of each indicator conveys its importance.

The 869 front panel provides 14 LED indicators and 3 LED pushbutton indicators. 10 LED’s are user- programmable, while “In service” and “Pickup” LED’s are non-programmable. “Trip” and “Alarm” LED’s are not color programmable but can be assigned with selected operands. User-programmable LED’s can be turned on by a selection of FlexLogic operands representing protection, control or monitoring elements. Each LED can be configured to be self-reset or latched and labeled based on the application and user requirements. User-programmable LED’s can be selected to be either Red, Green or Amber to give the distinctive indication of selected operations.

Front View Menu path display indicating location within menu structure Graphic Control Panel (GCP) Soft key navigation menu

Soft menu navigation keys LED status indicators

Navigation keys

User-programmable pushbuttons

Front USB port Self-captive screw on draw-out handle

Rear View Grounding screw

Standard serial and RJ45 Ethernet module

Power supply Analog I/O

Advanced communications module (fiber optic port)

Digital I/O CT, VT inputs

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869 Motor Protection System

Dimensions & Mounting

7.15”

9.90”

8.84”

5”

8.42”

5”

7.5

1.5

Typical Wiring Refer Page 5 (Stator Differential) for different CT connection types.

Motor Protection

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869 Motor Protection System

Technical Specifications POWER SUPPLY

Ground Fault

Power Supply

Pickup Level

Timer Accuracy For 1A/5A Ground CT Type: 0.01 to 10.00 x CT in steps of 0.01 x CT; For 50/0.025 Ground CT Type: 0.50 to 15.00 A in steps of 0.01A

Nominal DC Voltage

125 to 250 V

Minimum DC Voltage

88 V

Maximum DC Voltage

300 V

Dropout Level

97 to 98% of Pickup 0.00 to 180.00 s in steps of 0.01 s

Current Unbalance (46) Unbalance

I2/I1 x 100% if lavg ≥ FLA, I2/I1 x Iavg/FLA x 100% if lavg < FLA,

Nominal AC Voltage

100 to 240 V at 50/60 Hz

Alarm Pickup Delay

Minimum AC Voltage

88 V at 50/60 Hz

Trip Pickup Start Delay 0.00 to 180.00 s in steps of 0.01 s

Trip/Alarm Time delay

0.00 to 180.00 s in steps of 0.01 s

Maximum AC Voltage

265 V at 50 to 60 Hz

Trip Pickup Run Delay

0.00 to 180.00 s in steps of 0.01 s

Level Accuracy

50:0.025A CT: For 0.5A to 4A: ±0.1A; For > 4A ±0.2A 1A/5A CT: For 0.1 to 2.0 x CT: ±0.5% of reading or ±0.4% of rated, whichever is greater; For > 2.0 x CT: ±1.5% of reading

Single Phasing Pickup level

Unbalance level > 40% or when Iavg>=25%FLA and current in any phase is less than the cutoff current

Single Phasing Time Delay

2 seconds

Pickup accuracy

±2%

Operate time

<2 cycles at 1.10 x pickup

Timing accuracy

±3% of delay setting or ± 20 ms, whichever is greater

Elements

Trip and Alarm

ANALOG INPUTS AC Currents CT Rated Primary:

1 to 12000 A

CT Rated Secondary

1 A or 5 A based on relay ordering

Nominal Frequency

50 and 60 Hz

AC Voltage VT Range

10 to 260 V

Nominal Frequency

20 to 65 Hz

Burden

<0.25 VA at 120 V

Conversion Range.

1 to 275 V

Voltage Withstand

Continuous at 260 V to neutral; 1 min/hr at 420 V to neutral

RTD Inputs

Motor Protection

±3% of delay setting or ± ½ cycle (whichever is greater) from pickup to operate

Types (3-wire)

100 Ω Platinum

Sensing current

5 mA

Range

–40 to +250°C

Accuracy

±2°C

PULSED OUTPUTS Mode

3-phase positive and negative active energy measurement, 3-phase positive and negative reactive energy measurements

CONTACT OUTPUTS Form-A Relays Configuration

2 (two) electromechanical

Operate time

<8 ms

Continuous current

10 A

Make and carry for 0.2s 30 A per ANSI C37.90 Form-A Voltage Monitor Applicable voltage

20 to 250 VDC

Trickle current

1 to 2.5 mA

Form-C Relays Configuration

Electromechanical

Operate time

<8 ms

Continuous current

10 A

Make and carry for 0.2s 30 A per ANSI C37.90 CONTACT INPUTS

Operate Time

< 16 ms @ 60Hz (I > 2.0 x PKP), with 0 ms time delay < 20 ms @ 50Hz (I > 2.0 x PKP), with 0 ms time delay

Timing Accuracy

±3% of delay setting or ±1 cycle (whichever is greater) from pickup to operate

RTD Protection Pickup

1 to 250°C in steps of 1°C

Pickup Hysteresis

2°C

Timer accuracy

<2 s

Elements

Trip and Alarm

Operating condition

Three-phase real power

Number of elements

1, alarm and trip stages

Trip/Alarm Pickup level 1 to 25000 kW in steps of 1

Dropout Level

97 to 98% of Pickup

Pickup Delay

0.00 to 180.00 s in steps of 0.01 s

Level Accuracy

For 0.1 to 2 x CT: ±0.5% of reading or ±0.4% of rated, whichever is greater For > 2.0 x CT: ±1.5% of reading

Operate Time

< 16 ms @ 60Hz (I > 2.0 x PKP) with 0 ms time delay < 20 ms @ 50Hz (I > 2.0 x PKP) with 0 ms time delay

Timer Accuracy

± 3% of delay setting or ± 1/2 cycle (whichever is greater) from pickup to operate

Elements

Trip or Alarm

Pickup level accuracy

±1.0% of reading

Hysteresis

3%

Trip/Alarm Pickup delay

0 to 180.00 s in steps of 0.01

Thermal overload curves

Standard (Motor) curve, FlexCurve, Standard (Motor) curve with voltage dependent function, IEC curve

Timer accuracy

±3% of delay time or ±10 ms, whichever is greater, pick up to operate

Motor curve time multiplier

0.00 to 15.00 in steps of 0.01

Operate time

< 45 ms at 60 Hz, <50 ms at 50 Hz

FlexCurve time multiplier

0.00 to 600.00 in steps of 0.01

Phase overcurrent

IEC curve time constant

0 to 1000 in steps of 1

Operating Condition Arming Condition

Motor not starting 1.00 to 10.00 x FLA in steps of 0.01

Thermal overload pickup

Overload factor x FLA

Pickup Level Dropout Level

97 to 98% of Pickup

Overload factor (OL)

1.00 to 1.50 in steps of 0.01

Level Accuracy

For 0.1 to 2.0 x CT: ±0.5% of reading at > 2.0 x CT rating: ±1.5% of reading

Pickup Delay

0.00 to 180.00 s in steps of 0.01

Dropout Delay

0.00 to 180.00 s in steps of 0.01

Timer Accuracy

±3% of delay setting or ±20 ms, whichever is greater

Mechanical Jam

Based on relay ordering

Type

Wet or Dry

Undercurrent (37)

Wet Contacts

300 V DC maximum

Operating Parameter

Per-phase current Ia, Ib, Ic (RMS)

Selectable thresholds

17, 33, 84, 166 VDC

Pickup level

0.10 to 0.95 x FLA in steps of 0.01

Tolerance

±10%

Dropout level

102 to 103% of Pickup

Recognition time

1ms (typical)

Level Accuracy

Debounce time

0.0 to 16.0 ms in steps of 0.5 ms

For 0.1 to 2.0 x CT: ±0.5% of reading or ±0.4% of rated, whichever is greater

Continuous current draw

2 mA

Operate time

<45 ms at 60 Hz <50 ms at 50 Hz

Timer Accuracy

±3% of delay setting or ± 2 power cycles (whichever is greater) from pickup to operate

Acceleration Time (37P) Acceleration Current

1.00 to 10.00 x FLA in steps of 0.01

Overload Alarm

Acceleration Time

0.5 to 180.00 seconds in steps of 0.01

Operating parameter

Average phase current (RMS)

Operating Mode

Definite Time, Adaptive

Pickup Level

0.50 to 3.00 x FLA in steps of 0.01 x FLA

Dropout Level

97 to 98% of Pickup

Level Accuracy

For 0.1 to 2.0 x CT: ±0.5% of reading or ±0.4% of rated, whichever is greater

378

Short Circuit

Underpower

Number of Inputs:

PROTECTION

Trip/Alarm Pickup level 4.0 to 50.0% in steps of 0.1%

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Thermal Model

Motor full load current 1 to 5000 A in steps of 1 (FLA) Phase/Neutral/Ground Time Overcurrent (51) Current

Phasor or RMS

Pickup Level

0.050 to 30.000 x CT in steps of 0.001 x CT

Dropout Level

97 to 98% of Pickup

Level Accuracy

For 0.1 to 2 x CT: ±0.5% of reading or ±0.4% of rated, whichever is greater; For > 2.0 x CT: ±1.5% of reading

Curve Shape

IEEE Extremely/Very/Moderately Inverse ANSI Extremely/Very/Normally/ Moderately Inverse IEC Curve A/B/C and Short Inverse IAC Extremely/Very/Inverse/Short Inverse FlexCurve™ A, FlexCurve™ B, FlexCurve™ C, FlexCurve™ DI2t, I4t, Definite Time

Curve Multiplier

0.05 to 600.00 in steps of 0.01

Reset Time

Instantaneous, Timed

Curve Timing Accuracy Currents > 1.1 x pickup: ± 3% of operate time or ± ½ cycle (whichever is greater) from pickup to operate

869 Motor Protection System

Voltage Restrained Phase Time Overcurrent (51V)

Percent Differential (87S)

Negative Sequence Overvoltage (59_2)

Voltage Restraint

Methods

Internal summation and Core balance

Pickup Level

0.00 to 3.00 x VT in steps of 0.01 x VT

Pickup level

0.05 to 1.00 x CT in steps of 0.01

Dropout Level

97 to 98% of Pickup

Slope 1 and 2

1 to 100% in steps of 1

Pickup Time Delay

0.000 to 6000.000 s in steps of 0.001 s

Break 1

1.00 to 1.50 x CT in steps of 0.01

Dropout Time Delay

0.000 to 6000.000 s in steps of 0.001 s

Break 2

1.50 to 30.00 x CT in steps of 0.01

Operate Time

Operate time

<16 ms at >3 × Pickup at 60 Hz <20 ms at >3 × Pickup at 50 Hz

< 25 ms at 1.1 x pickup at 60 Hz < 30 ms at 1.1 x pickup at 50 Hz

Timer Accuracy

± 3% of delay setting or ± ¼ cycle (whichever is greater) from pickup to operate

Modifies Pickup from 0.1 < V < 0.9 VT Nominal in a fixed linear relationship

Phase/Neutral/Ground Instantaneous Overcurrent (50P/N/G) Current (for Phase IOC only)

Phasor or RMS

Current (for Neutral/ Ground IOC only)

Fundamental Phasor Magnitude

Pickup Level

0.050 to 30.000 x CT in steps of 0.001 x CT

Phase Undervoltage (27P)

Dropout Level

97 to 98% of Pickup

Voltage

Fundamental Phasor Magnitude

Level Accuracy

For 0.1 to 2 x CT: ±0.5% of reading or ±0.4% of rated, whichever is greater For > 2.0 x CT: ±1.5% of reading

Minimum Voltage

0.00 to 1.50 x VT in steps of 0.01 x VT

Pickup Level

0.00 to 1.50 x VT in steps of 0.01 x VT

Dropout Level

102 to 103% of Pickup

Phases Required for Operation

Any one, Any two, All three

Monitored Time Interval

1 to 300 minutes in steps of 1

Undervoltage Curves

Definite Time or Inverse Time

Maximum Number of Starts

1 to 16 starts in steps of 1

Pickup Time Delay

0.000 to 6000.000 s in steps of 0.001s

Time Between Starts

Operate Time

< 20 ms at 0.90 x pickup at 60 Hz < 25 ms at 0.90 x pickup at 50 Hz

Time Between Starts

Operate Time

<12 ms typical at 3 × Pickup at 60 Hz (Phase/Ground IOC) <16 ms typical at 3 × Pickup at 60 Hz (Neutral IOC) <15 ms typical at 3 × Pickup at 50 Hz (Phase/Ground IOC) <20 ms typical at 3 × Pickup at 50 Hz (Neutral IOC)

Current

I_2 Fundamental Phasor Magnitude

Phase Overvoltage (59P)

0.050 to 30.000 x CT in steps of 0.001 x CT

Votage

Fundamental Phasor Magnitude

Pickup Level

0.02 to 3.00 x VT in steps of 0.01 x VT

Dropout Level

97 to 98% of Pickup

Dropout Level

97 to 98% of Pickup

Level Accuracy

For 0.1 to 2.0 x CT: ±0.5% of reading or ±0.4% of rated, whichever is greater For > 2.0 x CT: ±1.5% of reading

Level Accuracy

±0.5% of reading from 15 to 208 V

Phases Required for Operation

Any one, Any two, All three

Pickup Time Delay

0.000 to 6000.000 s in steps of 0.001s (Definite Time)

Dropout Time Delay

0.000 to 6000.000 s in steps of 0.001s (Definite Time)

Operate Time Timer Accuracy

Pickup Level

±3% of delay setting or ± ¼ cycle (whichever is greater) from pickup to operate

Overreach

< 2%

Operate Time

< 12 ms typical at 3 x Pickup at 60 Hz < 15 ms typical at 3 x Pickup at 50 Hz

Timer Accuracy

±3% of delay setting or ± ¼ cycle (whichever is greater) from pickup to operate

Phase Directional Overcurrent (67P) Relay Connection

90º(Quadrature)

Quadrature Voltage

ABC phase seq.: phase A (Vbc), phase B (Vca), phase C (Vab); ACB phase seq.: phase A (Vcb), phase B (Vac), phase C (Vba)

Polarizing Voltage Threshold

0.05 to 3.000 x VT in steps of 0.001 x VT

Current Sensitivity Threshold

0.05 x CT

Characteristic Angle

0º to 359º in steps of 1°

Angle Accuracy

± 2º

2 0º to 359º in steps of 1°

Calibration Angle

0.00º to 0.95º in steps of 0.05°

Power Pickup Range

–1.200 to 1.200 in units of (Rated Power) in steps of 0.001

Pickup Level Accuracy

± 1% or ± 0.001 (Rated Power), whichever is greater

Hysteresis

2% or 0.001 (Rated Power), whichever is greater

Pickup Time Delay

0.000 to 6000.000 s in steps of 0.001 s

Operate Time

< 25 ms at 1.1 x pickup at 60Hz < 30 ms at 1.1 x pickup at 50Hz

< 55 ms at 1.1 x pickup at 60 Hz < 65 ms at 1.1 x pickup at 50 Hz

Timer Accuracy

± 3% of delay setting or ± ¼ cycle (whichever is greater)from pickup to operate

± 3% of delay setting or ± ¼ cycle (whichever is greater)from pickup to operate

Underfrequency (81U)

Auxiliary Overvoltage (59X) Pickup Level

0.00 to 3.00 x VT in steps of 0.01 x VT

Dropout Level

97 to 98% of Pickup

Pickup Time Delay

0.000 to 6000.000 s in steps of 0.001s

Dropout Time Delay

0.000 to 6000.000 s in steps of 0.001s

Operate Time

< 25 ms at 1.1 x pickup at 60Hz < 30 ms at 1.1 x pickup at 50Hz

Timer Accuracy

± 3% of delay setting or ± ¼ cycle (whichever is greater)from pickup to operate 0.02 to 3.00 x VT in steps of 0.01 x VT

Dropout Level

97 to 98% of Pickup

Directionality

Co-existing forward and reverse

Level Accuracy

±0.5% of reading from 15 to 208 V

Polarizing

Voltage, Current, Dual

Definite time, Flex Curve A,B,C,D

Polarizing Voltage

V_0 or VX

Neutral Overvoltage Curves

Polarizing Current

Ig

Pickup Time Delay

Operating Current

I_0

0.000 to 6000.000 s in steps of 0.001 s (Definite Time)

Level Sensing

3 x (|I_0| – K x |I_1|), Ig

Restraint, K

0.000 to 0.500 in steps of 0.001

Characteristic Angle

-90º to 90º in steps of 1°

Limit Angle

40º to 90º in steps of 1°, independent for forward and reverse

Dropout Level

97 to 98% of Pickup

Operate Time (no direction transition)

< 16 ms at 3 x Pickup at 60 Hz < 20 ms at 3 x Pickup at 50 Hz

0 to 65000 seconds in steps of 1

Directional Power (32)

Characteristic Angle

Pickup Level

0.050 to 30.000 x CT in steps of 0.001 x CT

Restart Delay

3-phase

Neutral Directional Overcurrent (67N)

Pickup Level

0 to 300 minutes in steps of 1

Restart Delay

Number of Stages

Neutral Overvoltage (59N)

±2º

Maximum starting rate

Measured Power

Operation Time Reverse to Forward transition : < 12 (FlexLogic™ operands) ms, typically; Forward to Reverse transition: <8 ms, typically

Angle Accuracy

Thermal Inhibit Margin 0 to 25 % in steps of 1%

Dropout Time Delay

0.000 to 6000.000 s in steps of 0.001 s (Definite Time)

Operate Time

< 25 ms at 1.1 x pickup at 60Hz < 30 ms at 1.1 x pickup at 50Hz

Curve Timing Accuracy at > 1.1 x Pickup ± 3% of curve delay or ± 1 cycle (whichever is greater) from pickup to operate

GEDigitalEnergy.com

Pickup Level

20.00 to 65.00 Hz in steps of 0.01

Dropout Level

Pickup + 0.03 Hz

Pickup Time Delay

0.000 to 6000.000 s in steps of 0.001s

Dropout Time Delay

0.000 to 6000.000 s in steps of 0.001s

Minimum Operating Voltage

0.000 to 1.250 x VT in steps of 0.001 x VT

Minimum Operating Current

0.000 to 30.000 x CT in steps of 0.001 x CT

Level Accuracy

± 0.001 Hz

Timer Accuracy

± 3% of delay setting or ± ¼ cycle (whichever is greater)from pickup to operate

Operate Time

Typically 7.5 cycles at 0.1 Hz/s change Typically 7 cycles at 0.3 Hz/s change Typically 6.5 cycles at 0.5 Hz/s change

Overfrequency (81O) Pickup Level

20.00 to 65.00 Hz in steps of 0.01

Dropout Level

Pickup - 0.03 Hz

Pickup Time Delay

0.000 to 6000.000 s in steps of 0.001 s

Dropout Time Delay

0.000 to 6000.000 s in steps of 0.001 s

Minimum Operating Voltage

0.000 to 1.250 x VT in steps of 0.001 x VT

Level Accuracy

± 0.001 Hz

Timer Accuracy

± 3% of delay setting or ± ¼ cycle (whichever is greater)from pickup to operate

Operate Time

Typically 7.5 cycles at 0.1 Hz/s change Typically 7 cycles at 0.3 Hz/s change Typically 6.5 cycles at 0.5 Hz/s change

379

Motor Protection

Negative Sequence Instantaneous Overcurrent (50_2)

Curve Timing Accuracy at < 0.90 x pickup ± 3.5% of curve delay or ± ½ cycle(whichever is greater) from pickup to operate

Timer Accuracy

Thermal Inhibit

869 Motor Protection System

Technical Specifications CONTROL

Transient Recorder

Trip Bus

Default AC Channels

Number of Elements

6

Configurable Channels 16 analog and 32 digital channels

Number of Inputs

16

Sampling rate

Pickup Time Delay

0.000 to 6000.000 s in steps of 0.001 s

Event Recorder

Dropout Time Delay

0.000 to 6000.000 s in steps of 0.001 s

Number of events

1024

Operate Time

< 2 ms at 60 Hz

Time-tag Accuracy

to one microsecond

Timer Accuracy

± 3% of delay setting or ± ¼ cycle (whichever is greater)from pickup to operate

Digital counters

MONITORING Trip Circuit Monitor (Tcm) Applicable Voltage

20 to 250 VDC

Trickle Current

1 to 2.5 mA

Timing Accuracy

± 3 % or ± 4 ms, whichever is greater

Close Circuit Monitor (Ccm) Applicable Voltage

20 to 250 VDC

Trickle Current

1 to 2.5 mA

Timing Accuracy

± 3 % or ± 4 ms, whichever is greater

128 /c, 64/c, 32/c, 16/c, 8/c

Number of Counters

16

Counting

preset, compare

Programmability

reset, up/down, set to pre-set, freeze/ reset, freeze/count

Timer Accuracy

± 3% of delay setting or ± 1¼ cycle (whichever is greater)from pickup to operate

Demand Measured Values

Measurement Type

Phase A/B/C present and maximum current; Three-phase present and maximum real/reactive/apparent power Thermal Exponential, 90% response time (programmed)

Block Interval / Rolling 5, 10, 15, 20, 30 minutes Demand, time interval (programmed) Current Pickup Level

10 to 10000 in steps of 1 A

Real Power Pickup Level

0.1 to 300000.0 kW in steps of 0.1 kW

2nd to 25th harmonic: per-phase displayed as % of f1 fundamental frequency

Accuracy

± 0.5% of reading from 15 to 208 V± 1% for open Delta connections

Real Power (Watts)

Modes:

10/100 Mbps

One Port

RJ45

Protocol

Modbus TCP

Ethernet – Card Option Modes

100 MB

Two Ports

ST (with this option both enabled ports are on the communications card; the Ethernet port located on the base CPU is disabled) Modbus TCP, DNP3.0, IEC60870-5-104, IEC 61850 Ed2, IEC 61850 GOOSE, IEEE 1588, SNTP, IEC 62439-3 clause 4 (PRP)

Range

-214748364.8 kW to 214748364.7 kW

Parameters

3-phase; per phase if VT is Wye

Accuracy

± 1.0% of reading or 0.1 kW (whichever is greater) at -0.8
Protocols

Range

-214748364.8 kvar to 214748364.7 kvar

USB

Parameters

3-phase; per phase if VT is Wye

Protocols

Accuracy

± 1.0% of reading or 0.1 kvar (whichever is greater) at -0.2
Serial

Reactive Power (Vars)

Apparent Power (VA)

Accuracy

± 1.0% of reading or 0.1 kVA (whichever is greater)

Apparent Power Pickup 0.1 to 300000.0 kVA in steps of 0.1 Level kVA

Power Factor Parameters

3-phase; per phase if VT is Wye

Dropout Level

96-98% of Pickup level

Range

0.01 Lag to 1.00 to 0.01 Lead

Level Accuracy

± 2%

Accuracy

± 0.02

RECORDING

Watt-Hours (Positive And Negative)

Learned Data Recorder

Range

- 2147483.648 MWh to 2147483.647 MWh

Parameters

3-phase only

Update Rate

50 ms

Accuracy

± 2.0% of reading

Var-Hours (Positive And Negative) Range

- 2147483.648 Mvarh to 2147483.647 Mvarh

Parameters

3-phase only

Update Rate

50 ms

Accuracy

± 2.0% of reading

Length

6 records, each containing a total of 60 seconds of motor starting data

PHASORS

Trigger

Motor starting status

Parameters

Phase A, B, C, Neutral and Ground

Trigger Position

1 second pre-trigger duration

Magnitude Accuracy

Sample Rate

1 sample/200 ms

± 0.5% of reading or ± 0.2% of rated (whichever is greater) from 0.1 to 2.0 x CT ± 1.0% of reading > 2.0 x CT

Angle Accuracy

2°

380

COMMUNICATIONS Ethernet – Base Offering

Wye VTs: A-n, B-n, C-n, A-B, B-C, C-A, Average Phase, Neutral and Residual Delta VTs: A-B, B-C, C-A, Neutral and Residual

Reactive Power Pickup 0.1 to 300000.0 kvar in steps of 0.1 Level kvar

Motor Start Records

I = 0.1 to 0.25 x CT ± 0.02 Hz (input frequency 15 to 70 Hz); I > 0.25 x CT to 0.4 x CT ± 0.005 Hz (input frequency 15 to 70 Hz) I > 0.4 x CT ± 0.001 Hz (input frequency 15 to 70 Hz) Magnitude of each harmonic and THD

3-phase; per phase if VT is Wye

Learned/last acceleration time; Learned/last starting current; Learned/last start TCU; Learned average load, Learned average real power, Learned average reactive power, Learned average power factor, Average run time (days/hours/ minutes); RTD maximum temperature

V = 15 to 208 V

Range

Parameters

250

3 to 72 Hz

Accuracy at

Parameters

0 kVA to 214748364.7 kVA

Content

Range

± 0.25% of reading or ± 0.2% of rated (whichever is greater) from 0.1 to 2.0 x CT ± 1% of reading > 2.0 x CT

Range

Number of records

0.5° (15 V
Frequency

Accuracy

Parameters and Residual

± 0.02

Angle Accuracy

Current And Voltage Harmonics

0.01 Lead to 1 to 0.01 Lag in steps of 0.01

Level Accuracy

± 0.5% of reading from 15 to 208 V ± 1% for open Delta connections

Phase A, B, C, Neutral, Ground and Sensitive Ground

Dropout Level

0.00 to 1.25 x VT in steps of 0.01 x VT

A-B, B-C, C-A, Neutral and Residual

Magnitude Accuracy

Parameters

Voltages

Minimum Operating Voltage

Delta VTs

Currents

0.01 Lead to 1 to 0.01 Lag in steps of 0.01

0.000 to 6000.000 s in steps of 0.001 s

Wye VTs

RMS PARAMETERS

Switch-In Level

Delay

Parameters and Residual

METERING

Power Factor (55)

Motor Protection

Voltages 5 currents + 4 voltages

Current

GEDigitalEnergy.com

Standard specification Compliant with USB 2.0 Modbus TCP, TFTP

RS485 port

Isolated

Baud rates

up to 115 kbps

Response time:

10 ms typical

Parity

None, Odd, Even

Protocol

Modbus RTU, DNP 3.0, IEC 608705-103

Maximum distance

1200 m (4000 feet)

Isolation

2 kV

WIFI Standard specification IEEE802.11bgn Range

30 ft (direct line of sight)

PHYSICAL DIMENSIONS Size

Refer to Dimensions & Mounting (Pg. 15)

Weight

9 kg [20.0 lbs]

869 Motor Protection System

Testing and Certification TEST

REFERENCE STANDARD

TEST LEVEL

Dielectric voltage withstand

EN60255-5/IEC 60255-27

2.3 kV

Impulse voltage withstand

EN60255-5/IEC 60255-27

5kV

Damped Oscillatory

IEC61000-4-18IEC60255-22-1

2.5 kV CM, 1 kV DM

Electrostatic Discharge

EN61000-4-2/IEC60255-22-2

Level 4

RF immunity

EN61000-4-3/IEC60255-22-3

Level 3

Fast Transient Disturbance

EN61000-4-4/IEC60255-22-4

Class A and B

Surge Immunity

EN61000-4-5/IEC60255-22-5

Level 3 & 4

Conducted RF Immunity

EN61000-4-6/IEC60255-22-6

Level 3

Power Frequency Immunity

EN61000-4-7/IEC60255-22-7

Class A & B

Voltage interruption and Ripple DC

IEC60255-11

PQT levels based on IEC61000-4-29, IEC61000-4-11 and IEC61000-4-17

Radiated & Conducted Emissions

CISPR11 /CISPR22/ IEC60255-25

Class A

Sinusoidal Vibration

IEC60255-21-1

Class 1

Shock & Bump

IEC60255-21-2

Class 1

Seismic

IEC60255-21-3

Class 2

Power magnetic Immunity

IEC61000-4-8

Class 5

Pulse Magnetic Immunity

IEC61000-4-9

Class 4

Damped Magnetic Immunity

IEC61000-4-10

Class 4

Voltage Dip & interruption

IEC61000-4-11

0, 40, 70, 80% dips, 250/300 cycle interrupts

Conducted RF Immunity 0-150khz

IEC61000-4-16

Level 4

Ingress Protection

IEC60529

IP54 front

Environmental (Cold)

IEC60068-2-1

-40C 16 hrs

IEC60068-2-2

85C 16hrs

IEC60068-2-30

6day variant 2

EFT

IEEE/ANSI C37.90.1

4kV, 2.5 kHz

Damped Oscillatory

IEEE/ANSI C37.90.1

2.5kV, 1 MHz

RF Immunity

IEEE/ANSIC37.90.2

20V/m, 80 MhZ to 1GHz

ESD

IEEE/ANSIC37.90.3

8kV CD/ 15 kV AD

Safety

UL508

e57838 NKCR

UL C22.2-14

e57838 NKCR7

ENVIRONMENTAL

APPROVALS APPLICABLE COUNCIL DIRECTIVE

ACCORDING TO

Ambient temperatures:

CE compliance

Low voltage directive EMC Directive

North America

cULus

EN60255-5 / EN60255-27 EN60255-26 / EN50263 EN61000-6-2 / EN61000-6-4 UL508 UL1053 C22.2.No 14 ISO9001

Storage/Shipping: Operating: Humidity:

ISO

Motor Protection

Environmental (Dry heat) Relative Humidity Cyclic

Manufactured under a registered quality program

Altitude: Pollution Degree: Overvoltage Category: Ingress Protection:

GEDigitalEnergy.com

-40°C to 85°C -40°C to 60°C (continuous) Operating up to 95% (non condensing) @ 55°C (As per IEC60068-2-30 Variant 2, 6days) 2000m (max) II III IP54 Front

381

Ordering 869 Base Unit Language Phase Currents Slot J Bank 1/2 Phase Currents Slot K Bank 2/2

E

**

**

**

*

*

*

*

*

*

*

*

*

*

*

*

*

*

*

*

869 E

English P1

1A three phase current inputs (J1)

P5

5A three phase current inputs (J1) NN

No phase current inputs

P1

1A three phase current inputs 5A three phase current inputs G1

1A ground input

G5

5A ground input 1A ground + CBCT (included with current protection M option only)

B1

5A ground + CBCT (included with current protection M option only)

B5 Power Supply Slot B - LV I/O

H

110 - 250 V dc/110 - 230 Vac N

None

R Slot C - LV I/O

6 X RTDS N

None

R Slot F - HV I/O

Description Motor Protection Relay (Standard : English Language; High Voltage PS, Graphical Control Panel)

P5 Ground Currents

N

6 X RTDS A

Slot G - HV I/O

Slot H - HV I/O Faceplate Current Protection

2 Form A (Vmon), 3 Form C, 7 Digital Inputs (Low / High voltage, Int/Ext supply) N

None

A

2 Form A (Vmon), 3 Form C, 7 Digital Inputs (Low / High voltage, Int/Ext supply) N

None G

Color Graphical Display S

Basic = 14, 19, 37, 38, 46, 49, 50P, 50N, 50G, 50_2, 50LR, 51P, 51N, 51G, 66, 86 Standard = Basic + 67P, 67N, 87 (2nd CT Bank required for 87)

M Voltage Monitoring & Protection Control

S

Standard = 27P, 47, 59P, 59N, 59X, 81O, 81U, VTFF

P

Advanced = Standard + 32, 55, 59_2 B

Basic = Breaker / Contactor Control

F Monitoring

Standard = Basic + Flexlogic, 50BF, Trip Bus B

Basic = Motor Health Report, Motor Learned Data, Motor Start Report, Data Logger

C Communications

Fiber Optic Connector Wireless Communication Security

Standard = Basic + Breaker Health Report, Broken Rotor Bar S

E

1

E

Standard = USB, 1xRS485 : Modbus RTU, DNP3.0, IEC60870-5-103 + 1xEthernet Copper: Modbus TCP Advanced = USB, 1xRS485 : Modbus RTU, DNP3.0, IEC60870-5-103 + 2xEthernet Fiber, Modbus TCP/IP, DNP3.0, IEC 60870-5-104, SNTP, 1588

1

P

Advanced + PRP

2

E

Advanced + PRP + IEC 61850 Ed2 N

None

S

ST, Multi-mode 850nm N

None

W

WiFi 802.11 B

Basic

A

Advanced - CyberSentry Level 1

Note: Harsh Environment Coating is a standard feature on all 8 series units.

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12784A(E) English 150122

Multilin™ M60 Comprehensive Protection for Medium to Large Motors The Multilin M60 motor protection system offers comprehensive protection and control solutions for medium to large-sized three-phase motors. The M60 includes advanced automation and communication capabilities, extensive I/O options, and powerful fault recording features that can simplify postmortem fault analysis and help minimize motor downtime. The M60 provides superior protection, control, and diagnostics that includes a proven thermal model with RTD and current unbalance biasing, stator differential, reverse and low forward power, external RRTD module, two-speed motors, reduced voltage starting, and broken rotor bar detection.

Key Benefits • Extended motor life with advanced protection and control elements including a flexible and powerful thermal model and standard, custom, and voltage dependent overload curves • Integrated automation and process control functions eliminating the need for additional discrete devices • Simplified setup and configuration with EnerVista M60 Motor Settings auto-configurator • Enhanced motor-learned data provides critical information for preventative maintenance

Protection and Control • Enhanced thermal model with RTD and current unbalance compensation • Stator Differential, Mechanical Jam/Stall, Short circuit tripping, under-Current & -Power and Phase reversal • Two-speed motor protection and reduced voltage starting • CT failure for each CT bank, VT fuse failure • Optional internal RTDs & external RTD module

Communications • 3 independent Ethernet ports for simultaneous & dedicated network connections with IEEE 1588 support • Advanced IEC 61850 Edition 2 implementation and IEC 61850-9-2 process bus support

• Increased network availability via failover time reduced to zero through IEC® 62439-3 “PRP” support

• Supported industry protocols: IEC 61850 Ed. 2, SFTP, MMS File Transfer Service, DNP 3.0, Modbus Serial/TCP, IEEE 1588, IEC 60870-5-104 and 103, PRP, SNTP, HTTP, TFTP

• CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog)

• DeviceNet and Profibus protocol support using D485 and P485 protocol converters

• Advanced IEC 61850 Ed. 2 implementation, complete settings via SCL files and IEC 61850-9-2 process bus solution enable resource and platform managing optimization and reduce cost of ownership

• Advanced fault and disturbance recording, including internal relay operating signals, eliminating the need for external recording devices

Applications • Protection & control of most popular construction type medium to large three-phase induction motors • Protection of medium to large synchronous motors when paired with the SPM Synchronous Motor Protection System • Automation or process control functionality • Stand-alone protection or component in automated substation control system

Cyber Security • CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog) • Setting for security audit trails, tracking changes to device configurations

Monitoring & Metering • Advanced recording capabilities with highcapacity event recorder, configurable and extended waveform capture and data logger • Metering: current, voltage, power, energy, frequency, and harmonics

M60 Motor Protection System

Protection and Control

M60 - Protection, Metering, Monitoring and Control

Designed as an asset management device, the M60 utilizes a proven thermal model that mimics the design characteristics of each motor it protects. As part of the Universal Relay (UR) family, the M60 provides the modularity, flexibility, and reliability required to deliver superior protection and control capabilities, including:

Motor Thermal Model The M60 features an enhanced motor thermal model consisting of the following elements: • Thermal limit curves - NEMA standard, voltage dependent and customized

The M60 provides protection, control, metering, and monitoring in a single device, easily integrated into existing HMI or SCADA monitoring and control systems.

• IEC 60255-8 thermal overload curves • Current unbalance biasing

Motor Protection

• Independent running and stopped exponential cooling curves • Optional RTD biasing of the thermal model to adapt to real-time temperature measurements • Compensation for hot/cold motor conditions The M60 thermal model integrates both stator and rotor heating and cooling into a single model.

Overtemperature Protection

Acceleration Time

The M60 supports up to 16 programmable RTD inputs that allow for the configuration of the alarm and trip temperature of each RTD, detecting RTD shorting conditions, and selecting RTD voting that requires more than one RTD to detect an over-temperature condition before it will issue a trip command.

The M60 protects the motor from overheating in cases of abnormal loading during motor starts. The motor can be tripped if the motor does not reach a running condition within the programmable motor acceleration time.

Mechanical Jam

FlexCurves™

The mechanical jam element senses increased loading associated with process or load related faults such as an overloaded conveyor. A programmable delay setting can be used to allow the process to attempt to clear itself before issuing a trip.

For applications that require greater flexibility, FlexCurves can be used to define custom curve shapes. These curves can be used to protect motors with different rotor and stator damage curves, allowing complete protection over the total motor capacity.

Functional Block Diagram

52

59N,P

CLOSE

3

67P 2

M

2

50G

51G

4

4

32 50BF 50P 2

4

46

59_2

27P 3

47

4

67N 50N

49 2

2

RTD

81U

81O

3

50NBF 4

Metering 87S

M60 Motor Management System

384

The M60 provides stator differential protection for fast clearing of stator phase faults. Advanced CT saturation detection algorithms and dual-slope characteristics are incorporated for increased security during heavy faults.

ANSI® Device Numbers & Functions

TRIP

37

Stator Differential

GEDigitalEnergy.com

6

DEVICE NUMBER

FUNCTION

27P 27X 32 37 46 47 49 50BF 50G 50N 50P 51G 59N 59P 59X 59_2 66 67N 67P 87S 81O 81U -----

Phase Undervoltage Auxiliary Undervoltage Sensitive Directional Power Under Power Current Unbalance Phase Sequence Voltage Thermal Overload Breaker Failure Ground Instantaneous Overcurrent Neutral Instantaneous Overcurrent Phase Instantaneous Overcurrent Ground Time Overcurrent Neutral Overvoltage Phase Overvoltage Auxiliary Overvoltage Negative Sequence Overvoltage Starts Per Hour, Time Between Starts Neutral Directional Overcurrent Phase Directional Overcurrent Stator Differential Overfrequency Underfrequency Mechanical Jam Under Power

M60 Motor Protection System

10000

TYPICAL CUSTOM CURVE - 6500 HP, 13800 VOLT INDUCED DRAFT FAN MOTOR

1000

TIME TO TRIP IN SECONDS

1 2 100

3 10

4

The M60 percent differential element has enhanced saturation detection algorithms to provide additional security against AC and DC saturation that can occur during faults near the motor.

5 1.0

0.1 0.5

1.0

10

100

MULTIPLE OF PER UNIT CURRENT

1

PROGRAMMED FLEXCURVE

2

RUNNING SAFETIME (STATOR LIMIT)

3

ACCELERATION SAFETIME (ROTOR LIMIT)

4

MOTOR CURRENT @ 100% VOLTAGE

5

MOTOR CURRENT @ 80% VOLTAGE

Breaker Failure Protection The breaker failure protection element monitors for timely operation of the connected breaker. If a trip command is not successful in operating the breaker and clearing the fault, the breaker failure element can be used to send trip signals to upstream breakers to clear the fault.

Typical FlexCurve overload curve. RTD Bias Maximum

RTD Thermal Capacity Used (%)

100

The start inhibit function prevents the starting of a motor when the motor is too hot and does not have a sufficient amount of thermal capacity available to allow a start without being tripped offline.

90 80 70

Undercurrent Protection

60 50 40 30 20

RTD Bias Center Point

RTD Bias Minimum

10 0 -50

0

50

100

150

200

250

Maximum Stator RTD Temperature ( C)

RTD bias curve.

Short Circuit Protection Short circuit overcurrent protection protects damage to the motor during a locked rotor condition. The M60 comes with up to 8 instantaneous overcurrent elements that can be configured for protection, alarming, and control during locked rotor conditions.

The undercurrent protection element provides the ability to trip the motor due to external conditions that can cause the load being pulled by the motor to drop below a preset level. This element is useful when the loss of the load results in a loss of cooling which will cause the asset to overheat.

Under/Over Frequency Protection The under/over frequency protection element detects when the motor is operating at offnominal frequencies (which can damage the process) or signals to upstream protection or control to implement load-shedding actions.

RTD Protection (Module Option 5C) The M60 RTD option provides 8 programmable RTD inputs per module that are used for monitoring the stator, bearing and ambient

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temperatures. Each RTD input has 2 operational levels: alarm and trip. The M60 supports RTD trip voting and provides open RTD failure alarming. Alternatively, a remote RTD module “RRTD”, which supports 12 RTD inputs, can also be used with the M60 for temperature monitoring. The RRTD provides cost savings compared with standard RTD wiring.

Two-Speed Motor Protection The two-speed motor protection feature allows for the protection of motors that can operate at two different speeds and have different full load capacity levels at each speed. This feature can be used on motors that have two sets of windings on each stator, where each set is used to operate the motor at a different speed.

Underpower Protection The underpower protection feature provides for sensitive detection of a loss of load condition. The underpower protection element can be more sensitive for detecting loss of load conditions caused by process-related problems than is possible using a standard undercurrent element.

Reduced Voltage Starting The reduced voltage starting feature provides the controls for signaling the motor to switch over from a reduced voltage (that is used during startup) to the full voltage for motor running operation. This feature can issue the command to switch to full operating voltage, by detecting: a) if the motor load has reached a preset current level, or b) if a time delay has elapsed

385

Motor Protection

Start Inhibit

M60 Motor Protection System

(after starting), or c) both of these conditions combined.

IEC 61850 Process Bus The IEC 61850 Process Bus module is designed to interface with the Multilin HardFiber System, allowing bi-directional IEC 61850 fiber optic communications. The HardFiber System is designed to integrate seamlessly with existing UR applications, including protection functions, FlexLogic™, metering and communications. The Multilin HardFiber System offers the following benefits: • Communicates using open standard IEC 61850 messaging • Drastically reduces P&C design, installation and testing labor by eliminating individual copper terminations

Motor Protection

• Integrates with existing M60’s by replacing traditional CT/VT inputs with the IEC 61850 Process Bus module • Does not introduce new cyber security concerns Visit the HardFiber System product page on the GE Digital Energy web site for more details.

Advanced Automation The M60 incorporates advanced automation features including powerful FlexLogic programmable logic, communication, and SCADA capabilities that far surpass what is found in the average motor protection relay. The M60 integrates seamlessly with other UR relays for complete system protection, including the adjacent motors, feeders and other balance of plant protection.

FlexLogic FlexLogic is the powerful UR-platform programming logic engine that provides the ability to create customized protection and control schemes, minimizing the need and associated costs of auxiliary components and wiring. Using FlexLogic, the M60 can be programmed to provide the required tripping logic along with custom scheme logic for motor breaker control (including interlocking with internal motor start supervision and synchrocheck), interlocking schemes with adjacent protections (for example, preventing sympathetic tripping of healthy feeders), and dynamic setting group changes.

386

Scalable Hardware The M60 is available with a multitude of I/O configurations to suit the most demanding application needs. The expandable modular design allows for easy configuration and future upgrades. • Multiple CT/VT configurations allow for the implementation of many protection schemes, including applications with high-impedance machine grounding • RTD inputs allow biasing of the motor thermal model, as well as overtemperature protection of the stator, bearings, and other heatsensitive components of the motor • Types of digital outputs include triprated Form-A and Solid State Relay (SSR) mechanically latching, and Form-C outputs • DCmA inputs are available to monitor equipment and process parameters

Monitoring and Metering The M60 includes high accuracy metering and recording for all AC signals. Voltage, current, and power metering are built into the relay as a standard feature. Current and voltage parameters are available as total RMS magnitude, and as fundamental frequency magnitude and angle.

Advanced Device Health Diagnostics The M60 performs advanced motor health diagnostics and records this information for each of the last 250 consecutive motor starts. Analyzing this diagnostic information for operating parameters that have changed over these successive starts can indicate maintenance requirements before damage occurs and costly repairs are required For each motor start, the M60 will provide a record that contains the fol lowing information: • Date of each motor start • Motor acceleration time • Motor starting current • Motor thermal capacity used during starts • Average motor load • Running time after a start

Advanced Motor Diagnostics The Multilin M60 provides advanced motor diagnostics including a broken rotor bar detection function. The broken rotor bar detection is a condition maintenance function that continuously monitors the motor’s health

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while in operation. The advanced Motor Current Signature Analysis (MCSA) continuously analyzes the motor current signature and based on preset algorithms, will determine when a broken rotor bar is present in the motor. With fully programmable alarms, the broken rotor bar function will provide early detection of any rotor problems and advise maintenance personnel of the impending issue, allowing for predictive maintenance of the motor and prevention of catastrophic motor failures. By providing early indication of potential rotor problems, serious system issues, such as reduced starting torque, overloads, torque and speed oscillation and bearing wear, can be avoided. With the advanced broken rotor bar detection system, advanced warning of impending problems reduces catastrophic failures, maximizing motor life and system uptime.

Fault and Disturbance Recording The advanced disturbance and event recording features within the M60 can significantly reduce the time needed for postmortem analysis of power system events and the creation of regulatory reports. Recording functions include: • Sequence of Event (SOE) - 1024 time stamped events • Oscillography - 64 digital & up to 40 analog channels - Events up to 45s in length • Data Logger and Disturbance Recording - 16 channels up to 1 sample/cycle/channel The very high sampling rates and the large amount of storage space available for data recording in the M60 can eliminate the need for installing costly stand-alone recording equipment.

M60 Motor Protection System

Cyber Security – CyberSentry UR CyberSentry UR enabled UR devices deliver full cyber security features that help customers to comply with NERC CIP and NIST® IR 7628 cyber security requirements. This software option delivers the following core features:

AAA Server Support (Radius/LDAP) Enables integration with centrally managed authentication and accounting of all user activities and uses modern industry best practices and standards that meet and exceed NERC CIP requirements for authentication and password management.

Role Based Access Control (RBAC)

Event Recorder (Syslog for SEM) Capture all cyber security related events within a SOE element (login, logout, invalid password attempts, remote/local access, user in session,

• IEC 60870-5-103 and IEC 60870-5-104 • Modbus RTU, Modbus TCP/IP • HTTP, TFTP, SFTP and MMS file transfer • SNTP and IEEE 1588 for time synchronization • PRP as per IEC 62439-3

Communications The M60 provides advanced commun-ications technologies for remote data and engineering access, making it the easiest and most flexible motor protection relay to use and integrate into new and existing infrastructures. Direct support for fiber optic Ethernet provides high-bandwidth communications allowing for low-latency controls and high-speed file transfers of relay fault and event record information. The available three independent Ethernet ports, redundant Ethernet option and the embedded managed Ethernet switch provide the means of creating fault tolerant communication architectures in an easy, cost-effective manner without the need for intermediary communication hardware. The M60 supports the most popular industry standard protocols enabling easy, direct integration into DCS and SCADA systems. • IEC 61850 Ed. 2 with 61850-9-2 support

Interoperability with Embedded IEC 61850 Edition 2 The new IEC 61850 implementation in the UR Family positions GE as an industry leader in this standard. • Implements Edition 2 of the standard across the entire family of UR devices • Provides full relay setting management via standard SCL files (ICD, CID and IID) • Enables automated relay setting management using 3rd party tools through standard file transfer services (MMS and SFTP) • Increases the number of Logical Devices and data mapped to them, GOOSE messages, and reports to support different organizational needs for data transfer and reduce dependency on generic logical nodes • Configures GE Systems based on IEC 61850 using universal 3rd party tools

• DNP 3.0 (serial & TCP/IP)

Direct I/O Messaging

• Ethernet Global Data (EGD)

Direct I/O allows for the sharing of high-speed digital information between multiple UR relays via direct back-to-back connections or multiplexed through a standard DS0 multiplexer channel bank. Regardless of the connection method, direct I/O provides continuous real-time channel monitoring that supplies diagnostics information on channel health.

Power System Troubleshooting The M60 contains many tools and reports that simplify and reduce the amount of time required for troubleshooting power system events.

Direct I/O provides superior relay-to-relay communications that can be used in advanced interlocking and blocking schemes. • Communication with up to 16 UR relays in single or redundant rings rather than simplistic point-to-point configurations • Connect to standard DS0 channel banks through standard RS422, G.703 or IEEE C37.94 interfaces or via direct fiber optic connections • Built-in continuous loop and channel monitoring provides real-time diagnostics of your communication channels with no external or handheld tester required

LAN Redundancy

Analyze motor operating characteristics by recording analog waveforms during system voltage recovery.

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Substation LAN redundancy has been traditionally accomplished by reconfiguring the active network topology in case of failure. Regardless of the type of LAN architecture (tree,

387

Motor Protection

Efficiently administrate users and roles within UR devices. The new and advanced access functions allow users to configure up to five roles for up to eight configurable users with independent passwords. The standard “Remote Authentication Dial In User Service” (Radius) is used for authentication.

settings change, FW update, etc), and then serve and classify data by security level using standard Syslog data format. This will enable integration with established SEM (Security Event Management) systems.

M60 Motor Protection System

mesh, etc), reconfiguring the active LAN requires time to switchover, during which the LAN is unavailable. UR devices deliver redundancy as specified by PRP-IEC 62439-3, which eliminates the dependency on LAN reconfiguration and the associated switchover time. The UR becomes a dual attached node that transmits data packets over both main and redundant networks simultaneously, so in case of failure, one of the data packets will reach the receiving device with no time delay.

Multi-Language

Motor Protection

UR devices support multiple languages: English, French, Russian, Chinese, Turkish and German. These language options are available on the front panel, in the EnerVista setup software, and in the product manuals. Easily switch between English and an additional language on the local displays without uploading new firmware.

• Wiring Diagrams • FAQs • Service Bulletins The UR setup software now contains an M60 Motor Setting Auto-Configurator that configures all of the settings required to protect and control a motor in six simple steps. Simply entering the motor nameplate data, the CT and VT parameters, motor starting data, and application information, will allow the UR setup software to generate a complete setting file customized for protecting and controlling the motor.

Viewpoint Monitoring Viewpoint Monitoring is a simple-to-use and full-featured monitoring and data recording software package for small systems. Viewpoint Monitoring provides a complete HMI package with the following functionality:

EnerVista Software

• Plug & Play Device Monitoring

The EnerVista suite is an industry-leading set of software programs that simplifies every aspect of using the M60 relay. The EnerVista suite provides all the tools to monitor the status of your motor, maintain your relay, and integrate information measured by the M60 into DCS or SCADA monitoring systems. Convenient COMTRADE and SOE viewers are an integral part of the UR setup software included with every UR relay, to carry out postmortem event analysis and ensure proper protection system operation.

• System Single-Line Monitoring & Control

EnerVista Launchpad

drag-and-drop environment . Viewpoint UR Engineer provides the following configuration and commissioning utilities: • Graphical Logic Designer • Graphical System Designer • Graphical Logic Monitor • Graphical System Monitor

Viewpoint Maintenance Viewpoint Maintenance provides tools that will create reports on the operating status of the relay, simplify the steps to download fault and event data, and reduce the work required for cyber security compliance audits. Tools available in Viewpoint Maintenance include: • Security/Change History Report • Device Health Report • Single-Click Fault Data Retrieval

EnerVista Integrator

• Annunciator Alarm Screens

EnerVista Integrator is a toolkit that allows seamless integration of Multilin devices into new or existing automation systems. Included in

• Trending Reports

EnerVista Integrator is:

• Automatic Event Retrieval • Automatic Waveform Retrieval

• OPC/DDE Server • Multilin Drivers

Viewpoint UR Engineer

• Automatic Event Retrieval

Viewpoint UR Engineer is a set of powerful tools that allows you to configure and test GE relays at a system level in an easy-to-use graphical

• Automatic Waveform Retrieval

Simplifying Commissioning and Testing

EnerVista Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining Multilin products. The setup software within Launchpad allows for the configuration of devices in real-time by communicating using serial, Ethernet , or modem connections, or offline by creating setting files to be sent to devices at a later time. Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed. Documents made available include: • Manuals • Application Notes • Guideform Specifications • Brochures The internal operation of the M60 elements, logic, and outputs can be monitored in real-time to simplify commissioning and troubleshooting procedures.

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M60 Motor Protection System

User Interface

48 Configurable LED Indicators

The M60 front panel provides extensive local HMI capabilities. The local display is used for monitoring, status messaging, fault diagnosis, and device configuration. User-configurable messages that combine text with live data can be displayed when user-defined conditions are met.

Multi-Language Display • English • Russian • French • Chinese • Turkish • German User-Programmable Pushbuttons

Typical Wiring

A B

52

C

P4 SURGE

Return

H5a H5c H5b H6a H6c

Return

H7a H7c H7b H8a H8c

Return

M4c

M4b IG

M3c

M4a IG5

IG1

TC 1

TC 2

Comp

DB-9 RS-232 (front)

Hot Comp

UR

Hot Comp

TXD RXD

Hot Comp

SGND

Hot Comp Hot Comp Hot

M60

Comp

COMPUTER

1 2 3 4 5 6 7 8 9

1 2 3 4 5 6 7 8 9

8 3 RXD 2 TXD 20 7 SGND 6 4 5 22

CONNECTOR

CONNECTOR

Hot Comp

10BaseFL Rx1

10BaseFL

CRITICAL FAILURE

B

1 Power supply

D

9 CPU

1

SURGE

Rx2

OUTPUT

F

CONTROL POWER

G H

SURGE FILTER

J

NORMAL ALTERNATE

8 CT/VT 5 RTD

K L

COM 1

M N

10BaseT

P

RS485

R

com

8 CT/VT 6 Inputs/ outputs

S

Co-axial

BNC

Co-axial

BNC

IRIG-B Input

VERTICAL

IRIG-B Output

X

W

U

V

minimum

* GROUND BUS

V

P1a P1b P1c P2a P2b P2c P3a P3b P3c P4a P4b P4c

5C

Hot

B1b B1a B2b B3a B3b B5b HI B6b LO B6a B8a B8b

D1a D2a D3a D4b D4a

V I

H8b

Remote Device

V I

P3

H3a H3c H3b H4a H4c

Shielded

M3b P2

Return

Tx2

V I

H1a H1c H1b H2a H2c

Tx1

IC

P1

P8b

Fibre * Optic

I

6G

P7a P7c P8a P8c P7b

DC

IC1

M2c

M3a

M2b IB

IB1

IC5

M1c

M2a IB5

M1a IA5

M1b

IG1

IA

F4c

IG

IA1

F3c

F4a

F4b

IG5

F3b IC

IC1

F2c

F3a

IB1

IB

IC5

F1c

F2a

F2b

IB5

F1b

IA5

IA

F7c

F1a

VC

IA1

F6c

F7a

VB

VC

F5c

F6a VB

F5a

VA

VA

Motor Protection

P5a P5c P6a P6c P5b

*

T

S

R

P

N

M

L

K

J

H

G

F

D

B

6

8

5

8

9

1

Input/ output

VT/CT

RTD

VT/CT

CPU

Power Supply

PROVIDED

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389

Ordering M60 - * 00 - H * * - F ** - H ** - M ** - P ** - U ** - W/X ** For full sized horizontal mount Base Unit M60 Base Unit CPU E RS485 + RS485 (IEC 61850 option not available) J RS485 + multimode ST 100BaseFX K RS485 + multimode ST Redundant 100BaseFX N RS485 + 10/100 BaseT T RS485 + three multimode SFP LC 100BaseFX. Req FW v7xx or higher U RS485 + two multimode SFP LC 100BaseFX + one SFP RJ45 100BaseT. Req FW v7xx or higher V RS485 + three SFP RJ45 100BaseT. Req FW v7xx or higher Software Options 00 No Software Options (see note 1 below) 03 IEC 61850 A0 CyberSentry UR Lvl 1. Req UR FW 7.xx or higher B0 IEEE 1588. Req UR FW 7.xx or higher C0 PRP D0 IEEE 1588 + CyberSentry UR. Req UR FW 7.xx or higher Mount / Coating H Horizontal (19” rack) - Standard A Horizontal (19” rack) - Harsh Chemical Environment Option V Vertical (3/4 size) - Standard B Vertical (3/4 size) - Harsh Chemical Environment Option User Interface F Vertical Front Panel with English Display I Enhanced German Front Panel J Enhanced German Front Panel with User-Programmable Pushbuttons K Enhanced English Front Panel L Enhanced English Front Panel with User-Programmable Pushbuttons M Enhanced French Front Panel N Enhanced French Front Panel with User-Programmable Pushbuttons Q Enhanced Russian Front Panel T Enhanced Russian Front Panel with User-Programmable Pushbuttons U Enhanced Chinese Front Panel V Enhanced Chinese Front Panel with User-Programmable Pushbuttons W Enhanced Turkish Front Panel Y Enhanced Turkish Front Panel with User-Programmable Pushbuttons Power Supply H 125 / 250 V AC/DC (see note 2 below) H RH 125/250 V AC/DC with redundant 125/250 V AC/DC L 24 - 48 V (DC only) L RL 24 - 48 V (DC only) with redundant 24 - 48 V (DC only) CT/VT DSP 8L 8L Standard 4CT/4VT w/ enhanced diagnostics 8M 8M Sensitive Ground 4CT/4VT w/ enhanced diagnostics 8N 8N Standard 8CT w/ enhanced diagnostics 8R 8R Sensitive Ground 8CT w/ enhanced diagnostics IEC 61850 Process Bus 81 8 Port IEC 61850 Process Bus Module Digital I/O XX XX XX XX XX No module 4A 4A 4A 4A 4A 4 Solid State (No Monitoring) MOSFET Outputs 4C 4C 4C 4C 4C 4 Solid State (Current w/opt Voltage) MOSFET Outputs 4D 4D 4D 4D 4D 16 Digital Inputs with Auto-Burnish 4L 4L 4L 4L 4L 14 Form-A (No Monitoring) Latchable Outputs 67 67 67 67 67 8 Form-A (No Monitoring) Outputs 6C 6C 6C 6C 6C 8 Form-C Outputs 6D 6D 6D 6D 6D 16 Digital Inputs 6E 6E 6E 6E 6E 4 Form-C Outputs, 8 Digital Inputs 6F 6F 6F 6F 6F 8 Fast Form-C Outputs 6K 6K 6K 6K 6K 4 Form-C & 4 Fast Form-C Outputs 6L 6L 6L 6L 6L 2 Form-A (Current w/ opt Voltage) & 2 Form-C Outputs, 8 Digital Inputs 6M 6M 6M 6M 6M 2 Form-A (Current w/ opt Voltage) & 4 Form-C Outputs, 4 Digital Inputs 6N 6N 6N 6N 6N 4 Form-A (Current w/ opt Voltage) Outputs, 8 Digital Inputs 6P 6P 6P 6P 6P 6 Form-A (Current w/ opt Voltage) Outputs, 4 Digital Inputs 6R 6R 6R 6R 6R 2 Form-A (No Monitoring) & 2 Form-C Outputs, 8 Digital Inputs 6S 6S 6S 6S 6S 2 Form-A (No Monitoring) & 4 Form-C Outputs, 4 Digital Inputs 6T 6T 6T 6T 6T 4 Form-A (No Monitoring) Outputs, 8 Digital Inputs 6U 6U 6U 6U 6U 6 Form-A (No Monitoring) Outputs, 4 Digital Inputs 6V 6V 6V 6V 6V 2 Form-A (Cur w/ opt Volt) 1 Form-C Output, 2 Latching Outputs, 8 Digital Inputs Transducer I/O 5C 5C 5C 5C 5C 8 RTD Inputs 5E 5E 5E 5E 5E 4 dcmA Inputs, 4 RTD Inputs 5F 5F 5F 5F 5F 8 dcmA Inputs Inter-Relay Communications 7A 820 nm, multimode, LED, 1 Channel 7B 1300 nm, multimode, LED, 1 Channel 7H 820 nm, multimode, LED, 2 Channels 7I 1300 nm, multimode, LED, 2 Channels Ordering Notes:  . To view all available model order codes, options for M60 or to order the UR Classic Front Panel, please visit GE’s On-Line Store at http://store.gedigitalenergy.com/viewprod.asp?model=M60 1 2. Redundant power supply only available in horizontal unit. If redundant is chosen, must be same type. Maximum 2 per chassis

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12756G(E) English 150122

Multilin™ 339 Motor Protection System Intuitive Motor Protection The Multilin 339 is a member of the Multilin 3 Series protective relay platform and has been designed for the protection, control and management of medium voltage motors in industrial applications. The 339 delivers unparalleled protection, control, diagnostics and communications in an industry leading draw-out construction. Providing simplified setup configuration through the use of the Motor Settings Auto-Configurator, advanced graphical diagnostics with the Motor Health Report and support for multiple communication protocols including IEC 61850, the 339 Motor Protection System provides comprehensive motor protection for most small and medium sized motors.

Key Benefits • Cost-effective and flexible protection and control device for motors • Enhanced Thermal Model including RTD and current unbalance biasing • Time stamped event reports, waveform capture, motor start and motor trending • Security Audit Trail capturing setting and command changes • Draw-out construction eliminates the need for test switches • Reduced wiring with support for remote RTD’s using the RMIO module • Optional internal RTD board supporting 3 programmable RTDs

Protection and Control • Thermal model biased with RTD and negative sequence current feedback • Phase and ground overcurrent • Start supervision and inhibit • Mechanical Jam • Current Unbalance • Over/under voltage and phase reversal • Breaker Failure / Welded Contactor

Communications • Front USB and rear serial, Ethernet and Fiber ports • Multiple Communication Protocols including IEC 61850, IEC 61850 GOOSE, MODBUS TCP/ IP, MODBUS RTU, DNP 3.0, IEC60870-5-104, IEC60870-5-103

• Simplified Motor Setup screen reduces setup and configuration time

Metering & Monitoring

• Customized motor overload curve Flex curves

• Current &Voltage Metering

• Detailed Motor Health Report with critical data

• RTD Temperature

• Draw out or non draw out options available

• Power, Energy & Frequency Metering

• Multiple communication networks including USB, Serial, Fiber or copper Ethernet supporting the most popular industry standard protocols

• Event Recorder: 256 events with 1ms time stamping

Applications

• Oscillography with 32 samples per cycle and digital states

• Small to Medium sized Medium Voltage Motors

• IRIG-B clock synchronization

• Protection of pumps, conveyors, fans, compressors, etc.

• Motor health diagnostics

• Applications requiring fast and secure communications • Harsh environments requiring protection against corrosive chemicals and humid environments

EnerVista™ Software • Simplify setup and configuration • Strong document archive and management system • Simplify full featured monitoring

339 Motor Protection System

Overview

Easy to Use

Easy to Configure

The 339 relay is a member of the 3 Series family of Multilin relays. This motor protective device is used to perform primary motor protection of medium voltage motor applications.

Drawout Construction

Fast & Simple Configuration

The 339 offers a complete drawout feature eliminating the need for rewiring after testing has been concluded. The withdrawable feature also eradicates the need to disconnect communication cables, e.g. fiber, copper, RJ45, etc and helps retain communication status even after a relay has been withdrawn from its case.

Providing ease-of-use functionality, the 339 allows for motor configuration in a simple one page setup screen. Therefore complete motor protection setup can be completed in one easy step.

Effortless Retrofit

Easy integration into new or existing infrastructure

The basic protection functions of this relay include motor thermal model, time-delayed and instantaneous overcurrent, ground overcurrent and sensitive ground overcurrent protection. Additional control features such as logic control are available for applications that require additional motor control functionality.

Motor Protection

The robust 339 streamlines user work flow processes and simplifies engineering tasks such as configuration, wiring, testing, commissioning, and maintenance. This cost-effective relay also offers enhanced features such as diagnostics, preventative maintenance, motor health reports and advanced security features.

The compact and withdrawable feature of the 339 relay minimizes mounting requirements, enables easy retrofit to existing cases, and allows multiple relays to be mounted side by side on a panel. The 339 also provides a pluggable RS485 & IRIG-B connection for easy trouble shooting.

Advanced Communications

With several Ethernet and serial port options, and a variety of communication protocols, the 339 provides advanced and flexible communication selections for new and existing applications.

339 Relay Features

Advanced & Flexible Communication Options

Easy to Configure - 1 simple step

Easy to Use - Draw out case

392

Diagnostic Alarms

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339 Motor Protection System

Enhanced Diagnostics

Protection & Control

Preventative Maintenance

The 339 motor protection system is designed to protect and manage small to medium sized AC motors and driven equipment . Flexible and powerful, the 339 provides advanced motor protection, control and monitoring in one integrated, economical draw-out design. The 339 contains a full range of self contained protection and control elements as detailed in the Functional Block Diagram and Features table.

The 339 allows user to track relay exposure to extreme environmental conditions by monitoring and alarming at high or low temperatures. This data allows users to proactively schedule regular maintenance work and upgrade activities.

Failure Alarm The 339 detects and alarms on communication port and IRIG-B failures. The 339 also enables users to analyze system performance via diagnostics information such as event records, oscillography, etc. It issues detailed motor health reports and alarms when thresholds are exceeded.

Motor Thermal Model To provide optimal protection and maximum runtime, the 339 Motor Protection System employs GE’s Industry leading advanced Thermal Model, consisting of six key elements: • Overload Curves • Unbalance Biasing

Cost Effective

• Hot/Cold Safe Stall Ratio

Robust Design

• Thermal Inhibit and Emergency Restart • RTD Biasing

FlexCurves™ A smooth custom overload curve is created using FlexCurves. These curves can be used to protect motors with different rotor damage and stator damage curves, allowing total motor design capacity with complete protection.

Reduced Life Cycle Cost The 339 is designed to reduce total installation and life cycle cost for motor protection. The draw out construction of the device reduces downtime during maintenance and decreases extra wiring needed for relay testing and commissioning.

Over/Under Voltage Protection Overvoltage/Undervoltage protection features can cause a trip or generate an alarm when the voltage exceeds a specified voltage setting for a specified time.

Multiple Options Several options for protection and communications are provided to match basic to high end application requirements.

Frequency Protection The 339 offers over frequency and underfrequency protection elements that

Unbalance (Negative Sequence) Biasing Negative sequence current , which causes additional rotor heating, is not accounted for in the thermal limit curves provided by the manufacturer. The 339 measures current unbalance as a ratio of negative to positive sequence current. The thermal model is then biased to reflect the additional rotor heating.

RTD Biasing The Thermal Model relies solely on measured current to determine motor heating, assuming an ambient temperature of 40°C and normal motor cooling. The actual motor temperature will increase due to abnormally high ambient temperatures or if the motor cooling systems have failed. RTD Biasing enhances the motor thermal model by calculating the thermal capacity used based on available Stator RTD temperatures. RTD Biasing does not replace the TCU calculated using the motor current. It provides a second and independent measure of thermal capacity used. Based on a programmable curve, the 339 will calculate the TCU at any given temperature. This TCU is then compared to that of the thermal model, and the larger of the two will be used.

Hot / Cold Safe Stall Ratio The ratio defines the steady state level of thermal capacity used (TCU) by the motor. This level corresponds to normal operating temperature of a fully loaded motor and will

Functional Block Diagram ANSI® Device Numbers & Functions

BUS

52 27P 59P

47 59_2 81O 81U

37

49

46

DEVICE NUMBER 27P 37 38

50P 50BF 51 50N

Phase CT 3

50G Ground CT 1

RTD

Stator RTDs Bearing RTDs

49

TRIP

CLOSE

38

START

START INHIBIT

LOAD MOTOR

Optional Remote RTD

Ambient air

86

46 47 48 49 50BF 50G 50P

339

FUNCTION Phase UV Undercurrent, Underpower Bearing RTD, Stator/Ambient/ Other, RTD Trouble Alarm Current Unbalance Voltage Phase Reversal Acceleration Time Thermal Protection/Stall Protection Breaker Failure / Welded Contactor Ground Fault Short Circuit

DEVICE NUMBER 51P 50N 59_2 59P 66 81O 81U 86 VTFF

FUNCTION Mechanical Jam Neutral Instantaneous Overcurrent Negative Sequence OV Phase OV Starts per Hour & Time Between Starts, Restart Block, Thermal Inhibit Overfrequency Underfrequency Lockout VT Fuse Failure

MOTOR PROTECTION SYSTEM 896814.CDR

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393

Motor Protection

• Motor Cooling Time Constants

The 339 is subjected to Accelerated Life Testing (ALT) to validate accurate relay functions under specified normal conditions. The device is further tested for durability through High Accelerated Life Testing (HALT), undergoing stress testing for extreme operating conditions.

provide the ability to detect when the motor is operating at off-nominal frequencies which can cause damage to the process. In such cases, the protection elements can trip the motor off-line or can be used to signal to upstream protection and control devices to implement load-shedding schemes.

339 Motor Protection System

6500 H P, 138 00 Volt INDUCED DRAFT

1 PROGRAMMED 339 CUSTOM CURVE

Motor Cool Time Constants

2 RUNNING SAFETIME (STATOR LIMITED)

5 MOTOR CURRENT @ 80% VOLTAGE 1, 000

1 S TIME TO TRIP IN SECOND

100

CU RV E 15 12 9 7

10

These elements guard the motor against excessive starting duty, which is normally defined by the motor manufacturer in addition to the thermal damage curves.

Undercurrent The undercurrent function is used to detect a decrease in motor current caused by a decrease in motor load. This is especially useful for indication of conditions such as: loss of suction for pumps, loss of airflow for fans, or a broken belt for conveyors. A separate undercurrent alarm may be set to provide early warning.

Motor Protection

3 10

4 5 1.0

4 3

The Start Inhibit function prevents starting of a motor when insufficient thermal capacity is available or a motor start supervision function dictates inhibit.

Motor Start Supervision consists of the following features: Time-Between-Starts, Starts-per-hour, Restart Time.

2 100

Start Inhibit

Motor Start Supervision

3 ACCELERATION SAFETIME (ROTOR LIMITED ) 4 MOTOR CURRENT @ 100% VOLTAGE

1000

TRIP TIME (seconds)

Ground Overcurrent For zero sequence ground overcurrent protection, all three of the motor conductors must pass through a separate ground CT. CTs may be selected to detect either highimpedance zero sequence ground or residual ground currents. The ground fault trip can be instantaneous or programmed for a time delay.

Typical Flexcurve

RTD Protection

• 10 contact Inputs with programmable thresholds

The 339 provides programmable RTD inputs via the remote RMIO that are used for monitoring the Stator, Bearing and Ambient temperatures. Each RTD input has 2 operational levels: alarm and trip. The 339 supports RTD trip voting and provides open and short RTD monitoring.

• 2 Form A output relays for breaker trip and close with coil monitoring • 5 Form C output relays

Advanced Automation

The remote RMIO RTD module is used with the 339 in cases where RTD monitoring is required.

Logic Elements The 339 relay has sixteen Logic Elements available for the user to build simple logic using the state of any programmed contact, virtual, or remote input, or an output operand from protection, or control elements.

Inputs/Outputs The 339 features the following inputs and outputs for monitoring and control of typical motor applications:

Thermal Capacity Used

Motor cooling curves

100 90 80

FLC Reduction S et @ 20 % & 100% FLC .

70 60 50

FLC Reduction Set @ 8% & 40% FLC

40 30 20 10 0. 00 55

500

(Multiples of full load)

15 Standard Curves available in the 339.

27

600 700 800 900 1000

400

300

200

50

60 70 80 90 100

Phase Current

Full Load Setpoint

0. 00

394

40

MULTIPLE OF FULL LOAD CURRENT SETPOINT

10

Mechanical Jam During overload conditions, quick motor shutdown can reduce damage to gears, bearings and other mechanical parts associated with the drive combination.

30

5

4

3

0.5

2

0.1

1 1

0.1

20

2 1

0.6 0.7 0.8 0.9 1

The 339 has a true exponential cooldown characteristic which mimics actual motor cooling rates, providing that motor cooling time constants are available for both the stopped and running states. When ordered with RTD’s the stopped and running cool time constants will be calculated by the 339 based on the cooling rate of the hottest RTD, the hot/cold stall ratio, the ambient temperature, the measured motor load and the programmed service factor or overload pickup.

FAN MOTO R

10000

10, 000

6 7 8 9 10

be adjusted proportionally if the motor load is lower than rated.

82

110

137

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165

192

220

247

TIME (in seconds)

339 Motor Protection System

The logic provides for assigning up to three triggering inputs in an “AND/OR” gate for the logic element operation and up to three blocking inputs in an “AND/OR” gate for defining the block signal. Pickup and dropout timers are available for delaying the logic element operation and reset respectively.

Virtual Inputs Virtual inputs allow communication devices the ability to write digital commands to the 339 relay. These commands could be starting or stopping the motor, changing setting groups or blocking protection elements.

IEC 61850 The 339 supports IEC 61850 Logical Nodes which allows for digital communications to DCS, SCADA and higher level control systems.

• Eliminates the need for hardwiring contact inputs to contact outputs via communication messaging. • Transmits information from one relay to the next in as fast as 8 ms. • Enables sequence coordination with upstream and downstream devices. • When Breaker Open operation malfunctions, GOOSE messaging sends a signal to the upstream breaker to trip and clear the fault.

Monitoring & Diagnostics

Oscillography The 339 captures current and voltage waveforms and digital channels at 32 samples per cycle. The oscillography record captures 8 individual channels allowing for detailed analysis. The oscillography is triggered either by internal signals or an external contact.

Statistical Data The 339 records the following statistical data in order to assist in diagnosing common motor faults, as well as assisting in planning preventative maintenance.

Advanced Device Health Diagnostics The 339 performs comprehensive device health diagnostic tests during startup and continuously at runtime to test its own major functions and critical hardware. These diagnostic tests monitor for conditions that could impact system reliability. Device status is communicated via SCADA communications and the front panel display. This continuous monitoring and early detection of possible issues helps improve system availability by employing predictive maintenance.

IRIG-B IRIG-B is a standard time code format that allows time stamping of events to be synchronized among connected devices within 1 milliseconds. An IRIG-B input is provided in the 339 to allow time synchronization using a GPS clock over a wide area. The 339 IRIG-B supports both AM and DC time synchronization with an auto detect feature that removes the requirement for manual selection.

• Total running hours

Motor Health Report

• Number of motor starts

The Multilin 339 relay provides motor diagnostic information in a legible easy to use format that enables the user to make informed decisions on the health of their motor.

• Total number of motor trips

Pre-Trip Alarms The 339 can trigger an alarm prior to a trip caused by the following conditions: • Thermal Overload • Ground Fault • Unbalance • Undercurrent

Event Recording

• RTD over temperature

Events consist of a broad range of change of state occurrences, including pickups, trips,

• Broken RTD sensor

Based on the graphical representation and trended values of the motor data gathered by the 339, this enables users to quickly identify process and motor issues prior to a process failure. The 339 Motor Health Report provides a summary page detailing information on related motor performance.

• Internal self-test

Sixteen logic elements available for simple logic for applications such as manual control, interlocking, and peer to peer tripping.

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Motor Protection

In addition, the 339 also supports IEC 61850 GOOSE communication, providing a means of sharing digital point state information between 339’s or other IEC 61850 compliant IED’s.

contact operations, alarms and self test status. The 339 stores up to 256 events time tagged to the nearest millisecond. This provides the information required to determine sequence of events which facilitates diagnosis of relay operation. Event types are individually maskable in order to avoid the generation of undesired events, and includes metered values and status of all the protection elements at the moment of the event.

339 Motor Protection System

and separate access levels support changing of setpoints or sending commands.

Advanced Communications The 339 utilizes the most advanced communication technologies today making it the easiest and most flexible motor protection relay to use and integrate into new and existing infrastructures. Multiple communication ports and protocols allow control and easy access to information from the 339. All communication ports are capable of communicating simultaneously. The 339 supports the most popular industry standard protocols enabling easy, direct integration into electrical SCADA and HMI systems. Modbus RTU is provided as standard with a RS485 networking port. The following optional protocols are available:

Motor Protection

• IEC 61850 The Motor Heath Report allows you to easily “see” how your motor is doing:

• IEC 61850 GOOSE

• Start/stop history

• DNP 3.0

• Comprehensive trip details

• Modbus RTU

• Learned acceleration time and starting current

• Modbus TCP/IP

• Many other motor health details

The following information is detailed in the 339 Motor Health Report: • Motor Acceleration Time • Starting Current • Thermal capacity used during starting • Average Motor Load • Average Phase currents • Current unbalance • Ground current

Metering Actual Values

• IEC 60870-5-104 • IEC 60870-5-103

Security Security Audit Trail In accordance with NERC CIP security reporting requirements and to provide complete traceability, the 339 maintains a history of the last 10 changes made to the 339 configuration, including modifications to settings and firmware upgrades. In addition, the Security Audit Trail records the last ten commands sent to the relay through communications or from the front panel. Security Setting Report includes the following information:

The 339 provides users with the following metering information in order to accurately monitor the operating conditions of the motor:

• If Password was required to change settings

• Current: Ia, Ib, Ic, In, Ig, Isg

• Method of setting changes - Keypad, Front serial port, Ethernet, etc.  

• Phase-to-phase and phase-to-ground voltages: Van, Vbn, Vcn, Vab, Vbc, Vca • Active power (3-phase) kW • Reactive power (3-phase) kVAR • Frequency • Current Unbalance • Motor load current as a % of full load • Motor thermal capacity used • Stator/Bearing/Ambient RTD temperature 396

• MAC address of user making setting changes • Listing of modified changes

Password Control With the implementation of the Password Security feature in the 339 relay, extra measures have been taken to ensure unauthorized changes are not made to the relay. When password security is enabled, changing of setpoints or issuing of commands will require passwords to be entered. Separate passwords are supported for remote and local operators,

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Easy to Use Simplified Motor Setting Included with every 339 Motor Protection System is the Multilin Simplified Motor Setup. The Simplified Motor Setup provides users with a quick and easy method to setup and start the motor and process in applications that require fast commissioning. The Simplified Motor Setup will generate a complete 339 setting file based on the motor nameplate and system information entered by the user. Once all the information is entered, the Simplified Motor Setup will generate the settings file, as well as provide the documentation indicating which settings were enabled, along with an explanation of the specific parameters entered. The Simplified Motor Setup will provide a detailed setting file in PDF format that can be saved or printed for future reference.

339 Motor Protection System

Enervista Software The Enervista suite is an industry leading set of software programs that simplifies every aspect of using the 339 relay. The Enervista suite provides all the tools to monitor the status of the protected asset, maintain the relay, and integrate the information measured into DCS or SCADA monitoring systems. Convenient COMTRADE and sequence of event viewers are an integral part of the 339 set up software and are included to ensure proper protection and system operation.

Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed. Documents made available include: • Manuals • Application Notes • Guideform Specifications • Brochures

Viewpoint Maintenance Viewpoint Maintenance provides tools that will increase the security of the 339 Motor Protection System. Viewpoint Maintenance will create reports on the operating status of the relay, and simplify the steps to troubleshoot protected motors. The tools available in Viewpoint Maintenance include:

• Wiring Diagrams

• Settings Security Audit Trail

• FAQs

• Device Health Report

Launchpad

• SService Bulletins

• Comprehensive Fault Diagnostics

Enervista Launchpad is a powerful software package that provides users with all of the set up and support tools needed for configuring and maintaining GE products. The setup software within Launchpad allows configuring devices in real time by communicating using serial, Ethernet or modem connections, or offline by creating setting files to be sent to devices at a later time.

Viewpoint Monitoring

EnerVista Integrator

Viewpoint Monitoring is a simple to use and full featured monitoring and data recording software package for small systems. Viewpoint monitoring provides a complete HMI package with the following functionality:

EnerVista Integrator is a toolkit that allows seamless integration of Multilin devices into new or existing automation systems.

• Plug and play device monitoring • Annunciator alarm screens • Trending reports

• OPC/DDE Server • Multilin Devices

Motor Protection

• System single line monitoring and control

Included in the EnerVista Integrator is:

• Automatic Event Retrieval • Automatic Waveform Retrievel

• Automatic event retrieval • Automatic waveform retrieval

Trace any setting changes with security audit trail

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397

339 Motor Protection System

Dimensions DRAW-OUT DESIGN

H

NON DRAW-OUT DESIGN

in

mm

in

mm

7.93

201.5

7.98

202.7

W

6.62

168.2

6.23

158.2

D

9.62

244.2

9.35

237.5

W1

3.96

100.6

3.96

100.6

D1

7.89

200.4

7.88

200.2

D2

1.73

43.8

1.47

37.3

H1

6.82

173.2

6.82

173.2

Front

Top

W1

H

D2 W

D1 D

Side

Motor Protection

Rear

H1

User Interface IN SERVICE: This indicator will be on continuously lit if the relay is functioning normally and no major self-test errors have been detected. TROUBLE: Trouble indicator LED will be AMBER if there is a problem with the relay or if relay is not programmed. LOCKOUT: Lockout initiates when a lockout trip is active. RUNNING: Indicates that the motor is running in normal operation STOPPED: Indicates that the motor is stopped STARTING: Indicates that the motor is in the starting process TRIP: Indicates that the relay has tripped the motor offline based on predefined programmed conditions. ALARM: Indicates that the motor is currently operating in an alarm condition and may proceed to a trip condition if not addressed. MAINTENANCE: Environmental alarms such as ambient temperature alarm, coil monitor or trip counter. The display messages are organized into Main Menus, Pages, and Sub-pages. There are four main menus labeled Actual Values, Quick Setup, Setpoints, and Maintenance. Pressing the MENU key followed by the MESSAGE key scrolls through the four Main Menu Headers. The ten button keypad allows users easy access to relay configuration and information. USER INTERFACE OPTIONS: Draw out and non draw out options available

398

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339 Motor Protection System

Wiring Diagram

A B

A B C

MOTOR

WYE VT CONNECTION

CONTROL POWER

+

E9 D9 E10D10E11D11

E5 D5 E6 D6 E7 D7 E8 D8 E12 D12

VA VA VB VB VC VC

1A/5A COM 1A/5A COM 1A/5A COM 1A/5A COM 50:0.025 COM

B1 A1

B2

chassis gnd POWER SUPPLY

+ -

PHASE A PHASE B PHASE C GROUND SENS GROUND

CURRENT INPUTS

VOLTAGE INPUTS

BREAKER CONTROL CIRCUIT STOP

Breaker Aux Contacts 52a

H L

C1

52a

C2 C3

52b

C4

INPUT 4

1 TRIP

INPUT 3

C5

INPUT 5 C6 INPUT 6

C7

INPUT 7

339 Motor Protection System

V

2 CLOSE

DC

TRIP COIL

START

52b

CLOSE COIL

A4

3 START INHIBIT

B5 A5 B6 A6 B7

4 AUXILIARY

A7

C11 COMMON C12 CHASSIS GND +

A3 B4

V

C8 INPUT 8 C9 INPUT 9 C10 INPUT 10

52a

B3

Motor Protection

52b

A2

DIGITAL INPUTS

C

B8 A8 5 AUXILIARY

Front Panel

B9 A9

USB

B10 A10

TYPE B

6 AUXILIARY

USB

B11 4 WIRE USB

Rear Panel COMMUNICATIONS

ETHERNET RJ45 MTRJ

RMIO

- +

10/100 BASE-T 100 BASE-FX

4 WIRE ETHERNET

OPTIONAL

RS485

A11

7 CRITICAL FAILURE

B12 A12

IRIG-B

SELF TEST ANNUNCIATOR

- + - +

F8 F7 F6 F5 F4 F3 F2 F1

CONTACTOR CONTROL CIRCUIT CONTROL POWER

A2

+

B3

1 NOT USED V

A3 B4

2 NOT USED

A4 V

3 START INHIBIT OPEN DELTA VT CONNECTION

B5 A5 B6 A6 B7

4 TRIP

STOP

START CONTACTOR COIL

A7 B8 A8

5 AUXILIARY

B9

6 AUXILIARY

B10 A10

CC

A9

B11

E9 D9 E10D10 E11 D11

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7 CRITICAL FAILURE

A11 B12 A12

SELF TEST ANNUNCIATOR

399

339 Motor Protection System

Technical Specifications PASSWORD SECURITY Master Reset 8 to 10 alpha-numeric characters Password: Settings Password: 3 to 10 alpha-numeric characters for local or remote access Control Password: 3 to 10 alpha-numeric characters for local or remote access Pickup delay 0 to 30000 min. in steps of 1

Motor Protection

NEUTRAL INSTANTANEOUS OVERCURRENT (50N) Pickup Level: 0.05 to 20 x CT in steps of 0.01 x CT Dropout Level: 96 to 99% of Pickup @ I > 1 x CT Pickup - 0.02 x CT @ I <1 x CT Time Delay: 0.00 to 300.00 sec in steps of 0.01 Operate Time: <30 ms @ 60Hz (I > 2.0 x PKP), 0 ms time delay <35 ms @ 50Hz (I > 2.0 x PKP), 0 ms time delay Timer Accuracy: 0 to 1 cycle Level Accuracy: per CT input Elements: Trip or Alarm NEUTRAL DIRECTIONAL OVERCURRENT (67N) Directionality: 0.005 to 3 x CT in steps of 0.001 x T Polarizing: Voltage, Current, Dual Voltage can be: - Calculated from VT phases (VTs must be connected in “Wye”) - Measured by Vaux input (3V0 provided by an external open delta connection) Polarizing Voltage: -V0 Polarizing Current: IG MTA: From 0° to 359° in steps of 1° Angle Accuracy: ±2° Operation Delay: 20 to 30 ms UNDERCURRENT Pickup Level: 0.1 to 0.95 x FLA in steps of 0.01 x FLA Dropout Level: 101 to 104% of Pickup Time Delay: 1.00 to 60.00 s in steps of 0.01 s Block from Start: 0 to 600 s in steps of 1 s Pickup Accuracy: as per phase current inputs Timing Accuracy: ±0.5 s or ± 0.5% of total time Level Accuracy: per CT input Elements: Trip or Alarm CURRENT UNBALANCE Unbalance Pickup 4 to 40% in steps of 1% Level: Unbalance Time 1.00 to 60.00 s in steps of 0.01 s Delay: Single Phasing Pickup unbalance level > 40% or when Iavg Level: ≥25%FLA and current in any phase is less than the cutoff current Single Phasing Time 2 sec Delay: Dropout Level: 96 to 99% of pickup Pickup Accuracy: ±2% Timing Accuracy: ±0.5 s or ± 0.5% of total time Unbalance Elements: Trip and Alarm Single Phasing Trip Elements: RTD Pickup: 1 to 250°C in steps of 1°C Pickup Hysteresis: 2°C Time Delay: 3 sec Elements: Trip and Alarm RTD TROUBLE ALARM RTD Trouble Alarm: <-50°C or >250°C LOAD INCREASE ALARM Pickup Level: 50 to 150%FLA in steps of 1%FLA Dropout Level: 96 to 99% of Pickup Alarm Time Delay: 1.00 to 60.00 s in steps of 0.01 s Pickup Accuracy: as per phase current inputs Timing Accuracy: ±0.5 s or ±0.5% of total time SHORT CIRCUIT Pickup Level: 1.00 to 20.00 x CT in steps of 0.01 x CT Dropout Level: 96 to 99% of Pickup @ I > 1 x CT Pickup - 0.02 x CT @ I < 1 x CT Alarm Time Delay: 0.00 to 60.00 s in steps of 0.01 s Pickup Accuracy: as per phase current inputs Operate Time: <30 ms @ 60Hz (I > 2.0 x PKP), 0 ms time delay <35 ms @ 50Hz (I > 2.0 x PKP), 0 ms time delay Timing Accuracy: 0 to 1 cycle Elements: Trip or Alarm MECHANICAL JAM TRIP Pickup Level: 1.01 to 4.50 x FLA in steps of 0.01 x FLA, blocked from start Dropout Level: 96 to 99% of Pickup Trip Time Delay: 0.10 to 30.00 s in steps of 0.01 s Pickup Accuracy: as per phase current inputs

400

Operate Time:

Timing Accuracy: GROUND FAULT Pickup Level: Dropout Level: Alarm Time Delay on Run: Alarm Time Delay on Start: Trip Time Delay on Run: Trip Time Delay on Start: Pickup Accuracy: Operate Time:

<30 ms @ 60Hz (I > 2.0 x PKP), 0 ms time delay <35 ms @ 50Hz (I > 2.0 x PKP), 0 ms time delay ±0.5 s or ±0.5% of total time

Timers for two-speed: Stopped to high speed, stopped to low speed, low to high speed Time Delay: 1.0 to 250.0 s in steps of 0.1 Timing Accuracy: ±200 ms or ±1% of total time

0.03 to 1.00 x CT in steps of 0.01 x CT 0.50 to 15.00 A in steps of 0.01 A (CBCT) Pickup - 0.02 x CT 96 to 99% of Pickup (CBCT) 0.00 to 60.00 s in steps of 0.01 s

MOTOR DATA LOGGER Length: 6 buffers, containing a total of 30 seconds of motor starting data Trigger: Motor start status Trigger Position: 1-second pre-trigger duration Logging Rate: 1 sample/200 ms

0.00 to 60.00 s in steps of 0.01 s 0.00 to 5.00 s in steps of 0.01 s 0.00 to 10.00 s in steps of 0.01 s

as per ground current inputs <30 ms @ 60Hz (I > 2.0 x PKP), 0 ms time delay <35 ms @ 50Hz (I > 2.0 x PKP), 0 ms time delay Timing Accuracy: 0 to 1 cycle Elements: Trip and Alarm PHASE/AUXILIARY UNDERVOLTAGE Pickup Level: 1 to 100% Hz MNR 1% Dropout Level: 101% to 104% of Pickup Time Delay: 1.0 to 60.0 s in steps of 0.1 Pickup Accuracy: as per power monitoring specification Timing Accuracy: ±0.5 s or ±0.5% of total time Elements: Trip and Alarm THERMAL PROTECTION (49) Locked Rotor Current: 2.0 to 11.0 x FLA in steps of 0.1 x FLA Safe Stall Time: 1.0 to 600.0 s in steps of 0.1 s Curve Multiplier: 1 to 15 in steps of 1 Pickup Level: 1.01 to 1.25 x FLA in steps of 0.01 x FLA Curve Biasing: Phase unbalance Hot/cold biasing Stator RTD biasing Exponential Running and Stopped Cooling Rates TCU Update Rate: 3 cycles Pickup Accuracy: per phase current inputs Timing Accuracy: ± 200 ms or ±2% of total time Elements: Trip and Alarm PHASE/AUXILIARY UNDERVOLTAGE (27P/27X) Minimum Voltage: Programmable from 0.00 to 1.25 x VT in steps of 0.01 Pickup Level: 0.00 to 1.25 x VT in steps of 0.01 Dropout Level: 101 to 104% of pickup Curve: Definite Time, Inverse Time Time Delay: 0.1 to 600.0 s in steps of 0.1 Operate Time: Time delay ±30 ms @ 60 Hz (V < 0.85 x PKP) Time delay ±40 ms @ 50 Hz (V < 0.85 x PKP) Time Delay Accuracy: ±3% of expected time, or 1 cycle, whichever is greater Level Accuracy: Per voltage input NEGATIVE SEQUENCE/PHASE OVERVOLTAGE (59P/59_2) Pickup Level: 0.00 to 1.25 x VT in steps of 0.01 Dropout Level: 96 to 99% of pickup Time Delay: 0.1 to 600.0 s in steps of 0.1 Operate Time: Time delay ±30 ms @ 60 Hz (V < 0.85 x PKP) Timing Accuracy: ±0.5 s or ±0.3% of total time Level Accuracy: Per voltage input PHASE REVERSAL (47) Configuration: ABC or ACB phase rotation Time Delay: 100 ms Timing Accuracy: ±0.5 s Elements: Trip or Alarm UNDERFREQUENCY (81U) Minimum Voltage: 0.00 to 1.25 x VT in steps of 0.01 Pickup Level: 40.00 to 70.00 Hz in steps of 0.01 Dropout Level: Pickup +0.03 Hz Time Delay: 0.1 to 600.0 s in steps of 0.1 Timing Accuracy: ±0.5 s or ±0.5% of total time Level Accuracy: ±0.01 Hz Elements Trip and Alarm OVERFREQUENCY (81O) Minimum Voltage: 0.3xVT Pickup Level: 40.00 to 70.00 Hz in steps of 0.01 Dropout Level: Pickup -0.03 Hz Time Delay: 0.1 to 600.0 s in steps of 0.1 Timing Accuracy: ±0.5 s or ±0.5% of total time Level Accuracy: ±0.01 Hz Elements Trip and Alarm ACCELERATION TIME TRIP Pickup Level: Motor start condition Dropout Level: Motor run, trip, or stop condition Timers for Stopped to running single-speed:

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FUSE FAIL Time Delay: Timing Accuracy: Elements DATA LOGGER Number of Channels: Parameters: Sampling Rate: Trigger Source:

1s ±0.5 s Trip or Alarm 10 Any available analog actual value 1 cycle, 1 second, 1 minute, 1 hour All logic elements, Logic operand: Any Trip PKP/OP/DPO, Any Alarm PKP/OP/ DPO Continuous or triggered

Mode: TRANSIENT RECORDER Buffer size: 3s No. of buffers: 1x192, 3x64, 6x32 No. of channels: 14 Sampling rate: 32 samples per cycle Triggers: Manual Command Contact Input Virtual Input Logic Element Element Pickup/Trip/Dropout/Alarm Data: AC input channels Contact input state Contact output state Virtual input state Logic element state Data storage: RAM - battery backed-up EVENT RECORDER Number of events: 256 Content: event number, date of event, cause of event, per-phase current, ground current , sensitive ground current , neutral current , per-phase voltage (VTs connected in “Wye”), or phasephase voltages (VTs connected in “Delta”), system frequency, power, power factor, thermal capacity, motor load, current unbalance Data Storage: Non-volatile memory LEARNED DATA RECORDER Number of events: 250 Header: Date, number of records Content: learned acceleration time , learned starting current , learned starting capacity, last starting current , last starting capacity, last acceleration time , average motor load learned, average run time after start (days), average run time after start (minutes) Data Storage: Non-volatile memory CLOCK Setup: Date and time Daylight Saving Time RTC Accuracy: ± 1 min / month at 25°C IRIG-B: Auto-detect (DC shift or Amplitude Modulated) Amplitude modulated: 1 to 10 V pk-pk DC shift: 1 to 10 V DC Input impedance: 40 kOhm ± 10% LOGIC ELEMENTS Number of logic 16 elements: Trigger source inputs 3 per element: Block inputs per 3 element: Supported AND, OR, NOT, Pickup / Dropout timers operations: Pickup timer: 0 to 6000 ms in steps of 1 ms Dropout timer: 0 to 6000 ms in steps of 1 ms BREAKER CONTROL Operation: Asserted Contact Input , Logic Element, Virtual Input, Manual Command, Remote Input Function: Opens/closes the motor breaker START INHIBIT Thermal Start Inhibit: Thermal Inhibit Margin: 0 to 25 % in steps of 1% Starts per Hour Maximum: 1 to 5 starts in steps of 1 Inhibit: Time Between Starts Time Between Starts: 1 to 3600 s in Inhibit: steps of 1 s Restart Inhibit: Restart Inhibit Delay: 1 to 50000 s in steps of 1 s

339 Motor Protection System

Technical Specifications

CONTACT INPUTS Inputs: Selectable thresholds: Recognition time: Debounce time: Continuous current draw: Type: External switch: Maximum input voltage: CBCT INPUT (50:0.025) Range: Nominal frequency: Accuracy (CBCT):

10 17, 33, 84, 166 VDC 1/2 cycle 1 to 64 ms, selectable, in steps of 1 ms 2 mA opto-isolated inputs wet contact 300 VDC

PHASE VOLTAGE INPUTS Source VT: 100 to 20000 V VT secondary range: 50 to 240 V VT ratio: 1 to 300 in steps of 1 Nominal frequency: 50/60 Hz Accuracy: ±1.0% throughout range Voltage withstand: 260 VAC continuous PHASE & GROUND CURRENT INPUTS CT Primary: 30 to 1500 A Range: 0.05 to 20 × CT Input type: 1 A or 5 A (must be specified with order) Nominal frequency: 50/60 Hz Burden: <0.1 VA at rated load Accuracy: ±1% of reading at 1× CT ±3% of reading from 0.2 to 20 × CT ±20% of reading from 0.02 to 0.19 × CT CT withstand: 1 second at 100 × rated current 2 seconds at 40 × rated current continuous at 3 × rated current FREQUENCY Accuracy: ±0.05 Hz Resolution: 0.01 Hz Range: 40.00 to 70.00 Hz RTD INPUTS RTD Type: RTD Sensing Current: Isolation: Distance: Range: Accuracy: Lead Resistance:

100 Ohm platinum (DIN.43760) 5 mA 2 kV from base unit 250 m maximum -50 to +250°C ±2°C 25 Ohm max per lead

FORM-A VOLTAGE MONITOR Applicable voltage: 20 to 250 VDC Trickle current: 1 to 2.5 mA FORM-A RELAYS Configuration: Contact material: Operate time: Continuous current: Make and carry for 0.2s: Break (DC inductive, L/R=40 ms): Break (DC resistive): Break (AC inductive): Break (AC resistive):

2 (two) electromechanical silver-alloy <8 ms 10 A 30 A per ANSI C37.90 24 V / 1 A 48 V / 0.5 A 125 V / 0.3 A 250 V / 0.2 A 24 V / 10 A 48 V / 6 A 125 V / 0.5 A 250 V / 0.3 A 720 VA @ 250 VAC Pilot duty A300 277 VAC / 10 A

TRIP / CLOSE SEAL-IN Relay 1 trip seal-in: 0.00 to 9.99 s in steps of 0.01 Relay 2 close seal-in: 0.00 to 9.99 s in steps of 0.01 HIGH RANGE POWER SUPPLY Nominal: 120 to 240 VAC 125 to 250 VDC Range: 60 to 300 VAC (50 and 60 Hz) 84 to 250 VDC Ride-through time: 35 ms

0.5 to 15.0 A 50 or 60 Hz ±0.1 A (0.5 to 3.99 A) ±0.2 A (4.0 A to 15 A)

LOW RANGE POWER SUPPLY Nominal: 24 to 48 VDC

METERING SPECIFICATIONS Parameter 3-Phase Real Power (kW)

Accuracy ±1% of full scale

Resolution 0.1 kW

Range ±100000.0 kW

3-Phase Reactive Power (kvar) 3-Phase Apparent Power (kVA) 3-Phase Positive Watthour (MWh) 3-Phase Negative Watthour (MWh) 3-Phase Positive Varhour (Mvarh) 3-Phase Negative Varhour (Mvarh) Power Factor Frequency

±1% of full scale ±1% of full scale ±1% of full scale ±1% of full scale ±1% of full scale ±1% of full scale ±0.05 ±0.05 Hz

0.1 kvar 0.1 kVA ±0.001 MWh ±0.001 MWh ±0.001 Mvarh ±0.001 Mvarh 0.01 0.01 Hz

±100000.0 kvar 100000.0 kVA 50000.0 MWh 50000.0 MWh 50000.0 Mvarh 50000.0 Mvarh -0.99 to 1.00 40.00 to 70.00 Hz

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Range: FORM-C RELAYS Configuration: Contact material: Operate time: Continuous current: Make and carry for 0.2s: Break (DC inductive, L/R=40 ms): Break (DC resistive): Break (AC inductive): Break (AC resistive): ALL RANGES Voltage withstand: Power consumption: SERIAL RS485 port: Baud rates: Response time: Parity: Maximum Distance: Isolation: Protocol: ETHERNET (COPPER) Modes: Connector: Protocol: ETHERNET (FIBER) Fiber type: Wavelength: Connector: Transmit power: Receiver sensitivity: Power budget: Maximum input power: Typical distance: Duplex: Protocol: USB Standard specification: Data transfer rate: DIMENSIONS Size: Weight:

20 to 60 VDC 5 (five) electromechanical silver-alloy <8 ms 10 A 30 A per ANSI C37.90 24 V / 1 A 48 V / 0.5 A 125 V / 0.3 A 250 V / 0.2 A 24 V / 10 A 48 V / 6 A 125 V / 0.5 A 250 V / 0.3 A 720 VA @ 250 VAC Pilot duty A300 277 VAC / 10 A

2 × highest nominal voltage for 10 ms 15 W nominal, 20 W maximum 20 VA nominal, 28 VA maximum Opto-coupled up to 115 kbps 1 ms typical None, Odd, Even 1200 m (4000 feet) 2 kV Modbus RTU, DNP 3.0, IEC 60870-5-103 10/100 MB (auto-detect) RJ-45 Modbus TCP/IP, DNP 3.0, IEC 60870-5-104, IEC 61850 GOOSE 100 MB Multi-mode 1300 nm MTRJ -20 dBm -31 dBm 9 dB -11.8 dBm 2 km (1.25 miles) half/full Modbus TCP/IP, DNP 3.0, IEC 60870-5-104, IEC 61850 GOOSE

Compliant with USB 2.0 115 kbps Refer to Dimensions Chapter 4.1 kg [9.0 lb]

CERTIFICATION CE: ISO:

Low voltage directive EN60255-5 / EN60255-27 / EN61010-1 EMC Directive EN60255-26/EN50263, EN61000-6-2, UL508 Manufactured under a registered quality program ISO9001

401

Motor Protection

BREAKER FAILURE/WELDED CONTACTOR Current Supervision: Phase Current Current Supervision 0.05 to 20.00 x CT in steps of 0.01 x CT Pickup: Time Delay 1: 0.03 to 1.00 s in steps of 0.01 s Time Delay 2: 0.00 to 1.00 s in steps of 0.01 s Current Supervision 1 to 64 ms, selectable, in steps of 1 ms Dropout: Current Supervision Accuracy: 97 to 98% of pickup Timing Accuracy: 0 to 1 cycle (Timer 1, Timer 2) BREAKER TRIP COUNTER Trip Counter Limit 1 to 10000 in steps of 1 (Pickup): EMERGENCY RESTART Function: Defeats all motor start inhibit features, resets all trips and alarms, and discharges the thermal capacity to zero so that a hot motor can be restarted in the event of an emergency Operation: Contact Input 1 to 10, Virtual Input 1 to 32, Logic Element 1 to 16, Remote Input 1 to 32 LOCKOUT RESET Function: Reset any lockout trips when this feature is configured Operation: Contact Input 1 to 10, Virtual Input 1 to 32, Logic Element 1 to 16, Remote Input 1 to 32 RESET Function: Resets any alarms and non-lockout trips when LOCKOUT RESET is configured, or resets any alarms and trips (lockout and non-lockout trips) when LOCKOUT RESET is not configured. Operation: Contact Input 1 to 10, Virtual Input 1 to 32, Logic Element 1 to 16, Remote Input 1 to 32 AMBIENT TEMPERATURE High Temperature 20°C to 80°C in steps of 1°C Pickup: Low Temperature -40°C to 20°C in steps of 1°C Pickup: Time Delay: 1 to 60 min in steps of 1 mins Temperature Configurable 90 to 98% of pickup Dropout: Temperature ±10°C Accuracy: Timing Accuracy: ±1 second

Technical Specifications TYPE TESTS Dielectric voltage withstand: Impulse voltage withstand: Damped Oscillatory: Electrostatic Discharge: RF immunity: Fast Transient Disturbance: Surge Immunity: Conducted RF Immunity: Power Frequency Magnetic Field Immunity:

Radiated & CISPR11 / Conducted Emissions: CISPR22/ IEC 60255-25 Sinusoidal Vibration: IEC 60255-21-1 Shock & Bump: IEC 60255-21-2 Voltage Dip & IEC 61000-4-11 interruption:

2.3KV EN60255-5

5KV

IEC 61000-4-18/ IEC 60255-22-1 EN61000-4-2/ IEC 60255-22-2 EN61000-4-3/ IEC 60255-22-3 IEEE C37.90.1

2.5KV CM, 1KV DM

EN61000-4-5/ IEC 60255-22-5 EN61000-4-6/ IEC 60255-22-6 IEC 61000-4-8

Level 3 & 4

Level 4 Level 3

Ingress Protection:

IEC 60529

4KV CM & DM

Environmental (Cold): Environmental (Dry heat): Relative Humidity Cyclic: Fast Transient Disturbance: SWC Damped Oscillatrory: Electrostatic Discharge:

IEC 60068-2-1 IEC 60068-2-2

Level 3 Level 4

Class A Class 1 Class 1 0, 40, 70, 80% dips, 250/ 300 cycle interrupts IP40 front , IP10 Back -40C 16 hrs 85C 16hrs

IEC 60068-2-30

6day variant 2

IEEE® C37.90.1

4KV CM & DM

IEEE C37.90.1

2.5KV CM & DM

IEEE C37.90.3

8KV CD, 15KV AD

OPERATING ENVIRONMENT Ambient operating –40°C to +60°C [-40°F to +140°F] temperature: Ambient storage / –40°C to +85°C [-40°F to +185°F] shipping temperature: Humidity: Operating up to 95% (non condensing) @ 55C (As per IEC 60068-2-30 Variant 2, 6days) Pollution degree: II Overvoltage III category: Ingress Protection: IP40 Front , IP10 back

Ordering Base Unit Language Phase Currents* 339 Ground Currents* Power Supply Input/Output 339 Current Protection 339 Other Options Communications

339 339

E

**

**

**

*

S

N

*

**

*

*

E P1 P5 G1 G5 L H E S N M P SN 1E 2E 3E

Case Design Harsh Environment

D N N H

Description Base Unit English 1A three phase current inputs 5A three phase current inputs 1A ground current input 5A ground current input 24 - 48 Vdc 110 - 250 V dc/110 - 230 Vac 10 Inputs, 7 Outputs (2 Form A, 5 Form C) Standard Configuration – 14, 37, 46, 48, 49, 50P(1), 50G(1), 50M, 50L, 66, 86, 50BF(1), 50N(1), 51G(1) No Selection Voltage Metering Voltage Protection - 27P(2), 47(1), VTFF(1), 59P(2), 81O(2), 81U(2) , 59_2(1) Standard :Front USB, Rear RS485 : Modbus RTU, DNP3.0, IEC 60870-5-103 Standard + Ethernet (Copper & Fiber - MTRJ) MODBUS TCP/IP, DNP3.0, IEC 60870-5-104 Standard + Ethernet (Copper & Fiber - MTRJ) MODBUS TCP/IP, DNP3.0, IEC 60870-5-104, IEC 61850 GOOSE Standard + Ethernet (Copper & Fiber - MTRJ) MODBUS TCP/IP, DNP3.0, IEC 60870-5-104, IEC 61850 Draw-out Non Draw-out design None Harsh Environment Conformal Coating

Ordering Notes: G1/G5 and S1/S5 must match corresponding P1/P5 - there cannot be 5A and 1A mixing

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Multilin™ MM300 Integrated Automation and Protection for Low Voltage Motors The MM300 integrates protection, control, automation, metering, diagnostics and multiple communication protocols in a rugged compact device for low voltage motor applications. Designed for NEMA and IEC Motor Control Centers, the MM300 delivers superior protection and control to extend equipment life and maximize process uptime.

Key Benefits

Protection and Control • Enhanced Thermal Modeling • Mechanical Jam & Stalled Rotor • Undercurrent & Underpower • Acceleration Time & Current Unbalance • Ground & Sensitive Ground Fault • Phase Overvoltage / Undervoltage • Thermistor & RTD Overtemperature

• Full-featured protection for low voltage AC motors • Advanced automation capabilities for providing customized protection and integrated process control • Advanced FlexLogic™ reduces requirement for local controllers • Reduced space requirements through integration of multiple devices • Application flexibility with multiple I/O options and programmable logic options (FlexLogic™) • Enhanced troubleshooting tools including sequence of event records and waveform capture • Powerful communications including Serial, Ethernet, Profibus, and DeviceNet protocols • Small form factor and remote display options designed to fit in MCC buckets of various types • Universal device for all motor power ratings • No CTs required for less than 5A motor ratings • Thermistor input to monitor the ambient or motor temperature • Support for Hand Held Display (HHD) that provides a graphical color local interface allowing local operators to view and change setting files and quickly access relay diagnostic information

Applications • Low Voltage three phase AC motors • MCC or stand alone panel mount applications • Process control and applications requiring Automation or Control i.e. conveyor systems or well recovery pumps • IEC or NEMA class motors and Motor Control Centers (MCCs) • System architecture requiring multiple simultaneous communications • Applications require full-voltage reversing or non-reversing, two-speed, wye-delta open transition, inverter, soft starter or autotransformer motor starting

Automation • Programmable FlexlogicTM option • Starter Control & Process Interlocks • Programmable inputs and outputs • Undervoltage Auto-restart

Metering & Monitoring • Metering - current, voltage, power, energy, frequency, RTD & Thermistor • Oscillography (analog values at 32 samples/ cycle and digital states) & Event Recorder (256 events) • Advanced device health diagnostics

Communications • Two Wire RS485, RJ45 Ethernet • Programming Ports - USB, RS485 • Multiple Protocols (Modbus RTU or TCP/IP, Internally powered Profibus, ODVA compliant DeviceNet) & NPT

EnerVista™ Softwares • Simplify setup and configuration • Strong document archive/management system • Strong maintenance and troubleshooting tool

MM300 Motor Management System

Protection and Control

biased to reflect the additional rotor heating. A programmable K factor setting allows the amount of derating to be adjusted.

10, 000

The MM300 is a digital motor protection and control system, designed for Low Voltage motor applications. Flexible and powerful, the MM300’s protection can be scaled to the specific requirements of your system.

Hot / Cold Safe Stall Ratio This ratio defines the steady state level of thermal capacity used (TCU) by the motor. This level corresponds to normal operating temperature of a fully loaded motor and will be adjusted proportionally if the motor load is lower then rated.

1, 000

Motor Thermal Model TRIP TIME (seconds)

To provide optimal protection and maximize run time, the MM300 employs an advanced thermal model, consisting of six key elements: • Overload Curves • Unbalance Biasing • Hot/Cold Safe Stall Ratio

100

• Motor Cooling Time Constants

Motor Cool Time Constants

CU RV E 15 12 9 7

10

• RTD Biasing (Optional)

4

Overload Curves

2

3

1

The MM300 thermal model can be programmed with one of 15 standard overload curves.

10

Phase Current

Full Load Setpoint

When properly selected to match the motor manufactures thermal damage curves, the MM300 overload curve and Overload Pickup Level will determine the thermal capacity accumulated within the motor.

(Multiples of full load)

15 Standard Curves available in the MM300 in the thermal limit curves provided by the manufacturer. The MM300 measures current unbalance as a ratio of negative to positive sequence current. The thermal model is then

Unbalance (Negative Sequence) Biasing Negative sequence current , which causes additional rotor heating, is not accounted for

Functional Block Diagram

®

DEVICE NUMBER 27AUX 27 37 38 46 47 49 ANSI Device Numbers and Functions 50G Device Function Number 51G 27Aux Undervoltage - Auxiliary Input 27 Undervoltage - Three Phase 51R 37 Undercurrent/Underpower 59 38 Bearing Temperature RTD 66 46 Current Unbalance

BUS

Control PT Control fuse

27X Direct voltage inputs (690 V AC maximum)

Optional three-phase voltage card

Six inputs and two outputs (standard)

27

59

47

METERING V, A, W, var, VA, PF, Hz

Contactor

51R

49

37

66

46

Phase CT 3

47 Expansion module, two cards per module, 49 maximum of two modules

50G 51G

RTD

Stator RTDs Bearing RTDs

49

Temperature

38

LOAD

Thermistor

MOTOR

RS485 - Modbus RTU Ethernet - Modbus TCP/IP Profibus/DeviceNet

404

MM300

MOTOR MANAGEMENT SYSTEM

Options: Four form-C contact outputs (max 4 cards) Three RTDs - 100 ohm Platinum (max 2 cards)

Ground CT 1

Options: Three-phase voltage card (max 1 card) Six inputs & two form-A outputs (max 5 cards)

Ambient air

The Thermal Model relies solely on measured current to determine motor heating, assuming an ambient temperature of 40°C and normal motor cooling. The actual motor temperature will increase due to abnormally high ambient temperatures or if the motor cooling systems have failed. RTD Biasing enhances the motor thermal model by calculating the thermal capacity used based on available Stator RTD temperatures.

ANSI Device Numbers & Functions 52

Power Fuse

RTD Biasing

1 1

0.1

Optional RTD card

Motor Protection

• Start Inhibit and Emergency Restart

When the MM300 detects that the motor is running at a load lower then the overload pickup setpoint or the motor is stopped, it will start reducing the TCU value exponentially, based on the programmed cool time constants. As cooling occurs at different rates for stopped and running motors, two separate constants are used.

50G 51G 51R 59 66

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Voltage Phase Reversal Thermal Overload Ground Instantaneous Overcurrent Ground Time Overcurrent Locked/Stalled Rotor/Mechanical Jam Overvoltage - Three Phase Starts/Hour & Time Between Starts

By: René Midence Date: February 6, 2007 Title: MM300 Single Line Diagram For Brochure

FUNCTION Undervoltage - Auxiliary Input Undervoltage - Three Phase Undercurrent/Underpower Bearing Temperature RTD Current Unbalance Voltage Phase Reversal Thermal Overload Ground Instantaneous Overcurrent Ground Time Overcurrent Locked/Stalled Rotor/Mechanical Jam Overvoltage - Three Phase Starts/Hour & Time Between Starts

MM300 Motor Management System

RTD Thermal Capacity Used (%)

Voltage Protection

RTD Bias Maximum

100 90

The MM300 comes standard with a single phase voltage input , providing single phase underpower, auxiliary undervoltage and optional undervoltage auto-restart functionality.

80 70 60 50

Optional 3 phase voltage inputs offer the additional following protection elements:

40 30

• Undervoltage

20 10

RTD Bias Center Point

RTD Bias Minimum

0 -50

0

50

100

150

200

• Overvoltage 250

Maximum Stator RTD Temperature (C)

RTD Biasing curve

• Phase Reversal • Three Phase Underpower • VT Fuse Failure

Current Unbalance

To protect against faulty stator RTD’s, a TCU of 100% based on RTD Biasing will not cause a trip to be issued unless the motor current has exceeded the Overload Pickup Level.

In addition to Thermal model biasing, current unbalance is available in the MM300 relay as independent element with a built-in single phasing detection algorithm.

Thermistor A single input from a motor winding thermistor is provided with the MM300. The MM300 can accept both positive temperature coefficient (PTC) and negative temperature coefficient (NTC) sensors. A thermistor level can be selected for both alarm and trip.

Advanced Automation

Motor Start Supervision consists of the following features: Time-Between-Starts, Start-per-Hour, Restart Time.

The MM300’s powerful I/O and programmable flexlogic options offer advanced automation control, reducing the need for additional programmable controllers or discrete control relays.

Mechanical Jam and Acceleration Time These two elements are used to prevent motor damage during abnormal operating conditions such as driven load jams and excessively long acceleration times

Ground Fault This function is designed to protect motors against phase to ground faults. The MM300 comes with two separate ground CT inputs intended for one of two different ground protection: • Core balance (Zero sequence) . • Residual

Monitoring and Metering The MM300 includes high accuracy metering for all AC signals. Voltage, current, power metering, and temperature all available options. Current and voltage parameters are available as total RMS magnitude and angle.

Fault and Disturbance Recording The advanced disturbance diagnostic features within the MM300 can significantly reduce the time needed for troubleshooting power system events and reconstruction. Recording functions include: • Sequence of Event Recorder (SOE) - 256 time stamped events • Optional enhanced diagnostics with: • Waveform capture with up to 10 Analog Channels • Data Logger with 10 channel RMS recorder

Advanced Device Health Diagnostics

Motor Start Supervision

These elements guard the motor against excessive starting duty, which is normally defined by motor manufacturer in addition to the thermal damage curves.

• Types of digital outputs include trip-rated Form-A and Form-C

FlexLogic™ The MM300 optionally includes a control logic engine called FlexLogic™. This provides the ability of creating customized protection and control schemes thereby minimizing the need and the associated costs, of auxiliary components and wiring. Using FlexLogic™, the MM300 can be configured to specify what actions will be taken based on the status of protection or control elements, as well as inputs driven by connected sensors and equipment.

Scalable Hardware The MM300 is available with a multitude of I/O configurations to suit most application needs. The expandable modular design allows for easy configuration and future upgrades.

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The MM300 performs comprehensive device health diagnostic tests during startup and continuously at runtime to test its own major functions and critical hardware. These diagnostic tests monitor for conditions that could impact the MM300’s performance, evaluate the criticality of this impact and present device status via SCADA communications and front panel display. Providing continuous monitoring and early detection of possible issues helps improve system availability by employing predictive maintenance

Communications The MM300 utilizes the most advanced communications technologies available today making it the easiest and most flexible motor protection relay to use and integrate into new and existing infrastructures. Multiple communication ports and protocols allow control and easy access to information from the MM300. All communication ports are capable of communication simultaneously.

405

Motor Protection

RTD Biasing does not replace the TCU calculated using the motor current. It provides a second and independent measure of thermal capacity used. Based on a programmable curve, the MM300 will calculate the TCU at any given temperature. This TCU is then compared to that of the thermal model, and the larger of the two will be used.

• Up to 30 digital inputs (voltage rating up to 300V) and up to 18 digital outputs are available and can be used to monitor and control a wide range of auxiliary equipment

MM300 Motor Management System

Motor Protection

FlexLogic™ Designer

Flexlogic and additional I/O options allow the MM300 to replace local programmable controllers in LV applications, like conveyor belts as in this example TM

MM300 Dual Architecture Communication

The MM300 supports the most popular industry standard protocols enabling easy, direct integration into HMI and electrical SCADA systems. Modbus RTU is provided standard with a RS485 networking port. The following optional protocols and communication ports are available • Fieldbus Protocol with dedicated port - ODVA Compliant DeviceNet - Internally powered Profibus • Modbus TCP/IP with RJ45 10/100baseT Ethernet port

Profibus DP Providing a high degree of communication flexibility, the MM300 supports both Profibus DP-V0 and DP-V1. Profibus DP-V0 provides highspeed cyclic data exchange between distributed field devices and the Profibus master. In addition to the high-speed cyclic data communication with DP-V0, DP-V1 provides communication of acyclic data information between the slaves and the engineering workstation, which allows for independent diagnosing and fine-tuning of each slave on the network.

Rapid Device Replacement The MM300 supports Rapid Device Replacement, which is compatible with DeviceNet scanners that use Automatic Device Replacement (ADR)

406

functionality. When Rapid Device Replacement is used in DeviceNet networks, this allows rapid change of MM300 devices with minimum process interruption. When using Rapid Device Replacement , the MM300 can be replaced without the need to manually configure settings. The DeviceNet scanner will automatically recognize a new device and download the key protection, control and communication settings from the original MM300, reducing process downtime and manual setting file configuration.

EnerVista™ Software The EnerVista™ Suite is an industry-leading set of software programs that simplifies every aspect of using the MM300 relay. The EnerVistaTM suite provides all the tools to monitor the status of the protected asset , maintain the relay, and integrate information measured by the MM300 into DCS or SCADA monitoring systems. Convenient COMTRADE and Sequence of Events viewers are an integral part of the MM300 Setup software included with every MM300 to carry out postmortem event analysis to ensure proper protection system operation.

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EnerVista™ Launchpad EnerVista™ Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining Multilin products. The setup software within Launchpad allows configuring devices in real-time by communicating using serial, Ethernet , or modem connections, or offline by creating setting files to be sent to devices at a later time.

Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed. Documents made available include: • Manuals • Application Notes • Guideform Specifications • Brochures • Wiring Diagrams • FAQs • Service Bulletins

MM300 Motor Management System

Viewpoint Monitoring

Viewpoint Maintenance

User Interface

Viewpoint Monitoring is a simple-to-use and full-featured monitoring and data recording software package for small systems. Viewpoint Monitoring provides a complete HMI package with the following functionality:

Viewpoint Maintenance provides tools that will create reports on the operating status of the relay, simplify the steps to download fault and event data, and reduce the work required for cyber-security compliance audits. Tools available in Viewpoint Maintenance include:

The MM300 can be ordered with or without a control panel or display. If local control or monitoring is required, there are two available options:

• Plug & Play Device Monitoring • System Single-Line Monitoring & Control

• Settings Security Audit Report

• Annunciator Alarm Screens

• Device Health Report

• Trending Reports

• Single Click Fault Data Retrieval

• Automatic Event Retrieval

EnerVista™ Integrator

• Automatic Waveform Retrieval

EnerVista™ Integrator is a toolkit that allows seamless integration of Multilin devices into new or existing automation systems. Included in EnerVistaTM Integrator is:

Viewpoint Engineer Viewpoint Engineer is a set of powerful tools that will allow the configuration and testing of MM300 relays at a system level in an easyto-use graphical drag-and-drop environment. Viewpoint Engineer provides the following configuration and commissioning utilities:

1. Control Panel 2. Color HMI Display

• OPC/DDE Server • Multilin Drivers • Automatic Event Retrieval • Automatic Waveform Retrieval Motor Protection

• Graphical Logic Designer • Graphical Logic Monitor

Power System Troubleshooting The MM300 contains many tools and reports that simplify and reduce the amount of time required for troubleshooting power system events.

Configure the MM300 using the intuitive EnerVista™ MM300 setup program Analyze motor faults using both analog and digital power system quantities that are measured and recorded up to a rate of 32 samples per cycle.

Log motor operating parameters to allow for analyzing motor loading and performance over prolonged periods of time.

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407

MM300 Motor Management System

Technical Specifications PROTECTION ACCELERATION TIMER Pickup Iav > Icutoff

Motor Protection

Dropout

Iav < Ipu or timer expired

Time delay 0.5 to 250.0 seconds in steps of 0.1 Timing accuracy ±500 ms or 1.5% of total time AUXILIARY UNDERVOLTAGE Pickup level 60 to 90% of NCV Time delay 1 to 60 seconds in steps of 1 Timing accuracy ± 500 ms CURRENT UNBALANCE Range 4 to 40% in steps of 1 Accuracy ±2% Time delay 1 to 60 seconds in steps of 1 s Timing accuracy ±500 ms FUSE FAILURE (RUNNING STATE ONLY) Timing <500 ms GROUND FAULT (CBCT OR RESIDUAL) Pickup level 0.5 to 15.0 A in steps of 0.1 (CBCT); 10 to 100% of FLA in steps of 1% (residual) Trip time delay on 0 to 10 s in steps of 0.1 s start Trip time delay 0 to 5 s in steps of 0.1 s on run Alarm time delay 0 to 60 s in steps of 1 s on start/run Timing accuracy ±50 ms or ±0.5% of total time LOAD INCREASE Pickup level 50 to 150% of FLA in steps of 1% Timing accuracy ±500 ms MECHANICAL JAM Pickup level 1.01 to 4.50 × FLA in steps of 0.01 Time delay 0.1 to 30.0 seconds in steps of 0.1 Timing accuracy ±500 ms PHASE UNDERVOLTAGE Pickup level 101 to 120% of rated in steps of 1% Time delay 1 to 60 seconds in steps of 1 s Timing accuracy ±500 ms PHASE OVERVOLTAGE Pickup level 60 to 99% of rated in steps of 1 Time delay 1 to 60 seconds in steps of 1 s Timing accuracy ±500 ms RTD PROTECTION RTD types three-wire (100 ohm Platinum) Range –50 to 250°C in steps of 1 Hysteresis 2°C THERMAL MODEL Standard curve 1 to 15 in steps of 1 time multiplier Thermal overload 1.01 to 1.25 in steps of 0.01 pickup Motor full load 0.5 to 1000 A in steps of 0.1 current (FLA) Motor rated 100 to 690 V AC voltage Elements trip and alarm THERMISTOR Sensor types PTC (RHOT = 100 to 30 kohms); NTC (RHOT = 100 to 30 kohms) UNDERCURRENT Pickup level 1 to 100% of FLA in steps of 1 Time delay 1 to 60 seconds in steps of 1 UNDERPOWER Pickup level 1 to 100% of kW in steps of 1 Time delay 1 to 60 seconds in steps of 1 VOLTAGE PHASE REVERSAL Configuration ABC or Rev starter METERING AND MONITORING EVENT RECORDER Capacity 256 events Time tag 1 ms Data storage non-volatile memory FREQUENCY METERING Range 40.00 to 70.00 Hz in steps of 0.01 POWER METERING Real power range –2000.0 to 2000.0 kW in steps of 0.1 Apparent power 0.0 to 2500.0 kVA in steps of 0.1 range POWER FACTOR METERING Range –0.99 to +0.99 in steps of 0.01 CONTROL UNDERVOLTAGE RESTART Dropout/Pickup 60 to 100% NCV in steps of 1% Level Short Dip Time 100 to 500 ms or OFF in steps of 10 ms Medium Dip Time 0.1 to 10.0 s in steps of 0.1 s Medium Dip Delay 0.2 to 60 s in steps of 0.2 s Long Dip Time 0.5 to 60.0 min or OFF in steps of 0.5 min Long Dip Delay 1.0 to 1200.0 s in steps of 1.0 s Time Accuracy ±1 s or ±5% of total time

Please refer to the Multilin MM300 Motor Management System Instruction Manual for complete technical specifications

408

USER INTERFACE GRAPHICAL CONTROL PANEL Size height 102mm, width 153mm, depth 35mm

POWER SUPPLY POWER SUPPLY Nominal

LCD LED Indicators Pushbuttons

Range

3.5-inch colour, 320 by 240 pixels 10 LEDs Start A, Start B, Stop, plus 11 LCD screen display control keys USB 2.0 port for laptop computer connection

Ports

INPUTS CONTROL VOLTAGE INPUT (UNDERVOLTAGE RESTART SOURCE) External VT 110 to 690 V AC in steps of 10 primary (if used) Input range 60 to 300 V AC Nominal frequency 50 or 60 Hz Accuracy ±5% of reading DIGITAL INPUTS Fixed pickup 65 V AC Recognition time 2 cycles Current draw at 60 mA @ 120 V; 75 mA @ 240 V rated voltage Momentarily sampled every cycle Input impedence 1.7 kΩ Type opto-isolated inputs External switch wet contact Maximum input 300 V AC voltage GROUND CURRENT INPUT (50:0.025) CT primary 0.5 to 15.0 A Nominal frequency 50 or 60 Hz Accuracy (CBCT) ±0.1 A (0.5 to 3.99 A) ±0.2 A (4.0 A to 15 A) PHASE CURRENT INPUTS (INCLUDING RESIDUAL GROUND CURRENT) Range 0.2 to 40 A (8 × CT), direct connection up to 5 A FLA Input type combined 1 A / 5 A Frequency 50 or 60 Hz Accuracy ExtCT: ±2% of reading or ±1% of 8× CTPrimary, whichever is greater Direct: ±2% of reading or ±0.1 A, whichever is greater Withstand (at 5A nominal) 0.2 s at 100× 1.0 s at 50× 2.0 s at 40× continuous at 3× rated current INPUTS (CON’T) PHASE VOLTAGE INPUTS (THREE-PHASE VOLTAGE) Input range 208 to 690 V Nominal frequency 50 or 60 Hz Accuracy ±2% of reading, or ±1 V, whichever is greater RTD INPUTS Sensor type Three-wire RTD (100 ohm Platinum) Sensing current 5 mA Accuracy ±3°C THERMISTOR INPUTS Sensor type Positive temperature coefficient PTC (RHOT = 100 to 30000 ohms), negative temperature coefficient NTC (RHOT = 100 to 30000 ohms) Accuracy

±6% of reading or ±100 ohms, whichever is greater

OUTPUTS OUTPUT RELAYS Configuration Contact material Operate time Minimum contact load Maximum switching rate Mechanical life Continuous current Make and carry for 0.2s

electromechanical form-A (IO_C) and form-C (IO_D) silver-alloy 10 ms 10 mA at 5 V DC 300 operations per minute (no load), 30 operations per minute (load) 10 000 000 operations 10 A 30 A per ANSI C37.90

OUTPUT RELAY BREAK CAPACITY (FORM-A RELAY) AC resistive, 120 10 A V AC AC resistive, 240 10 A V AC AC inductive, PF = 2 A 0.4 pilot duty DC resistive, 30 10 A V DC OUTPUT RELAY BREAK CAPACITY (FORM-A RELAY) AC resistive, 120 10 A normally-open, 5 A normally-closed V AC AC resistive, 240 10 A normally-open, 8 A normally-closed V AC AC inductive, PF = 2.5 A 0.4 pilot duty DC resistive, 30 10 A V DC

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ALL RANGES Power consumption

120 to 240 V AC 125 to 250 V DC 60 to 300 V AC (50 and 60 Hz) 84 to 250 V DC 24 to 48 V DC 16 W typical, 25 W maximum

COMMUNICATIONS DEVICENET (COPPER) Modes slave (125, 250, and 500 kbps) ETHERNET (COPPER) Modes 10/100 MB (auto-detect) Connector RJ-45 Protocol Modbus TCP PROFIBUS (COPPER) Modes DP V0 slave, up to 1.5 Mbps RS485 PORT Protocol Modbus RTU USB PORT (GRAPHIC CONTROL PANEL ONLY) Standard Compliant with both USB 2.0 and USB 1.1 specification TYPE TESTS Dielectric voltage EN60255-5 withstand: Impulse voltage EN60255-5 withstand: Damped IEC 61000-4-18 / IEC 60255-22-1 Oscillatory: Electrostatic EN61000-4-2 / IEC 60255-22-2 Discharge: RF immunity: EN61000-4-3 / IEC 60255-22-3 Fast Transient EN61000-4-4 / IEC 60255-22-4 Disturbance: Surge Immunity: EN61000-4-5 / IEC 60255-22-5 Conducted RF EN61000-4-6 / IEC 60255-22-6 Immunity: Voltage IEC 60255-11 interruption and Ripple DC: Radiated & CISPR11 /CISPR22/ IEC 60255-25 Conducted Emissions: Sinusoidal IEC 60255-21-1 Vibration: Shock & Bump: IEC 60255-21-2 Power magnetic IEC 61000-4-8 Immunity: Pulse Magnetic IEC 61000-4-9A Immunity: Voltage Dip & IEC 61000-4-11 interruption: Damped IEC 61000-4-12 Oscillatory: Harmonics & IEC 61000-4-13 Interharmonics: Voltage Ripple: IEC 61000-4-17 Ingress Protection: IEC 60529 Environmental IEC 60068-2-1 (Cold): Environmental IEC 60068-2-2 (Dry heat): Relative Humidity IEC 60068-2-30 Cyclic: Safety: UL508 / UL C22.2-14 / UL1053 TESTING AND CERTIFICATION CERTIFICATION ISO Manufactured under an ISO9001 registered program CE EN60255-5, EN61010-1, EN50263, EN61000-6-2, EN61000-6-4 cULus UL508, UL1053, C22.2.No 14 PHYSICAL SPECIFICATIONS DIMENSIONS Size Base: 120 mm (W) × 90 mm (H) × 113 mm (D) [+ terminals 10mm] Expansion: 62 mm (W) × 90 mm (H) × 113 mm (D) GCP: 153 mm (W) × 102 mm (H) × 35 mm (D) BCP: 75 mm (W) × 75 mm (H) × 31 mm (D) Weight (Base)

0.75 kg

ENVIRONMENTAL

OPERATING ENVIRONMENT

Ambient temperature:

Humidity Polution degree IP rating

Storage / Shipping: -40C to +90C* Operating: -20C to +60C* * based on 1” around base unit up to 95% non-condensing 2 IP20 (base unit), IP54 (control panel)

MM300 Motor Management System

User Interface Graphical Interface • Easy to Use • Wide viewing angle

Navigation Keys • View actual values and status • View and modify settings LED Indicator • Motor status • Alarm Indication • System Status • Communication Status • Additional user LEDs

Color HMI Display

Control Panel

Front USB Port Security Revision control/history

RS485 Communications and Thermistor Input

3 Phase + Residual Ground CT Inputs

Integrated Device Control

Motor Protection

Profibus or DeviceNet Optional fieldbus protocols

Soft key Navigation

Expansion module to base unit with a single connector Optional 3-phase Voltage Module

Switched Power Supply allows AC or DC control voltage

RTD Module with three RTD inputs

Optional TCP / IP Ethernet

Core Balance Ground CT Input

I/O card includes: • 2 Contactor Outputs (Form A) • 6 Programmable inputs • Single Phase VT input (60-300Vac)

Expansion Module allows additional Digital I/O, RTD, or Voltage inputs

Dimensions 6.071”

(154mm)

4.059”

3.746”

(103mm)

(95mm)

.565” (14.5mm)

5.228”

(133mm)

5.599” (142mm)

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5.550” (141mm)

409

Mounting

3.775” (96mm)

DIN Rail Mounting

Door Mounting

5

(1

The Hand Held Display (HHD) provides a rugged local interface for MM300 Motor Protection Systems where a local display is not used in the MCC. The HHD provides a graphical color local interface to the MM300 Motor Protection Systems allowing local operators to view and change setting files and quickly access relay diagnostic information. The HHD provides a clear and detailed view of all motor settings, diagnostic information and metering data available in the MM300 allowing local operators to make informed decisions on the motors operation.

Ordering MM300 *

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Description

Control Panel X None B Basic Control Panel, no USB G Graphical Control Panel inc USB Language E English (Standard) C Chinese * Power Supply H High (60-300 Vac/80-250Vdc) L Low (24-48 Vdc) Communication S RS485 Modbus RTU (Standard) D RS485 + DeviceNet Slave + 10/100 Modbus TCP P RS485 + Profibus DP Slave + 10/100 Modbus TCP Options S Standard Control and Event Recorder 1 + Undervoltage Auto-restart 2 + Waveform Capture, Data Logger 3 + FlexLogic I/O Modules X X X X None A 3 Phase Current + Thermal O/L, Under Current, Single Phase Under Power B 3 Phase Voltage Metering + 3 Phase Under Power, Under / Over Voltage, Phase reversal G G G G 3 x RTD : 100PT - max 2 C C C C C 2 x 10A Relay Form A and 6 x Digital Input 60-300ac/ (Standard) - max 5 D D D D 4 x 10A Relay Form C - max 4 E E E E E 6 x Digital Inputs 20-60 VDC, 2 x 10A Relay Form A (max 4)

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Multilin™ MM200 Low Voltage Motor Protection and Control

Protection and Control

The Multilin MM200 is a digital motor protection and control system, designed for low voltage motor applications that integrates protection, control and multiple communication protocols in a rugged compact device. Easily integrated into new and existing control system architectures, the Multilin MM200 provides comprehensive low voltage motor protection and communications for all types of motor protection applications.

• Motor Thermal Model • Undercurrent & Current Unbalance • Acceleration Time • Sensitive Ground Fault • Built-in Starter Logic

Key Benefits

• FVNR, FVR, Two-Speed

• Flexible protection, control, and communication options to suit low voltage motor applications

• Auto / Manual Control

• Small footprint designed specifically for IEC and NEMA MCC applications

• Configurable Inputs

• Integrated pushbuttons and LED indicators reduce external components and wiring

• Power Fail Restart

• Flexible DIN rail mounting • Multiple communication protocols allows simple integration into monitoring and control systems.

Metering & Monitoring

• Optional control panel provides local control

• Current, Motor Loads, Thermal Capacity

• Universal device for all motor power ratings • No CTs required for less than 5A motor ratings

• Motor Running Time, Cause of Trip, Total Number of Trips

• Thermistor input to monitor the ambient or motor temperature

• 1A / 5A combined CT inputs

• Support for Hand Held Display (HHD) that provides a graphical color local interface allowing local operators to view and change setting files and quickly access relay diagnostic information

Applications

Communications • Networking through RS485

• MCC and standalone Panel Mount Applications

• Multiple protocols - Modbus RTU ODVA Compliant DeviceNet Internally powered Profibus

• IEC and NEMA Motor Control Center (MCCs)

• Simultaneous Communications

• Low Voltage Three-Phase Motors

• Process control applications • System architecture requiring multiple simultaneous communications

EnerVista™ Software

• FVNR, FVR, two speed

• Simplify setup and configuration • Strong document archive and management system • Simplify full featured monitoring and data recording • Strong maintenance and troubleshooting tool • Seamless integration toolkit

MM200 Motor Manager

Protection and Control

Motor Thermal Model To provide optimal protection and maximize run time, the MM200 employs an advanced thermal model, consisting of four key elements: • Overload Curves • Hot/Cold Safe Stall Ratio

Mechanical Jam and Acceleration Time

1, 000

TRIP TIME (seconds)

The MM200 is a digital motor protection and control system, designed for Low Voltage motor applications. Compact and powerful, the MM200’s protection can be scaled to the specific requirements of your system.

reducing the TCU value exponentially, based on the programmed cool time constants. As cooling occurs at different rates for stopped and running motors, two separate constants are used.

10, 000

These two elements are used to prevent motor damage during abnormal operating conditions such as driven load jams and excessively long acceleration times

100

Ground Fault CU RV E 15 12 9 7

10

• Motor Cooling Time Constants • Thermal protection reset

Overload Curves

Motor Protection

The MM200 thermal model can be programmed with one of 15 standard overload curves. When properly selected to match the motor manufactures thermal damage curves, the MM200 overload curve and Overload Pickup Level will determine the thermal capacity accumulated within the motor.

Hot / Cold Safe Stall Ratio This ratio defines the steady state level of thermal capacity used (TCU) by the motor. This level corresponds to normal operating temperature of a fully loaded motor and will

4 3 2 1

1 1

0.1

Full Load Setpoint

10

Phase Current

(Multiples of full load)

15 Standard Curves available in the MM200

be adjusted proportionally if the motor load is lower then rated.

Motor Cool Time Constants When the MM200 detects that the motor is running at a load lower then the overload pickup setpoint or the motor is stopped, it will start

Functional Block Diagram ANSI® Device Numbers & Functions DEVICE NUMBER

FUNCTION

37 46 49 50G 51R

Undercurrent Current Unbalance Thermal Overload Ground Instantaneous Overcurrent Locked/Stalled Rotot, Mechanical Jam

412

This function is designed to protect motors against phase to ground faults. The MM200 comes with one ground CT input intended for Core balance (Zero sequence)protection.

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Current Unbalance In addition to the Thermal model, current unbalance is available in the MM200 relay as an independent element with a built-in single phasing detection algorithm.

Undercurrent Protection Undercurrent protection is standard in the MM200. providing additional protection while the motor is in the running state and any of the phase currents drop below the defined pick-up level for the durartion specified.

MM200 Motor Manager

Power Fail Restart

Communications

EnerVista™ Software

The MM200 supports a Power Fail Restart element (PFR), which provides an undervoltage motor restart after a momentary power loss (dip). The undervoltage condition is detected by a digital input associated with an externally mounted voltage relay.

The MM200 utilizes the most advanced communications technologies available today making it an easier and more flexible motor protection relay to use and integrate into new and existing infrastructures. Multiple communication ports and protocols allow control and easy access to information from the MM200. All communication ports are capable of communication simultaneously.

The EnerVista™ Suite is an industry-leading set of software programs that simplifies every aspect of using the MM200 relay. The EnerVistaTM suite provides all the tools to monitor the status of the protected asset, maintain the relay, and integrate information measured by the MM200 into DCS or SCADA monitoring systems.

The MM200 supports the most popular industry standard protocols enabling easy, direct integration into HMI and electrical SCADA systems. Modbus RTU is provided standard with a RS485 networking port. The following optional protocols and communication ports are available:

EnerVista™ Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining Multilin products. The setup software within Launchpad allows configuring devices in real-time by communicating using serial, Ethernet , or modem connections, or offline by creating setting files to be sent to devices at a later time.

The PFR in combination with a voltage relay provides an undervoltage motor restart solution in applications such as; oil and gas, where process uptime is critical to the overall operation of the facility.

Thermistor A single input from a motor winding thermistor is provided with the MM200. The MM200 can accept both positive temperature coefficient (PTC) and negative temperature coefficient (NTC) sensors. A thermistor level can be selected for both alarm and trip.

The MM200 includes high accuracy metering of current signals. Current parameters are available as total RMS magnitude.

Digital Counters The MM200 provides ten digital counters to aid in system analysis. The digital counters can be used for scheduling inspections on equipment, performing qualitative analysis of system problems and spotting trends.

Learned Data Monitoring the motor’s operating characteristics assists in determining the motor start parameters and is a critical tool for determining the operating characteristics of the system, motor and connected load.

Advanced Device Health Diagnostics The MM200 performs comprehensive device health diagnostic tests during startup and continuously at runtime to test its own major functions and critical hardware. These diagnostic tests monitor for conditions that could impact the MM200’s performance, evaluate the criticality of this impact and present device status via SCADA communications. Providing continuous monitoring and early detection of possible issues helps improve system availability by employing predictive maintenance

Profibus DP Providing a high degree of communication flexibility, the MM200 supports both Profibus DP-V0 and DP-V1. Profibus DP-V0 provides highspeed cyclic data exchange between distributed field devices and the Profibus master. In addition to the high-speed cyclic data communication with DP-V0, DP-V1 provides communication of acyclic data information between the slaves and the engineering workstation, which allows for independent diagnosing and fine-tuning of each slave on the network.

Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed. Documents made available include: • Manuals • Application Notes • Guideform Specifications • Brochures • Wiring Diagrams • FAQs • Service Bulletins

Rapid Device Replacement The MM200 supports Rapid Device Replacement, which is compatible with DeviceNet scanners that use Automatic Device Replacement (ADR) functionality. When Rapid Device Replacement is used in DeviceNet networks, this allows rapid change of MM200 devices with minimum process interruption.

MM200 Dual Architecture Communication

When using Rapid Device Replacement , the MM200 can be replaced without the need to manually configure settings. The DeviceNet scanner will automatically recognize a new device and download the key protection, control and communication settings from the original MM200, reducing process downtime and manual setting file configuration.

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Motor Protection

Monitoring and Metering

• Fieldbus Protocol with dedicated port - ODVA compliant DeviceNet - Internally powered Profibus

EnerVista™ Launchpad

MM200 Motor Manager

Viewpoint Monitoring

EnerVista™ Integrator

Viewpoint Monitoring is a simple-to-use and full-featured monitoring and data recording software package for small systems. Viewpoint Monitoring provides a complete HMI package with the following functionality:

EnerVistaTM Integrator is a toolkit that allows seamless integration of Multilin devices into new or existing automation systems. Included in EnerVistaTM Integrator is:

• Plug & Play Device Monitoring

• OPC/DDE Server

• System Single-Line Monitoring & Control

• Multilin Drivers

• Annunciator Alarm Screens

• Automatic Event Retrieval

• Trending Reports

• Automatic Waveform Retrieval

• Automatic Event Retrieval • Automatic Waveform Retrieval

Viewpoint Maintenance Viewpoint Maintenance provides tools that will create reports on the operating status of the relay, simplify the steps to download fault and event data, and reduce the work required for cyber-security compliance audits.

Motor Protection

EnerVista MM200 Set-up

Online Device Window: • Online communication to device • Relay designation • Online configuration of all relay setpoints • Communication to multiple devices • Copy online settings to files offline Active Settings Window: • Simple drop down menu options for setting parameters • Detailed view parameter set points

Offline File Window: • Create setting file templates • Copy and paste settings from one relay to another • Copy offline settings to online devices

EnerVista setup software simplifies every aspect of using the MM200 relay. The EnerVista suite provides all the tools required to configure monitor & maintain the relay. Advanced communications support ensures easy integration into new or existing DCS scada systems.

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MM200 Motor Manager

User Interface Front Panel Controls

Optional Fieldbus Protocols

• Integrated Device Controls

(ProfiBus or DeviceNet)

12 LED Indicators:

Power Supply and Digital Inputs:

• Motor Status • Alarm Indication & trip • Communication Status • Additional user LEDs • Auto/Manual

3 Phase CT Inputs

RS485 Communications and Thermistor Input

• 24 VDC Power Supply • 7 x 24 VDC Inputs (wet) • 60-300VAC Power Supply • 6x AC Inputs

• % Motor Load

• Sensitive Ground Fault

Optional Control Panel Interface

• 2 Form A Outputs (5 Amps) • 1 Form C Outputs (5 Amps)

Motor Protection

Dimensions Side View

Front View

Top View

3.542” (90 mm)

4.437” (112.7 mm) 3.100” (78.7 mm)

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MM200 Motor Manager

HandHeld Display (HHD) The Hand Held Display (HHD) provides a rugged local interface for MM200 Motor Protection Systems where a local display is not used in the MCC. The HHD provides a graphical color local interface to the MM200 Motor Protection Systems allowing local operators to view and change setting files and quickly access relay diagnostic information. The HHD provides a clear and detailed view of all motor settings, diagnostic information and metering data available in the MM200 allowing local operators to make informed decisions on the motors operation.

Motor Protection

Wiring Diagrams

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MM200 Motor Manager

Wiring Diagrams (Cont)

Motor Protection

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417

Technical Specifications INPUTS PHASE CURRENT INPUTS CT Primary: 0.5A to 1000A CT Secondary: 1A or 5A (Both supported as standard) Burden: 0.2VA Conversion Range: 0.2 to 40 A (8x CT) Nominal Frequency: 50/60 Hz Frequency Range: 40-70 Hz Accuracy: (Ext CT) 2% of injected or 1% of 8xCTP Accuracy: (Direct) 2% of injected or 0.1A CT Withstand: 0.2 seconds at 100 x rated current 1.0 second at 50 x rated current 2.0 seconds at 40 x rated current continuous at 3 x rated current (40DegC) SENSITIVE GROUND CURRENT INPUT CT Primary: 0.5A to 15A Conversion Range: 0.5A to 15A, 2000:1 CBCT Accuracy: 0.1A (0.5A to 3.99A) 0.2A (4.0A to 15A) DIGITAL INPUTS X7 Fixed Threshhold: 24VDC Recognition Time: 2 cycle recognition Continuous Current 4mA Draw: Type: Opto-isolated inputs External Switch: Wet Contact Max. Inputs Voltage: 30VDC DIGITAL INPUTS (HI) Nominal voltage 120 V AC to 240 V AC Recognition time 2 cycles Continuous current 4 mA @120 V AC; 8 mA @ 240 V AC draw Type opto-isolated inputs External switch wet contact Voltage range 65 V AC to 300 V AC OUTPUTS Configuration:

Electromechanical 2 x Form-A and 1 x Form-C Silver aloy 10ms 10mA at 5Vdc

Contact Material: Operate Time: Minimum Contact Load: Maximum Switching 300 ops / min (no load), Rate: 30 ops per min (load) Mechanical Life: 10,000,000 ops Continuous Current 5 A at 60°C Make and Carry 30A per ANSI C37.90 for 0.2s: OUTPUT RELAY BREAK CAPACITY (FORM_A) AC resistive, 5A 120Vac: AC resistive, 5A 240Vac: AC inductive, 240VA PF = 0.4 pilot duty: DC resistive, 30Vdc 5A OUTPUT RELAY BREAK CAPACITY (FORM_C) AC resistive, 5A (NO) 5A (NC) 120Vac: AC resistive, 5A (NO) 8A (NC) 240Vac: AC inductive, 2 40VA PF = 0.4 pilot duty: DC resistive, 30Vdc 5A

POWER SUPPLY SPECIFICATIONS POWER SUPPLY (LO RANGE) Nominal 24 V DC Range 18 to 36 V DC Power Consumption 10 W typical POWER SUPPLY (HI RANGE) Nominal 120 to 240 V AC; 125 to 250 V DC Range 60 to 300 V AC (50 and 60 Hz); 84 to 250 V DC Power consumption 10 W typical Voltage withstand 2 × highest nominal voltage for 10 ms PROTECTION THERMAL MODEL Standard Curve Time Multiplier: Thermal Overload Pickup: Motor Full Load Current (FLA): Motor Rated Voltage: Curve Biasing:

1 to 15 in steps of 1 1.01 to 1.25 in steps of 0.01 x FLA 0.5A to 1000A step 0.1A 100Vac - 690Vac Hot/Cold Curve Ratio Stopped / Running Cool Rate Exponential

Stopped/Running Time Cool Constants Decay: Hot/Cold Safe Stall 1% to 100% steps 1% Ratio: Timing Accuracy: ±500 ms Elements: Trip and Alarm CURRENT UNBALANCE Unbalance: (Imax - Iav) / Iav, if Iav >= Ifla (Imax - Iav) / Iflc, if Iav < Ifla Range/Pickup 4% to 40% steps of 1% Level: Time Delay: 1 to 60s in steps of 1 Pickup Accuracy: ±2% Timing Accuracy: ±500ms Elements: Trip and Alarm UNDERCURRENT Pickup Level: 1 to 100% of FLC Time Delay: 1 to 60 s in steps of 1 Timing Accuracy: ±500ms Elements: Trip and Alarm MECHANICAL JAM Pickup Level: 1.01 to 4.50 of FLA in steps of 0.01 Time Delay: 0.1 to 30.0s in steps of 0.1 Timing Accuracy: ±500ms Elements: Trip GROUND FAULT Pickup Level: 0.5 to 15.0A in steps 0.1 (CBCT) Time Delay: 0 to 10s in steps 0.1s (start) 0 to 5s in steps 0.1s (run) Alarm time delay on start/run: 0 to 60s in steps of 1s Timing Accuracy: +100ms or ±0.5% of total time Elements: Trip and Alarm ACCELERATION TIMER Pickup: Iav > Icuttoff Dropout: Iav < Ipu or Timer expired Time Delay 0.5 to 250.0 s in steps of 0.1 (force to running if 0 to 5s in steps 0.1s (run) expired): Timing Accuracy: ±500ms or ±1.5% of total time Elements: Trip and Alarm CERTIFICATION ISO:

cULus

Manufactured under an ISO9001 registered system conforms to EN60255-5, EN60255-27, EN60255-26, EN50263 UL508 / UL1053 / C22.2.No 14

TYPE TESTS Dielectric voltage withstand: Impulse voltage withstand: Damped Oscillatory: Electrostatic Discharge: RF immunity: Fast Transient Disturbance: Surge Immunity: Conducted RF Immunity: Power Frequency Immunity: Voltage interruptionand Ripple DC: Radiated & Conducted Emissions: Sinusoidal Vibration: Shock & Bump: Siesmic: Power magnetic Immunity: Pulse Magnetic Immunity: Damped Magnetic Immunity: Voltage Dip & interruption: Damped Oscillatory: Voltage Ripple: Ingress Protection: Environmental (Cold): Environmental (Dry heat): Relative Humidity Cyclic: Safety:

EN60255-5 EN60255-5 IEC 61000-4-18/ IEC 60255-22-1 EN61000-4-2 / IEC 60255-22-2 EN61000-4-3 / IEC 60255-22-3 EN61000-4-4 / IEC 60255-22-4 EN61000-4-5 / IEC 60255-22-5 EN61000-4-6 / IEC 60255-22-6 EN61000-4-7 / IEC 60255-22-7 IEC 60255-11 CISPR11 / CISPR22 / IEC 60255-25 IEC 60255-21-1 IEC 60255-21-2 IEC 60255-21-3 IEC 61000-4-8 IEC 61000-4-9 IEC 61000-4-10 IEC 61000-4-11 IEC 61000-4-12 IEC 61000-4-17 IEC 60529 IEC 60068-2-1 IEC 60068-2-2 IEC 60068-2-30 UL508 / UL C22.2-14 / UL1053

ENVIRONMENTAL Temperature Range *: Ambient Operating: -20°C to +60°C Ambient Storage: -40°C to +90°C Humidity: Up to 90% non-condensing @ 55C Pollution degree: II IP Rating Base Unit IP20, Control panel IP54 *Temperature range based on 1” around base unit

COMMUNICATIONS SERIAL RS485 Baud Rates: Parity: Protocol: Typical Distance: Isolation: DEVICENET (COPPER) Modes: Connector: PROFIBUS (COPPER) Modes: Connector:

Up to 115kbps None Modbus© RTU/half duplex 1200m 2kV Slave at 125, 250, 500 kbaud 5 pin terminal DP V0 Slave, up to 1.5MB 5 pin terminal

Please refer to MM200 Motor Manager Instruction Manual for complete technical specifications.

Ordering MM200

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Control Panel X B Power Supply L H Communication 1 2 Protection S

Description

None Basic Control Panel, no USB 24 VDC 60 - 300 VAC RS485 Modbus RTU + DeviceNet Slave RS485 Modbus RTU + Profibus DP Slave Standard Protection & Control

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Specialized Protection, Control and Recording Specialized Protection, Control and Recording Overview GE specialized solution include Microgrid Control Systems, breaker protection, capacitor bank protection, and programmable logic controllers for advanced load shedding and remedial action schemes.

Product Listing Complete product brochures for multilin specialized protection, control and recording offered by GE.

Product Listing

Specialized Protection, Control and Recording – Product Listing C90Plus

Automation Control System

421

The C90Plus Automation Control System with fast load shed is a powerful automation control system that eliminates the need for several separate devices. Performing intelligent high-end and fast optimal load shedding, it is highly customizable and scalable. It can additionally be used in applications for advanced Bay control/monitoring, frequency/voltage load shed, substation alarm concentrator, annunciator and controller, advanced automation schemes such as bus transfer, stand alone breaker protection and monitoring.

C60

Breaker Protection System

437

Integrated breaker monitoring and control for substation automation. The C60, a member of the UR Family, is a substation hardened controller that provides a complete integrated package for the protection, control, and monitoring or circuit breakers within a substation. The C60 provides fast and deterministic execution of programmable logic necessary for substation automation applications.

Specialized Protection & Control

C30

Controller System

445

Substation hardened, relay grade programmable logic controller. The C30, a member of the UR Family, is a digital IED designed to act as a substation hardened programmable logic controller that can also expand the I/O capability of protection devices and replace existing Sequence of Events (SOE) Recorders. The C30 provides fast and deterministic execution of programmable logic with I/O capabilities far above an average protection relay.

C70

Capacitor Bank Protection and Control System

451

Integrated protection, control and monitoring for capacitor banks. Based on the well-established and proven UR relay platform, the C70 provides both bank and system protection schemes for shunt capacitor protection. The current and voltage-based protection functions are designed to provide sensitive protection for grounded, ungrounded single and parallel capacitor banks and banks with taps, for a variety of capacitor bank configurations. Combined with the sophisticated built-in control functions turn ON/OFF banks with relative ease and flexibility for automatic voltage regulation.

U90Plus

Microgrid Control System

459

GE’s Grid IQ™ Microgrid Control System enables distribution grid operators to integrate and optimize energy assets (electrical and/or thermal) to reduce the overall energy cost for the local distribution grid, known as a “microgrid”. The Microgrid Control System is based on a supervisory control architecture provided by the Multilin™ U90Plus Generation Optimizer, intelligent electronic devices (IEDs), substation gateways and a secure communications network.

Go online for the full listing of Multilin Protection & Control products

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Multilin C90 ™

Plus

Automation Control System

Bay Protection & Control

The Multilin™ C90  is a powerful automation controller that eliminates the need for several external devices, such as substation programmable logic controllers and disturbance recorders. Highly customizable and scalable, C90Plus is designed for blackout and emergency events in transmission and industrial power systems.

• Dedicated automation controller with 4000 lines of logic

Plus

The C90Plus features intelligent high-end and fast load shedding, bay protection and control, and comprehensive communications.

• 10 stages of under/over frequency protection, 4 stages of rate-of-change-of frequency, 6 stages of undervoltage elements • Protection logic at 1 msec execution rate • HMI for breaker and disconnect control

Key Benefits

• Dual breaker failure protection

• Powerful automation controller eliminates the need for separate substation PLCs

• Direct and tele-protection elements using inter-relay comms

• High-end load shedding with multiple stages of frequency and voltage retains system stability after disturbances • Fast optimal load shedding executed within 20ms minimizing process outages and costs associated with system downtime • Intelligently sheds loads to maintain system / process integrity • Highly customizable and scalable, integrating easily into most industrial facilities with new or existing EMS/SCADA systems • Configurable annunciator panel capable of handling up to 288 alarms, eliminating the need for a separate panel • Embedded Synchrophasor measurement capabilities (per IEEE® C37.118), eliminating the need for dedicated PMUs and support for synchrophasor multi-cast (per IEC® 61850-90-5) reducing bandwidth and communications infrastructure costs • Increased network availability via failover time reduced to zero through IEC® 62439-3 “PRP” support • Advanced fault and disturbance recording, including internal relay operating signals, eliminating the need for external recording devices

Monitoring & Metering • Advanced recording capabilities with high-capacity event recorder, transient & disturbance recording, configurable and extended waveform capture and data logger • Current, voltage, frequency, power, energy and synchrophsors (per IEEE C37.118) measurement

Fast Load Shed • Intelligently shed necessary loads per customized priorities

• HMI with pre-configured and customizable displays including real-time bay control, metering, fast load shed reports, equipment status, fault and event recording

• Highly customizable and scalable for simplified integration into new or existing EMS/SCADA systems

Applications

• Suitable for small or large industrial systems without re-design

• Advanced bay control / monitoring (6 breakers and 30 disconnects) • Fast, power-balance load shed • Frequency and voltage load shed • Substation alarm concentrator, annunciator, and controller • Advanced automation schemes such as bus transfer • Stand-alone breaker protection and monitoring

Communications • Supported industry protocols: IEC 61850, DNP 3.0, Modbus Serial/TCP, IEC 60870-5-104 and 103, PRP • Up to 3 independent IP addresses with failover features & standards based inter relay comms

C90Plus Automation Control System

Advanced Bay Control

• Instantaneous and timed overcurrent elements for phase, neutral, ground and negative sequence protection

The C90 Plus bay control or monitoring functionality is intended for high-end bay control applications typically used in transmission installations, where a larger quantity of I/O, advanced protection and control functionality and an advanced HMI is desired.

voltage functions including neutral overvoltage, negative sequence overvoltage and phase undervoltage. The phase undervoltage can be programmed as definite time or inverse time.

• Directional supervision is available for phase neutral and negative sequence elements

Over and Under Frequency Protection

• Time O/C elements can individually be set to use IEEE, IEC or custom FlexCurves™

Over and Under Voltage Protection

Bay Control Protection Functions

Long lines under lightly loaded conditions or no-load or sudden loss of power may experience voltages exceeding the rated per unit voltage level of the line. Use the phase overvoltage element of the C90Plus to initiate a local trip as well as a remote trip using direct transfer trip. The C90Plus also provides additional

Overcurrent The C90 Plus provides multiple stages of overcurrent functions for phase, neutral and ground. Overcurrent functions include:

The multiple stages of under and over frequency elements can be used to initiate load shedding or remedial action schemes or frequencybased load restoration schemes during lack of generation in the network or due to sudden load drops. Combined with the advanced automation capabilities of the C90 Plus, flexible, special protection schemes, advanced load shedding and load restoration schemes can be built.

Specialized Protection & Control

Functional Block Diagram

52

52

Monitoring

CLOSE

TRIP

59X(2)

27X(2)

25 (2)

79 50DD

50P(4)

50_2 (2)

51P(4)

51_2 (2)

50BF (2)

67P (2)

67_2 (2)

50N(4)

FlexElement

Metering

TM

50G(4)

51N(4)

Transducer Inputs

67N/G (2)

59_2(2)

59P(2)

27P (2)

51G(4)

59N(2)

C90Plus

Controller System

ANSI Device Numbers & Functions ®

DEVICE NUMBER

FUNCTION

DEVICE NUMBER

FUNCTION

25 27P 27X 50BF 50DD 50G 50N 50P

Synchronism Check Phase Undervoltage Auxiliary Undervoltage Breaker Failure Current Disturbance Detector Ground Instantaneous Overcurrent Neutral Instantaneous Overcurrent Phase Instantaneous Overcurrent

50_2 51G 51N 51P 51_2 52 59N 59P

Negative Sequence Instantaneous Overcurrent Ground Time Overcurrent Neutral Time Overcurrent Phase Time Overcurrent Negative Sequence Time Overcurrent AC Circuit Breaker Neutral Overvoltage Phase Overvoltage

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DEVICE NUMBER

FUNCTION

59X 59_2 67N 67P 67_2 79 81 U/O

Auxiliary Overvoltage Negative Sequence Overvoltage Neutral Directional Overcurrent Phase Directional Overcurrent Negative Sequence Directional Overcurrent Automatic Recloser Under and Over Frequency

C90Plus Automation Control System

Small Signal Oscillation Functionality A new protection element called the small signal oscillation detection is added to the product. Modern power systems are becoming increasingly interconnected to each other for the benefits of increased reliability, reduced operation cost , improved power quality and reduced necessary spinning reserve. With the increasingly large interconnected power systems some technical challenges also become apparent. One of these challenges is the interarea low frequency oscillations that are a major threat to reliable operations of large-scale power systems. Inter-area oscillations not only limit the amount of power transfer, but also threaten the system security and equilibrium, as they may lead to system instability and cascading outages.

Bay Configurations The C90Plus has 12 pre-configured bay single line diagrams and corresponding controls for each of the bay equipment. Users can also program their own single line diagrams using the ANSI/ IEC library symbols provided in the EnerVista setup program.

Breaker-and-Half Configuration.

Two-Main and Transfer Bus Configuration.

Double Bus Configuration.

Power System Troubleshooting The C90Plus contains tools that allow for the early detection of impending breaker problems and allow for maintenance to be performed before serious damage occurs.

Breaker Latch Release Time: Indicates how long it took for the breaker latch to release from the time the trip coil was energized by the relay

Arc Extinguish Time: Indicates the length of time that was required for the breaker to extinguish the arc and finally clear the fault

Breaker Mechanism Travel Time: Indicates time interval required for the breaker mechanism to travel to its rest position

Triggering a waveform on each breaker operation can identify changes in the length of time each part or mechanism in the breaker takes to perform its function.

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Specialized Protection & Control

Therefore, it is essential to identify the characteristics of the inter-area oscillations, including oscillation frequency and damping ratio, so that proper actions can be taken based on the results. This is required to improve the system damping and maintain stability in the

power system. The C90 Plus can detect these inter-area oscillations and provide an alarm or even a trip signal to prevent a large-scale system disturbance.

C90Plus Automation Control System

Fast Load Shed Why Fast Load Shed?

Speed of Fast Load Shed Scheme: The speed of Fast Load Shedding including internal processing is as follows:

Conventional frequency and voltage load shedding schemes operate typically in 250 ms to seconds.

Origin

UR end device detects trip/breaker operation

3000 µs

UR GOOSE message with change of online state

200 µs

Message passed through multiple LAN switches

Contingency based load shedding schemes are typically faster at 160 – 400 ms depending on both system architecture and communications employed.

3000 µs

FLSC processing and calculations

1000 µs

Shed command GOOSE message composed

500 µs

FLSC GOOSE message is sent through LAN switches

3000 µs

Shed command GOOSE message parsed by load URs

Both these scheme types are too slow for industrial cogeneration applications, such as oil and gas or manufacturing, where very fast load shedding is required to ensure power system and critical processes integrity.

4000 µs

UR end device calculations and processing

2000 µs

Trip contact output closes

16.7 ms

Total

End-to-end execution made under 20 ms 17 milliseconds

Specialized Protection & Control

What is Fast Load Shed? Fast load shed is a system consisting of one or more C90Plus, IEC 61850-Ethernet network, UR, URPlus or IEC 61850-8-1 capable end devices that provides fast load shedding, to re-establish power balance when source/loads balance is disrupted. End devices are of UR, URPlus, SR or IED’s with IEC 61850-8-1 support (other vendor IED interoperability not proven/tested). It is possible to use existing devices which do not support IEC 61850. In those cases the D25 RTU can be used to communicate between those existing devices and the fast load shed controller (FLSC), however this will slow the scheme down. The C90 Plus FLSC checks if generation lost exceeds remaining generation reserve per:

Δ(Pgen) + Preserve ≥ 0 In case of generation loss or power unbalance GOOSE messages are sent to shed enough load per pre-defined priorities above available generation reserve (Adaptive Mode). Load priorities can be changed/updated via HMI within a second. Alternatively, a pre-defined shedding scenario can be executed upon each defined contingency (Static Mode). Up to 16 automatic reports are generated for any scheme operation containing Fast Load Shed Controller (FLSC) relay name, firmware revision, contingency date/time and duration, steady-state power flows, infeeds lost, scenarios encountered, load groups shed, settings last changed date.

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GOOSE message is parsed in the C90Plus controller GOOSE message is created in Source/Generator Protection End device (Source or Generator Protection) detects a change/trip

Shed command parsed by end devices/load relays

Shed command goes through 20 Ethernet switches Shed command composed and sent from C90Plus controller to load relays

C90Plus Load Shed Scheme Devices C90Plus Fast Load Shed Controller (FLSC) The controller is the main decision point of the system where all the calculations and intelligent commands are sent. It is a substation hardened device with a real-time operating system that is highly reliable and accurate. It is also equipped with a local annunciator panel and HMI screen (optional) for ease-of-use for maintenance and operation. The controller receives source data from end devices, load data from end devices or aggregators via analog GOOSE. It handles up to 64 loads or infeeds as well as 6 local infeeds, and makes the final decision to shed load. The load shed commands are issued via GOOSE to end devices.

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Load trip contact closes

Trip command is sent to contact in load relay

C90Plus Fast Load Shed Aggregator (FLSA) This is an extension of the system allowing for aggregation of load data and is a load shed data concentrator, combining load data from end devices and sending as analog GOOSE to the FLSC. It does not make load shed decisions. It allows the controller to handle more than 64 loads. By connecting the aggregators in a treelike matrix, the number of loads controlled with this scheme can reach over 2500.

Load Shed Controller Design The FLSC can interface or aggregate measurements into 32 sources/infeeds and 32 loads/load groups (many loads/group).

C90Plus Automation Control System

User-defined shed priorities of the load groups are fixed or user-selectable through an HMI. Loads can be taken out of scan if it is determined that shedding is not required. The FLSC has an auto-compute solution option (Adaptive Mode) where loads to be shed are calculated based on priorities, generation lost and generation reserve, and a manual scenario execution option (Static Mode) where load shedding is predetermined for each power loss contingency.

Scalability of the Fast Load Shed Scheme

Interoperability

The controller can handle up to 64 infeeds/loads or aggregators plus 6 local devices (infeeds or loads).

All communications are based on GOOSE and IEC 61850-8-1.

Adding another C90Plus as an aggregator extends the system by an additional 70 loads. With 12 infeeds, 18 loads & 40 aggregators (64 loads each), the system can support 12 infeeds and 2578 sheddable loads. Minimal re-configuration is required in the case of system expansion.

The System Overview and Architecture Below is a typical Fast Load Shed scheme, consisting of: • 1 x C90Plus FLSC • IEC 61850-Ethernet network

External computer (optional)

• 2 x C90Plus FLSA’s (optional based on system size) • IEC 61850-8-1 capable end devices

32 load group powers 32 infeed powers 32 reserve powers Specialized Protection & Control

Priorities or trip masks

ML3000 Ethernet Switch

Aggregator

ML3000 Ethernet Switch

F35

F60

SR350

C90Plus Fast Load Shed Controller (FLSC)

Aggregator ML3000 Ethernet Switch

G60

T60

F60

SR350

M60

SR339

End Devices

End Devices

End Devices

Loads

Loads, Infeeds

Loads

F650

Legend GOOSE

Aggregator data message (32 load power groups)

Shed commands, digital GOOSE messages

Modbus over TCP/IP

Load data units, analog/online status GOOSE messages (power, unavailable)

Infeed data units (power, offline)

The above system architecture can be expanded to cater for non-IEC 61850 end devices by adding a D25 Substation Controller.

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Simplified Source-Load Example Below is a simplified system illustrating the load shed priorities and how shedding is determined:

G1

230 kV Feed 1

G2

230 kV Feed 2

G1

G2

GA

MA

Positive Power

MB

GB

Positive Power

C90Plus Automation Control System The C90 Plus is a powerful logic controller and protection product designed for the requirements of industrial and utility power systems. Its unparalleled list of features make the C90Plus one of the most agile and advanced products, allowing it to perform several functions and be used in many scenarios based on the needs of each customer. The C90Plus provides unmatched logic processing ability combined with a powerful math engine with deterministic execution of logic equations, regardless of the configuration of the number of lines of logic. The C90Plus provides the tools and functionality necessary for creating customized automation and control schemes that include: • Advanced bay control and interlocking

TIE

• Breaker monitoring and control

Specialized Protection & Control

Grp1

Grp2

Grp3

Grp4

Grp5

• Automatic bus transfer schemes • Load shedding and load restoration schemes • Ultra fast load shedding in industrial plants

The Total System Load = PGrp1 + PGrp2 + PGrp3 + PGrp4 + PGrp5 Total Source/Generation = PG1 + PG2 + PMA + PMB The C90Plus calculates: Δ(Pgen)+ Preserve ≥ 0

Automation Logic

LOAD PRIORITIZATION: (AS SET BY END-USER) Asset

Value

Priority/Status (User set)

Group 1

10MW

5

Group 2

10 MW

0 (Don’t Shed)

Group 3

5 MW

1

Group 4

20MW

4

Group 5

5 MW

2

Example: For a loss of 9MW of Generation with no generation reserve, the scheme will trip Load Groups 3 and 5 for a total of 10MW.

Actual Load Shed Performance Results (System Islanded) Below are some test results from a C90Plus fast load shed scheme operation in conjunction with backup df/dt and under frequency load shedding, illustrating operating speed of each system at a petrochemical facility that got islanded as a 4.5MW underpowered island. In this case the scheme operated in 13 ms, including trip command to shedding load breakers. TIME(MS)

EVENT

0

Breaker MB Opened Manually

8

Breaker Open De-bounced Island Detected Priorities 1, 2 and, 3 Load Shed Sent

10

Shed Message Received at Load Relays

13

Trip Coils Energized

50

Shed Breaker Open – Load Shed

64

ROCOF(df/dt) Trigger

106

Under Frequency Load Shed Trigger

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The C90Plus incorporates advanced automation features including powerful FlexLogic™ (user programmable logic) for its protection and advanced automation schemes. Combined with the communication capabilities, C90Plus automation features far surpass what is found in average relays with programmable logic. The C90Plus integrates seamlessly with UR and URPlus relays for complete system protection, including interlocking and special protection schemes.

FlexLogic FlexLogic is the powerful user programmable logic engine that provides the ability to create customized protection and control schemes thereby minimizing the need, and the associated costs, of auxiliary components and wiring. The independent automation FlexLogic features math, Boolean and control functions, which can be used for advanced load shedding, load restoration and dynamic Volt/VAR control schemes. More than 4000 lines of logic are provided with a deterministic execution rate of 50 msec, irrespective of the number of lines of logic.

C90Plus Automation Control System

Automation FlexLogic operators include:

Custom Programmable Logic Designer

• Math: EXP, ACOS, ATAN2, ATAN, ASIN, FLOOR, CEIL, LOG, LOG10, POW, SIN, COS, TAN, NEG, ABS, SQRT, ADD, SUB, MUL, DIV, CONSTANT • Boolean: AND, NAND, NOR, NOT, OR, XOR • Control: =, <=, !=, >=, <, >, Latch, Positive/ Negative/Dual one shot, Timers, Counters

Deterministic Automation A power system is a real-time system in which time and accuracy of every control should be considered critical. The C90Plus operating system ensures that every action and control is scheduled properly and beforehand to guarantee that nothing is missed nor delayed. This intelligence inside the C90 Plus handles both protection trip commands as well as any other logic written for execution as per its programmed timeline. No more delays or missed timelines when it comes to control because the processor is ‘busy’ or otherwise.

The C90Plus supports an advanced automation logic engine that supports Boolean operators, analog comparisons, and advanced mathematical operations.

The C90Plus supports the most popular industry standard protocols enabling easy, direct integration into DCS and SCADA systems including: • IEC 61850 • DNP3 • Ethernet Global Data (EGD) • IEC 60870-5-104 • Modbus RTU, Modbus TCP/IP • PRP as per IEC 62439-3 • Three independently configurable IP’s with failover features • Inter-relay communication card to enable implementation of pilot schemes based on standard communication protocols • Front USB for maintenance and downloading records and events

Interoperability with Embedded IEC 61850 Use the C90Plus with integrated IEC 61850 to lower costs associated with protection, control and automation. GE Multilin’s leadership in IEC 61850 comes from thousands of installed devices and follows on many years of development and operational experience with UCA 2.0. • Replace expensive copper wiring between devices with direct transfer of data using GOOSE messaging

• Configure systems based on IEC 61850 and also monitor and troubleshoot them in realtime with EnerVista Viewpoint Engineer • Integrate GE Multilin IEDs and generic IEC 61850-compliant devices seamlessly in EnerVista Viewpoint Monitoring

Extreme Communication • High reliable communication card with automatic failover and extremely fast redundant schemes • Inter-relay communication card to enable implementation of pilot schemes that are based on standard communication protocols, and both “Direct” and “Tele-Protection” input and output elements available Ease-of-use, security ease-of-use and quick setups are considered throughout every application and configuration parameter requiring virtually no training for those working in the power industry. The EnerVista suite is an industry-leading set of software programs that simplifies every aspect of using the C90Plus relay. The EnerVista suite provides all the tools to monitor the status of the protected asset, maintain the relay, and integrate information measured by the C90Plus into DCS or SCADA monitoring systems. Convenient COMTRADE and Sequence of Events viewers are an integral part of the URPlus Setup software included with every URPlus relay, to carry out postmortem event analysis to ensure proper protection system operation.

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Security and NERC® CIP • Audit Trail • Password protection and authentication • Support for alphanumeric passwords • Role-based access control to manage multiple personnel rights as per ANSI INCITS 359-2004

LAN Redundancy Substation LAN redundancy has been traditionally accomplished by reconfiguring the active network topology in case of failure. Regardless of the type of LAN architecture (tree, mesh, etc), reconfiguring the active LAN requires time to switchover, during which the LAN is unavailable. UR devices deliver redundancy as specified by PRP-IEC 62439-3, which eliminates the dependency on LAN reconfiguration and the associated switchover time. The UR becomes a dual attached node that transmits data packets over both main and redundant networks simultaneously, so in case of failure, one of the data packets will reach the receiving device with no time delay.

EnerVista Launchpad EnerVista Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining GE’s Multilin products. The setup software within Launchpad allows for the configuration of devices in real-time by communicating using serial, Ethernet , or

427

Specialized Protection & Control

Communications

C90Plus Automation Control System

modem connections, or offline by creating setting files to be sent to devices at a later time. Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed. Documents made available include: • Manuals • Application Notes

• A separate self-test message page on the annunciator panel shows clear error messages about the device health, greatly assisting in identifying, and correcting device related issues.

• Multiple programmable control pushbuttons, ten pushbuttons per page with multiple levels of control. • Local/remote control.

• For easy maintenance and asset management, product information, such as IP addresses and serial numbers of each module, are also accessible without the need to connect to the unit.

• Guideform Specifications • Brochures • Wiring Diagrams • FAQ’s • Service Bulletins

Sequence of event records provide the ability to view the time difference between two events for troubleshooting and analysis.

Viewpoint Engineer

Specialized Protection & Control

Viewpoint Engineer is a set of powerful tools that will allow you to configure and test your relays at a system level in an easy-to- use, graphical drag-and-drop environment . Viewpoint Engineer provides the following configuration and commissioning utilities:

12 to 48 user-configurable alarms per page eliminate the need for a separate annunciator.

HMI • Comprehensive data visualization.

• Graphical Logic Designer • Graphical System Designer • Graphical Logic Monitor • Graphical System Monitor

• Pre-programmed comprehensive displays for: ----------

Metering Bay Control Fault Reports Sequence of Event Reports Fault Records Device Diagnostics Equipment Manager Fast Load Shed Status and Reports Real-Time Phasor Displays of Voltage, Current and Sequence Components

User Interface and HMI The C90 Plus provides extensive local HMI capability through two dedicated display panels. One serves as a digital annunciator and the other optional HMI is for display and control functions.

Annunciator Enhanced HMI and Annouciator panels on the front of the C90Plus make it one of the most powerful human machine interfaces on local units. The C90 Plus provides an embedded, configurable color LCD annunciator on the front panel of the device, eliminating the need for LED labels and separate annunciators in the relay panel.

Easy-to-read large display of metering values. • User-programmable single line diagram supported by ANSI/IEC symbols. Preprogrammed single line diagrams for bay monitoring and control for common bus configurations, including ring-bus, double breaker and breaker-and-half configurations.

Front Panel USB The front panel of the C90Plus provides a USB 2.0 host for field laptop connections for highspeed data transfers, making downloading and uploading faster than a conventional RS232 connection.

• Any contact/direct/remote input or internally generated FlexLogic operand can be assigned to be displayed on the annunciator. • Up to 288 targets may be assigned. The display can be configured for 12/24/48 alarms per page to a maximum of 24 pages using a 16-color pallet for better visualization and customization.

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Phasor display of sequence components showing the standing unbalance in the line.

Single Bus Configuration.

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C90Plus Automation Control System

C90Plus Automation Control System Digital Alarm Annunciator

Intuitive HMI

Bay Protection

• 288 customizable alarms in multiple pages using a pallet of 16 colors

• User-configurable single line diagrams using IEC/ANSI library symbols

• Overcurrent, over/under voltage, over/under frequency

• Eliminates the need for separate annunciator

• Local control and status indication of breakers & disconnect switches, 20 userprogrammable pushbuttons

• Breaker failure, autoreclose, synch check

• Descriptive self-test messages

• Local/remote control

• 512 lines of Protection FlexLogic @ 1 msec execution

• Fault, event, disturbance and transient reports

Communication Capabilities

Recorders

• Built-in industry hardened logic controller

• Up to three independent Ethernet ports with redundant fast-over

• Eliminates the need for stand-alone disturbance recorders

• IEC 61850, DNP3, MODBUS TCP/IP, IEC 608705-104 protocols

• Configurable and up to 256 samples/cycle, 1 min duration recorder

• Front USB port for high speed data transfer

• Dedicated disturbance recorder for recording long term events

• 4096 lines of independent userprogrammable logic, 50 msec execution rate • Advanced math, Boolean and control operations

Specialized Protection & Control

Automation Controller

• Synchrophasors over Ethernet

Disturbance Recorder Eliminates Stand-Alone DFR and Phasor Measurement Unit

Real-Time Phasor Information of Fundamental and Sequence Components

Digital fault recorder summary with the latest information on events, faults, transients and disturbances.

Real-time display of the fundamental phasors of voltage and current in the front panel HMI.

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C90Plus Automation Control System

mm

mm

Dimensions mm mm

mm

mm

mm

mm

mm

mm mm

mm

mm

Typical Wiring Diagram

mm mm

Specialized Protection & Control

mm

mm

mm

mm

g

430

Multilin C90Plus Controller

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C90Plus Automation Control System

Technical Specifications AUTORECLOSURE Applications: Tripping schemes: Reclose attempts: Reclosing mode: Breaker sequence:

two breakers single-pole and three-pole up to 4 before lockout selectable selectable

AUXILIARY OVERVOLTAGE Pickup level: 0.000 to 1.100 pu in steps of 0.001 Dropout level: <98% of pickup Level accuracy: ±0.5% of reading from 10 to 208 V Pickup delay: 0.00 to 600.00 seconds in steps of 0.01 Reset delay: 0.00 to 600.00 seconds in steps of 0.01 Timing accuracy: ±3% of operate time or ±4 ms (whichever is greater) Operate time: <2 cycles at 1.10 × pickup at 60 Hz

AUXILIARY UNDERVOLTAGE Pickup level: 0.000 to 1.100 pu in steps of 0.001 Dropout level: >102% of pickup Level accuracy: ±0.5% of reading from 10 to 208 V Curve shapes: GE IAV inverse, definite time Curve multiplier: 0.00 to 600.00 in steps of 0.01 Timing accuracy: ±3% of operate time or ±4 ms (whichever is greater)

BREAKER FAILURE Mode: single-pole, three-pole Current supervision: phase current, neutral current Supervision pickup: 0.001 to 30.000 pu in steps of 0.001 Supervision dropout: <98% of pickup Supervision accuracy at 0.1 to 2.0 × CT: ±2% of rated Supervision accuracy at >2.0 × CT: ±2.5% of reading Time accuracy: ±3% or 4 ms (whichever is greater)

BREAKER FLASHOVER

CONTACT INPUTS Input rating: 300 V DC maximum On threshold: 70% of nominal voltage setting or 20 V (whichever is greater) Off threshold: 30% of nominal voltage setting or 15 V (whichever is greater) Bounce threshold: 50% of nominal voltage setting or 20 V (whichever is greater) AZ threshold: 80% of nominal voltage setting Overvoltage threshold: 130% of nominal voltage setting or 285 V maximum Maximum current: 10 mA during turn on, 0.5 mA steady-state Nominal voltage: 24 to 250 V Input impedance: active Recognition time: <1 ms Debounce timer: 1.50 to 16.00 ms in steps of 0.25 Chatter detection timer: 1 to 100 seconds Chatter state changes: 10 to 100

DISTURBANCE DETECTOR (50DD) Type: sensitive current disturbance detector Range: 0.004 to 0.04 pu (twice the current cut-off level threshold)

FLEXCURVES Number: Reset points: Operate points: Time delay:

4 (A through D) 40 (0 through 1 of pickup) 80 (1 through 20 of pickup) 0 to 65535 ms in steps of 1

FLEXELEMENTS Elements: 8 Operating signal: any analog actual value, or two values in differential mode Operating signal mode: signed or absolute value Operating mode: level, delta Comparator detection: over, under Pickup level: –90.000 to 90.000 pu in steps of 0.001 Hysteresis: 0.1 to 50.0% in steps of 0.1 Delta dt: 20 ms to 60 days Pickup delay: 0.000 to 65.535 seconds in steps of 0.001 Dropout delay: 0.000 to 65.535 seconds in steps of 0.001

GROUND TIME OVERCURRENT Current: phasor or RMS Pickup level: 0.000 to 30.000 pu in steps of 0.001 Dropout level: <98% of pickup Level accuracy at 0.1 to 2.0 × CT: ±0.5% of reading or ±1% of rated (whichever is greater) Level accuracy at >2.0 × CT: ±1.5% of reading Curve shapes: IEEE Moderately Inverse, IEEE Very Inverse, IEEE Extremely Inverse, IEC (BS) A, IEC (BS) B, IEC (BS) C, IEC Short Inverse, IAC Inverse, IAC Short Inverse, IAC Very Inverse, IAC Extremely Inverse, I2t, FlexCurves™ (programmable), definite time (0.01second base curve) Curve multiplier: 0.01 to 600.00 in steps of 0.01 Reset type: instantaneous/timed (per IEEE) Timing accuracy for 1.03 to 20 × pickup: ±3.5% of operating time or ±1 cycle (whichever is greater)

NEGATIVE-SEQUENCE DIRECTIONAL OVERCURRENT Directionality: co-existing forward and reverse Polarizing: voltage Polarizing voltage: V_2 Operating current: I_2 Level sensing (zero-sequence): |I_0| – K × |I_1| Level sensing (negative-sequence): |I_2| – K × |I_1| Restraint, K: 0.000 to 0.500 in steps of 0.001 Characteristic angle: 0 to 90° in steps of 1 Limit angle: 40 to 90° in steps of 1, independent for forward and reverse Angle accuracy: ±2° Offset impedance: 0.00 to 250.00 ohms in steps of 0.01 Pickup level: 0.05 to 30.00 pu in steps of 0.01 Dropout level: <98% Operation time: <16 ms at 3 × pickup at 60 Hz

NEGATIVE-SEQUENCE INSTANTANEOUS OVERCURRENT Pickup level: 0.000 to 30.000 pu in steps of 0.001 Dropout level: <98% of pickup Level accuracy at 0.1 to 2.0 × CT: ±0.5% of reading or ±1% of rated (whichever is greater) Level accuracy at >2.0 × CT: ±1.5% of reading Overreach: <2% Pickup delay: 0.00 to 600.00 seconds in steps of 0.01 Reset delay: 0.00 to 600.00 seconds in steps of 0.01 Operate time: <20 ms at 3 × pickup at 60 Hz Timing accuracy for operation at 1.5 × pickup: ±3% or ±4 ms (whichever is greater)

NEGATIVE-SEQUENCE OVERVOLTAGE Pickup level: Dropout level: Level accuracy: Pickup delay: Reset delay: Timing accuracy: Operate time:

0.000 to 1.250 pu in steps of 0.001 <98% of pickup ±0.5% of reading from 10 to 208 V 0.00 to 600.00 seconds in steps of 0.01 0.00 to 600.00 seconds in steps of 0.01 ±3% or ±20 ms (whichever is greater) < 30 ms at 1.10 × pickup at 60 Hz

NEGATIVE-SEQUENCE TIME OVERCURRENT Pickup level: 0.000 to 30.000 pu in steps of 0.001 Dropout level: <98% of pickup Level accuracy at 0.1 to 2.0 × CT: ±0.5% of reading or ±1% of rated (whichever is greater) Level accuracy at >2.0 × CT: ±1.5% of reading Curve shapes: IEEE Moderately Inverse, IEEE Very Inverse, IEEE Extremely Inverse, IEC (BS) A, IEC (BS) B, IEC (BS) C, IEC Short Inverse, IAC Inverse, IAC Short Inverse, IAC Very Inverse, IAC Extremely Inverse, I2t, FlexCurves™ (programmable), definite time (0.01 second base curve) Curve multiplier: 0.01 to 600.00 in steps of 0.01 Reset type: instantaneous/timed (per IEEE) and linear Timing accuracy for 1.03 to 20 × pickup: ±3.5% of operating time or ±1 cycle (whichever is greater)

NEUTRAL DIRECTIONAL OVERCURRENT

Number: up to 256 logical variables grouped under 16 Modbus addresses Programmability: any logical variable, contact, or virtual input

Directionality: co-existing forward and reverse Polarizing: voltage, current, dual Polarizing voltage: V_0 or VX Polarizing current: IG Operating current: I_0 Level sensing: 3 × (|I_0| – K × |I_1|), IG; independent for forward and reverse Restraint (K): 0.000 to 0.500 in steps of 0.001 Characteristic angle: –90 to 90° in steps of 1 Limit angle: 40 to 90° in steps of 1, independent for forward and reverse Angle accuracy: ±2° Offset impedance: 0.00 to 250.00 ohms in steps of 0.01 Pickup level: 0.002 to 30.000 pu in steps of 0.01 Dropout level: <98% Operation time: <16 ms at 3 × pickup at 60 Hz

GROUND INSTANTANEOUS OVERCURRENT

NEUTRAL INSTANTANEOUS OVERCURRENT

Pickup level: 0.000 to 30.000 pu in steps of 0.001 Dropout level: <98% of pickup Level accuracy at 0.1 to 2.0 × CT: ±0.5% of reading or ±1% of rated (whichever is greater) Level accuracy at >2.0 × CT: ±1.5% of reading Overreach: <2%

Pickup level: 0.000 to 30.000 pu in steps of 0.001 Dropout level: <98% of pickup Level accuracy at 0.1 to 2.0 × CT: ±0.5% of reading or ±1% of rated (whichever is greater) Level accuracy at >2.0 × CT: ±1.5% of reading Overreach: <2%

FLEXMATRIX Principle: aggregates and conditions signals for tripping and auxiliary functions Timing accuracy: ±1 ms

FLEX STATES

Specialized Protection & Control

Operating quantity: phase current, voltage, and voltage difference Pickup level voltage: 0.000 to 1.500 pu in steps of 0.001 Dropout level voltage: 97 to 98% of pickup Pickup level current: 0.000 to 1.500 pu in steps of 0.001 Dropout level current: 97 to 98% of pickup Level accuracy: ±0.5% or ±0.1% of rated (whichever is greater) Pickup delay: 0.000 to 65.535 seconds in steps of 0.001 Time accuracy: ±3% or ±42 ms (whichever is greater) Operate time: <42 ms at 1.10 × pickup at 60 Hz

Pickup delay: 0.00 to 600.00 seconds in steps of 0.01 Reset delay: 0.00 to 600.00 seconds in steps of 0.01 Operate time: <16 ms at 3 × pickup at 60 Hz Timing accuracy for operation at 1.5 × pickup: ±3% or ±4 ms (whichever is greater)

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C90Plus Automation Control System

Pickup delay: 0.00 to 600.00 seconds in steps of 0.01 Reset delay: 0.00 to 600.00 seconds in steps of 0.01 Operate time: <20 ms at 3 × pickup at 60 Hz Timing accuracy for operation at 1.5 × pickup: ±3% or ±4 ms (whichever is greater)

Supported operations: NOT, XOR, OR (2 to 16 inputs), AND (2 to 16 inputs), NOR (2 to 16 inputs), NAND (2 to 16 inputs), latch (reset-dominant), edge detectors, timers Inputs: any logical variable, contact, or virtual input Number of timers: 32 Pickup delay: 0 to 60000 (ms, seconds, or minutes) in steps of 1 Dropout delay: 0 to 60000 (ms, seconds, or minutes) in steps of 1

NEUTRAL OVERVOLTAGE Pickup level: 0.000 to 1.250 pu in steps of 0.001 Dropout level: <98% of pickup Level accuracy: ±0.5% of reading from 10 to 208 V Pickup delay: 0.00 to 600.00 seconds in steps of 0.01 (definite time) or user-defined curve Reset delay: 0.00 to 600.00 seconds in steps of 0.01 Timing accuracy: ±3% or ±20 ms (whichever is greater) Operate time: <3 cycles at 1.10 × pickup

NEUTRAL TIME OVERCURRENT Current: phasor or RMS Pickup level: 0.000 to 30.000 pu in steps of 0.001 Dropout level: <98% of pickup Level accuracy at 0.1 to 2.0 × CT: ±0.5% of reading or ±1% of rated (whichever is greater) Level accuracy at >2.0 × CT: ±1.5% of reading Curve shapes: IEEE Moderately Inverse, IEEE Very Inverse, IEEE Extremely Inverse, IEC (BS) A, IEC (BS) B, IEC (BS) C, IEC Short Inverse, IAC Inverse, IAC Short Inverse, IAC Very Inverse, IAC Extremely Inverse, I2t, FlexCurves™ (programmable), definite time (0.01 second base curve) Curve multiplier: 0.01 to 600.00 in steps of 0.01 Reset type: instantaneous/timed (per IEEE) Timing accuracy at 1.03 to 20 × pickup: ±3.5% of operating time or ±1 cycle (whichever is greater)

NON-VOLATILE LATCHES Type: set-dominant or reset-dominant Number: 16 (individually programmed) Output: stored in non-volatile memory Execution sequence: as input prior to protection, control, and FlexLogic

Specialized Protection & Control

Input points: 64 Programmability: self-reset or latched Output points: 96 Programmability: output of a protection FlexLogic equation or input to a protection FlexLogic equation

REMOTE INPUTS (IEC 61850 GSSE/GOOSE) Input points: 64 Remote devices: 32 Default states on loss of communications: on, off, latest/off, latest/on Remote double-points status inputs: 16

REMOTE OUTPUTS (IEC 61850 GSSE/GOOSE) Standard output points: 32 User output points: 32

SENSITIVE DIRECTIONAL POWER Measured power: three-phase, true RMS Stages: 2 Characteristic angle: 0 to 359° in steps of 1 Calibration angle: 0.00 to 0.95° in steps of 0.05 Minimum power: –1.200 to 1.200 pu in steps of 0.001 Pickup level accuracy: ±1% or ±0.001 pu (whichever is greater) Hysteresis: 2% or 0.001 pu (whichever is greater) Pickup delay: 0.00 to 600.00 seconds in steps of 0.01 Time accuracy: ±3% or ±4 ms (whichever is greater) Operate time: 50 ms

SMALL SIGNAL OSCILLATION DETECTOR

PHASE DIRECTIONAL OVERCURRENT Relay connection: 90° (quadrature) Quadrature voltage: phase A (VBC), phase B (VCA), phase C (VAB) for ABC phase sequence; phase A (VCB), phase B (VAC), phase C (VBA) for ACB phase sequence Polarizing voltage threshold: 0.000 to 3.000 pu in steps of 0.001 Current sensitivity threshold: 0.05 pu Characteristic angle: 0 to 359° in steps of 1 Angle accuracy: ±2° Tripping operation time: <12 ms, typically (reverse load, forward fault) Blocking operation time: <8 ms, typically (forward load, reverse fault)

PHASE INSTANTANEOUS OVERCURRENT

Measured value: any analog value Elements: 2 Inputs: 6 Minimum pickup: 0.02 to 10.00 pu in steps of 0.01 for alarm; 0.05 to 10.00 pu in steps of 0.01 for trip Pickup level accuracy: ±5% or ±0.1 pu (whichever is greater) Pickup delay: definite time, 0.00 to 600.00 seconds in steps of 0.01 Time accuracy: ±3% or ± 20 ms (whichever is greater) Operate time: 3 / (4 × fs) to 1 / fs, where fs is the signal frequency

VT FUSE FAILURE SUPERVISION Elements: 1 per source Monitored parameters: V_2, V_1, I_1

Automation

Pickup level: 0.000 to 30.000 pu in steps of 0.001 Dropout level: <98% of pickup Level accuracy at 0.1 to 2.0 × CT: ±0.5% of reading or ±1% of rated (whichever is greater) Level accuracy at >2.0 × CT: ±1.5% of reading Overreach: <2% Pickup delay: 0.00 to 600.00 seconds in steps of 0.01 Reset delay: 0.00 to 600.00 seconds in steps of 0.01 Operate time: <16 ms at 3 × pickup at 60 Hz Timing accuracy for operation at 1.5 × pickup: ±3% or ±4 ms (whichever is greater)

AUTOMATION LOGIC

PHASE OVERVOLTAGE Voltage: Pickup level: Dropout level: Level accuracy: Pickup delay: Operate time: Timing accuracy:

PROTECTION VIRTUAL INPUTS

phasor only 0.000 to 3.000 pu in steps of 0.001 <98% of pickup ±0.5% of reading from 10 to 208 V 0.00 to 600.00 seconds in steps of 0.01 <3 cycles at 1.10 × pickup ±3% or ±4 ms (whichever is greater)

PHASE TIME OVERCURRENT Current: phasor or RMS Pickup level: 0.000 to 30.000 pu in steps of 0.001 Dropout level: <98% of pickup Level accuracy at 0.1 to 2.0 × CT: ±0.5% of reading or ±1% of rated (whichever is greater) Level accuracy at >2.0 × CT: ±1.5% of reading Curve shapes: IEEE Moderately Inverse, IEEE Very Inverse, IEEE Extremely Inverse, IEC (BS) A, IEC (BS) B, IEC (BS) C, IEC Short Inverse, IAC Inverse, IAC Short Inverse, IAC Very Inverse, IAC Extremely Inverse, I2t, FlexCurves™ (programmable), definite time (0.01 second base curve) Curve multiplier: 0.01 to 600.00 in steps of 0.01 Reset type: instantaneous/timed (per IEEE) Timing accuracy at 1.03 to 20 × pickup: ±3.5% of operating time or ±1 cycle (whichever is greater)

PHASE UNDERVOLTAGE

Number of lines of logic: 4096 Number of blocks: 1 Edit and view capability: yes Logic type: cyclic Programming language: proprietary Execution rate: 50 ms Variable types: Boolean, IEEE floating point Boolean operations: NOT, XOR, OR, AND, NOR, NAND, any contact input, any direct input, any teleprotection input, any remote input, any virtual input, any automation logic operand Arithmetic operations: add, subtract, multiply, divide, negation, absolute value, square root, exponent, logarithm, sine, cosine, tangent, arcsine, arccosine, arctangent, natural logarithm, base 10 algorithm, modulo, ceiling, floor Control operations: latch, timer, comparator, absolute timer functions Boolean inputs: any contact input, direct input, teleprotection input, remote input, virtual input, or automation logic operand Analog inputs: any FlexAnalog™ quantity Virtual inputs: 128 Virtual outputs: 255 Remote inputs: 64 Remote outputs: 64 Remote devices: 32

AUTOMATION VIRTUAL INPUTS Input points: Programmability:

AUTOMATION VIRTUAL OUTPUTS Output points: 255 Programmability: output of an automation logic equation or input to an automation logic equation

BREAKER CONTROL Mode: Control: Control seal-in:

single-pole, three-pole open/close, local/SCADA 0 to 2000 ms in steps of 1

BREAKER INTERLOCKING

Pickup level: 0.000 to 1.100 pu in steps of 0.001 Dropout level: >102% of pickup Level accuracy: ±0.5% of reading from 10 to 208 V Curve shapes: GE IAV Inverse; Definite Time (0.1 second base curve) Curve multiplier: 0.00 to 600.00 in steps of 0.01 Timing accuracy for operation at <0.90 × pickup: ±3.5% of operate time or ±4 ms (whichever is greater)

Interlocking inputs:

PROTECTION FLEXLOGIC Programming: Reverse Polish Notation with graphical visualization (keypad programmable) Lines of code: 512 Internal variables: 64

432

128 self-reset or latched

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C90Plus Automation Control System

Metering

DISCONNECT CONTROL Mode: Control: Control seal-in:

single-pole, three-pole open/close, local/SCADA 0 to 2000 ms in steps of 1

CURRENT METERING

DISCONNECT INTERLOCKING Interlocking inputs:

3

FAST LOAD SHEDDING (FLS) Elements: 1 Algorithm: adaptive (using priorities) or static (using trip masks) Static mode scenarios: up to 32 Adaptive mode priorities: up to 128 Total of infeeds, loads, and aggregators monitored per C90Plus: up to 64 via communications plus 6 local infeeds or loads Infeeds: up to 32 Loads per end device: up to 6 per GOOSE data message Loads per C90Plus: up to 70 (up to 64 from end device, plus up to 6 from local contact input/output cards) Load groups: up to 32 Operate time: 1/8 power system cycle (exclusive of communications and end device delays) Power measurement updating: 250 ms Elements: 4 Minimum voltage: 0.10 to 1.25 pu in steps of 0.01 Pickup level: 0.10 to 15.00 Hz/s in steps of 0.01 Dropout level: pickup – 0.02 Hz/s Pickup delay: 0.00 to 99.99 seconds in steps of 0.001 Dropout delay: 0.00 to 99.99 seconds in steps of 0.001 Level accuracy: 30 mHz/s or 3.5% (whichever is greater) Time accuracy: ±3% or ±4 ms (whichever is greater) 95% settling time for df/dt: <24 cycles Operate time (typical): 6 cycles at 2 × pickup; 5 cycles at 3 × pickup; 4 cycles at 5 × pickup

SYNCHROCHECK Elements: 2 Maximum voltage difference: 0 to 100000 volts in steps of 1 Maximum angle difference: 0 to 100° in steps of 1 Maximum frequency difference: 0.00 to 2.00 Hz in steps of 0.01 Hysteresis for maximum frequency difference: 0.00 to 0.10 Hz in steps of 0.01 Dead source function: none, LV1 & DV2, DV1 & LV2, DV1 or DV2, DV1 xor DV2, DV1 & DV2 (L = live, D = dead)

UNDERFREQUENCY LOAD SHEDDING Elements: 10 Pickup level: 45.00 to 65.00 Hz in steps of 0.01 Dropout level: pickup level + 0.03 Hz Pickup delay: 0.00 to 99.99 seconds in steps of 0.01 Dropout delay: 0.00 to 99.99 seconds in steps of 0.01 Level accuracy: ±0.01 Hz Time accuracy: ±3% or 4 ms (whichever is greater) Operate time (typical): 4 cycles at –0.1 Hz/s change; 3.5 cycles at –0.3 Hz/s change; 3 cycles at –0.5 Hz/s change

BREAKER ARCING CURRENT Elements: 1 per breaker (to a maximum of 2) Principle: accumulates contact wear (Ixt), measures fault magnitude and duration Auxiliary contact compensation: 0 to 50 ms in steps of 1 Alarm threshold: 0 to 50000 kA2-cycle in steps of 1 Fault duration accuracy: 0.25 of power cycle

FREQUENCY METERING

Specialized Protection & Control

Upper position limit: 1 to 7 in steps of 1 Selecting mode: time-out or acknowledge Time-out timer: 3.0 to 60.0 seconds in steps of 0.1 Control inputs: step-up and three-bit Power-up mode: restore from non-volatile memory or synchronize to a three bit control input or synchronize/restore mode

Principle: monitors battery voltage and auxiliary alarms Hysteresis: 5% Timing accuracy: 1 cycle

Type: positive and negative watt-hours and var-hours Accuracy: ±2.0% of reading Range: –2.0 × 109 to 2.0 × 109 MWh/Mvarh Parameters: three-phase only Update rate: 50 ms

POWER METERING

SELECTOR SWITCH

BATTERY MONITOR

ENERGY METERING

Output format: per IEEE C37.118 standard Channels: 14 synchrophasors, 8 analogs, 16 digitals TVE (total vector error): <1% Triggering: frequency, voltage, current, power, rate of change of frequency, user-defined Reporting rate: 1, 2, 5, 10, 12, 15, 20, 25, 30, 50, or 60 times per second Number of clients: One over TCP/IP port, two over UDP/IP ports AC ranges: as indicated in appropriate specifications sections Network reporting format: 16-bit integer or 32-bit IEEE floating point numbers Network reporting style: rectangular (real and imaginary) or polar (magnitude and angle) coordinates Post-filtering: none, 3-point, 5-point, 7-point Calibration: ±5°

Minimum voltage pickup: 0.00 to 1.25 pu in steps of 0.01 Minimum voltage dropout: pickup + 0.20 pu Maximum negative-sequence voltage pickup: 0.00 to 1.25 pu in steps of 0.01 Maximum negative-sequence voltage dropout: pickup – 0.20 pu

Equipment Manager

Channels: 1 to 16 Parameters: any FlexAnalog value Statistics: maximum and time of maximum, minimum and time of minimum, average Alarms: high, high-high, low, low-low

PHASOR MEASUREMENT UNIT

LOAD SHEDDING SOURCE

Elements: 6 Pickup level: 0.10 to 1.25 pu in steps of 0.01 Dropout level: pickup level + 0.20 pu Pickup delay: 0.00 to 99.99 seconds in steps of 0.01 Dropout delay: 0.00 to 99.99 seconds in steps of 0.01 Level accuracy: ±0.5% of reading from 10 to 208 volts Time accuracy: ±3% or 4 ms (whichever is greater) Operate time (typical): 2 cycles at 0.90 × pickup

DATA LOGGER

Accuracy at V = 0.8 to 1.2 pu: ±0.001 Hz (when voltage signal is used for frequency measurement) Accuracy at I = 0.1 to 0.25 pu: ±0.05 Hz (when current signal is used for frequency measurement) Accuracy at I > 0.25 pu: ±0.001 Hz (when current signal is used for frequency measurement)

FREQUENCY RATE OF CHANGE LOAD SHEDDING

UNDERVOLTAGE LOAD SHEDDING

Type: phase and ground RMS current Accuracy at 0.1 to 2.0 × CT: ±0.25% of reading or ±0.1% of rated (whichever is greater) at 50/60 Hz nominal frequency Accuracy at >2.0 × CT: ±1.0% of reading, at 50/60 Hz nominal frequency

Real power accuracy: ±1.0% of reading at –1.0 ≤ PF < 0.8 and 0.8 < PF ≤ 1.0 Reactive power accuracy: ±1.0% of reading at –0.2 ≤ PF ≤ 0.2 Apparent power accuracy: ±1.0% of reading

VOLTAGE METERING Type: RMS voltage Accuracy: ±0.5% of reading from 30 to 208 volts at 50/60 Hz nominal frequency

Digital Fault Recorder DISTURBANCE RECORDER Storage capacity: one record with all available channels at 60 samples per second for 40 seconds Maximum records: 64 Sampling rate: 1 sample per cycle Sampling accuracy: <1 ms per second of recording Analog channels: 64 Analog channel data: any FlexAnalog™ quantity Digital channels: 32 Digital channel data: any contact input, direct input, remote input, virtual input, automation logic operand, or FlexLogic operand Triggers: any digital change of state (user-programmable), undervoltage, overvoltage, undercurrent, overcurrent, underfrequency, overfrequency, rate of change of frequency, 1 user-programmable trigger, 1 lock Storage modes: automatic overwrite, protected Triggering modes: time window from rising edge of trigger, continuous recording as long as trigger is active Pre-trigger window: 0 to 100% Data storage: non-volatile memory

EVENT RECORDER Storage capacity: 8192 events Time tag: to 1 ms Triggers: any contact input, direct input, remote input, virtual input, logic operand, or self-test event Data storage: non-volatile memory

FAULT REPORT Records: 5 Data: station and circuit ID, date and time of trip, fault type, active setting group at time of trigger, pre-fault current and voltage phasors (2 cycles before 50DD associated with fault report source), fault current and voltage phasors (1 cycle after trigger), protection elements operated at time of trigger, firmware revision Triggers: user-selected operand Data storage: non-volatile memory

FAULT LOCATOR Method: single-ended Accuracy: 2% of line length Units: miles or kilometers Trigger: from fault report Data storage: non-volatile memory

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433

C90Plus Automation Control System

FAST LOAD SHED REPORT

CONTACT INPUTS

Records: 16 Data: FLSC relay name, firmware revision, contingency date/time and duration, steadystate power flows, infeeds lost, scenarios encountered, load groups shed, settings last change date Triggers: any FLS contingency Data storage: non-volatile memory

Input rating: 300 V DC maximum Selectable thresholds: 24 to 250 V Maximum current: 10 mA during turn on, 0.5 mA steady-state Recognition time: <1 ms Debounce timer: 1.50 to 16.00 ms in steps of 0.25

TRANSIENT RECORDER Storage capacity: one record with all available channels at 32 samples per cycle for 1 minute Number of records: 1 to 64 Sampling rate: 16 to 256 samples per power cycle Timestamp accuracy: <10 μs per second of recording Analog channels: up to twelve 16-bit, unprocessed, AC input channels Analog channel data: any FlexAnalog quantity Digital channels: up to 128 Digital channel data: any contact input, direct input, remote input, virtual input, automation logic operand, or FlexLogic operand Sampled channels: up to 24 Sampled channel data: 16-bit, unprocessed sampled channels Triggers: any digital channel change of state, undervoltage, overvoltage, undercurrent, overcurrent, underfrequency, overfrequency, rate of change of frequency, one userprogrammable, one block Storage modes: automatic overwrite, protected Triggering modes: time window from rising edge of trigger, continuous recording as long as trigger is active Pre-trigger window: 0 to 100% Data storage: non-volatile memory

Front Panel Interface

Make and carry for 0.2 s: 10 A Continuous carry: 6A Break at L/R of 40 ms: 0.250 A at 125 V DC; 0.125 A at 250 V DC Operate time: <8 ms Contact material:

Inputs: 288 Windows per page: 12 to 48 Pages: up to 24 Sequence: manual reset, locking Off indication: alarm inactive and reset Flashing indication: alarm active and not acknowledged, alarm inactive and not acknowledged On indication: alarm active and acknowledged, alarm inactive and not reset Priority: by active window and page number Data storage: non-volatile memory

Make and carry for 0.2 s: 30 A per ANSI C37.90 Carry continuous: 6A Break at L/R of 40 ms: 0.250 A DC at 125 V DC; 0.125 A DC at 250 V DC Operate time: <4 ms Contact material: silver alloy

CONTACT OUTPUTS: SOLID-STATE RELAY Make and carry for 0.2 s: 30 A as per ANSI C37.90 Continuous carry: 6:00 AM Break at L/R of 40 ms: 10 A at 250 V DC Operate time: <100 μs Contact material: silver alloy Capacity: Isolation:

CRITICAL FAILURE RELAY Make and carry for 0.2 s: 30 A as per ANSI C37.90 Carry continuous: 6:00 AM Break at L/R of 40 ms: 0.250 A DC at 125 V DC; 0.125 A DC at 250 V DC; 0.10 A DC maximum at 125 V Operate time: <8 ms Contact material: silver alloy Standard: 1 port supporting Modbus TCP Optional: 2 ports supporting DNP 3.0, IEC 60870-5-104, or IEC 61850 located on communications module 100Base-FX media type: 1300 nm, multi-mode, half/full-duplex, fiber optic with ST connector 10/100Base-TX media type: RJ45 connector Power budget: 10 dB Maximum optical input power: –14 dBm Receiver sensitivity: –30 dBm Typical distance: 2.0 km SNTP clock synchronization: <10 ms typical

Devices: status and control of up to 8 power system devices Pushbuttons: 30 dedicated user-programmable pushbuttons Functionality: supports select-before-operate functionality

DIGITAL FAULT RECORDER DISPLAY Sequence of events: displays the stored sequence of events record Fault reports: display and retrieval of the critical metrics of a stored fault report Transient records: retrieval of a stored transient record Disturbance records: retrieval of a stored disturbance record Fast load shedding (FLS) records: retrieval of a stored FLS record

EQUIPMENT MANAGER DISPLAY Battery monitoring: displays the current battery voltage and alarm states

IRIG-B INPUT

METERING DISPLAY

Amplitude modulation: DC shift: Input impedance: Isolation:

Summary: displays present values of voltage, current, real power, reactive power, power factor, and frequency on a per-phase and total basis Phasors: digital and graphical display of present voltage and current magnitudes and angles Sequence components: displays present magnitudes and angles of current and voltage sequence components Energy: four-quadrant display of accumulated energy Demand: present and peak demand values for current and real, reactive, and apparent power Input and output status: displays the current status of all contact inputs and outputs

Hardware AC CURRENT CT rated primary: 1 to 50000 A CT rated secondary: 1 A or 5 A Nominal frequency: 50 or 60 Hz Relay burden: <0.2 VA secondary Conversion range: 0.02 to 46 × CT rating RMS symmetrical Current withstand: 20 ms at 250 × rated, 1 second at 100 × rated, continuous at 3 × rated

AC VOLTAGE VT rated secondary: 50.0 to 240.0 V VT ratio: 1.00 to 24000.0 Nominal frequency: 50 or 60 Hz Relay burden: <0.25 VA at 120 V Conversion range: 1 to 275 V Voltage withstand: continuous at 260 V to neutral, 1 minute per hour at 420 V neutral

434

100 mA DC at 48 V DC 2 kV

ETHERNET PORTS

CONTROL DISPLAY

MAINTENANCE DISPLAY

silver alloy

FORM-A RELAY

CONTROL POWER EXTERNAL OUTPUT

ANNUNCIATOR

Specialized Protection & Control

CONTACT OUTPUTS: CRITICAL FAILURE RELAY

1 to 10 V pk-pk TTL 50 kΩ 2 kV

POWER SUPPLY Nominal DC voltage: Minimum DC voltage: Maximum DC voltage: Nominal AC voltage: Minimum AC voltage: Maximum AC voltage: Voltage withstand: Voltage loss hold-up: Power consumption:

125 to 250 V 80 V 300 V 100 to 240 V at 50/60 Hz 80 V at 48 to 62 Hz 275 V at 48 to 62 Hz 2 × highest nominal voltage for 10 ms 200 ms duration at nominal 30 VA typical, 65 VA maximum

RS485 PORT Baud rates: 300, 600, 1200, 2400, 4800, 9600, 19200, 38400, 57600, 115200 Protocol: Modbus RTU and DNP 3.0 Distance: 1200 m Isolation: 2 kV

SOLID-STATE RELAY Make and carry for 0.2 s: 30 A as per ANSI C37.90 Carry continuous: 6A Break at L/R of 40 ms: 10.0 A DC at 250 V DC Operate time: < 100 μs

USB PORT Standard: type B USB connector for EnerVista software

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C90Plus Automation Control System

Communications

Tests

DIRECT INPUTS

PRODUCTION TESTS

Input points: 96 per channel Remote devices: 16 Default states on loss of communications: On, Off, Latest/On, Latest/Off Ring configuration: yes, no Data rate: 64 or 128 kbps CRC: 32-bit CRC alarm: responding to rate of messages failing the CRC CRC alarm monitoring message count: 10 to 10000 in steps of 1 CRC alarm threshold: 1 to 1000 in steps of 1 Unreturned messages alarm: responding to rate of unreturned messages in the ring Unreturned messages alarm monitoring message count: 10 to 10000 in steps of 1 Unreturned messages alarm threshold: 1 to 1000 in steps of 1

Thermal: products go through a 12 hour burn-in process at 60°C

TYPE TESTS Vibration: IEC 60255-21-1, 1G (class Bm) Shock / bump: IEC 60255-21-2, 10G (class Bm) Seismic (single axis): IEC 60255-21-3, 1G / 3.5 mm (class 1) Make and carry (30 A): IEEE C37.90 Conducted immunity: IEC 61000-4-6 / IEC 60255-22-6, class 3 (10 V RMS) Surge: IEC 61000-4-5 or IEC 60225-22-5, 1.2/50 test up to level 4 (4 kV) Burst disturbance (1 MHz oscillatory): IEC 60255-22-1 up to 2.5 kV at 1 MHz damped Fast transients: ANSI/IEEE C37.90.1, EC61000-4-4 class 4, (2 kV, 5 kHz / 4 kV, 2.5 kHz, 2 kV on data control ports and inputs/outputs), IEC 60255-22-4 Radiated immunity: IEC 61000-4-3 / IEC 60255-22-3 class 3 (10 V/m) or IEEE C37.90.2 radiated RFI (35 V/m) Power frequency disturbance: IEC 61000-4-8 (30 A/m) class 4 Radiated/conducted emissions: IEC 60255-25 / CISPR 11/22 class A Insulation resistance: IEC 60255-5 Dielectric strength: IEC 60255-5, ANSI/IEEE C37.90 Dielectric across relay contacts: IEEE C37.90 (1.6 kV) Electrostatic discharge: EN 61000-4-2, IEC 60255-22-2 8 kV C, 15 kV A, L4 Voltage dips/interruptions/variations: IEC 61000-4-11 (30% 1 cycle), IEC 60255-11 AC ripple: IEC 61000-4-17 (standard) Interruptions on DC power: IEC 61000-4-29 Damped magnetic immunity: IEC 61000-4-10 (level 5, 100A/m) Impulse voltage withstand: EN/IEC 60255-5 (5 kV) Humidity cyclic: IEC 60068-2-30, 6 days 55°C, 95%RH (variant 1)

DIRECT OUTPUTS Output points:

96 per channel

FAST LOAD SHEDDING (FLS) END DEVICE DATA UNITS (IEC 61850 GOOSE) Number: 64

MODBUS USER MAP Number: Programmability:

up to 256 Modbus addresses any setting or actual value in decimal

REMOTE INPUTS (IEC 61850 GSSE/GOOSE) Input points: 64 Remote devices: 32 Default states on loss of communications: On, Off, Latest/Off, Latest/On Remote double-point status inputs: 16

REMOTE OUTPUTS (IEC 61850 GSSE/GOOSE)

Environmental

Standard output points: 12A User output points: 32

Specialized Protection & Control

TELEPROTECTION

OPERATING TEMPERATURE

Input points: 16 per channel Remote devices: 3 Default states on loss of communications: On, Off, Latest/On, Latest/Off Ring configuration: No Data rate: 64 or 128 kbps CRC: 32-bit

Cold: Dry heat:

IEC 60068-2-1, 16 hours at –40°C IEC 60068-2-2, 16 hours at 80°C

OTHER ENVIRONMENTAL SPECIFICATIONS Altitude: Installation category: IP rating:

up to 2000 m II IP30 for front, IP10 for back

Approvals and Certification

Inter-Relay Communications TYPICAL DISTANCE

APPROVALS

RS422 interface: 1200 m (based on transmitter power; does not take into consideration the clock source provided by the user) G.703 interface: 100 m 850 nm laser (multimode) interface: 2.0 km (50/125 μm cable with ST connector); 2.9 km (62.5/125 μm cable with ST connector) NOTE: The typical distances shown are based on the assumptions for system loss shown below. As actual losses vary from one installation to another, the distance covered by your system may vary.

UL508 17th edition and C22.2 No.14-05: UL listed for the USA and Canada

CERTIFICATION CE LVD 2006/95/EC: CE EMC 89/336/EEC:

EN/IEC 61010-1:2001 / EN60255-5:2000 EN 60255-26:2004-08

LINK LOSSES (850 NM LASER, MULTIMODE MODULE) ST connector losses: 2 dB (total of both ends) 50/125 μm fiber loss: 2.5 dB/km 62.5/125 μm fiber loss: 3.0 dB/km Splice loss: one splice every 2 km, at 0.05 dB loss per splice System margin: 3 dB of additional loss was added to calculations to compensate for all other losses, including age and temperature

LINK POWER BUDGET (850 NM LASER, MULTIMODE MODULE) Maximum optical input power: –9 dBm Minimum transmit power: –22 dBm (into 50 μm fiber), –18 dBm (into 62.5 μm fiber) Maximum receiver sensitivity: –32 dBm Power budget: 10 dBm (for 50 μm fiber), 14 dBm (for 62.5 μm fiber) NOTE: These power budgets are calculated from the manufacturer’s worst-case transmitter power and worst-case receiver sensitivity.

Typical C90Plus Fast Load Shed Order Codes: Controller

Aggregator

GEDigitalEnergy.com

435

Ordering Base Unit Front Panel

C90P C90P

Language Protection

*

E

*

* ** *

*

X H *

*

*

*

*

* ** *

X A B C D E F

X A B C D E F

X A B C D E F

X A B C D E F

A H E X P O

Automation

S E L C A

Communications

Metering

Digital Fault Recorder Equipment Manager Harsh Environment Coating Power Supply Inter-relay Communications

Communications Module I/O Module

AC Module

Notes for Fast Load Shedding: Front Panel: Can be either A or H (HMI is an option) Automation: C or A for Controller or Aggregator Communication Module: Only option A available AC Module: X – none only option

*

01 02 03 04 A2 A3 A4 D S P L U S D X S X C H X B C D X A X A B C D E F X 01 02

Description Base Unit Annunciator Annunciator & HMI English None Basic Protection and Protection FlexLogic Basic protection, protection FlexLogic, small-signal oscillation detection Breaker Control & Synchrocheck Breaker Control, Synchrocheck, & Automation Controller Breaker Control, Synchrocheck, Automation Controller, & Load Shedding Fast load shedding (controller) Fast load shedding (aggregator) ModBus TCP/IP, DNP 3.0 Serial, and Serial Modbus ModBus TCP/IP & IEC 61850 ModBus TCP/IP, IEC 61850, & DNP 3.0 TCP/IP ModBus TCP/IP, IEC 61850, & IEC 60870-5-104 ModBus TCP/IP, IEC 61850 & PRP ModBus TCP/IP, IEC 61850, DNP 3.0 TCP/IP & PRP ModBus TCP/IP, IEC 61850, IEC 60870-5-104 & PRP No AC metering; data logger for non-metering data Basic Metering Basic Metering & Synchrophasors Basic Metering & Data Logger Basic Metering, Data Logger, & Synchrophasors Fault Recorder & Sequence of Events Fault Recorder, Sequence of Events, & Disturbance Recorder No equipment manager features Circuit breaker, communications statistics, and battery monitor None (Standard) Harsh Environment Conformal Coating High (88-275VAC/80-300VDCI) Reserved G.703, 64/128 kbps, two channels RS422, 64/128 kbps, two channels, two clock inputs 850 nm, 64/128 kbps, ST multi-mode laser, two channels with DDMI None Dual ST fiber and copper module None 8 Inputs, 4 Form-A Outputs with Voltage & Current Monitoring 8 Inputs, 4 Solid State Outputs with Voltage & Current Monitoring 8 Inputs, 4 Form-A Outputs 4 Inputs, 8 Form-A Outputs 23 Inputs 12 Form-A Outputs No AC module 5 VT & 7 CT (5 Amp current) 5 VT & 7 CT (1 Amp current)

Accessories for the C90Plus • • • • • • • • • • • • •

MultiLink Ethernet Switch Viewpoint Engineer Viewpoint Maintenance Viewpoint Monitoring IEC 61850 350 Feeder Protection 339 Motor Protection F35 Feeder Protection F60 Feeder Protection F650 Bay Controller 850 Feeder Protection 869 Motor Protection G30 Generator Protection G60 Generator Protection

ML3K-F-HX-A-B-E-E-W-W-Y-Y-X-X-X VPE-1 VPM-1 VP-1-61850 350-E-P5-G5-H-E-S-N-M-3E-D-N 339-E-P5-G5-H-E-S-N-M-3E-D-N F35-N03-VKH-F8L-H6P-MXX-PXX F60-N03-VKH-F8L-H6P-MXX-PXX F650-B-F-B-F-1-G-0-HI-6E 850-E-P5-NN-G5-H-N-N-A-N-N-G-S-S-B-B-SE-N-N-B-N 869-E-P5-NN-G5-H-R-R-A-N-N-G-S-P-B-B-SE-N-N-B-N G30-N03-VKH-F8L-H6P-M8L-PXX G60-N03-VKH-F8L-H6P-M8L-PXX

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Multilin™ C60 Breaker Monitoring and Control for Substation and Industrial Automation The Multilin C60 Breaker Protection System is a substation hardened controller that provides a complete integrated package for the protection, control, and monitoring of circuit breakers. The C60 supports dual-breaker busbar configurations such as breaker-and-a-half or ring bus arrangements. Signals from up to 4 sets of CT’s can be brought into the C60 for internal summation, which is advantageous by still having the individual currents available for metering and the additional protection elements that operate on individual currents. The C60 provides fast and deterministic execution of programmable logic and extensive I/O options that are necessary for substation automation applications. All of the necessary control logic functions are available for creating automated breaker control schemes, such as the popular main-tie-main scheme using a single C60 device. Using high-speed peer-to-peer communications for inter-device messaging, the C60 can also accept breaker opening, closing and lock-out commands from other devices at a fraction of the cost of hardwiring these signals.

Key Benefits • Complete breaker control, protection, monitoring and integration in a single platform • Advanced automation capabilities for providing customized protection and control solutions • Modular hardware architecture allows for flexibility in device configurations to cover most breaker applications • Advanced IEC 61850 Ed. 2 implementation, complete settings via SCL files and IEC 61850-9-2 process bus solution enable resource and platform managing optimization and reduce cost of ownership • Increased network availability via failover time reduced to zero through IEC® 62439-3 “PRP” support • CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog) • Advanced fault and disturbance recording, including internal relay operating signals, eliminating the need for external recording devices

Applications • Stand-alone breaker monitoring and control • Automatic bus transfer scheme using a single device • Multiple breaker configuration control including breaker-and-a-half and ring bus • As part of a distributed bay controller

Protection and Control • Breaker failure & Synchronism check • Autoreclose and open pole detector • Phase, neutral and auxiliary overvoltage • Sensitive directional power & dual breaker control

Communications • 3 independent Ethernet ports for simultaneous & dedicated network connections with IEEE  1588 support • Phasor Measurement Unit (Synchrophasor) according to IEEE® C37.118 (2011) and IEC  61850-90-5 • Supported industry protocols: IEC 61850 Ed. 2, SFTP, MMS File Transfer Service, DNP 3.0, Modbus Serial/TCP, IEEE 1588, IEC 60870-5-104 and 103, PRP, SNTP, HTTP, TFTP

Cyber Security • CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog) • Setting for security audit trails, tracking changes to device configurations

Monitoring & Metering • P & M Class Synchrophasors of voltage, current and sequence components • Fault Locator • Advanced recording capabilities with highcapacity event recorder, configurable and extended waveform capture and data logger • Metering: current, voltage, power, energy, frequency, and harmonics

C60 Breaker Protection System

Protection and Control

C60 - Protection, Metering, Monitoring and Control

As part of the UR family of Protection & Control devices, the Multilin C60 Breaker Protection System offers a high degree of modularity in its design and functionality, providing superior performance while meeting the toughest requirements of the marketplace. Advanced protection and control features of this relay includes:

Breaker Failure

Specialized Protection & Control

The breaker failure functions included in the C60 are available to detect breaker failure conditions for both single and three-pole tripping schemes. The C60 provides two independent breaker failure functions, and all of the current source inputs, digital inputs and digital outputs need to perform breaker failure functions on dual breaker schemes, such as breaker-and-a-half or ring bus arrangements. Breaker failure initiation and transfer tripping signals can be done using hardwired contacts or through communications (IEC 61850 and direct I/O).

The C60 is the single point for protection, control, metering, and monitoring in one integrated device that can easily be connected directly into DCS or SCADA monitoring and control systems like Viewpoint Monitoring as shown.

users to select the reclosure mode to suit specific applications. The autoreclose modes can be dynamically changed by any internal FlexLogic™ digital operand, allowing flexibility with changing system conditions.

Autorecloser The C60 provides multi-shot autoreclosing on all types of faults for single or three-pole applications with independent dead time for each shot . The protection settings can be changed between shots (typical application being an accelerated zone 1 extension scheme). Autoreclosure can also be dynamically blocked by user-programmable logic. Four different autoreclose modes are available, enabling

Synchrocheck The C60 provides four synchrocheck elements that monitor voltage difference, phase angle difference and slip frequency to ensure proper breaker closure as per user requirements. Any of the four synchrocheck elements can be

dynamically blocked or unblocked by other elements or user logic, allowing coordination with other C60 protection settings and groups. The C60 provides additional enhancements in synchronizing by checking dead source conditions for synchronism bypass under these conditions.

Overcurrent and Thermal Elements Overcurrent protection is delivered through instantaneous and time overcurrent elements available for phase, neutral, ground and

Functional Block Diagram ANSI® Device Numbers & Functions

59N 50P

51P

32

50BF

TRIP

49

2

2

METERING

CLOSE FlexElement

TRIP

50BF

51P 2

25

27

27X 2

79

50P

50NBF

2

59X

CLOSE

52

3

2

2

52

59P 2

Transducer Input

TM

50NBF

32 32

2

27

25 2

59N

C60 Breaker Protection System 438

ANSI DEVICE NUMBERS AND FUNCTIONS

GEDigitalEnergy.com

DEVICE NUMBER

FUNCTION

DEVICE NUMBER

25 27P 27X 32 50G 50N

Synchrocheck Phase Undervoltage Auxiliary Undervoltage Sensitive Directional Power Ground Instantaneous Overcurrent Neutral Instantaneous Overcurrent

50P BF Phase Instantaneous Overcurrent, Breaker Failure 51G Ground Time Overcurrent 51N Neutral Time Overcurrent 51P Phase Time Overcurrent 52 AC Circuit Breaker

FUNCTION

DEVICE NUMBER

FUNCTION

25(4) 27P 27X 32 49 50G 50N 50P 51G 51N 51P 59N 59P 59X 79 50BF 50NBF

Synchrocheck Phase Undervoltage Auxiliary Undervoltage Directional Power Thermal Overload Ground Instantaneous Overcurrent Neutral Instantaneous Overcurrent Phase Instantaneous Overcurrent Ground Time Overcurrent Neutral Time Overcurrent Phase Time Overcurrent Neutral Overvoltage Phase Overvoltage Auxiliary Overvoltage Autoreclose Breaker Failure Neutral Instantaneous Breaker Failure

C60 Breaker Protection System

sensitive ground protection. Most of the standard protection curves are provided. Thermal overload elements as per the IEC 255-8 standard are also available.

FlexLogic Designer

Sensitive Directional Power Two separate directional power elements are provided to detect reverse and low forward power conditions for use in IEEE 1547 DG interconnection anti-islanding protection.

Breaker Control

IEC 61850 Process Bus The IEC 61850 Process Bus module is designed to interface with the GE Multilin HardFiber System, allowing bi-directional IEC 61850 fiber optic communications. The HardFiber System is designed to integrate seamlessly with existing Universal Relay (UR) applications, including protection functions, FlexLogic, metering and communications. The GE Multilin HardFiber System offers the following benefits: • Communicates using open standard IEC 61850 messaging • Drastically reduces P&C design, installation and testing labor by eliminating individual copper terminations • Integrates with existing C60’s by replacing traditional CT/VT inputs with the IEC 61850 Process Bus module • Does not introduce new cyber security concerns Visit the HardFiber System product page on the GE Multilin web site for more details.

Advanced Automation The C60 incorporates advanced automation features including powerful FlexLogic programmable logic, communication, and SCADA capabilities that far surpass what is found in the average breaker relay or controller.

FlexLogic allows for the creation of customized C60 breaker control schemes, including the receipt of trip and close commands from other devices, and the creation of logic to replace the need for external lockout relays.

The C60 integrates seamlessly with other UR relays for complete breaker management including reclosing, load shedding, and synchronism applications.

FlexLogic FlexLogic is the powerful UR-platform programming logic engine that provides the ability to create customized protection and control schemes, minimizing the need and associated costs of auxiliary components and wiring. Using FlexLogic, the C60 can be programmed to provide the required logic for performing complete breaker control in schemes that may include simple single breaker management, equipment backup protection as well as sophisticated automatic transfer schemes.

Scalable Hardware The C60 is available with a multitude of I/O configurations to suit the most demanding application needs. The expandable modular design allows for easy configuration and future upgrades. • Multiple CT/VT configurations allow for the implementation of many different schemes, including single and dual breaker applications • Flexible, modular I/O covering a broad range of input signals and tripping schemes • RTDs and DCmA inputs are available to monitor equipment parameters such as temperature and pressure

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Monitoring and Metering The C60 includes high accuracy metering and recording for all AC signals. Voltage, current, and power metering are built into the relay as a standard feature. Current and voltage parameters are available as total RMS magnitude, and as fundamental frequency magnitude and angle.

Fault and Disturbance Recording The advanced disturbance and event recording features within the C60 can significantly reduce the time needed for postmortem analysis of power system events and the creation of regulatory reports. Recording functions include: • Sequence of Event (SOE) - 1024 time stamped events • Oscillography • - 64 digital & up to 40 analog channels - Events up to 45s in length • Data Logger and Disturbance Recording - 16 channels up to 1 sample/cycle/channel • Fault Reports - Powerful summary report of pre-fault and fault values The very high sampling rate and large amounts of storage space available for data recording in the C60 can eliminate the need for installing costly stand-alone recording equipment.

439

Specialized Protection & Control

The C60 allows for control of up to two breakers through commands given to it from either local or remote users. The C60 front panel can have 16 user-configurable pushbuttons that can be used to select and operate the breaker functions. Each button can be customized and labeled for easy operator identification. The C60 can also accept breaker operation commands from remote users through one of the many available communication protocols including Modbus, DNP 3.0, IEC 61850, and IEC  60870-5-104.

C60 Breaker Protection System

Advanced Device Health Diagnostics

Role Based Access Control (RBAC)

The C60 performs comprehensive device health diagnostic tests at startup and continuously during run-time to test its own major functions and critical hardware. These diagnostic tests monitor for conditions that could impact security and availability of protection, and present device status via SCADA communications and front panel display. Providing continuous monitoring and early detection of possible issues help improve system uptime.

Efficiently administrate users and roles within UR devices. The new and advanced access functions allow users to configure up to five roles for up to eight configurable users with independent passwords. The standard “Remote Authentication Dial In User Service” (Radius) is used for authentication.

• Comprehensive device health diagnostic performed at startup • Monitors the CT/VT input circuitry to validate the integrity of all signals

Cyber Security – CyberSentry UR

Specialized Protection & Control

CyberSentry UR enabled UR devices deliver full cyber security features that help customers to comply with NERC CIP and NIST® IR 7628 cyber security requirements. This software option delivers the following core features:

AAA Server Support (Radius/LDAP) Enables integration with centrally managed authentication and accounting of all user activities and uses modern industry best practices and standards that meet and exceed NERC CIP requirements for authentication and password management.

Event Recorder (Syslog for SEM) Capture all cyber security related events within a SOE element (login, logout, invalid password attempts, remote/local access, user in session, settings change, FW update, etc), and then serve and classify data by security level using standard Syslog data format. This will enable integration with established SEM (Security Event Management) systems.

and the embedded managed Ethernet switch provide the means to create fault tolerant communication architectures in an easy, cost-effective manner without the need for intermediary communication hardware. The C60 supports the most popular industry standard protocols enabling easy, direct integration into DCS and SCADA systems. • IEC 61850 Ed. 2 with 61850-9-2 and 6185090-5 support • DNP 3.0 (serial & TCP/IP) • Ethernet Global Data (EGD) • IEC 60870-5-103 and IEC 60870-5-104 • Modbus RTU, Modbus TCP/IP • HTTP, TFTP, SFTP and MMS file transfer • SNTP and IEEE 1588 for time synchronization • PRP as per IEC 62439-3

Communications The C60 provides advanced commun-ications technologies for remote data and engineering access, making it easy and flexible to use and integrate into new and existing infrastructures. Direct support for fiber optic Ethernet provides high-bandwidth communications allowing for low-latency controls and high-speed file transfers of relay fault and event record information. The available three independent Ethernet ports, redundant Ethernet option

Interoperability with Embedded IEC  61850 Edition 2 The new IEC 61850 implementation in the UR Family positions GE as an industry leader in this standard. • Implements Edition 2 of the standard across the entire family of UR devices • Provides full relay setting management via standard SCL files (ICD, CID and IID)

Power System Troubleshooting The C60 contains tools that allow for the early detection of impending breaker problems and allow for maintenance to be performed before serious damage occurs. Triggering a waveform on each breaker operation can identify changes in the length of time each part or mechanism in the breaker takes to perform its function. Breaker Latch Release Time: Indicates how long it took for the breaker latch to release from the time the trip coil was energized by the relay. Arc Extinguish Time: Indicates the length of time that was required for the breaker to extinguish the arc and finally clear the fault. Breaker Mechanism Travel Time: Indicates time interval required for the breaker mechanism to travel to its rest position.

440

GEDigitalEnergy.com

C60 Breaker Protection System

• Enables automated relay setting management using 3rd party tools through standard file transfer services (MMS and SFTP) • Increases the number of Logical Devices and data mapped to them, GOOSE messages, and reports to support different organizational needs for data transfer and reduce dependency on generic logical nodes • Configures GE Systems based on IEC 61850 using universal 3rd party tools • Multicast IEEE C37.118 synchrophasor data between PMU and PDC devices using IEC  91850-90-5

Direct I/O Messaging Direct I/O allows for the sharing of high-speed digital information between multiple UR relays via direct back-to-back connections or multiplexed through a standard DS0 multiplexer channel bank. Regardless of the connection method, direct I/O provides continuous real-time channel monitoring that supplies diagnostics information on channel health.

front panel, in the EnerVista setup software, and in the product manuals. Easily switch between English and an additional language on the local displays without uploading new firmware.

• Connect to standard DS0 channel banks through standard RS422, G.703 or IEEE C37.94 interfaces or via direct fiber optic connections

EnerVista Software

• No external or handheld tester required to provide channel diagnostic information

LAN Redundancy Substation LAN redundancy has been traditionally accomplished by reconfiguring the active network topology in case of failure. Regardless of the type of LAN architecture (tree, mesh, etc), reconfiguring the active LAN requires time to switchover, during which the LAN is unavailable. UR devices deliver redundancy as specified by PRP-IEC 62439-3, which eliminates the dependency on LAN reconfiguration and the associated switchover time. The UR becomes a dual attached node that transmits data packets over both main and redundant networks simultaneously, so in case of failure, one of the data packets will reach the receiving device with no time delay.

Multi-Language UR devices support multiple languages: English, French, Russian, Chinese, Turkish and German. These language options are available on the

Simplifying Fault and Disturbance Analysis

The EnerVist suite is an industry-leading set of software programs that simplifies every aspect of using the C60 relay. The EnerVista suite provides all the tools to monitor the status of the protected asset, maintain the relay, and integrate information measured by the C60 into DCS or SCADA monitoring systems. Convenient COMTRADE and SOE viewers are an integral part of the UR setup software included with every UR relay, to carry out postmortem event analysis to ensure proper protection system operation.

EnerVista Launchpad EnerVista Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining GE Multilin products. The setup software within Launchpad allows for the configuration of devices in real-time by communicating using serial, Ethernet , or modem connections, or offline by creating setting files to be sent to devices at a later time. Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed. Documents made available include: • Manuals • Application Notes • Guideform Specifications • Brochures • Wiring Diagrams • FAQ’s • Service Bulletins

The events recorded in multiple GE devices can be collected and merged into a single station-wide SOE record to simplify the tracking of substation operations.

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441

Specialized Protection & Control

Direct I/O provides superior relay-to-relay communications that can be used in advanced interlocking, generation rejection and other special protection schemes.

• Communication with up to 16 UR relays in single or redundant rings rather than strictly limited to simplistic point-to-point configurations between two devices

C60 Breaker Protection System

Viewpoint Monitoring

EnerVista Integrator

Viewpoint Monitoring is a simple-to-use and full-featured monitoring and data recording software package for small systems. Viewpoint Monitoring provides a complete HMI package with the following functionality:

EnerVista Integrator is a toolkit that allows seamless integration of GE Multilin devices into new or existing automation systems. Included in EnerVista Integrator is:

• Plug-&-Play Device Monitoring • System Single-Line Monitoring & Control • Annunciator Alarm Screens • Trending Reports • Automatic Event Retrieval • Automatic Waveform Retrieval

• OPC/DDE Server • GE Multilin Drivers • Automatic Event Retrieval • Automatic Waveform Retrieval

User Interface The C60 front panel provides extensive local HMI capabilities. The local display is used for monitoring, status messaging, fault diagnosis, and device configuration. User-configurable messages that combine text with live data can be displayed when user-defined conditions are met.

Viewpoint UR Engineer Viewpoint UR Engineer is a set of powerful tools that allows the configuration and testing of GE relays at a system level in an easy-touse graphical drag-and-drop environment . Viewpoint UR Engineer provides the following configuration and commissioning utilities:

48 Configurable LED Indicators

Multi-Language Display • English

Specialized Protection & Control

• Graphical Logic Designer

• Russian

• Graphical System Designer

• French

• Graphical Logic Monitor

• Chinese

• Graphical System Monitor

Viewpoint Maintenance Viewpoint Maintenance provides tools that will create reports on the operating status of the relay, simplify the steps to download fault and event data, and reduce the work required for cyber security compliance audits. Tools available in Viewpoint Maintenance include:

• Turkish • German User-Programmable Pushbuttons

• Settings Security Audit Report • Device Health Report • Single-Click Fault Data Retrieval

442

GEDigitalEnergy.com

C60 Breaker Protection System

Typical Wiring

52

52

V I

2

V I

3

V I

4

10BaseFL 10BaseFL

Rx2

CRITICAL FAILURE

M 4b

M 4c

IG

IG1

P1a P1b P1c P2a P2b P2c P3a P3b P3c P4a P4b P4c

TC 1

TC 2

UR

Multilin TXD RXD

OUTPUT

C60

CONTROL POWER

SGND

SURGE FILTER

NORMAL ALTERNATE

V

H1a H1b H1c H2a H2b H2c H3a H3b H3c H4a H4b H4c

1

SURGE

Rx1

1 2 3 4 5 6 7 8 9

CONNECTOR

COMPUTER

1 2 3 4 5 6 7 8 9

8 3 RXD 2 TXD 20 7 SGND 6 4 5 22

CONNECTOR

COM 1

RS-232

10BaseT

D1a D2a D3a D4b D4a

I

1

B1b B1a B2b B3a B3b B5b HI B6b LO B6a B8a B8b

Shielded

V

6G

P8b

Remote Device

V I

H4 SURGE

P7a P7c P8a P8c P7b

Tx1

M 3c I

H3

P5a P5c P6a P6c P5b

Tx2

V

M 4a

IC

I

H2

H8b

Fibre * Optic

V

IG5

M 3a

M 3b

IC5

H1

H7a H7c H8a H8c H7b

DC

I

6G

Specialized Protection & Control

H5a H5c H6a H6c H5b

IC1

M 2b

M 2c

IB

IB1

M 1c

M 2a

IA1

IA

IB5

M 1a

M 1b

IA5

M 8a

VC

M 8c

M 7a

M 7c

VC

M 6a

M 6c VB

VA

VB

M 5a

M 5c

VA

F 4b

IG5

F 4c

IC1

IG

F 3c

F 4a

IC

IG1

F 3a

F 3b

IC5

F 2b

F 2c

IB

IB1

F 1c

F 2a

IA1

IA

IB5

F 1a

F 1b

IA5

F 8a

F 8c VX

VC

VX

F 7a

F 7c

VC

F 6a

F 6c VB

VA

VB

F 5a

F 5c

VA

VX

CONNECTION

CONNECTION

VX

A B C

DB-9 RS485

(front)

com

Co-axial

BNC

Co-axial

BNC

PERSONAL COMPUTER

IRIG-B Input IRIG-B Output

Minimum

X PROVIDED

W

V

U

T

S

R

P

N

M

6

8

Inputs/ outputs

CT/VT

L

K

J

H 6

G

F 8

Inputs/ CT/VT outputs

D

B

9

1

CPU

Power Supply

C60-H00-HCL-F8F-H6G-M8F-P6G

GEDigitalEnergy.com

443

Ordering C60 - * ** - H * * - F ** - H ** - M ** - P ** - U ** - W ** For Full Sized Horizontal Mount C60 - * ** - V F * - F ** - H ** - M ** # ** For Reduced Size Vertical Mount Base Unit C60 Base Unit CPU E RS485 + RS485 (IEC 61850 option not available) J RS485 + multimode ST 100BaseFX K RS485 + multimode ST Redundant 100BaseFX N RS485 + 10/100BaseT T RS485 + three multimode SFP LC 100BaseFX. Req FW v7xx or higher U RS485 + two multimode SFP LC 100BaseFX + one SFP RJ45 100BaseT. Req FW v7xx or higher V RS485 + three SFP RJ45 100BaseT. Req FW v7xx or higher Software Options 00 No Software Options (see note 1 below) 01 Ethernet Global Data 03 IEC 61850 04 Ethernet Global Data 14 2 x PMU 15 IEC 61850 + 2 x PMU A0 CyberSentry UR Lvl 1. Req UR FW 7.xx or higher B0 IEEE 1588. Req UR FW 7.xx or higher C0 PRP D0 IEEE 1588 + CyberSentry UR. Req UR FW 7.xx or higher M2 IEC 61850 + 2 x PMU + 61850-90-5 Mount H Horizontal (19" rack) - Standard A Horizontal (19" rack) - Harsh Chemical Environment Option V Vertical (3/4 size) - Standard B Vertical (3/4 size) - Harsh Chemical Environment Option User Interface F Vertical Front Panel with English Display I Enhanced German Front Panel J Enhanced German Front Panel with User-Programmable Pushbuttons K Enhanced English Front Panel L Enhanced English Front Panel with User-Programmable Pushbuttons M Enhanced French Front Panel N Enhanced French Front Panel with User-Programmable Pushbuttons Q Enhanced Russian Front Panel T Enhanced Russian Front Panel with User-Programmable Pushbuttons U Enhanced Chinese Front Panel V Enhanced Chinese Front Panel with User-Programmable Pushbuttons W Enhanced Turkish Front Panel Y Enhanced Turkish Front Panel with User-Programmable Pushbuttons Power Supply H 125 / 250 V AC/DC (see note 2 below) H RH 125/250 V AC/DC with redundant 125/250 V AC/DC power supply L 24 - 48 V (DC only) CT/VT DSP 8L 8L Standard 4CT/4VT w/ enhanced diagnostics 8M 8M Sensitive Ground 4CT/4VT w/ enhanced diagnostics 8N 8N Standard 8CT w/ enhanced diagnostics 8R 8R Sensitive Ground 8CT w/ enhanced diagnostics IEC 61850 Process Bus 81 8 Port IEC 61850 Process Bus Module Digital I/O XX XX XX XX XX No module 4A 4A 4A 4A 4A 4 Solid State (No Monitoring) MOSFET Outputs 4C 4C 4C 4C 4C 4 Solid State (Current w/opt Voltage) MOSFET Outputs 4L 4L 4L 4L 4L 14 Form-A (No Monitoring) Latchable Outputs 67 67 67 67 67 8 Form-A (No Monitoring) Outputs 6C 6C 6C 6C 6C 8 Form-C Outputs 6D 6D 6D 6D 6D 16 Digital Inputs 6E 6E 6E 6E 6E 4 Form-C Outputs, 8 Digital Inputs 6F 6F 6F 6F 6F 8 Fast Form-C Outputs 6K 6K 6K 6K 6K 4 Form-C & 4 Fast Form-C Outputs 6L 6L 6L 6L 6L 2 Form-A (Current w/ opt Voltage) & 2 Form-C Outputs, 8 Digital Inputs 6M 6M 6M 6M 6M 2 Form-A (Current w/ opt Voltage) & 4 Form-C Outputs, 4 Digital Inputs 6N 6N 6N 6N 6N 4 Form-A (Current w/ opt Voltage) Outputs, 8 Digital Inputs 6P 6P 6P 6P 6P 6 Form-A (Current w/ opt Voltage) Outputs, 4 Digital Inputs 6R 6R 6R 6R 6R 2 Form-A (No Monitoring) & 2 Form-C Outputs, 8 Digital Inputs 6S 6S 6S 6S 6S 2 Form-A (No Monitoring) & 4 Form-C Outputs, 4 Digital Inputs 6T 6T 6T 6T 6T 4 Form-A (No Monitoring) Outputs, 8 Digital Inputs 6U 6U 6U 6U 6U 6 Form-A (No Monitoring) Outputs, 4 Digital Inputs 6V 6V 6V 6V 6V 2 Form-A (Cur w/ opt Volt) 1 Form-C Output, 2 Latching Outputs, 8 Digital Inputs Transducer I/O 5A 5A 5A 5A 5A 4 dcmA Inputs, 4 dcmA Outputs 5C 5C 5C 5C 5C 8 RTD Inputs 5D 5D 5D 5D 5D 4 RTD Inputs, 4 dcmA Outputs 5E 5E 5E 5E 5E 4 dcmA Inputs, 4 RTD Inputs 5F 5F 5F 5F 5F 8 dcmA Inputs Inter-Relay Communications 2B IEEE C37.94, 1300nm, singlemode, ELED, 2 Channel 2I Channel 1 - IEEE C37.94, 820nm, multimode fiber, 64/128 kbps; Channel 2 - 1300 nm, singlemode, LASER 2J Channel 1 - IEEE C37.94, 820nm, multimode fiber, 64/128 kbps; Channel 2 - 1550 nm, singlemode, LASER 7A 820 nm, multimode, LED, 1 Channel 7B 1300 nm, multimode, LED, 1 Channel 7C 1300 nm, singlemode, ELED, 1 Channel 7H 820 nm, multimode, LED, 2 Channels 7I 1300 nm, multimode, LED, 2 Channels 7J 1300 nm, singlemode, ELED, 2 Channels 7S G.703, 2 Channels 7W RS422, 2 Channels 77 IEEE C37.94, 820 nm, multimode, LED, 2 Channel

Ordering Notes: 1. To view all the options available for C60, please visit GE’s On-Line Store at http://store.gedigitalenergy.com/viewprod.asp?model=C60 2. Redundant power supply only available in horizontal unit. If redundant is chosen, must be same type. Maximum 2 per chassis

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Multilin™ C30 Substation Hardened Programmable Logic Controller The Multilin C30 controller system is a substation hardened device designed to perform substation control logic that can also expand the I/O capability of protection devices and replace existing SOE recorders. The C30 provides fast and deterministic execution of programmable logic with I/O capabilities far above an average protection relay. Graphical programming tools, supported by a library of logic operators, make the C30 simple to use and configure. Using high-speed peer-to-peer communications for inter-device messaging, the C30 can also accept signals and commands from other protection and control devices at a fraction of the cost of hard-wiring these signals.

Key Benefits • Powerful and deterministic programmable logic suitable for creating most customized automated substation control solutions • Modular hardware architecture allowing for flexibility in the I/O configuration to support most bay management applications • Reduced bay or station wiring through the use of high-speed peer-to-peer communication for sending and accepting control commands from other relays • Simplified system integration and access to information through the use of multiple communication options and protocols not found in industrial grade PLCs • Advanced IEC 61850 Ed. 2 implementation, complete settings via SCL files and IEC 61850-9-2 process bus solution enable resource and platform managing optimization and reduce cost of ownership • Increased network availability via failover time reduced to zero through IEC® 62439-3 “PRP” support • CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog) • Advanced fault and disturbance recording, including internal relay operating signals, eliminating the need for external recording devices

Applications • Bay control and substation automation • Programmable logic control • UR I/O expansion • Sequence of Events (SOE) recorder replacement

Protection and Control • Programmable logic, timers, counters • Distributed logic, remote I/O expansion • User-definable protection elements • Up to 96 digital inputs and 64 digital outputs • Transducer I/Os (RTD, DCmA)

Advanced Communications • 3 independent Ethernet ports for simultaneous & dedicated network connections with IEEE 1588 support • Advanced IEC 61850 Edition 2 implementation and IEC 61850-9-2 process bus support • Supported industry protocols: IEC 61850 Ed. 2, SFTP, MMS File Transfer Service, DNP 3.0, Modbus Serial/TCP, IEEE 1588, IEC 60870-5104 and 103, PRP, SNTP, HTTP, TFTP • Direct I/O: secure, high-speed exchange of data between UR relays for Direct Transfer Trip and I/O extension applications

Cyber Security • CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog) • Setting for security audit trails, tracking changes to device configurations

Monitoring & Metering • Advanced recording capabilities with highcapacity event recorder, configurable and extended waveform capture and data logger • Metering: current, voltage, power, energy, frequency, and harmonics

C30 Controller System

Protection and Control As part of the UR family of Protection & Control devices, the Multilin C30 offers a high degree of modularity in its design and functionality, providing superior performance while meeting the toughest requirements of the marketplace. Control, automation, I/O expansion and data gathering are ideally suited for the C30 in the following applications: • Bay control • Substation automation • Remote I/O

Advanced Automation

Specialized Protection & Control

The C30 incorporates advanced automation features including powerful FlexLogic™ programmable logic, peer-to-peer communications and SCADA capabilities that far surpass what is found in the average PLC or controller. The C30 integrates seamlessly with other UR relays to extend the I/O capabilities and perform complete bay management and control.

FlexLogic FlexLogic is the powerful UR-platform programming logic engine that provides the ability to create customized protection and control schemes minimizing the need and the associated costs of auxiliary components and wiring. The execution of all logic is performed every 2ms regardless of the complexity or amount of logic used, providing the determinist operation required for utility power system control schemes.

Scalable Hardware The C30 is available with a multitude of I/O configurations to suit the most demanding application needs. The expandable modular design allows for easy configuration and future upgrades. • Flexible, modular I/O covering a broad range of input signals and tripping schemes • RTDs and DCmA inputs are available to monitor equipment parameters such as temperature and pressure

IEC 61850 Process Bus The IEC 61850 Process Bus module is designed to interface with the Multilin HardFiber System, allowing bi-directional IEC 61850 fiber optic communications. The HardFiber System is designed to integrate seamlessly with existing UR applications, including protection functions, FlexLogic, metering and communications.

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The C30 is a complete solution for controlling and monitoring substation devices and can easily be connected directly into DCS or SCADA monitoring and control systems like Viewpoint Monitoring as shown.

The Multilin HardFiber System offers the following benefits: • Communicates using open standard IEC 61850 messaging • Drastically reduces P&C design, installation and testing labor by eliminating individual copper terminations • Integrates with existing C30’s by replacing traditional CT/VT inputs with the IEC 61850 Process Bus module • Does not introduce new cyber security concerns Visit the HardFiber System product page on the GE Digital Energy web site for more details.

Monitoring and Metering The C30 provides high resolution measuring of the status of external devices wired to its contact inputs. The changing of a contact input status can be measured and time-stamped with a 0.5ms resolution, making the C30 ideal for bay or substation SOE recording.

Fault and Disturbance Recording The advanced disturbance and event recording features within the C30 can significantly reduce the time needed for postmortem analysis of power system events and the creation of regulatory reports.

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Advanced Device Health Diagnostics The C30 performs comprehensive device health diagnostic tests at startup and continuously during run-time to test its own major functions and critical hardware. These diagnostic tests monitor for conditions that could impact security and availability of protection, and present device status via SCADA communications and front panel display. Providing continuous monitoring and early detection of possible issues help improve system uptime.

Cyber Security – CyberSentry UR CyberSentry UR enabled UR devices deliver full cyber security features that help customers to comply with NERC CIP and NIST® IR 7628 cyber security requirements. wThis software option delivers the following core features:

AAA Server Support (Radius/LDAP) Enables integration with centrally managed authentication and accounting of all user activities and uses modern industry best practices and standards that meet and exceed NERC CIP requirements for authentication and password management.

Role Based Access Control (RBAC) Efficiently administrate users and roles within UR devices. The new and advanced access functions allow users to configure up to five roles for up to eight configurable users with

C30 Controller System

independent passwords. The standard “Remote Authentication Dial In User Service” (Radius) is used for authentication.

Event Recorder (Syslog for SEM) Capture all cyber security related events within a SOE element (login, logout, invalid password attempts, remote/local access, user in session, settings change, FW update, etc), and then serve and classify data by security level using standard Syslog data format. This will enable integration with established SEM (Security Event Management) systems.

Communications

The C30 supports the most popular industry standard protocols enabling easy, direct integration into DCS and SCADA systems. • IEC 61850 Ed. 2 with 61850-9-2 support • DNP 3.0 (serial & TCP/IP) • Ethernet Global Data (EGD) • IEC 60870-5-103 and IEC 60870-5-104 • Modbus RTU, Modbus TCP/IP • HTTP, TFTP, SFTP and MMS file transfer • SNTP and IEEE 1588 for time synchronization • PRP as per IEC 62439-3

Interoperability with Embedded IEC 61850 Edition 2 The new IEC 61850 implementation in the UR Family positions GE as an industry leader in this standard: • Implements Edition 2 of the standard across the entire family of UR devices • Provides full relay setting management via standard SCL files (ICD, CID and IID) • Enables automated relay setting management using 3rd party tools through standard file transfer services (MMS and SFTP)

• Configures GE Systems based on IEC 61850 using universal 3rd party tools

Direct I/O Messaging Direct I/O allows for the sharing of high-speed digital information between multiple UR relays via direct back-to-back connections or multiplexed through a standard DS0 multiplexer channel bank. Regardless of the connection method, direct I/O provides continuous real-time channel monitoring that supplies diagnostics information on channel health. Direct I/O provides superior relay-to-relay communications that can be used in advanced interlocking, generation rejection and other special protection schemes. • Communication with up to 16 UR relays in single or redundant rings rather than strictly limited to simplistic point-to-point configurations between two devices • Connect to standard DS0 channel banks through standard RS422, G.703 or IEEE C37.94 interfaces or via direct fiber optic connections • No external or handheld tester required to provide channel diagnostic information

EnerVista Software The EnerVista suite is an industry-leading set of software programs that simplifies every aspect of using the C30 relay. The EnerVista suite provides all the tools to monitor the status of the protected asset, maintain the relay, and integrate information measured by the C30 into DCS or SCADA monitoring systems. Convenient COMTRADE and SOE viewers are an integral part of the UR setup software included with every UR relay, to carry out postmortem event analysis and ensure proper protection system operation.

EnerVista Launchpad EnerVista Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining Multilin products. The setup software within Launchpad allows for the configuration of devices in real-time by communicating using serial, Ethernet , or modem connections, or offline by creating setting files to be sent to devices at a later time.

Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed. Documents made available include: • Manuals • Application Notes

LAN Redundancy

• Guideform Specifications

Substation LAN redundancy has been traditionally accomplished by reconfiguring the active network topology in case of failure. Regardless of the type of LAN architecture (tree, mesh, etc), reconfiguring the active LAN requires time to switchover, during which the LAN is unavailable. UR devices deliver redundancy as specified by PRP-IEC 62439-3, which eliminates the dependency on LAN reconfiguration and the associated switchover time. The UR becomes a dual attached node that transmits data packets over both main and redundant networks simultaneously, so in case of failure, one of the data packets will reach the receiving device with no time delay.

• Brochures

Multi-Language

• Trending Reports

UR devices support multiple languages: English, French, Russian, Chinese, Turkish and German. These language options are available on the front panel, in the EnerVista setup software, and in the product manuals. Easily switch between English and an additional language on the local displays without uploading new firmware.

• Automatic Event Retrieval

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• Wiring Diagrams • FAQs • Service Bulletins

Viewpoint Monitoring Viewpoint Monitoring is a simple-to-use and full-featured monitoring and data recording software package for small systems. Viewpoint Monitoring provides a complete HMI package with the following functionality: • Plug-&-Play Device Monitoring • System Single-Line Monitoring & Control • Annunciator Alarm Screens

• Automatic Waveform Retrieval

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Specialized Protection & Control

The C30 provides advanced communications technologies for remote data and engineering access, making it easy and flexible to use and integrate into new and existing infrastructures. Direct support for fiber optic Ethernet provides high-bandwidth communications allowing for low-latency controls and high-speed file transfers of relay fault and event record information. The available three independent Ethernet ports, redundant Ethernet option and the embedded managed Ethernet switch provide the means to create fault tolerant communication architectures in an easy, cost-effective manner without the need for intermediary communication hardware.

• Increases the number of Logical Devices and data mapped to them, GOOSE messages, and reports to support different organizational needs for data transfer and reduce dependency on generic logical nodes

C30 Controller System

Viewpoint UR Engineer Viewpoint UR Engineer is a set of powerful tools that allows the configuration and testing of GE relays at a system level in an easy-to-use graphical drag-and-drop environment. Viewpoint UR Engineer provides the following configuration and commissioning utilities: • Graphical Logic Designer • Graphical System Designer • Graphical Logic Monitor • Graphical System Monitor

Viewpoint Maintenance Viewpoint Maintenance provides tools that will create reports on the operating status of the relay, simplify the steps to download fault and event data, and reduce the work required for cyber security compliance audits. Tools available in Viewpoint Maintenance include: • Settings Security Audit Report

Specialized Protection & Control

• Device Health Report • Single-Click Fault Data Retreival

EnerVista Integrator EnerVista Integrator is a toolkit that allows seamless integration of Multilin devices into new or existing automation systems. Included in EnerVista Integrator is: • OPC/DDE Server • Multilin Drivers • Automatic Event Retrieval • Automatic Waveform Retrieval

The Viewpoint Monitoring software can merge the events logged by the C30 with those logged in other Multilin relays to create a station-wide SOE record.

User Interface The C30 front panel provides extensive local HMI capabilities. The local display is used for monitoring, status messaging, fault diagnosis, and device configuration. User-configurable messages that combine text with live data can be displayed when user-defined conditions are met.

48 Configurable LED Indicators

Multi-Language Display • English • Russian • French • Chinese • Turkish • German User-Programmable Pushbuttons

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C30 Controller System

Typical Wiring

W3a W3c W4a W4c W3b

U3a U3c U4a U4c U3b

W5a W5c W6a W6c W5b

U5a U5c U6a U6c U5b

W7a W7c W8a W8c W7b W8b

C30 CONTROLLER 6E

H1

SURGE

6K

SURGE

P3

H3

P4

H4

P5

P6

P7

SURGE

6B

I

H1

V

6G

I

H1a H1b H1c H2a H2b H2c H3a H3b H3c H4a H4b H4c H5a H5b H5c H6a H6b H6c H7a H7c H8a H8c H7b

M1

V I

M2

I

H2

V

V I

M3

H3

V I

M4

H4

V

H5

H6

Specialized Protection & Control

P8

H8b

M1a M1b M1c M2a M2b M2c M3a M3b M3c M4a M4b M4c M5a M5c M6a M6c M5b

M7a M7c M8a M8c M7b SURGE

H8b

M8b

UR

SURGE

CRITICAL FAILURE

TXD RXD

1

B 1b B 1a B 2b B 3a B 3b B5b HI B 6b LO B 6a B 8a B 8b

DC

P1a P1b P1c P2a P2b P2c P3a P3b P3c P4a P4b P4c P5a P5b P5c P6a P6b P6c P7a P7b P7c P8a P8b P8c

P1

P2

H2

H7a H7c H8a H8c H7b

TC 2

U7a U7c U8a U8c U7b U8b

Multilin

H1a H1b H1c H2a H2b H2c H3a H3b H3c H4a H4b H4c H5a H5c H6a H6c H5b

TC 1

U1a U1c U2a U2c U1b

6D

6D

W1a W1c W2a W2c W1b

SGND

OUTPUT CONTROL POWER SURGE FILTER

1 2 3 4 5 6 7 8 9

COMPUTER

1 2 3 4 5 6 7 8 9

8 3 RXD 2 TXD 20 7 SGND 6 4 5 22

CONNECTOR

Fibre * Optic

Tx1

10BaseFL Rx1

Tx2

10BaseFL Rx2

Shielded Remote Device

RS-232

NORMAL ALTERNATE

DB-9 COM 1

(front)

10BaseT

D1a D2a D3a D4b D4a

RS485 com

Co-axial

BNC

Co-axial

BNC

IRIG-B Input IRIG-B Output

Minimum

X PROVIDED

W

U

V

Input/ Input/ output output

*

*

T

S

R

P

N

M

L

K

Input/ Input/ output output

*

*

GEDigitalEnergy.com

J

F

D

B

6 6 Input/ Input/ output output

H

G

9

1 Power Supply

CPU

C30-H00-HCH-F6B-H6E-M6G-P6K-U6D-W6D

*

449

Ordering C30 - * ** - H * * - F ** - H ** - M ** - P ** - U ** - W ** For Full Sized Horizontal Mount C30 Base Unit CPU E RS485 + RS485 J RS485 + multimode ST 100BaseFX K RS485 + multimode ST Redundant 100BaseFX N RS485 + 10/100 BaseT T RS485 + three multimode SFP LC 100BaseFX. Req FW v7xx or higher U RS485 + two multimode SFP LC 100BaseFX + one SFP RJ45 100BaseT. Req FW v7xx or higher V RS485 + three SFP RJ45 100BaseT. Req FW v7xx or higher Software Options 00 No Software Options (see note 1 below) 01 Ethernet Global Data 03 IEC 61850 04 Ethernet Global Data (EGD) + IEC 61850 A0 CyberSentry UR Lvl 1. Req UR FW 7.xx or higher B0 IEEE 1588. Req UR FW 7.xx or higher C0 PRP D0 IEEE 1588 + CyberSentry UR. Req UR FW 7.xx or higher Mount/Coating H Horizontal (19” rack) - Standard A Horizontal (19” rack) - Harsh Chemical Environment Option V Vertical (3/4 size) - Standard B Vertical (3/4 size) - Harsh Chemical Environment Option User Interface F Vertical Front Panel with English Display I Enhanced German Front Panel J Enhanced German Front Panel with User-Programmable Pushbuttons K Enhanced English Front Panel L Enhanced English Front Panel with User-Programmable Pushbuttons M Enhanced French Front Panel N Enhanced French Front Panel with User-Programmable Pushbuttons Q Enhanced Russian Front Panel T Enhanced Russian Front Panel with User-Programmable Pushbuttons U Enhanced Chinese Front Panel V Enhanced Chinese Front Panel with User-Programmable Pushbuttons W Enhanced Turkish Front Panel Y Enhanced Turkish Front Panel with User-Programmable Pushbuttons Power Supply H 125 / 250 V AC/DC (see note 2 below) H RH 125/250 V AC/DC with redundant 125/250 V AC/DC power supply L 24 - 48 V (DC only) IEC 61850 Process Bus 81 8 Port IEC 61850 Process Bus Module Digital I/O XX XX XX XX XX XX No module 4A 4A 4A 4A 4A 4A 4 Solid State (No Monitoring) MOSFET Outputs 4B 4B 4B 4B 4B 4B 4 Solid State (Voltage w/opt Current) MOSFET Outputs 4C 4C 4C 4C 4C 4C 4 Solid State (Current w/opt Voltage) MOSFET Outputs 4D 4D 4D 4D 4D 4D 16 Digital Inputs with Auto-Burnish 4L 4L 4L 4L 4L 4L 14 Form-A (No Monitoring) Latchable Outputs 67 67 67 67 67 67 8 Form-A (No Monitoring) Outputs 6A 6A 6A 6A 6A 6A 2 Form-A (Voltage w/ opt Current) & 2 Form-C Outputs, 8 Digital Inputs 6B 6B 6B 6B 6B 6B 2 Form-A (Voltage w/ opt Current) & 4 Form-C Outputs, 4 Digital Inputs 6C 6C 6C 6C 6C 6C 8 Form-C Outputs 6D 6D 6D 6D 6D 6D 16 Digital Inputs 6E 6E 6E 6E 6E 6E 4 Form-C Outputs, 8 Digital Inputs 6F 6F 6F 6F 6F 6F 8 Fast Form-C Outputs 6G 6G 6G 6G 6G 6G 4 Form-A (Voltage w/ opt Current) Outputs, 8 Digital Inputs 6H 6H 6H 6H 6H 6H 6 Form-A (Voltage w/ opt Current) Outputs, 4 Digital Inputs 6K 6K 6K 6K 6K 6K 4 Form-C & 4 Fast Form-C Outputs 6L 6L 6L 6L 6L 6L 2 Form-A (Current w/ opt Voltage) & 2 Form-C Outputs, 8 Digital Inputs 6M 6M 6M 6M 6M 6M 2 Form-A (Current w/ opt Voltage) & 4 Form-C Outputs, 4 Digital Inputs 6N 6N 6N 6N 6N 6N 4 Form-A (Current w/ opt Voltage) Outputs, 8 Digital Inputs 6P 6P 6P 6P 6P 6P 6 Form-A (Current w/ opt Voltage) Outputs, 4 Digital Inputs 6R 6R 6R 6R 6R 6R 2 Form-A (No Monitoring) & 2 Form-C Outputs, 8 Digital Inputs 6S 6S 6S 6S 6S 6S 2 Form-A (No Monitoring) & 4 Form-C Outputs, 4 Digital Inputs 6T 6T 6T 6T 6T 6T 4 Form-A (No Monitoring) Outputs, 8 Digital Inputs 6U 6U 6U 6U 6U 6U 6 Form-A (No Monitoring) Outputs, 4 Digital Inputs 6V 6V 6V 6V 6V 6V 2 Form-A (Cur w/ opt Volt) 1 Form-C Output, 2 Latching Outputs, 8 Digital Inputs Transducer I/O 5A 5A 5A 5A 5A 5A 4 dcmA Inputs, 4 dcmA Outputs 5C 5C 5C 5C 5C 5C 8 RTD Inputs 5D 5D 5D 5D 5D 5D 4 RTD Inputs, 4 dcmA Outputs 5E 5E 5E 5E 5E 5E 4 dcmA Inputs, 4 RTD Inputs 5F 5F 5F 5F 5F 5F 8 dcmA Inputs Inter-Relay Communications 2A C37.94SM, 1300nm singlemode, ELED, 1 Channel singlemode 2B C37.94SM, 1300nm singlemode, ELED, 2 Channel singlemode 2I Channel 1 - IEEE C37.94, 820nm, multimode fiber, 64/128 kbps; Channel 2 - 1300 nm, singlemode, LASER 2J IEEE C37.94, 820 nm, multimode, LED, 2 Channels 7A 820 nm, multimode, LED, 1 Channel 7B 1300 nm, multimode, LED, 1 Channel 7C 1300 nm, singlemode, ELED, 1 Channel 7H 820 nm, multimode, LED, 2 Channels 7I 1300 nm, multimode, LED, 2 Channels 7J 1300 nm, singlemode, ELED, 2 Channels 7R G.703, 1 Channel 7S G.703, 2 Channels 7T RS422, 1 Channel 7W RS422, 2 Channels 76 IEEE C37.94, 820 nm, multimode, LED, 1 Channel 77 IEEE C37.94, 820 nm, multimode, LED, 2 Channels 76 IEEE C37.94, 820 nm, multimode, LED, 1 Channel 77 IEEE C37.94, 820 nm, multimode, LED, 2 Channels

Ordering Notes: 1. T o view all the options available for C30, please visit GE’s On-Line Store at http://store. gedigitalenergy.com/viewprod.asp?model=C30 2. R  edundant power supply only available in horizontal unit. If redundant is chosen, must be same type. Maximum 2 per chassis

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Multilin™ C70 Capacitor Bank Protection & Control

Protection and Control

The Multilin C70 is an integrated protection, control, and monitoring device for shunt capacitor banks based on the well established and proven Multilin Universal Relay (UR) platform. The C70 provides both the bank and system protection schemes for shunt capacitor bank protection. The current and voltagebased protection functions are designed to provide sensitive protection for grounded, ungrounded single, and parallel capacitor banks and banks with taps, for a variety of capacitor bank configurations. The sophisticated built-in control functions can be used to automate capacitor switching with ease and flexibility for automatic voltage regulation of the system.

• Voltage differential protection and compensated bank neutral voltage unbalance

In addition, the C70 comes with a variety of versatile features truly integrating protection, monitoring, metering, communication and control in one easy-to-use device.

• Capacitor control supervision block for processing commands from SCADA, remote communication and local control through front panel HMI

Key Benefits

• AVR for switching capacitor banks based on voltage, power factor and reactive power • Time and date function allowing capacitor bank switching, based on time of day, week and seasons

• Comprehensive capacitor bank protection for a variety of configurations with sensitive current and voltage balance protection functions

Communications

• Adaptive compensation techniques truly compensate for the inherent bank unbalance, providing sensitive protection

• 3 independent Ethernet ports for simultaneous & dedicated network connections with IEEE 1588 support

• Custom programmable logic for advanced shunt capacity bank controls • Flexible automatic voltage regulation of shunt capacitor banks along with control supervision • Advanced IEC 61850 Ed. 2 implementation, complete settings via SCL files and IEC 61850-9-2 process bus solution enable resource and platform managing optimization and reduce cost of ownership • Increased network availability via failover time reduced to zero through IEC® 62439-3 “PRP” support

• Supported industry protocols: IEC 61850 Ed  .2, SFTP, MMS File Transfer Service, DNP 3.0, Modbus Serial/TCP, IEEE 1588, IEC 60870-5-104 and 103, PRP, SNTP, HTTP, TFTP

• CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog)

Cyber Security

• Advanced fault and disturbance recording, including internal relay operating signals, eliminating the need for external recording devices

• CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog)

Applications

• Setting for security audit trails, tracking changes to device configurations

• Protection, control, monitoring and automation of shunt capacitor banks at different voltage levels • Sensitive protection for grounded and ungrounded single and parallel capacitor banks and banks with taps, for a variety of capacitor bank configurations

Monitoring & Metering

• Suitable for protecting multiple capacitor banks

• Advanced recording capabilities with highcapacity event recorder, configurable and extended waveform capture and data logger

• Capacitor bank-based automatic voltage regulator (AVR) and capacitor control supervision

• Metering: current, voltage, power, energy, frequency, and harmonics

C70 Capacitor Bank Protection and Control System

Introduction Part of the Multilin UR family of Protection & Control devices, the Multilin C70 Capacitor Bank Protection and Control System offers a high degree of modularity in its design and functionality, providing superior performance while meeting the toughest requirements of the marketplace. Coupled with the unparalleled EnerVista software toolsets, common architecture and user-friendly interfaces helps managing the relay and the power system in the easiest way. Advanced protection and control features of the Multilin C70 Capacitor Bank Protection and Control System includes:

Specialized Protection & Control

Protection C70 provides sensitive protection functions designed specifically to protect the shunt capacitor banks effectively. The C70 provides current-based protection functions, which include phase, ground, and neutral instantaneous and time overcurrent elements for standard overcurrent protection of the bank. Two elements per configured CT bank are available.

Apart from the standard current and voltagebased functions, the C70 comes with protection functions specifically designed to provide sensitive protection for capacitor banks in a single box. Typical configurations with their associated model numbers are shown.

Voltage Differential • Applicable for both grounded and ungrounded banks. In the ungrounded case, the algorithm uses the neutral point voltage to provide sensitive protection. • Based on a simple voltage divider principle, which compares the bus voltage with the tap voltage of the bank. • Three-phase element with four independent stages for alarming and control. Each stage has independent per-phase settings and a common time delay. • Provision to set the per-phase voltage divider factors manually, or by selecting the autosetting feature. The voltage divider factor can be calculated automatically under user supervision either locally or remotely. • One voltage differential element provided per VT bank up to a maximum of three.

The standard current-based protection functions include:

Compensated Bank Neutral Voltage Unbalance

• Phase instantaneous overcurrent (50P)

• Applicable to ungrounded banks.

• Phase time overcurrent (51P)

• Truly compensates for both the system unbalance and the bank unbalance.

• Phase directional (67P) • Thermal overload (49) • Ground instantaneous overcurrent (50G) • Ground time overcurrent (51G) • Neutral instantaneous overcurrent (50N) • Neutral time overcurrent (51N) • Neutral directional overcurrent with dual polarity criteria (67N) • Negative sequence instantaneous overcurrent (50_2) • Negative sequence time overcurrent (51_2) • Negative sequence directional overcurrent (67_2) The C70 also provides breaker failure protections and standard voltage-based protection functions which include: • Phase overvoltage (59P) • Phase undervoltage (27P) • Auxiliary overvoltage (59X) • Neutral overvoltage (59N) • Negative sequence undervoltage (27N)

452

• Each element has four independent stages; each stage has an independent threshold, restraint slope, and time delay. • Provisions to set the inherent bank unbalance factors manually, or by selecting the autosetting feature. The bank unbalance factor can be calculated automatically under user supervision either locally or remotely.

Bank Phase Overvoltage • Applicable for both grounded and ungrounded banks. In the latter case the relay takes the neutral point voltage in order to derive the voltage drop across the capacitor strings. • Three-phase elements with three definite time stages and three inverse time stages. • One bank overvoltage element provided per VT bank up to a maximum of three.

Phase Current Unbalance • Based on the balance between phase currents of two parallel banks and is applicable to both grounded and ungrounded banks. • SCompensates for bank unbalances to provide better sensitivity.

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• Three-phase element with four independent stages for protection and alarming. Each stage has independent per-phase settings and a common time delay. • Provision to set the current divider factor individually, per-phase, manually, or by selecting the auto-setting feature. The current divider factor can be calculated automatically under user supervision either locally or remotely. • Immune to system transients, providing secure operation without resorting to any excessive filtering. • One phase current unbalance element is provided per CT/VT module up to a maximum of three.

Neutral Current Unbalance • Based on the balance between the interconnected neutral current of two parallel banks and is applicable to both grounded and ungrounded banks. • Grounded banks require a window CT. • Each element has four independent stages; each stage has independent threshold and time delay settings. • Provision to set the bank unbalance factors manually, or by selecting the auto-setting feature. The bank unbalance factor can be calculated automatically under user supervision either locally or remotely. • One neutral current unbalance element provided per CT/VT module, up to a maximum of three.

Control The C70 is provided with built-in control functions to help end users build capacitor bank control schemes of their choice with ease and  flexibility.

Automatic Voltage Regulator The AVR is a capacitor bank controller responding to either voltage, reactive power, or power factor. One AVR element is provided per CT/VT module, up to a maximum of three. The AVRs can operate independently, each on their own section of the bank, or on only the one set for present conditions/time-of-day, as determined by FlexLogic™ (user programmable logic). For the voltage control path, a provision is made to operate from any phase-phase voltage (VAB, VBC, VCA), average voltage (VAVER), positive-sequence voltage (V1) or the single-phase auxiliary voltage. Two applications using the reactive power/power factor path are shown below.

C70 Capacitor Bank Protection and Control System

Typical Application: Ungrounded wye banks with taps Typical Model No: C70-N03-HPH-F8L-H6P-M8L-PXX-UXX-WXX

Typical Application: Ungrounded wye banks

Typical Application: Ungrounded, parallel banks Typical Model No: C70-N03-HPH-F8N-H6P-M8L-PXX-UXX-WXX

Specialized Protection & Control

Typical Application: Grounded, parallel banks Typical Model No: C70-N03-HPH-F8L-H6P-M8N-PXX-UXX-WXX

Typical Model No: C70-N03-HPH-F8L-H6P-MXX-PXX-UXX-WXX

Typical Application: Grounded wye banks with taps Typical Model No: C70-N03-HPH-F8L-H6P-M8V-PXX-UXX-WXX

Typical Application: Grounded, parallel banks with taps Typical Model No: C70-N03-HPH-F8N-H6P-M8L-PXX-U8V-WXX

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C70 Capacitor Bank Protection and Control System

optic communications. The HardFiber System is designed to integrate seamlessly with existing UR applications, including protection functions, FlexLogic, metering and communications. The GE Multilin HardFiber System offers the following benefits: • Communicates using open standard IEC 61850 messaging • Drastically reduces P&C design, installation and testing labor by eliminating individual copper terminations • Integrates with existing C70’s by replacing traditional CT/VT inputs with the IEC 61850 Process Bus module

Specialized Protection & Control

Time and Date Function • Provides the user with ability to program certain actions based on time.

Using FlexLogic, the C70 can be programmed to provide required tripping logic along with custom scheme logic for dynamic setting group changes.

• 5 time of day timers.

Scalable Hardware

• User-accessible time/date information for more sophisticated custom schemes, that respond to weekdays, weekends, summer or winter.

The C70 is available with a multitude of I/O configurations to suit the most demanding application needs. The expandable modular design allows for easy configuration and future upgrades.

Capacitor Control Supervision This feature supervises the capacitor bank open and close commands from the command sources, including the relay front panel HMI (push buttons), AVR and SCADA/HMI.

Advanced Automation The C70 incorporates advanced automation features including powerful FlexLogic programmable logic, communication, and SCADA capabilities that far surpass what is found in the average capacitor bank relay. The C70 integrates seamlessly with other UR relays for complete system protection.

• Does not introduce new cyber security concerns Visit the HardFiber System product page on the GE Multilin web site for more details.

Monitoring and Metering

• Multiple CT/VT configurations allow for the implementation of many different schemes

The C70 includes high accuracy metering and recording for all AC signals. Voltage, current , and power metering are built into the relay as a standard feature. Current and voltage parameters are available as total RMS magnitude, and as fundamental frequency magnitude and angle.

• Flexible, modular I/O covering a broad range of input signals and tripping schemes

Fault and Disturbance Recording

• RTDs and DCmA inputs are available to monitor equipment parameters such as temperature and pressure

IEC 61850 Process Bus The IEC 61850 Process Bus module is designed to interface with the GE Multilin HardFiber System, allowing bi-directional IEC 61850 fiber

The advanced disturbance and event recording features within the C70 can significantly reduce the time needed for postmortem analysis of power system events and the creation of regulatory reports. Recording functions include: • Sequence of Event (SOE) - 1024 time stamped events • Oscillography • - 64 digital & up to 40 analog channels - Events with up to 45s length

FlexLogic

• Data Logger and Disturbance Recording - 16 channels up to 1 sample/cycle/channel

FlexLogic is the powerful UR-platform programming logic engine that provides the ability to create customized protection and control schemes, minimizing the need and associated costs of auxiliary components and wiring.

• Fault Reports - Powerful summary report of pre-fault and fault values The very high sampling rate and large amount of storage space available for data recording in the C70 can eliminate the need for installing costly stand-alone recording equipment.

Advanced Device Health Diagnostics

Capacitor control supervision block

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The C70 performs comprehensive device health diagnostic tests at startup and continuously during run-time to test its own major functions and critical hardware. These diagnostic tests

C70 Capacitor Bank Protection and Control System

FlexLogic Designer

• Modbus RTU, Modbus TCP/IP • HTTP, TFTP, SFTP and MMS file transfer • SNTP and IEEE 1588 for time synchronization • PRP as per IEC 62439-3

Interoperability with Embedded IEC 61850 Edition 2 The new IEC 61850 implementation in the UR Family positions GE as an industry leader in this standard. • Implements Edition 2 of the standard across the entire family of UR devices • Provides full relay setting management via standard SCL files (ICD, CID and IID) • Enables automated relay setting management using 3rd party tools through standard file transfer services (MMS and SFTP) FlexLogic allows for the customization of the C70 outputs for capacitor bank protection schemes and applications.

• Comprehensive device health diagnostic performed at startup • Monitors the CT/VT input circuitry to validate the integrity of all signals

Cyber Security – CyberSentry UR CyberSentry UR enabled UR devices deliver full cyber security features that help customers to comply with NERC CIP and NIST® IR 7628 cyber security requirements. This software option delivers the following core features:

AAA Server Support (Radius/LDAP) Enables integration with centrally managed authentication and accounting of all user activities and uses modern industry best practices and standards that meet and exceed NERC CIP requirements for authentication and password management.

Role Based Access Control (RBAC) Efficiently administrate users and roles within UR devices. The new and advanced access functions allow users to configure up to five roles for up to eight configurable users with independent passwords. The standard “Remote Authentication Dial In User Service” (Radius) is used for authentication.

Event Recorder (Syslog for SEM) Capture all cyber security related events within a SOE element (login, logout, invalid password attempts, remote/local access, user in session, settings change, FW update, etc), and then serve and classify data by security level using standard Syslog data format. This will enable integration with established SEM (Security Event Management) systems.

Communications The C70 provides advanced commun-ications technologies for remote data and engineering access, making it easy and flexible to use and integrate into new and existing infrastructures. Direct support for fiber optic Ethernet provides high-bandwidth communications allowing for low-latency controls and high-speed file transfers of relay fault and event record information. The available three independent Ethernet ports, redundant Ethernet option and the embedded managed Ethernet switch provide the means to create fault tolerant communication architectures in an easy, cost-effective manner without the need for intermediary communication hardware. The C70 supports the most popular industry standard protocols enabling easy, direct integration into DCS and SCADA systems. • IEC 61850 Ed. 2 with 61850-9-2 support • DNP 3.0 (serial & TCP/IP) • Ethernet Global Data (EGD) • IEC 60870-5-103 and IEC 60870-5-104

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• Configures GE Systems based on IEC 61850 using universal 3rd party tools

Direct I/O Messaging Direct I/O allows for the sharing of high-speed digital information between multiple UR relays via direct back-to-back connections or multiplexed through a standard DS0 multiplexer channel bank. Regardless of the connection method, direct I/O provides continuous real-time channel monitoring that supplies diagnostics information on channel health. Direct I/O provides superior relay-to-relay communications that can be used in advanced interlocking, generation rejection and other special protection schemes. • Communication with up to 16 UR relays in single or redundant rings rather than strictly limited to simplistic point-to-point configurations between two devices • Connect to standard DS0 channel banks through standard RS422, G.703 or IEEE C37.94 interfaces or via direct fiber optic connections • No external tester required to provide channel diagnostic information

LAN Redundancy Substation LAN redundancy has been traditionally accomplished by reconfiguring the active network topology in case of failure. Regardless of the type of LAN architecture (tree, mesh, etc), reconfiguring the active LAN requires time to switchover, during which the LAN is

455

Specialized Protection & Control

monitor for conditions that could impact security and availability of protection, and present device status via SCADA communications and front panel display. Providing continuous monitoring and early detection of possible issues help improve system uptime.

• Increases the number of Logical Devices and data mapped to them, GOOSE messages, and reports to support different organizational needs for data transfer and reduce dependency on generic logical nodes

C70 Capacitor Bank Protection and Control System

unavailable. UR devices deliver redundancy as specified by PRP-IEC 62439-3, which eliminates the dependency on LAN reconfiguration and the associated switchover time. The UR becomes a dual attached node that transmits data packets over both main and redundant networks simultaneously, so in case of failure, one of the data packets will reach the receiving device with no time delay.

Multi-Language UR devices support multiple languages: English, French, Russian, Chinese, Turkish and German. These language options are available on the front panel, in the EnerVista setup software, and in the product manuals. Easily switch between English and an additional language on the local displays without uploading new firmware.

Specialized Protection & Control

EnerVista Software The EnerVista suite is an industry-leading set of software programs that simplifies every aspect of using the C70 relay. The EnerVista suite provides all the tools to monitor the status of the protected asset, maintain the relay, and integrate information measured by the C70 into DCS or SCADA monitoring systems. Convenient COMTRADE and SOE viewers are an integral part of the UR setup software included with every UR relay, to carry out postmortem event analysis and ensure proper protection system operation.

EnerVista Launchpad

Viewpoint UR Engineer

EnerVista Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining GE Multilin products. The setup software within Launchpad allows for the configuration of devices in real-time by communicating using serial, Ethernet , or modem connections, or offline by creating setting files to be sent to devices at a later time.

Viewpoint UR Engineer is a set of powerful tools that allows the configuration and testing of GE relays at a system level in an easy-touse graphical drag-and-drop environment . Viewpoint UR Engineer provides the following configuration and commissioning utilities:

Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed. Documents made available include: • Manuals

• Brochures

• Application Notes

• Wiring Diagrams

• Guideform Specifications

• FAQ’s • Service Bulletins

• Graphical Logic Designer

• Graphical Logic Monitor

• Graphical System Designer

• Graphical System Monitor

User Interface The C70 front panel provides extensive local HMI capabilities. The local display is used for monitoring, status messaging, fault diagnosis, and device configuration. User-configurable messages that combine text with live data can be displayed when user-defined conditions are met.

48 Configurable LED Indicators Multi-Language Display • English • Russian • French • Chinese • Turkish • German User-Programmable Pushbuttons

Power System Troubleshooting The C70 contains many tools and reports that simplify and reduce the amount of time required for troubleshooting power system events.

Record the operation of the internal C70 elements and external connected devices with 1ms time-stamped accuracy to identify the Sequence of Operation of station devices during capacitor bank faults and disturbances.

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Analyze capacitor bank faults using both analog and digital power system quantities that are measured and recorded up to a rate of 64 samples per cycle.

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C70 Capacitor Bank Protection and Control System

Typical Wiring

A B

52

C

H7a H7c H8a H8c H7b

CONTACT CONTACT CONTACT CONTACT C

H8b

CONTA CONTACT CONTACT CONTACT C

U8b

DIGIT

I

U1

V I

U2

V I

CONTACT INPUT S5a CONTACT 5c CONTACT 6a CONTACT 6c C

S7a S7c S8a S8c S7b S8b

CONTACT CONTACT CONTACT CONTACT C SURGE

1c 2a 2c

6D

U3

S5a S5c S6a S6c S5b

Co-axial

BNC

V I

6C

U6

N1

N2

N3

DIGIT

7a 7c 8a 8c

Multilin

N4

N5

C70 Pr Contr

CONTROL POWER SURGE FILTER

BNC

V I

U5

3a 3c 4a 4c

OUTPUT

Co-axial

V I

U4

CRITICAL FAILURE

D2a 10BaseT D3a com D4b D1a D4a D2a com D3a BNC D4b D4a BNC

L8c VX

L8a

V

6H

7c 8a 8c

CONTACT CONTACT CONTACT CONTACT C

N6

N7

elay

RS485 NORMAL C ALTERNATE RS485 C

VX

V I

H4

S3a S3c S4a S4c S3b

HI LO

L7a I

H3

CONTA CONTACT CONTACT CONTACT C

com D3b10BaseFL Tx2 Rx2 D1a

Shielded

V

SURGE

D1b10BaseFL Tx1 Rx1 D2b

Remote Device

V I

H2

DIGIT

Optic

I

7a 7c 8a 8c

P

*Fibre

6G H1

S1a S1c S2a S2c S1b

B1b B1a B2b B3a B3b B5b B6b B6a B8a B8b

DC

DIGIT 5c 6a 6c

SURGE

U7a U7c U8a U8c U7b

L7c

VB

8F

N8

V

TC 1

H1a H1b H1c H2a H2b H2c H3a H3b H3c H4a H4b H4c

Specialized Protection & Control

CONTA CONTACT CONTACT CONTACT C

VC

L6a

L6 c

VB

VOLTA

VOLTA 8F

H5a H5c H6a H6c H5b

VC

L5a

L5c VA

L4c

VA

IG1

L4a

IC1

IG5

L4b

L3c

IC

IG

L3a

L3b

IC5

L2b

L2c

IB

IB1

L1c

L2a

IA1

IB5

L1a

L1b

F8c VX

IA

F8a VX

IA5

F7a

F7c VC

VB

VC

F6a

F6c

VB

F5a

F5c VA

F4c

VA

IG1

F4a

F4b

IG5

IG

F3b

F3c

IC

IC1

F2c

F3a IC5

F2b IB

IB1

F1c

F2a

IA1

IA

IB5

F1a

F1b

IA5

Optional

TC 2

U1a U1b U1c U2a U2b U2c U3a U3b U3c U4a U4b U4c U5a U5b U5c U6a U6b U6c N1a N1b N1c N2a N2b N2c N3a N3b N3c N4a N4b N4c N5a N5b N5c N6a N6b N6c N7a N7b N7c N8a N8b N8c

C70

1 2 3 4 SGND 5 6 7 8 9 TXD RXD

CONNECTOR

COMPUTER

1 2 3 4 5 6 7 8 9

8 3 RXD 2 TXD 20 7 SGND 6 4 5 22

CONNECTOR

COM 1

RS-232

RS485 IRIG-B input

DB-9 (front)

IRIG-B IRIG-B output Input

PERSONAL COMPUTER

IRIG-B Output

Minimum

X W

PROVIDED

V

U

T

S

6 6 Inputs/ Inputs/ outputs outputs* *

R

P

N

6 Inputs/ outputs *

M

L

8 CT/ VT *

K

J

H G

6 Inputs/ outputs

F

8 CT/ VT

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D 9 CPU

B 1 Power supply

457

Ordering C70 - * - 00 Base Unit CPU

Software Options (See note below)

*

*

* -

F ** - H ** - M ** - P ** - U ** - W/X **

E J N K T U V

00 03 12 13 A0 B0 C0 D0 Mounting / Conformal Coating H A User Interface

Power Supply CT/VT DSP

IEC 61850 Process Bus Digital I/O

Transducer I/O Inter-Relay Communications

F I J K L M N Q T U V W Y H L 8L 8N 8V

8L 8N 8V 81 XX 6A 6B 6C 6D 6E 6F 6G 6H 6K 6L 6M 6N 6P 6R 6S 6T 6U 6V

5A

XX 6A 6B 6C 6D 6E 6F 6G 6H 6K 6L 6M 6N 6P 6R 6S 6T 6U 6V

5A

8L 8N 8V XX 6A 6B 6C 6D 6E 6F 6G 6H 6K 6L 6M 6N 6P 6R 6S 6T 6U 6V

XX 6A 6B 6C 6D 6E 6F 6G 6H 6K 6L 6M 6N 6P 6R 6S 6T 6U 6V

XX 6A 6B 6C 6D 6E 6F 6G 6H 6K 6L 6M 6N 6P 6R 6S 6T 6U 6V 2S 2T

5A

2S 2T 5A

2I 2J 7H 7I 7S 7W 77

Base Unit RS485 + RS485 (IEC 61850 option not available) RS485 + multimode ST 100BaseFX RS485 + 10/100 BaseT RS485 + multimode ST Redundant 100BaseFX RS485 + three multimode SFP LC 100BaseFX. Req FW v7xx or higher RS485 + two multimode SFP LC 100BaseFX + one SFP R J45 100BaseT. Req FW v7xx or higher RS485 + three SFP RJ45 100BaseT. Req FW v7xx or higher None IEC 61850 Enhanced Capacitor Bank Control (AVR, Capacitor Control Supervision, Time & Date) Enhanced Capacitor Bank Control (AVR, Capacitor Control Supervision, Time & Date) + IEC 61850 CyberSentry UR Lvl 1. Req UR FW 7.xx or higher IEEE 1588. Req UR FW 7.xx or higher PRP IEEE 1588 + CyberSentry. Req UR FW 7.xx or higher Horizontal (19” rack) - Standard Harsh Chemical Environment Option Vertical Front Panel with English Display Enhanced German Front Panel Enhanced German Front Panel with User-Programmable Pushbuttons Enhanced English Front Panel Enhanced English Front Panel with User-Programmable Pushbuttons Enhanced French Front Panel Enhanced French Front Panel with User-Programmable Pushbuttons Enhanced Russian Front Panel Enhanced Russian Front Panel with User-Programmable Pushbuttons Enhanced Chinese Front Panel Enhanced Chinese Front Panel with User-Programmable Pushbuttons Enhanced Turkish Front Panel Enhanced Turkish Front Panel with User-Programmable Pushbuttons 125/250 V AC/DC 24 - 48 V (DC only) Standard 4CT/4VT w/ enhanced diagnostics Standard 8CT w/ enhanced diagnostics Standard 8VT w/ enhanced diagnostics 8 Port IEC 61850 Process Bus Module No Module 2 Form-A (Voltage w/ opt Current) & 2 Form-C Outputs, 8 Digital Inputs 2 Form-A (Voltage w/ opt Current) & 4 Form-C Outputs, 4 Digital Inputs 8 Form-C Outputs 16 Digital Inputs 4 Form-C Outputs, 8 Digital Inputs 8 Fast Form-C Outputs 4 Form-A (Voltage w/ opt Current) Outputs, 8 Digital Inputs 6 Form-A (Voltage w/ opt Current) Outputs, 4 Digital Inputs 4 Form-C & 4 Fast Form-C Outputs 2 Form-A (Current w/ opt Voltage) & 2 Form-C Outputs, 8 Digital Inputs 2 Form-A (Current w/ opt Voltage) & 4 Form-C Outputs, 4 Digital Inputs 4 Form-A (Current w/ opt Voltage) Outputs, 8 Digital Inputs 6 Form-A (Current w/ opt Voltage) Outputs, 4 Digital Inputs 2 Form-A (No Monitoring) & 2 Form-C Outputs, 8 Digital Inputs 2 Form-A (No Monitoring) & 4 Form-C Outputs, 4 Digital Inputs 4 Form-A (No Monitoring) Outputs, 8 Digital Inputs 6 Form-A (No Monitoring) Outputs, 4 Digital Inputs 2 Form-A (Cur w/ opt Volt) 1 Form-C Output, 2 Latching Outputs, 8 Digital Inputs High Power Supply 6-port managed Ethernet switch Low Power Supply 6-port managed Ethernet switch 4 dcmA Inputs, 4 dcmA Outputs 820 nm, multimode, LED, 2 Channels Channel 1 - IEEE C37.94, 820nm, multimode fiber, 64/128 kbps; Channel 2 - 1300 nm, singlemode, LASER Channel 1 - IEEE C37.94, 820nm, multimode fiber, 64/128 kbps; Channel 2 - 1550 nm, singlemode, LASER 1300 nm, multimode, LED, 2 Channels G.703, 2 Channels RS422, 2 Channels IEEE C37.94, 820 nm, multimode, LED, 2 Channel 6 port, 100 Mbps, Managed Ethernet Switch, HI (125/250V AC/DC)

Ordering Notes: To view all the options available for C70, please visit GE’s On-Line Store at http://store. gedigitalenergy.com/viewprod.asp?model=C70

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12755H(E) English 150121

Grid IQ™ Microgrid Control System Optimization Solution for Permanently Islanded or Grid-Connected Microgrids

Generation Optimization

The Grid IQ Microgrid Control System (MCS) enables distribution grid operators to integrate and optimize energy assets with an objective to reduce the overall energy cost for a local distribution grid, also known as a “microgrid”.

• Maximizes the use of renewable generation by leveraging the available energy storage system

The MCS is based on a supervisory control architecture provided by the Multilin™ U90Plus Generation Optimizer, Intelligent Electronic Devices (IEDs), substation gateways, a Human Machine Interface (HMI) and a secure communications network.

Holistic Energy System

• Provides substantial reduction in fuel costs by intelligent management of generating assets

The MCS provides a simple yet effective solution to integrate fossil fuel based (dispatchable) Distributed Energy Resources (DERs), renewable (non-dispatchable) DERs and energy storage to best optimize the operation of a local microgrid with a goal to minimize the total cost of operation, including Cost of Energy (CoE).

Key Benefits • Enables integration of renewable energy resources such as wind turbines or solar PV with conventional fossil based generators • Optimizes the dispatch of distributed energy system resources to reduce the total cost of energy and cost of operating a microgrid system • Maintains a secure and reliable power supply for mission critical loads with ability to operate in ‘islanded’ mode

• Integrates electrical and thermal energy assets such as CHP and boilers • Maximizes overall system optimization and minimizes the total energy costs

Improved Return on Investment • Enables integration of existing power system assets to the new infrastructure for an improved asset utilization • Further reduces distribution system losses through the integration of Volt/VAR controls

• Enables integration with Volt/VAR controls for a better utilization of existing or new distribution system assets to further reduce system losses and increase overall system efficiency

Reliable Power

• Maximizes the use of renewable assets for reduced GHG emissions and environmental impact

• Maintains uninterruptible power supply for mission critical infrastructure with ability to operate in ‘islanded’ mode

Application Specific Solutions • Off-the-grid remote communities: Opportunities to optimize operation of diesel generators and integration with renewable energy resources • Military bases: Provides reliable power for critical loads at military bases in case of an unwanted interruption of power from the main grid • Mining communities: Opportunities to best utilize the available energy resources and help reduce diesel consumption for community energy needs

• Manages turn on/off operation of low priority controllable loads in case of generation deficit situation within the “islanded” microgrids

Microgrid Visualization • Empowers local microgrid system operators to make informed decisions by providing system visualization • Provides a man-machine interface to configure and monitor the microgrid system for automatic dispatch of DERs



ecomagination™ Certified

Microgrid Control System

What is a Microgrid A microgrid system is typically capable of operating in “islanded” (off-the grid) or grid-connected mode. Based on the grid connection "status" of a microgrid, it can be categorized as:

Permanently Islanded Microgrid Permanently Islanded microgrid networks are stand alone networks that must produce all of the generation locally that will be consumed by the loads in the network. Islanded microgrid networks are quite often found in remote, northern or island communities where the high cost of importing fuel and the availability of renewable resources (wind, hydro) can make optimization of generation resources very desirable.

Grid-Tied Microgrid Grid-tied microgrid networks are able to produce power within its distribution networks as well as import power from a utility source. University campuses and military facilities that have on-site generation for backup power can utilize their on-site generation to offset the costs of electricity when it is cheaper to produce electricity than to buy it.

Specialized Protection & Control

MCS Components The MCS is based on a supervisory control architecture provided by Multilin U90Plus Generation Optimizer. The core function of the U90Plus Generation Optimizer is its ability to monitor, track, and forecast load and generation resources within the microgrid. In order to facilitate this, the U90Plus is required to communicate with intelligent controllers distributed at key points across the microgrid.

Grid IQ’s MCS is a system solution offering with the U90Plus Generation Optimizer as “heart” of the control system, surrounded by intelligent controllers, communications and other power system devices.

U90Plus Generation Optimizer The U90Plus Generation Optimizer is the central engine of an advanced microgrid control solution that provides management of DERs for the most economical power. A detailed functionality description of the U90Plus controller is provided in following sections.

Typical Microgrid Control System Architecture and Optimization Sequence The U90Plus is the central supervisory controller of a microgrid control system that maximizes the use of the renewable DERs and provides set points for various energy resources to provide power for the load demand in the most economical method possible.

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Microgrid Control System

Grid IQ MCS Features

Communications Network The U90Plus is able to measure load requirements and generation capacity at various locations across the microgrid network. As these load and generation centers are spread out geographically, a reliable and robust communications network is provided in order for the U90Plus to monitor and control various assets with in the spreadout power system network. Where economical to do so, an Ethernet network can be deployed at each critical measurement point. When the microgrid spans long distances or laying fiber optic cables is uneconomical, a secure, industrial wireless network can be deployed. The U90Plus minimizes the amount of information needed to be transmitted over the communications network by optimizing the data requirements at each load or generation location.

The MCS provides a multitude of functionalities for permanently islanded (off-the-grid) and grid-connected microgrid systems.

Lowers Cost of Producing power Through its ability to monitor and trend key load, the U90Plus is able to predict the load requirements within a microgrid for future periods through a smart dispatch mechanism. The smart dispatch send commands to dispatchable generators to meet these load requirements in the most economical method possible.

Maximizes Use of Green Power

Intelligent Local Controllers Each generating source and energy storage unit is monitored, and receives commands from the U90Plus by an intelligent controller located locally at DER locations. These controllers perform the real time measurements of the load or generating units and communicate back to the U90Plus. These controllers also receive the commands from the U90Plus to initiate the turning on or off of the dispatchable generators.

Integration and Configuration Services The MCS offering includes microgrid system feasibility studies, engineering, system design and modeling, U90Plus Generation Optimizer configuration, first level system integration services, system commissioning support and training. GE has a team of subject matter experts to help develop and build a microgrid project.

Load Forecasting The capability of the U90Plus to forecast the future load requirements is key to providing the optimum generation to support the load. All loads are continuously tracked and used by the U90Plus to create a forecast for the load profile of the microgrid for the next 24 hours. If the actual measured load usage differs from what the U90Plus forecasts for reasons such as a drop in temperature resulting in less load requirements, the U90Plus will continually adjust its forecast to make the best predictions for load requirements.

Typical Distributed Energy Resources (DERs) for Microgrid Systems The U90Plus can integrate many different types of Distributed Energy Resources into its generation optimization control algorithms. Power Loss

Generation Optimization Using Traditional Generation

Dispatchable Generator 3

Dispatchable Generator 2

Dispatchable Generator 1 6 AM

12 PM

6 PM

12 AM Hours in a day

Diesel Generation

Dispatchable Distributed Energy Resources • • • •

Diesel Generators Fuel Cell Systems Batteries Combined Heat & Power (CHP) • Dispatchable Loads – Demand Response

Minimized Wasted Fuel

Forecasted Load Requirements

Isochronous Generation

Renewable Generation

Energy Storage

Loads

• Diesel Generators • Hydro Generators • Utility Source

• • • • •

• Hydrogen Electrolyzer • Batteries – Various Battery Technologies

• Aggregated Residential • Industrial • Commercial

Hydro Generators Wind Generators Solar Generators Bio-gas Based Generation Hydrogen Fuel Cell

GEDigitalEnergy.com

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Specialized Protection & Control

These intelligent controllers are required to support the Modbus TCP/IP protocols and have the appropriate control capability to interact with the generator or storage unit control systems. Multilin’s Universal Relay family is an ideal solution as it contains the necessary control and protection functions to protect the assets at the same time.

When renewable generation (hydro, wind, solar) and methods of storing power (hydrogen, battery, pumped storage) are available, the U90Plus is able to maximize the use of DERs by enabling energy storage when it determines there is excess renewable power available or it is economically viable to do so. At a later time when there is not enough renewable generation to support the load, the U90Plus can dispatch this low cost stored energy to meet the load requirements in the most efficient manner possible.

Microgrid Control System

Generation Forecasting The distributed generators that are connected to the microgrid are currently monitored by the U90Plus and their output is constantly tracked. A forecast for the expected output of generation from renewable sources over the next prediction horizon (e.g. 24 hours) is then created to predict the contribution to the overall generation that will be supplied by these renewable sources. Similar to the load forecast predictions, if the actual measured generation from available sources differs from what the U90Plus forecasts for reasons such as a drop in wind or an increase in clouds as compared to previous days, the U90Plus will continually adjust its forecast to make the best predictions for the contribution of renewable generation that will be available to support the required loads in the microgrid.

In order to use the minimal amount of fuel required to support the load, the U90Plus will turn on the dispatchable generators just before needed in order to minimize the idling time of the generators to provide the most cost effective method in supporting the load. As a part of its generation optimization algorithms, the U90Plus takes into account the operational characteristics of the generators such as the start up time required and the minimal generation loading that is require to make it operate efficiently. The U90Plus performs its generation optimization calculations and sends commands to the generators to maximize generator performance every 12 minutes. As changes in the load occurs between 12 minute optimization cycles, the U90Plus ensures that it took into account enough generation loading margin known as “Isochronous Generator Margin” or “Isoc Margin” to support the addition to the load.

Generation Optimization Using Traditional Generation Power Loss

If the local utility or campus has the ability to perform advanced load requirement forecasts that could be used instead of or to compliment the forecasts made by the U90Plus, these forecasts can be uploaded into the U90Plus for use in its optimization calculations. Note that if the U90Plus measures that this external forecast is not matching the actual load profile, it will adjust the uploaded forecast to more accurately match what is being used in the microgrid.

Dispatchable Generator 3

Power Loss

Based on previous 24 hour period Dispatchable Generator 2

Actual Load Measured Adjusted Forecasted Load Based on real time measurements

Dispatchable Generator 1 6 AM

12 PM

6 PM

12 AM Hours in a day

Diesel Generation

Hours in a day 6 AM

12 PM

6 PM

12 AM

The U90Plus develops a 24 hour expected load profile for which it will provide the necessary generation within the system to support it. If the actual measured load is different than the forecasted load, the U90Plus will continually adjust the forecast to provide the appropriate generation.

Optimal Generation Dispatch

Forecasted Load Requirements

Minimized Wasted Fuel

The U90Plus generation optimization algorithms intelligently start and stop the dispatchable generators at the optimal times to support the load and minimize the time the generators are running.

Generation Optimization with Integrated Renewable Generation Power Loss

Specialized Protection & Control

Expected Load

Dispatchable Generator 2

Using the load profile that was created based on historical power usage and adjustments made on real time monitoring, the U90Plus will optimize the use of the available generation to provide power in the most economical means possible. As a part of the configuration process of the U90Plus, each generation source is given a cost value to run that generating source. Renewable generators such as wind or solar power will be given a lower cost than diesel or other fuel based generators. Using this information, along with the operating and efficiency characteristics of the generators, the U90Plus will give commands to the dispatchable generators and/or storage devices to best match the generation with the load requirements.

Dispatchable Generator 1 6 AM

12 PM

6 PM

12 AM Hours in a day

Diesel Generation

Renewable Generation

Forecasted Load Requirements

As it is not dispatchable, when renewable generation is integrated into the microgrid system, the U90Plus will dispatch available generation taking into account the contribution of renewable generation into the system.

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Microgrid Control System

Renewable Generation Integration

Storing Energy

Using the forecasts made for the amount of renewable generation that will be available in the microgrid, the U90Plus is able to provide additional cost savings in the microgrid network. By taking into account the amount of renewable generation that will be available for future periods, the U90Plus will reduce the amount of dispatchable fossil fuel based generation running to meet the load requirements. Since by its nature renewable generation is variable and can very quickly decrease in contribution to the system (wind slows or increased cloud cover), the U90Plus will incorporate an additional margin of standby generation (Isoc Margin) when renewable contribution is high to ensure there will always adequate generation available to support the load.

During periods of time where there is more renewable generation available than is required to support the load (such as spilling over the dam at night for hydro), or when there is additional generation margin due to lightly loaded generators, the U90Plus can initiate the hydrogen production or storage (battery or pumped storage) of “fuel”. Using cost information that was entered at the time of configuration of the U90Plus, the optimization algorithms in the U90Plus analyze the excess generation available and determine if it is economically beneficial to store energy at that time. The U90Plus will take into consideration the amount of time it takes the storage medium, to operate efficiently and how long it must run for prior to seeing benefits, before it initiates the storage process.

Using Stored Energy

Isochronous Generation Control The isochronous generators (or "isoc generator" are the generators in the microgrid that are used to stabilize the frequency of the system. Based on a pre-defined configuration, the U90Plus is able to identify which generators are the isoc generators as specified by preference of the system operators. The types of generators that can be used as an isoc generator in the microgrid are defined below: • Utility source

When there is not enough renewable generation in the system to support the load requirements and there is sufficient stored energy available to support the loads, U90Plus will initiate the use of available stored energy and will help reducing the fossil fuel consumption to run the diesel generators to feed the loads. In this case, the stored energy resource will act as one of the dispatchable generators in the system.

Generator Unit Commitment

• Hydro generator • Fuel cell generator • Battery

Energy Storage Integration When a method of storing energy is available, (hydrogen electrolyzer or batteries) renewable generation can be used to its maximum potential for providing cost savings. Energy storage is possible since low cost energy does not need to be used at the exact time that it is produced, therefore it can be used later when renewable sources may not be available.

This function also enables use of grid connection as a resource and determines the total share of power to be imported from the grid to be able to support the load demand. The Unit Commitment function of the U90Plus feeds the Optimal Dispatch algorithm to commit certain generating assets considering system parameters and forecasted demand.

Generator Unit Commitment Integration System Topology, Fuel Cost, Start-up/Shut-down Costs, Isoch Margin, ... SETTINGS

Device Status

Post-proccesing Unit

Storage State of Charge

Microgrid Optimization Model Setpoints of Dispatchables

Pre-proccesing Unit

Setpoints of Storage Devices

FORECASTS Load

Renewables

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Electricity Price

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Specialized Protection & Control

This function of U90Plus enables users to force select the dispatchable generators to be committed for a certain minimum time over the forecasted horizon with a minimum delay. This function considers a portion of the energy storage outputs defined by a predetermined profile - which is calculated by microgrid optimization algorithms based on readings from storage device and the results of previous optimal dispatch.

• Diesel generator

Microgrid Control System

Automation Control

Security

The U90 Plus Generation Optimizer algorithms are able to make recommendations as to when to use the various dispatchable resources in the network. When appropriate, these commands can be sent directly to the local controllers that are connected to the generators.

The U90Plus and associated software tools provide a suite of security features that ensure only authorized personnel can make changes to the configuration of the system.

When there are special requirements or operating conditions that need to first be considered before these commands can be sent to the local controllers, the U90Plus contains an advanced logic engine that can be used to customize the control of these resources. This logic engine includes many different types of logic operators including Boolean logic and mathematical operators. For example, in cases where it is not possible to directly measure the hydrogen state of charge in a hydrogen based energy storage system, by using a mathematical equation value of hydrogen charge level it can be calculated locally using this powerful logic and math engine.

Password Security The U90Plus provides password security to ensure that only authorized personnel can change the settings in the U90Plus. There are four levels of password security provided: • Local Settings Access • Local Control Access • Remote Settings Access • Local Settings Access

Security Audit Trail

Communications

Specialized Protection & Control

Modbus Master The U90Plus Generation Optimizer uses the Modbus TCP/IP protocols and acts as a Modbus Master to communicate with the devices connected to the Generation and Load points. The U90Plus optimizes the amount of information needed and uses the low bandwidth required in the Modbus protocol so that the Microgrid optimization system can operate even where there is limited bandwidth between the U90Plus and the local control devices.

Modbus TCP/IP Modbus TCP/IP protocols are supported in the U90Plus for the purpose of integration into SCADA or Energy Management Systems. Information that can be made available to these systems include: • Real time load being used

The U90 Plus continually monitors itself to ensure the security of its configuration. The U90Plus offers complete traceability of any setting changes and commands given, allowing the user to quickly identify changes made to the device. A security file (security.txt) can be retrieved via the setup software from the U90Plus. This security file can help identify the time of sending the setting file and alarm configurations (for the annunciator) to the U90Plus.

Maximize the Distribution Network Efficiency (Grid Tied Networks) The MCS system can also provide capability to minimize the distribution system losses and maximize network efficiency by leveraging the existing system assets such as Voltage regulators and capacitor banks. The Multilin D400 controller, as part of the MCS system, can host advanced algorithms for Volt/VAR controls for a distribution network. It is possible to increase local distribution network efficiency by optimizing and flattening the voltage profile and by maximizing the reactive power injection into the local distribution network.

• Total renewable generation being provided • Total stored energy being provided • Amount of stored energy available for use • Total dispatchable generation available

Microgrid Visualization and HMI

Upstream System Communications

The Grid IQ MCS system offering includes a powerful, user-friendly HMI for monitoring, control and visualization of a Microgrid network.

The D400 controller, as part of the MCS system, can act as a gateway device to be able to communicate to upstream utility systems on standard DNP 3.0 utility communications protocol. This functionality may be desired for grid tied microgrid systems.

Sequence of Events Record The U90Plus provides a Sequence of Events Record that records all of the generation optimization decisions and logic operations performed by the U90Plus. The Sequence of Events can be monitored locally on the front panel HMI and can also by retrieving the event file (event.txt) through the setup software.

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GE’s Proficy™ HMI, offered as a part of the Grid IQ MCS system, provides complete visualization, monitoring and control solution for a microgrid system. GE’s Proficy HMI is a purpose built electric utility oriented system based on GE’s market-leading, industry-standard SCADA software, CIMPLICITY™. CIMPLICITY is a well suited platform for both the permanently islanded (off-the-grid) and grid-connected Microgrid systems.

GEDigitalEnergy.com

Microgrid Control System

Typical Microgrid Applications Islanded Mining and Remote Communities One of the biggest challenges that permanently islanded remote and mining communities face is to reduce total cost of energy, primarily driven by fossil fuel cost and quite exorbitant fuel transportation costs. Although, many of these remote communities may have some form of a renewable resource, such as run of a river hydro, small bio-gas plant, wind, or solar, unfortunately because of lack of smart control system infrastructure, they are primarily dependent upon fossil fuel based generation for their energy needs. The Grid IQ MCS system can help many of these remote islanded communities by optimizing the operation of existing assets and also by helping integrating renewable energy resources into the existing network. Such capability not only helps these communities to reduce the total cost of energy, but can also help reduce the GHG emissions and resulting adverse environmental impacts.

Specialized Protection & Control

A microgrid system architecture diagram for a typical remote community suitable for application of GE’s Grid IQ MCS system.

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Grid Connected Military Bases The defense departments across various parts of the world are up against critical challenges to sustain their mission critical infrastructure during an unplanned event. Their objective is to provide secure and reliable power to their critical infrastructure regardless of situation of the main grid. Although cost of energy and environmental impacts of fossil fuels are important considerations for them, their primary reason for exploring microgrids is to provide a safe, secure and reliable power network for their mission critical buildings and assets. The MCS system can help many of these defense installations by providing a capability to operate in secure islanded mode in case the main grid has an unwanted interruption. The MCS can manage available backup power sources and storage devices, possibly in combination with demand side management for low priority loads to sustain mission critical infrastructure.

Bulk Grid

U90Plus Generation Optimizer

BEM/HMI

Existing Protection/ Meetering Relay

Existing Fiber Network

Ethernet Switch

Wireless Signal

MDS Mercury 3650 Radio

32 kV Distribution

Buildingloads with PV

Substation Loads

Fuel Cells - 500 KW

Base Housing

CHP Generation CHP PLC

Diesel Backup 1MW PV

A microgrid system architecture diagram for a typical military base capable of operating in islanded mode in case of an adverse event on the main grid.

g

imagination at work



ecomagination™ Certified

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GE’s Grid IQ Microgrid Control System is “ecomagination approved” by GE. This means it has been proven to deliver significant operational and environmental benefits to customers. Ecomagination is GE’s way of creating new value for customers, investors and society by helping to solve energy and efficiency challenges.

GEA-12690A(E) English 150121

Network Protection Network Protection Overview Advanced visualization technologies enable the efficient recovery of distribution systems utilizing fault isolation, sectionalization and power system restoration capacities within our wide range of distribution assets, controllers, and high accuracy measurement devices.

Featured Products Product brochures for featured Multilin Network Protection systems offered by GE.

Featured Products

Network Protection – Featured Products N60

Network Stability and Synchrophasor Measurement System

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Load shedding, remedial action and special protection schemes. The N60 Network Stability and Synchrophasor Measurement System, a member of the UR Family of protection relays, is a flexible device intended for either the development of special protection schemes and/or serving synchrophasor data. The N60 delivers PMU data as per the latest version of the standard IEEE C37.118 (2011) with a sampling rate of up to 120Hz and supports multicast synchrophasors as per the newest IEC61850-90-5.

PDC

Synchrophasor Data Concentrator

477

The Multilin P30 PDC comes equipped with as many as 40 PMU inputs, up to 8 individually configurable C37.118 outputs and an incredibly fast recording capability of up to 120 frames per second. The built-in historian processor is capable of securely recording and archiving up to 100,000 values per second, sufficiently supporting the NERC PRC-002 standard.

MultiSync 100

MultiSync 100 1588 GPS Clock – 1588 Time Synchronization

Network Protection

The MultiSync 100 1588 GPS Clock provides a complete 1588/C37.238 time synchronization solution for ML3000 Ethernet Switches, Universal Relays and the 8 Series Relay family. The GPS clock is compatible with IEEE 1588 version 2 implementation, including the C37.238 power profile, support for NTP, SNTP, IRIG-B, DFC77 and TTL time synchronization. The MultiSync 100 1588 GPS Clock is compact in size (45 x 110 x 155 mm), has DIN-rail mounting and is rated for -40 to 85 C temperatures.

Go online for the full listing of Multilin Protection & Control products

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Multilin™ N60 Synchrophasors, Load Shedding, Remedial Action, Special Protection Schemes The Multilin N60 network stability and synchrophasor measurement system is a flexible device intended for the development of load shedding, remedial action, special protection schemes and wide area monitoring and control. Special protection schemes are unique to each installation and are carefully matched to a given system topology, operating practices and system protection philosophies of a given utility. The N60 provides an exceptionally flexible platform to easily integrate and facilitate the specific special protection schemes needed for a wide range of applications.

Key Benefits • Scalable synchrophasor measurements with up to 6 PMUs per relay reducing synchrophasor cost by up to 80% • Real-time access to remote analog data, providing for advanced wide area applications and enhanced system security • Exceeds latest IEEE® C37.118 (2011) standard for PMU measurement devices with a TVE of less than 1%, protection and metering class synchrophasors and multi-cast IEC® 61850-90-5 support • Uninterrupted synchrophasor measurements during fault and disturbances, providing highly reliable capture of data for critical control functions and post-mortem analysis • Simplified system integration with direct connection to JungleMUX SONET, TN1U SDH and TN1Ue SDH networks • Advanced IEC 61850 Ed. 2 implementation, complete settings via SCL files and IEC 61850-9-2 process bus solution enable resource and platform managing optimization and reduce cost of ownership • Increased network availability via failover time reduced to zero through IEC 62439-3 “PRP” support • CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog)

Protection & Control • Underfequency, overfrequency, and rate-of-change of frequnecy (df/dt) , and Synchrocheck • Three phase undervoltage and one phase overvoltage elements • FlexMath for automated network control enabling automatic load shedding, power balancing and remedial action schemes

Communications • Synchrophasor streaming over Ethernet, up to four PDCs simultaneously, reporting rates from 1 to 120 phasors/sec • 3 independent Ethernet ports for simultaneous & dedicated network connections with IEEE 1588 support • N60-to-N60 communications using direct fiber or through multiplexers using G.703, RS422, or C37.94 interfaces • Multiple protocols: IEC 61850 edition 2, SFTP, MMS file transfer service, DNP 3.0 and Modbus serial/TCP, IEEE 1588, IEC 60870-5104 and 103, PRP, SNTP, HTTP, TFTP • CyberSentry™ provides high-end cyber security aligned to industry standards and services (NERC® CIP, AAA, Radius, RBAC, Syslog)

• Advanced fault and disturbance recording, including internal relay operating signals, eliminating the need for external recording devices

Monitoring & Metering

Applications

• Synchrophasor recording: 12MB of memory with multiple recording and triggering options, 46 configurable channels

• Decrease blackouts by identifying network instabilities and taking fast preventative action • Increase utilization of existing investments by identifying power transfer capability on existing lines • Facilitate contingency planning through continuous synchrophasor data collection and postmortem analysis • Provides enhanced state estimation for SCADA to optimize system-wide load shedding and remedial action schemes

• Advanced recording capabilities with highcapacity event recorder, configurable and extended waveform capture and data logger • Metering: current, voltage, power, energy, frequency, and harmonics

N60 Network Stability and Security System

Overview

N60 - Protection, Metering, Monitoring and Control

As part of the UR family of Protection & Control devices, the Multilin N60 Network Stability and Security System offers a high degree of modularity in its design and functionality, providing superior performance while meeting the toughest requirements of the marketplace. As an advanced Synchrophasor Measurement device, the N60 supports wide area monitoring and other grid modernization applications through the following:

Synchrophasors The N60 is also a source of synchronized phasor measurements known as synchrophasors. The N60 meets all and exceeds many of the requirements of the IEEE C37.118 synchrophasors for power systems standard. The N60 can simultaneously stream P and M class synchrophasors over its Ethernet ports at configurable discrete rates of 1 to 120 frames per second. In addition to streaming synchrophasors, the N60 can be controlled through programmable triggers to store snapshot records of synchrophasor data in the 12MB of onboard memory.

Network Protection

Peer-to-Peer Communications The N60 provides two distinct methods, direct I/O and IEC 61850 GOOSE, for sharing information about the state of a local station to other local or remote N60’s. Using direct I/O messaging, the N60’s can share real-time analog information and local control decisions with other remote sites to facilitate a desired control action. In addition, local control

The N60 is the single point for protection, control, metering, and monitoring in one integrated device that can easily be connected directly into DCS or SCADA monitoring and control systems like Viewpoint Monitoring as shown.

commands can be sent to other IEDs via the IEC 61850 GOOSE mechanisms where digital point-to-point messaging can be achieved in 4ms. Further operational sophistication can be achieved by using the analog GOOSE capability to transfer analog values between local devices.

network stability applications including:

Special Protection Schemes

• Tripping of generators

The advanced local and remote communications ability of the N60, along with its superior automation control functions, provide a flexible platform for addressing a broad range of

Functional One-Line Diagram

2

3

4

5

Same Functions as Breaker 1

TRIP

For Breaker 1

50DD 50

49 4

68

32 2

2

81U

59P

27P 3

3

6

81O

81R 4

4

METERING

25 FlexElement

TM

Digitizer

Transducer Inputs

4

N60 Network Stability and Security Relay 847700A2.CDR

The N60 can monitor and control up to 5 power system circuits.

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• Controlled islanding of the local system • Load shedding • Fast-valving • Fast dispatch of generation • HVDC power control adjustments • Series capacitor Automatic Voltage Regulator (AVR) setpoint and tap change control

ANSI® Device Numbers & Functions

52

CLOSE

• Controlled openings of interconnections

GEDigitalEnergy.com

DEVICE NUMBER

FUNCTION

25 27P 32 49 50DD 50P 59P 68 81O 81U 81R

Synchrocheck Phase Undervoltage Sensitive Dir Power Thermal Protection Disturbance Detector Phase Inst Overcurrent Phase Overvoltage Power Swing Blocking Overfrequency Underfrequency Rate of Change of Frequency

N60 Network Stability and Security System

Truly Distributed Architecture Sophisticated special protection schemes can be developed exclusively using N60 devices without any other central controllers. The N60 can be configured to make smart decisions based on real-time information that it has received from N60’s located across a large geographic area. The N60 has built-in abilities to detect the failure of communications to other devices, which allows for the configuration of the devices to self-adjust or adapt its decisions based on the information that is available to it.

Monitor Multiple Power Circuits

N60’s can be directly connected to multiplexed networks using a variety of different interfaces to communicate with other N60’s spread out across the transmission network.

IEC 61850 Process Bus The IEC 61850 Process Bus module is designed to interface with the Multilin HardFiber System, allowing bi-directional IEC 61850 fiber optic communications. The HardFiber System is designed to integrate seamlessly with existing Universal Relay (UR) applications, including protection functions, FlexLogic™, metering and communications. The Multilin HardFiber System offers the following benefits:

Figure 1

• Communicates using open standard IEC 61850 messaging • Drastically reduces P&C design, installation and testing labor by eliminating individual copper terminations • Integrates with existing N60’s by replacing traditional CT/VT inputs with the IEC 61850 Process Bus module • Does not introduce new cyber security concerns Visit the HardFiber System product page on the GE Digital Energy web site for more details.

Figure 2

N60’s can be directly connected to other N60’s in a ring configuration, providing network redundancy as seen in Figure 1, or an open ring configuration to span long distances, as seen in Figure 2.

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Network Protection

The N60 can monitor from one up to six threephase power circuits and can be configured to simultaneously provide as many as 6 PMUs. The N60 provides metering of many power system quantities including active, reactive and apparent power on a per-phase, and three-phase basis, true RMS value, phasors and symmetrical components of currents and voltages, power factor, and frequency. Frequency can be measured independently and simultaneously from up to six different signals, including currents if needed. The N60 allows for creating and processing virtual sums of currents through its user configuration mechanism of “signal sources”.

N60 Network Stability and Security System

Cyber Security – CyberSentry UR CyberSentry UR enabled UR devices deliver full cyber security features that help customers to comply with NERC CIP and NIST® IR 7628 cyber security requirements. This software option delivers the following core features:

AAA Server Support (Radius/LDAP) Enables integration with centrally managed authentication and accounting of all user activities and uses modern industry best practices and standards that meet and exceed NERC CIP requirements for authentication and password management.

Role Based Access Control (RBAC) Efficiently administrate users and roles within UR devices. The new and advanced access functions allow users to configure up to five roles for up to eight configurable users with independent passwords. The standard “Remote Authentication Dial In User Service” (Radius) is used for authentication.

Network Protection

Event Recorder (Syslog for SEM) Capture all cyber security related events within a SOE element (login, logout, invalid password attempts, remote/local access, user in session, settings change, FW update, etc), and then serve and classify data by security level using standard Syslog data format. This will enable integration with established SEM (Security Event Management) systems.

Communications

completely segregated networks and allow for truly redundant inter-substation communication architectures. The communications interfaces available include direct fiber optics (up to 100km), G.703, and RS422 interfaces and is fully compatible with Multilin’s JMUX SONET, TN1U SDH and TN1Ue SDH multiplexers.

information transfers in a cost-effective fault tolerant network.

Direct I/O

• DNP 3.0 (serial & TCP/IP)

Using the direct I/O, each N60 can send the status of up to 64 ON/OFF digital states to other N60’s spread across the network. The message delivery from one N60 to another varies with the number of other N60’s located between the sending and receiving devices, but delivery times of one to two cycles is achievable for very large networks and will be repeatable and deterministic for all communications between those two devices. This high-speed sharing of information allows for N60’s to obtain real-time information about the status of other parts of the network and of decisions made by other devices on the network.

• Ethernet Global Data (EGD)

Direct Analogs

• Implements Edition 2 of the standard across the entire family of UR devices

Direct analogs provide the ability to share the value of analog quantities measured by the local N60 with other N60’s distributed across the network. This analog data is transmitted across the network whenever the value varies beyond a preset deadband, up to a rate of every 250ms. With this information, N60’s can evaluate what is happening around the rest of the network and make smart decisions about what control actions to take, as implemented for the various special protection schemes.

The N60 has very advanced communications capabilities in the protection and contol industry, for sharing information about the power system with other local or remote devices. Using direct peer-to-peer communications for sharing information with other N60’s distributed across the network, and using the many available SCADA protocols, the N60 can provide the complete solution for carrying out special protection schemes and SCADA monitoring and control functions.

Network Communications Diagnostics

Direct I/O and Direct Analog

The N60 embraces the most advanced communication technologies available today for remote data and engineering access that provide an easy method of integrating information from around a network into new or existing infrastructures. Direct support for redundant fiber optic Ethernet provides high-bandwidth communications allowing for low-latency controls and high-speed file transfer of synchrophasor and event recording

The direct I/O and direct analog features allow for the sharing of both digital and analog information with up to 16 other N60 devices connected directly through fault tolerant fiber optic ring networks or through a multiplexed communications network. The N60 supports dual channel communications where each channel can support a different physical connection, providing the ability to connect to

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The N60 direct I/O and direct analogs incorporate sophisticated self-monitoring and diagnostic functions that can be monitored and evaluated to identify problems with the integrity of the communications network. Included in these diagnostics features are a 32-bit CRC, an unreturned messages count, and a count of the total number of lost packets.

SCADA Integration

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The N60 supports the most popular industry standard communications protocols enabling easy, direct integration into SCADA systems. • IEC 61850 Ed. 2 with 61850-9-2 and 6185090-5 support

• IEC 60870-5-103 and IEC 60870-5-104 • Modbus RTU, Modbus TCP/IP • HTTP, TFTP, SFTP and MMS file transfer • SNTP and IEEE 1588 for time synchronization • PRP as per IEC 62439-3

Interoperability with Embedded IEC 61850 Edition 2 The new IEC 61850 implementation in the UR Family positions GE as an industry leader in this standard.

• Provides full relay setting management via standard SCL files (ICD, CID and IID) • Enables automated relay setting management using 3rd party tools through standard file transfer services (MMS and SFTP) • Increases the number of Logical Devices and data mapped to them, GOOSE messages, and reports to support different organizational needs for data transfer and reduce dependency on generic logical nodes • Configures GE Systems based on IEC 61850 using universal 3rd party tools • Multicast IEEE C37.118 synchrophasor data between PMU and PDC devices using IEC 91850-90-5

LAN Redundancy Substation LAN redundancy has been traditionally accomplished by reconfiguring the active network topology in case of failure. Regardless of the type of LAN architecture (tree, mesh, etc), reconfiguring the active LAN requires time to switchover, during which the LAN is unavailable. UR devices deliver redundancy as specified by PRP-IEC 62439-3, which eliminates the dependency on LAN reconfiguration and the associated switchover time. The UR becomes a dual attached node that transmits data packets over both main and redundant networks simultaneously, so in case of failure, one of the data packets will reach the receiving device with no time delay.

N60 Network Stability and Security System

Multi-Language UR devices support multiple languages: English, French, Russian, Chinese, Turkish and German. These language options are available on the front panel, in the EnerVista setup software, and in the product manuals. Easily switch between English and an additional language on the local displays without uploading new firmware.

of the four synchrocheck elements can be dynamically blocked or unblocked by other elements or user logic.

• Multiple CT/VT configurations allow for measuring inputs from up to 6 power system circuits

Advanced Automation

• Types of digital outputs include triprated Form-A and Solid State Relay (SSR) mechanically latching, and Form-C outputs

FlexLogic

The N60 incorporates a wide range of protection and control functions that are typically required for special protection schemes. These protection and control elements along with the use of the advanced FlexLogic, FlexMath, and FlexElements, allow for the creation of automated system controls for customized special protection schemes.

FlexLogic is the powerful UR-platform programming logic engine that provides the ability to create customized protection and control schemes based on information measured locally by the N60 and received from remote N60’s sent to it over the communications network. With FlexLogic, the N60 can use the status of measured inputs, along with the output of the protection elements, FlexElements and FlexMath summators, in Boolean logic equations to perform automated functions for customized special protection schemes.

Abnormal Frequency Protection

FlexMath

Detecting changes in the frequency at a particular location and relaying that information to other N60’s deployed across the network can allow for creating customized schemes such as shedding some load or islanding parts of the system to counter the effect of impending system problems. Frequency elements include underfrequency, overfrequency, and rate of change of frequency.

FlexMath uses a summator function to analyze and compare analog information that has been measured locally by the N60 and analog information that has been sent to it from remote N60’s. Using summators, the N60 can identify differences in power quantities measured across the network and be configured to make smart decisions on this information, such as, what breakers to automatically close to restore power to non-energized parts of the system. Each FlexMath equation is executed every power system cycle, which allows the N60 to react in real-time to changing power system events.

Protection and Control

The power swing blocking element provides the blocking of protection elements under power swing conditions. Negative sequence current supervisors provide extended selectivity for detecting evolving faults that may appear as a power swing event (faults with slow moving impedance locus). Additionally, the out-of-step tripping element can be used for tripping the generator when an unstable power swing is  detected.

Directional Power Two separate directional power elements are provided to detect reverse power and low forward power to interconnections that involve co-generation. Each element can be used to provide both alarming and tripping upon the detection of undesired power flow conditions.

Synchrocheck The N60 provides four synchrocheck elements that monitor voltage difference, phase angle difference and slip frequency to ensure proper breaker closure as per user requirements. Any

Monitoring and Metering The N60 includes high accuracy metering and recording for all AC signals. Voltage, current , and power metering are built into the relay as a standard feature. Current and voltage parameters are available as total RMS magnitude, and as fundamental frequency magnitude and angle.

Synchrophasors

FlexElements FlexElements can be used to create userdefined protection elements that are based on analog parameters measured by the N60, including currents, voltages, power, frequency and power factor. Each FlexElement will analyze the programmed analog parameter for absolute changes in the input, the rate of change of the input, or by comparing the difference between two measured inputs.

Scalable Hardware The N60 is available with a multitude of I/O configurations to suit the most demanding application needs. Each N60 can be configured to monitor up to 6 power system circuits, and when connected to other N60’s using interIED communications modules, can create a distributed logic scheme with each N60 measuring and protecting a particular portion of the system.

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With the ability of having up to 6 PMU elements in one device, the N60 permits accurate measurement of synchrophasors over an extremely wide frequency range. The N60 exceeds the IEEE C37.118 requirements for Total Vector Error (TVE) less than 1% over a range of 40Hz to 70Hz. Additionally, the N60 can measure and report synchrophasors over a frequency range from 30Hz to 90Hz with little effect on TVE and the new P & M class synchrophasor. A special feature of the N60 synchrophasor implementation is the ability to apply magnitude and phase angle correction on a per-phase basis for known CT and PT magnitude and phase errors. The N60 can apply magnitude correction of up to +/- 5% and phase correction of up to +/- 5 degrees, both of which can be applied to each phase. The N60 also provides the ability to adjust for delta-wye phase angle shifts or polarity reversal in the synchrophasor reporting of the sequence of voltages and currents.

Synchrophasor Records The N60 has the ability to record files of synchrophasor-measured data when instructed to, by user-configurable digital and analog triggers. The storing of synchrophasor data can programmed to record events of a pre-defined length, or have a dynamic recording length that will continue recording as long as the trigger remains either in the high state or until the internal memory of the N60 is filled. The user can select to have old synchrophasor records to be automatically overwritten when new data is available, or have them protected until later and cleared manually. Synchrophasor records can be analyzed using the COMTRADE viewer included with the EnerVista software.

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Network Protection

Power Swing/Out-of-Step

• RTDs and DCmA inputs are available to monitor equipment parameters such as temperature and pressure

N60 Network Stability and Security System

Fault and Disturbance Recording

Viewpoint Monitoring

Viewpoint Maintenance

The advanced disturbance and event recording features within the N60 can significantly reduce the time needed for postmortem analysis of power system events and the creation of regulatory reports. Recording functions include:

Viewpoint Monitoring is a simple-to-use and full-featured monitoring and data recording software package for small systems. Viewpoint Monitoring provides a complete HMI package with the following functionality:

• Sequence of Event (SOE) - 1024 time stamped events

• Plug-&-Play Device Monitoring

Viewpoint Maintenance provides tools that will create reports on the operating status of the relay, simplify the steps to download fault and event data, and reduce the work required for cyber security compliance audits. Tools available in Viewpoint Maintenance include:

• System Single-Line Monitoring & Control

• Settings Security Audit Report

• Oscillography - 64 digital & up to 40 analog channels - Events with up to 45s length

• Annunciator Alarm Screens

• Device Health Report

• Trending Reports

• Single-Click Fault Data Retreival

• Automatic Event Retrieval

EnerVista Integrator

EnerVista Software

• •Automatic Waveform Retrieval

The EnerVista suite is an industry-leading set of software programs that simplifies every aspect of using the N60 relay. The EnerVista suite provides all the tools to monitor the status of your system, maintain your relay, and integrate information measured by the N60 into DCS or SCADA monitoring systems. Convenient COMTRADE and SOE viewers are an integral part of the UR setup software included with every UR relay, to carry out postmortem event analysis and ensure proper protection system operation.

Viewpoint UR Engineer

EnerVista Integrator is a toolkit that allows seamless integration of Multilin devices into new or existing automation systems. Included in EnerVista Integrator is:

Viewpoint UR Engineer is a set of powerful tools that allows you to configure and test GE relays at a system level in an easy-to-use graphical drag-and-drop environment . Viewpoint UR Engineer provides the following configuration and commissioning utilities:

Network Protection

• Multilin Drivers • Automatic Event & Waveform Retrieval

• Graphical System & Logic Designer

User Interface

• Graphical Logic Monitor

The N60 front panel provides extensive local HMI capabilities. The local display is used for monitoring, status messaging, fault diagnosis, and device configuration. User-configurable messages that combine text with live data can be displayed when user-defined conditions are met.

• Graphical System Monitor

EnerVista Launchpad EnerVista Launchpad is a powerful software package that provides users with all of the setup and support tools needed for configuring and maintaining Multilin products. The setup software within Launchpad allows for the configuration of devices in real-time by communicating using serial, Ethernet , or modem connections, or offline by creating setting files to be sent to devices at a later time. Included in Launchpad is a document archiving and management system that ensures critical documentation is up-to-date and available when needed. Documents made available include:

• OPC/DDE Server

48 Configurable LED Indicators

Multi-Language Display • English • Russian • French • Chinese

• Manuals

• Turkish

• Application Notes

• German

• Guideform Specifications

User-Programmable Pushbuttons

• Brochures • Wiring Diagrams • FAQ’s • Service Bulletins

474

GEDigitalEnergy.com

N60 Network Stability and Security System

Typical Wiring

2

IA

F1c

IA1

F2a

IB5

F2b

IB

F2c

IB1

F3a

IC5

F3b

IC

F3c

IC1

F4a

IG5

F4b

IG

F4c

IG1

F5a

IA5

F5b

IA

F5c

IA1

F6a

IB5

F6b

IB

F6c

IB1

F7a

IC5

F7b

IC

F7c

IC1

F8a

3

5

IG

F8c

IG1

M1a

IA5

M1b

IA

M1c

IA1

M2a

IB5

M2b

IB

M2c

IB1

M3a

IC5

M3b

IC

M3c

IC1

M4a

IG5

M4b

IG

M4c

IG1

M5a

IA5

M5b

IA

M5c

IA1

M6a

IB5

M6b

IB

M6c

IB1

M7a

IC5

M7b

IC

M7c

IC1

M8a

IG5

M8b

IG

M8c

IG1

U1a

IA5

U1b

IA

U1c

IA1

U2a

IB5

U2b

IB

U2c

IB1

U3a

IC5

U3b

IC

U3c

IC1

U4a

IG5

U4b

IG

U4c

IG1

U5a

VA

U5c

VA

U6a

VB

U6c

VB

U7a

VC

U7c

VC

U8a

VX

U8c

VX

I

P2

I

U5c

VA

U6a

VB

U6c

VB

U7a

VC

U7c

VC

V I

P4

V

TC 1

TC 2

P7a P7c P8a P8c P7b P8b

SURGE

Digital Energy Multilin

N60 N60-H17-HLH-F8L-H6G-M8N-P6G-U8N-W6G

H1a H1b H1c H2a H2b H2c H3a H3b H3c H4a H4b H4c H5a H5c H6a H6c H5b

I

H1

V I

H2

V I

H3

V I

H4

V

H7a H7c H8a H8c H7b H8b

SURGE

UR TXD RXD

SGND

1 2 3 4 5 6 7 8 9

COMPUTER

1 2 3 4 5 6 7 8 9

8 3 RXD 2 TXD 20 7 SGND 6 4 5 22

CONNECTOR

CONNECTOR

RS-232 DB-9 (front)

W1a W1b W1c W2a W2b W2c W3a W3b W3c W4a W4b W4c W5a W5c W6a W6c W5b

I

W1

V I

W2

V I

W3

V I

W4

V

W7a W7c W8a W8c W7b W8b

SURGE

B1b B1a B2b B3a B3b B5b B6b B6a B8a B8b

CRITICAL FAILURE OUTPUT CONTROL POWER

HI LO

SURGE FILTER

NORMAL COM 1

ALTERNATE

Tx1

10BaseFL

W

U

V 8

Inputs/ CT/VT outputs

T

S

R

P

N

M

L

K

J

H

G

F

D

Shielded Remote Device

D1a D2a D3a D4b D4a

com

IRIG-B input

Fibre * Optic

10BaseFL

Rx2

10BaseT

IRIG-B output

DC

Rx1 Tx2

RS485

6

VA

V

P3

X

U5a

V

Network Protection

4

P1

IG5

F8b

P1a P1b P1c P2a P2b P2c P3a P3b P3c P4a P4b P4c P5a P5c P6a P6c P5b

I

6G

IA5

F1b

6G

1

F1a

6G

C

1

B

CONNECTION

A

BNC

Co-axial

BNC

Co-axial

minimum

B

6

8

6

8

9

1

Inputs/ outputs

CT

Inputs/ outputs

CT

CPU

Power Supply

PROVIDED

This diagram is based on the following order code: N60-H17-HLH-F8L-H6G-M8N-P6G-U8N-W6G This diagram provides an example of how the device is wired, not specifically how to wire the device. Please refer to the Instruction Manual for additional details on wiring based on various configurations.

GEDigitalEnergy.com

475

Ordering N60- * ** H * * F** H** M** P** U** W/X** For Full Sized Horizontal Mount Base Unit N60 Base Unit CPU E RS485 & RS485 (IEC 61850 option not available) J RS485 + multimode ST 100BaseFX K RS485 + multimode ST Redundant 100BaseFX N RS485 + 10/100 BaseT T RS485 + three multimode SFP LC 100BaseFX. Req FW v7xx or higher U RS485 + two multimode SFP LC 100BaseFX + one SFP RJ45 100BaseT. Req FW v7xx or higher V RS485 + three SFP RJ45 100BaseT. Req FW v7xx or higher Software Options 00 No Software Options (See note 1 below) 03 IEC 61850 06 1 Phasor Measurement Units (PMU) 07 1 Phasor Measurement Units (PMU) + IEC 61850 14 2 Phasor Measurement Units (PMU) 15 2 Phasor Measurement Units (PMU) + IEC 61850 16 4 Phasor Measurement Units (PMU) 17 4 Phasor Measurement Units (PMU) + IEC 61850 A0 CyberSentry UR Lvl 1. Req UR FW 7.xx or higher B0 IEEE 1588. Req UR FW 7.xx or higher C0 PRP D0 IEEE 1588 + CyberSentry. Req UR FW 7.xx or higher I0 6 x PMU I1 6 x PMU + IEC61850 M0 IEC 61850 + PMU + 61850-90-5 Mount H Horizontal (19" rack) - Standard A Horizontal (19" rack) - Harsh Chemical Environment Option User Interface F Vertical Front Panel with English Display I Enhanced German Front Panel J Enhanced German Front Panel with User-Programmable Pushbuttons K Enhanced English Front Panel L Enhanced English Front Panel with User-Programmable Pushbuttons M Enhanced French Front Panel N Enhanced French Front Panel with User-Programmable Pushbuttons Q Enhanced Russian Front Panel T Enhanced Russian Front Panel with User-Programmable Pushbuttons U Enhanced Chinese Front Panel V Enhanced Chinese Front Panel with User-Programmable Pushbuttons W Enhanced Turkish Front Panel Y Enhanced Turkish Front Panel with User-Programmable Pushbuttons Power Supply H 125/250 V AC/DC L 24 - 48 V (DC only) CT/VT DSP Required for PMU Option 8L 8L Standard 4CT/4VT w/ enhanced diagnostics Required for PMU Option 8N 8N Standard 8CT w/ enhanced diagnostics IEC 61850 Process Bus 81 8 Port IEC 61850 Process Bus Module Digital I/O XX XX XX XX XX XX No Module 67 67 67 67 67 67 8 Form-A (No Monitoring) Outputs 6A 6A 6A 6A 6A 6A 2 Form-A (Voltage w/ opt Current) & 2 Form-C Outputs, 8 Digital Inputs 6B 6B 6B 6B 6B 6S 2 Form-A (Voltage w/ opt Current) & 4 Form-C Outputs, 4 Digital Inputs 6C 6C 6C 6C 6C 6C 8 Form-C Outputs 6D 6D 6D 6D 6D 6D 16 Digital Inputs 6E 6E 6E 6E 6E 6E 4 Form-C Outputs, 8 Digital Inputs 6F 6F 6F 6F 6F 6F 8 Fast Form-C Outputs 6L 6L 6L 6L 6L 6L 2 Form-A (Current w/ opt Voltage) & 2 Form-C Outputs, 8 Digital Inputs 6N 6N 6N 6N 6N 6N 4 Form-A (Current w/ opt Voltage) Outputs, 8 Digital Inputs 6P 6P 6P 6P 6P 6P 6 Form-A (Current w/ opt Voltage) Outputs, 4 Digital Inputs 6R 6R 6R 6R 6R 6R 2 Form-A (No Monitoring) & 2 Form-C Outputs, 8 Digital Inputs 6S 6S 6S 6S 6S 6S 2 Form-A (No Monitoring) & 4 Form-C Outputs, 4 Digital Inputs 6T 6T 6T 6T 6T 6T 4 Form-A (No Monitoring) Outputs, 8 Digital Inputs 6U 6U 6U 6U 6U 6U 6 Form-A (No Monitoring) Outputs, 4 Digital Inputs 6V 6V 6V 6V 6V 6V 2 Form-A (Cur w/ opt Volt) 1 Form-C Output, 2 Latching Outputs, 8 Digital Inputs 4D 4D 4D 4D 4D 4D 16 Digital Inputs with Auto-Burnish 4L 4L 4L 4L 4L 4L 14 Form-A (No Monitoring) Latchable Outputs Transducer I/O 5A 5A 5A 5A 5A 5A 4 dcmA Inputs, 4 dcmA Outputs 5C 5C 5C 5C 5C 5C 8 RTD Inputs 5F 5F 5F 5F 5F 5F 8 RTD Inputs Inter-Relay Communications 2A 2A C37.94SM, 1300 nm singlemode, ELED, 1 Channel singlemode 2B 2B C37.94SM, 1300 nm singlemode, ELED, 2 Channel singlemode 2I 2I Channel 1 - IEEE C37.94, 820nm, multimode fiber, 64/128 kbps; Channel 2 - 1300 nm, singlemode, LASER 2J 2J Channel 1 - IEEE C37.94, 820nm, multimode fiber, 64/128 kbps; Channel 2 - 1550 nm, singlemode, LASER 7C 7C 1300 nm, singlemode, ELED, 1 channel 7H 7H 820 nm, multimode, LED, 2 Channels 7I 7I 1300 nm, multimode, LED, 2 Channels 7J 7J 1300 nm, singlemode, ELED, 2 Channels 7M 7M Channel 1 - RS422; Channel 2 - 1300 nm, multimode, LED 7R 7R G.703, 1 Channel 7S 7S G.703, 2 Channels 7T 7T RS422, 1 Channel 7V 7V RS422, 2 Channels, Dual ClockV 7W 7W RS422, 2 Channels, Single Clock 73 73 1550 nm, singlemode, LASER, 2 Channels 76 76 IEEE C37.94, 82 nm, multimode, LED, 1 Channel 77 77 IEEE C37.94, 820 nm, multimode, LED, 2 Channel

Ordering Notes: To view all the options available for N60, please visit GE’s On-Line Store http://store.gedigitalenergy.com/viewprod.asp?model=N60

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

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Multilin™ P30 Phasor Data Concentrator Wide area monitoring and dynamic disturbance analysis

Connectivity

The Multilin P30 Phasor Data Concentrator is a modular, substation rated, high performance device capable of collecting, processing, recording and archiving C37.118 compliant synchrophasor data.

• Up to 8 configurable C37.118 output channels

GE’s series of Multilin P30 PDCs and PMU devices leverage the latest advances in synchrophasor and computing technologies available for the power industry to enable synchrophasor based wide area monitoring applications.

• Configurable reporting (1 to 120 frames per second accuracy) • Supports up to 40 PMU inputs • Pseudo PMUs to notify Multilin P30 diagnostics

Recording and Archiving • Recording up to 100,000 values/second

Key Benefits • Reduce deployment and operation cost of wide area monitoring systems integrating more Phasor Measurement Units (PMUs) per PDC • Simplify analysis of power system events through fast and easy access to time synchronized phasor data archives

• Access to the archived database from up to seven locations simultaneously • Up to 16 simultaneous connections to Multilin P30 historians

• Implement NERC-PRC-002-2 (draft) compliant dynamic disturbance recording (DDR) systems

Security

• Integrate P30 PDC into NERC-CIP compliant systems using the built-in security features

• Designed for NERC-CIP compliant systems

• Enable control system wide area monitoring applications to reveal dynamics of the power grid though low latency time aligned synchrophasor signals

• Centralized user profiles (RADIUS)

• Customize wide area monitoring systems with the optional Multin P30 applications module without the costs associated with additional hardware

• Encrypted local passwords • Prevents installation of unauthorized firmware

Applications

Software

• Collection, aggregation, archiving of synchrophasor time aligned data within the Substation for enhanced post event analysis.

• Easy device setup and maintenance through the EnerVista suite

• Continuous recording and reporting of synchrophasor data through up to eight C37.118 clients for wide area monitoring applications

• Built in synchrophasor data analysis and reporting tools

• Deployment of NERC-PRC-002-2 compliant Dynamic Disturbance Recording systems

• Easy export of Multilin P30 historian data to Microsoft® Excel®

• Visualization of live or recorded synchronized phasor data at substation, multiple substations and regional control

PDC Phasor Data Concentrator

Overview

Traditional SCADA

Monitoring of electrical grid infrastructure is a critical task carried out continuously by system operators to ensure safe and reliable operations. Traditional SCADA systems give operators a view of the system’s operating conditions with a typical latency in the range of seconds and minutes. The relative low measurement frequency and low speed communications combined with the time required to execute analysis programs do not allow SCADA systems to handle system emergency operations in real time. Decisions are made based on static power system models where a trade-off with accuracy is generally needed.

Network Protection

Communication and computing technologies available today allow monitoring functions with sub cycle resolution for power systems over large geographical areas. The faster and higher resolution measurements introduced with synchrophasor technologies, also known as dynamic monitoring capabilities, enable wide area monitoring at the system level based on accurate and precise data at high-speed data rates with extremely low latency, less than 200ms. When applied to wide area applications, typically executed at the operation center level, synchrophasors enable operators to optimize system availability, reliability and stability analysis and operations. Phasor

Synchrophasors Monitoring

150

150

100

100

50

50

0

0 0

0.02

0.04

0.06

0.08

0.1 -50

-100

-100

-150

Monitored Signal

0.08

0.1

Synchrophasor

Monitored Signal

Static: Steady and non-synchronous measurements

Dynamic: Synchronous measurements

Resolution

1 – 10 second scan rates

Sub cycle scan rate capabilities

Latency

Seconds, minutes

<200miliseconds

Data Concentrators (PDCs) and the Phasor Measurement Units (PMUs), that supply control centers with phasor data, are key components of synchrophasor based wide area monitoring systems. GE’s series of Multilin P30 PDCs and PMU devices leverage the latest advances in synchrophasor and computing technologies available for the power industry to enable synchrophasor based wide area monitoring applications. The above table highlights key differences between traditional SCADA and synchrophasor monitoring technologies.

Multilin P30 PDC

Multilin P30 PDC

LAN

LAN

EnerVista Synchrophasor Viewer

Typical synchrophasor based wide area monitoring system architecture

GEDigitalEnergy.com

Connectivity The Multilin P30 Phasor Data Concentrator is a modular, substation rated, high performance device capable of collecting, processing, recording and archiving C37.118 compliant synchrophasor data. The Multilin P30 supports up to forty PMU or PDC inputs and up to eight user configurable channels for transmission of synchrophasor data to clients such as other PDCs, Super PDCs and/or EnerVista Synchrophasor Viewer.

High Performance PDC The primary function of the Multilin P30 PDC is to provide enhanced visibility of the electrical

Operation Center

ISO

Visualization

Visualization

Super PDC

Super PDC

PMU Data

478

0.06

Example: 100ms data for 115kV line voltage monitored with PDC at 120 frames per second

Regional Control Center

Distance Protection

0.04

Example: 100ms data for 115kV line voltage monitored with traditional SCADA. 1 poll every 2 seconds

Substation PMU/PDC

Multi-feeder Generator Protection Protection

0.02

-150

SCADA value

Monitoring

0

-50

Analytics

PDC Phasor Data Concentrator

power grid. The Multilin P30 PDC data collector module communicates with up to forty PMUs or other PDCs to acquire and time-align synchrophasor data. The Multilin P30 processor module structures output datasets from available data, interpolates, filters and decimates data as required.

C37.118 Clients • Up to 8 Client Connections

The Multilin P30 PDC can connect to up to eight output streams which can be individually configured to ensure clients such as other PDCs, Super PDCs, visualization devices, external historians and other external applications receive accurate and precise data at rates previously impossible to obtain from traditional SCADA systems.

Multilin P30 PDC

Easy Expansion and Customization of Multilin P30 PDC

Collector Module

Processing Module

Output Module

• Data Reception

• Time Alignment • Data Structuring

• Data Broadcast

The Multilin P30 Applications Processor option is available to users that need to integrate custom applications into their synchrophasor monitoring systems.

Historian Module

The Multilin P30 Applications Processor is equipped with a Windows® operating system that allows installation of user’s preferred applications including development tool kits.

• Up to 40 PMU inputs

Network Protection

Reduce synchrophasor based wide area monitoring deployment and maintenance cost by integrating more PMUs per PDC, while being compliant to NERC-PRC-002-2 dynamic disturbance recording requirements.

Applications Module

PMU Inputs

The Multilin P30 Applications Processor can reduce DDR systems deployment cost leveraging the infrastructure built in to the Multilin P30 PDC to expand and customize the PDC platform while maintaining the system reliability associated with the Multilin P30 substation rated platform.

Enabling Synchrophasor Based Wide Area Monitoring

• 1 to 120 frames/sec

• 1 to 120 frames/sec.

Multilin P30 Phasor Data Concentrator product architecture

Multilin P30 Supported Rates System Frequency

Input and output supported rates, Frames per Second (FS)

50Hz†

1

2

5*

10*

25

50

100

60Hz

1

2

5

10*

12*

15*

20*

30*

60

120

* Required per C37.118-2005 standard †

Available Q1-2012

GEDigitalEnergy.com

479

PDC Phasor Data Concentrator

Operation Center Visualization

Wide Area Data Analysis

Analytics

Output module transmits the concentrated PMU’s data to other PDCs, SuperPDCs and other external clients based on preset configuration

Super PDC

Regional Control Center Regional Data Processing &/Analysis Multilin P30

EnerVista Viewer

PMU/PDC data collection, time alignment, interpolation, filtering, decimation and decimate as required, and reporting up to 8 C37.118 clients.

EnerVista Viewer

Multilin P30

Ethernet Switch

Ethernet Switch

Substation Substation 1

Network Protection

Multilin P30

Substation 2

EnerVista Synchrophasor Viewer

Multilin P30

Multi-feeder Protection with PMU

Distance Protection with PMU

Multilin P30

EnerVista Synchrophasor Viewer

Ethernet Switch

Generator Protection with PMU

Substation N

Ethernet Switch

Line Protection with PMU

Multi-feeder Protection with PMU

Third-party PMU

EnerVista Synchrophasor Viewer

Ethernet Switch

Generator Protection with PMU

Multi-feeder Protection with PMU

Distance Protection with PMU

Data Collection Multilin P30 PDC collects data from C37.118 compliant PMUs at 1 to 120 frames per second. Multilin P30 PDC extracts, buffers, aggregates and archives data from up to 40 PMU devices.

Integration of Phasor Measurement Units (PMUs) PMUs connect to the instrument transformers on the power grid and serve current and voltage data to the wide area monitoring system. PMU function is becoming a standard function in most GE Protection & Control Relays. GE’s Multilin UR family of protection and control devices (D60, F60, G60, L30, L90, T60 and N60) support PMU capabilities. GE’s Multilin PMUs meet or exceed the requirements of the C37.118 synchrophasors for power systems standard for virtually all practical applications. The Multilin N60 Network Stability and Synchrophasor Measurement System for example supports up to four PMUs and can stream synchrophasors over its Ethernet ports at discrete rates from 1 to 120 frames per second. These high data rates

480

allow GE’s synchrophasor systems to measure and visualize the power system at twice the Nyquist rate for a 60Hz power system and therefore capture all essential waveform data.

Seamless Interface to Super PDCs The Multilin P30 PDC is designed to stream data to a Super PDC using the C37.118 protocol. Super PDC devices typically collect and archive synchrophasor data at the control and system level. Super PDCs are designed to run on nonsubstation rated powerful computing platforms with large processing and storage capacity in order to support the large volumes of synchrophasor data reported from PMUs, PDCs and / or Regional PDCs.

GEDigitalEnergy.com

Communications Infrastructure Requirements T h e b a n d w i d t h re q u i re d f o r P M U communications for a typical PMU including one Phasor, two analog channels, and sixteen digital channels reported at sixty frames per second is in the range of 70 to 75 kbps (kilobits per second). While it is possible to communicate synchrophasor information over serial communication channels, utilities taking advantage of synchrophasor technologies typically implement synchrophasor based wide area monitoring systems based on communication systems with that support Mega bit communications bandwidth.

PDC Phasor Data Concentrator

Recording & Archiving

NERC PRC-002-2 Highlights * Applicability

PRC-002-2 Dynamic Disturbance Recording (DDR)

• Transmission: substations having facilities rated 200kV or above • Generation: single generating unit of 500MVA or higher nameplate rating • Generation: generating plants with an aggregate plant total nameplate capacity of 1500MVA or higher

PRC-002 is a standard under development that will define the requirements for recording and reporting Sequence Of Events (SOE) data, Fault Recording (FR) data, and Dynamic Disturbance Recording (DDR). The purpose of the standard is to facilitate analysis of disturbances.

Dynamic Disturbance Recording (DDR) Data, Transmission & Generation Owners (Sections 7 & 8)

• At least one phase to neutral voltage • Frequency (at least one at the required substation) • At least one phase current • Power and reactive power

Specifications for DDR Data

• Use same phase for voltage and current recordings • Collect at least 960 samples per second to calculate RMS electrical quantities

FR and SOE are features commonly available today in protection relays and SCADA equipment.

• Store calculated RMS values of electrical quantities at a rate of at least 6 times per second • SOE, FR and DDR functions to within +/- 2 ms of Universal Coordinated Time (UTC)

The third type of recording defined in the PRC002-2 standard is DDR. Large interconnected systems can have inter-area responses to each other resulting in slow oscillating load swings. These disturbances are characterized by oscillating power swings that can have frequencies in the neighborhood of 0.1 to 4Hz, and duration in the range of a few seconds to minutes or hours.

• Have all recorded SOE, FR, DDR data available (locally or remotely) for 10 calendar days after a disturbance.

* Check NERC standard for latest available information.

The advanced high capacity disturbance and event recording features available in the Multilin P30 Substation Phasor Data Concentrator support the requirements of the PRC-002-2 standard and can significantly reduce the time needed for analysis and reporting of disturbance analysis and regulatory reports.

Local Archiving

A typical GE substation DDR system comprises of several PMUs reporting synchrophasor data at various different rates from 1 to 120 frames per second to a Multilin P30 PDC. Each of GE’s Multilin PMUs may include 1 to 14 sets of phasor values (Multilin N60). Below are some typical examples of different types of PMUs with various combinations of phasor, analog and digital parameters. Large volumes of data generated by a DDR system requires a fast and reliable archiving method to guarantee data integrity for future analysis.

Distributed synchrophasor data storage through local archiving is recommended under the following two scenarios:

The Multilin P30 PDC historian processor is a high capacity platform capable of recording up to 100,000 values per second.

1. Upstream communication channels don’t support the bandwidth to report all data monitored by the PDC. 2. Communication channels supports transmission of all data monitored by the Multilin P30 PDC. Archiving at the Substation level is introduced to increase system reliability and preserve monitored data in case of upstream channel communications failure.

Multilin P30 PMU Input Type Examples PMU TYPE

PHASORS

ANALOG CHANNELS

DIGITAL CHANNELS

FRAMES PER SECOND

KILOBIT PER SECOND

PMUS (QTY)

STORAGE CAPACITY (DAYS) 1098

Type 1

1

0

0

60

20.7

1

Type 2

1

0

0

60

414.8

20

55

Type 3

8

2

1

60

2193

28

10

Type 4

4

2

16

60

94.6

1

240

Type 5

12

8

16

60

171.5

1

132

Type 6

12

2

16

60

1188

8

19

Type 7

12

2

16

120

2370

7

11

Type 8

12

8

16

120

5135

15

4.4

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Network Protection

A dynamic disturbance recorder is a device cable of recording incidents that portray power system behavior during dynamic events such as low frequency (0.1Hz - 4Hz) oscillations and abnormal frequency or voltage excursions.

Multilin P30 Built-in Historian Capabilities

PDC Phasor Data Concentrator

Software

EnerVista Synchrophasor Viewer Software

EnerVista™ P30 Setup Software The EnerVista P30 Setup software follows the user friendly structure characteristic of the industry leading EnerVista suite of software applications. The EnerVista P30 Setup application provides easy access to the Multilin P30 PDC feature set through an intuitive tree view of the Multilin P30 parameters for a clear and simple configuration process. A series of convenient troubleshooting and diagnostic tools such as trending, Multilin P30 sequence of events recorder live view of actual values is available in EnerVista P30 Setup to optimize the testing, commissioning and monitoring activities. The Multilin P30 Setup software can operate without a Multilin P30 device physically connected to the computer allowing users to work on configuration projects and save settings in a configuration file for future use.

EnerVista Synchrophasor Viewer is a powerful yet simple to use synchrophasor data management and visualization tool. EnerVista Synchrophasor Viewer can be customized to provide different views of the power system in a time aligned, live view or time aligned replay of historical events over user defined time span. The visualization interface is based on an easy to use “worksheet” work environment. Users can create multiple worksheets on which multiple user configurable objects such as Phasor Displays, Trend Charts, Historian Statistics and PMU Status tables are displayed. EnerVista Synchrophasor Viewer supports up to 16 Multilin P30 historians simultaneously. Each historian can be accessed by up to seven concurrent users.

The EnerVista P30 Setup software user friendly structure Online Device Window • Online communication to device

Network Protection

• Copy online settings to files offline

Active Settings Windows • Consolidated views of device settings • Simple access to configurable parameters

Offline File Window • Direct access to device parameters from tree structured view • Input settings summary for optimized validation and configuration

482

GEDigitalEnergy.com

PDC Phasor Data Concentrator

EnerVista Synchrophasor Viewer Phasor display object:

PMU and Historian Status objects:

• Display up to 16 synchrophasor values with magnitude (length) and absolute or relative angles

• Visual Indication of triggered events

• One click “Best Scaling” feature for automatic optimized display adjustment

Trend chart object:

Worksheet work environment:

• User configurable X and Y scales

• Customizable worksheet layouts

• Sliding bars for quick indication of values at specific points in time or difference in values between two points

• Flexible grouping of objects for visualization of synchrophasor data from up to 16 P30 PDC historians

• PMU and historian Status and system health indication to facilitate Synchrophasor system operation

• Live view or replay of synchrophasor data from P30 PDC historian

Hardware Overview Back Panel 100,000 Values per second Recording 2500 tags 2 x 10/100/1000 BaseT Ports for Configuration and Historian Access

Applications Module

Electrical Connections Module

Windows XP Embedded System

2. Power Supply Fail Alarm Contacts

Network Protection

Historian Module

1. Power Input 3. IRIG-B (DC Shift) Input

External Power Source Dual SCADA Alarmed power supplies:

C37.118 Synchrophasor Processor Module

1. 36-72 VDC 2. 85-264VAC/88-280VDC

IEEE 1586.1 Single Width PCI Mezzanine Card (PMC) Expansion Slot

10/100/1000 BaseTX or 100 Base FX Ethernet Ports

Maintenance Port DB9 / RS 232 USB Port (Disabled)

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Technical Specifications PHASOR DATA PROCESSING SPECIFICATIONS

TYPE TESTS

Number of supported PMUs

Up to 40 PMUs

SAFETY

Synchrophasor data format

C37.118 2005

IEC60255-5

Dielectric Voltage Withstand

Number of c37.118 client connections supported

Seven concurrent C37.118 clients

IEC61010-1

Impulse Voltage Withstand

Supported data scan rate

1 to 120 frames per second

ENVIRONMENTAL

MEMORY AND STORAGE Historian recording capacity

100,000 values/second

Historian number of tags

2500

HARDWARE SPECIFICATIONS

Low Range

Environmental Testing Cold (0C)

IEC-60068-2-2

Environmental Testing Dry Heat (70C)

IEC-60255-21-1

Environmental Testing Vibration, Vibration Tests (sinusoidal)

IEC-60255-21-2

Shock and Bump Tests

IEC-60255-21-3

Seismic Tests

IMMUNITY

POWER SUPPLY High Range

IEC-60068-2-1

Nominal:

100-240VAC (50/60hz) 125 to 250VDC

Range:

85 to 264VAC (48/62hz) 88 to 280VDC

Ride though time:

35ms

Nominal:

48VDC

Range:

36 to 72 VDC

IEC61000-4-18/IEC60255-22-1

Damped Oscillatory

EN61000-4-2/IEC60255-22-2

Electrostatic Discharge

EN61000-4-3/IEC60255-22-3

Radiated RF Immunity

EN61000-4-4/IEC60255-22-4

Fast Transient Disturbance

EN61000-4-5/IEC60255-22-5

Surge Immunity

EN61000-4-6/IEC60255-22-6

Conducted RF Immunity

IEC61000-4-8

Power Frequency Magnetic Field Immunity

DIMENSIONS Form Factor:

19” Euro Chassis

WxDxH:

19x11.29x10.48”

COMMUNICATIONS Ethernet LAN

2 x 100 Base FX or 2 x 10/100/1000 Base TX

IRIGB

IRIG-B DC Shift (BNC or two wire connections)

Historian Module

2 x 10/100/1000 Base T Ports for Configuration and Historian Access

Ordering P30 Base Unit Ethernet Interface Type

*

**

**

XX

**

XX

***

P30

Base Unit T

P30 Synchrophasor Processor Module, 10/100/1000 Base TX Ethernet Ports, 8 PMUs

F Power Supply

P30 Synchrophasor Processor Module, 100 Base FX Ethernet Ports, 8 PMUs HI

HI

125/250VDC (88-280VDC); 120/240VAC (85-264 VAC, 50/60hz) input.

LO

LO

48 VDC (36-72 VDC) Input

XX Historian

No Secondary Power Supply Option XX

No Historian

02 PMU inputs

2,500 Tag Historian Option* 040

Up to 40 PMU inputs

XXX

Base Model: Up to 8 PMU Inputs

*Includes EnerVista Synchrophasor Viewer license.

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MultiSync™ 100 Modernize time synchronization for power systems Accurate time synchronization is required to coordinate the actions of protective relays, generator controllers, distributed resources, power system controllers, energy storage, and microgrids. Every device must be synchronized to the same time source to ensure coordinated action. Traditional time synchronization methods have shortcomings, such as the separate analog copper wiring required for IRIG-B or the lower accuracy of SNTP/NTP over Ethernet networks.

Precise Time Synchronization • Supports IEEE 1588-2008 and C37.238-2011 for power system applications • Operates as a master clock or ordinary clock

The MultiSync 100 uses the IEEE Standard 1588-2008 for Precision Clock Synchronization Protocols used in Networked Measurement and Control Systems, as well as the C37.238-2011 IEEE Standard Profile used in Precision Time Protocols within Power System Applications. As a result, the MultiSync 100 provides highly accurate time synchronization, and allows for the gradual retirement of less accurate or more costly methods.

• Part of complete GE end-to-end timing solution for protection and control

Key Benefits

Supports Common Methods

®

• Supports latest 1588-2008 and C37.238-2011 standards for Ethernet-based time synchronization • Upgrade existing substations to 1588 support without replacing existing time synchronization infrastructure

• Integrates into existing time synchronization networks by supporting traditional time synchronizing methods

• IEEE 1588-2008

• Provides accurate time synchronization for protection and control applications through MultiLink™ Ethernet switches, Multilin™ Universal Relays and Multilin 8 Series Relays

• IEEE 1588-2008 / C37.238-2011

• Designed and tested specifically for rugged environments such as utility substations

• IRIG-B

Applications • Power substations for synchrophasor and grid modernization applications • IEC® 61850 process bus sampled value applications • Industrial Ethernet for time-based control • Upgrading legacy installations to IEEE 1588

• NTP/SNTP • DCF77 • TTL • XYZ

Flexible Design • Compact size and DIN rail mountable case for easy mounting • Tested to substation environmental standards • Wide range, Isolated power supply

MultiSync™ 100

The need for cost-effective, accurate time synchronization

Upgrade to IEEE 1588 at low cost

Accurate time synchronization is becoming a critical requirement in today’s power system substations. For example: • Synchrophasor measurements to support wide area monitoring systems and remedial action schemes require time synchronization accurate down to 1 microsecond • Merging units, that publish sampled values for use by protective relays, meters, and control devices require time synchronization accuracy of 25 microseconds • Coordinating fault records and event logs across multiple devices requires time synchronization of 500 microseconds

Network Protection

There are two different challenges to the traditional method for time synchronization. The first is that time synchronization has been implemented by connecting end devices to a local satellite clock. This synchronizes all elements in a specific substation together, but this may not be adequate for system wide synchrophasor applications. The second challenge is that accurate time synchronization has required a dedicated time network. The most common method employed which provides the accuracy required is IRIB-G. IRIG-B sends out analog pulses, which requires a dedicated analog network built on copper wiring. This network must be installed separately, and is challenged by voltage drop due to distance and the number of connected devices, as well as electrical interference. SNTP/NTP can send time synchronization signals via an Ethernet network, but does not account for switching time delays, and therefore doesn’t meet the accuracy requirements of time sensitive applications.

IEEE 1588-2008 is the technical solution designed to provide cost effective time synchronization from devices in a substation up to the whole utility grid. The challenge to implementing 1588 in a substation is interfacing with devices that only support legacy time synchronization methods. The MultiSync 100 1588 GPS Clock is a cost-effective solution to this challenge. Compact size, with DIN rail mounting, provides great flexibility in installation. Network and analog output ports allow interfacing into legacy time synchronization networks while simultaneously providing IEEE 1588 signals. The MultiSync 100 supports common network time synchronization methods, including IEEE 1588, C37.238 and SNTP/NTP. The MultiSync 100 also supports common analog methods of time synchronization, including IRIG-B, TTL, and user defined pulse methods. The network and analog methods can be supported simultaneously by MultiSync 100. One compact, affordable MultiSync 100 GPS Clock can provide timing synchronization for 1588 compliant devices and legacy devices in the substation, providing a simple, low cost upgrade path.

A complete end-to-end solution for IEEE 1588

One compact, affordable MultiSync 100 GPS Clock can provide timing synchronization for 1588 compliant devices and legacy devices in the substation, providing a simple, low cost upgrade path.

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MultiSync™ 100

IEEE 1588-2008 support

A complete end-to-end solution for IEEE 1588

The MultiSync 100 clock is a 1588 GrandMaster clock that can be synchronized to a GPS satellite, and also an ordinary clock synchronized to a local or system wide 1588 GrandMaster clock. The operating mode is determined by the Best Master Clock algorithm. The MultiSync 100 supports both IEEE 1588-2008 and the C37.238-2011 Power Profile. Specifics of the 1588-2008 implementation are as follows:

The MultiSync 100 is part of a complete end-to-end 1588 time synchronization solution for power system substations and industrial applications. This solution includes:

• Timing accuracy is <100ns to UTC for 1588 and SNTP/NTP • Best Master Clock algorithm to determine GrandMaster or ordinary clock operation • Profile selection: 1588-2008 or C37.238-2011 • Peer-to-Peer and End-to-End delay support • Multicast operation • Typical ordinary clock PPS accuracy (single subnet) <250ns

• The MultiLink switches can operate as a 1588 Transparent Clock or 1588 Boundary Clock

Retrofit application



Network Protection

IRIG-B is a separate analog communication network just for timing.

• MultiLink ML3001/ML3100 Ethernet switches with 1588 modules

A utility desires to add 1588/C37.238 time synchronization to an existing substation. Installed devices only support IRIG-B or other traditional time synchronization methods. The MultiSync 100 integrates into the existing infrastructure through the included TTL (IRIG-B) analog output ports, while simultaneously publishing 1588/C37.238 time synchronization signals over the Ethernet network. Adding 1588 simply requires installing the MultiSync 100, and an Ethernet switch that supports 1588 such as the MultiLink ML3000 Series.

• Layer 2 or Layer 3 mapping

Before

• MultiSync 100 operating as a GrandMaster clock

After upgrade to IEEE 1588

Upgrade to 1588 over Ethernet while maintaining existing timing network for installed relays.

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MultiSync™ 100

Ease of configuration The MultiSync 100 provides intuitive software to completely configure all aspects of the clock, as well as to display time synchronization data. Timing and synchronization options include: • Worldwide daylight savings and local time configuration using rule based or fixed date methods • Adjustable holdover times for reliability for poor GPS coverage • Compensation for installation parameters such as GPS signal delay through antenna cable • Programmable outputs include: • IRIG-B (B00x/B22x) time code with selectable IEEE 1344 and AFNOR S87500 extensions • DCF77 time code • ¬1000Hz (500¬s) pulse • User defined pulse sequences with repetition rates from 20ms to 24 hours, and 100ns accuracy Configuration screen for MultiSync 100.

Connection drawings

Network Protection

Top of the clock

IRIG-B (TTL) Output IRIG-B (TTL) Output Alarm Contacts GPS Antenna Input

Bottom of the clock

Power Supply Inputs Ground Input USB Port Ethernet Port for 1588, NTP, configuration 488

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MultiSync™ 100

Technical specifications ELECTRICAL

OUTPUT OPTIONS

POWER SUPPLY

TTL

Voltage

36 to 300 VDC

Power drain

5 W max

ISOLATION Power to antenna

3.75kV

Power to I/O

3.75kV

General

Programmable pulses

From 1000 per second to 1 per day with programmable offset & duration

DCF-77

• DC level shift • Local or universal time

IRIG-B

• DC level shift or Modified Manchester • IEEE 1344 extensions (C37.118) • AFNOR NF S87-500 extensions • Local or universal time

INPUTS RJ45 UTP connector

10/100 Mbps

USB2.0

Type B

NTP

SNMP General

• V1, V2C, and V3 support, independently enabled • Configurable V1 and V2C community names and security groups • Fully configurable via SNMP • V3 User-based Security Module (USM) support • USM MIB support

USM authentication methods

MDS, SHA

USM privacy methods

• DES, AES (Ingress Protection rating)

NETWORKING

OUTPUTS

GENERAL

Sync indication output

200 V, 150 mA (max)

2 x TTL outputs

• Time codes or pulses or user defined • Electrical specifications: TTL/ CMOS compatible • 0-5 V, 150 mA sink/source • Timing accuracy ≤ 100 ns to UTC

DHCP

Auto-configuration with fallback to ARP tested link-local Address

VLAN

Packet tagging

PTP (IEEE 1588 V2) • One-step or two-step operation • End-to-end or peer-to-peer delay calculations • Layer 2 (Ethernet) or Layer 3 (UDP) transport • Slave only mode • Default profile support

General

ENVIRONMENT SPECIFICATIONS AMBIENT TEMPERATURES Operating temperature

-40 to +85 C

OTHER ENVIRONMENTAL Humidity (noncondensing)

to 95%

MECHANICAL PROPERTIES Dimensions (H x W x D)

45 x 110 x 155 mm

Weight

0.42 kg

Insulation

Metal DIN rail-mountable case with IP30 (Ingress Protection rating)

Power Profile support

C37.238

TLV support

C37.238

Alternate Time Offset TLV support

with automatic or manual offset

SNMP MIB support

C37.238

NOTIFICATIONS General

• SNMP trap generation V1, V2C, and V3 • SNMPv3 traps authenticated and privatized via USM • Syslog (RFC-3164 and 5424 verified)

Type tests

COMPLIANCE

APPLICABLE COUNCIL DIRECTIVE

ACCORDING TO

TEST

REFERENCE STANDARD

LEVELS

CE compliance

Low voltage directive

EN60950-1

Electrostatic Discharge

EN61000-4-2

Level 4

EMC directive

EN61000-6-2, EN61000-6-4

North America

cULus

UL60950-1, C22.2 No. 60950-1, CB Report including all country deviations

RF immunity

EN61000-4-3

Level 3

ISO

Manufactured under a registered quality program

ISO 9001:2008

IEEE 1613 (37.90.X) EMI immunity type tests TEST

DESCRIPTION

IEEE 37.90.3

ESD

LEVELS

20V/m 80-1GHz, 1.4 GHz to 3 GHz Fast Transient Disturbance

EN61000-4-4

Level 3 & 4

Surge Immunity

EN61000-4-5

Level 4

Conducted RF Immunity

EN61000-4-6

Level 3

Power magnetic Immunity

IEC61000-4-8

Level 3

Enclosure Contact

+/-2 kV, +/-4 kV, +/- 8 kV

Voltage Dip & interruption

IEC61000-4-29, IEC61000-4-11

Enclosure Air

+/-4 kV, +/-8 kV, +/- 15 kV

Ripple on DC power supply

IEC61000-4-17

Damped Oscillatory

IEC61000-4-12

IEEE 37.90.2

Radiated RFI

Enclosure Ports

35 V/m

IEEE 37.90.1

Fast Transient

Signal Ports

+/-4 kV @2.5kHz

D.C. Power Ports

+/-4 kV

Radiated & Conducted Emissions

CISPR22

Class A

IEEE 37.90.1

Oscillatory

Signal Ports

2.5kV common mode @1MHz

Sinusoidal Vibration

60255-21-1

Class 1

D.C Power ports

2.5 kV common, 1 kV diff. Mode @1MHz

Shock & Bump

60255-21-2

Class 1

Signal Ports

5 kV (fail-safe relay output)

D.C. Power ports

5 kV

Seismic

60255-21-3

Class 2

Safety

EN60950-1

standard

RF Immunity

IEEE C37.90.2

20 V/m, 80-1 GHz

Oscillatory Surge

IEC61850-3

Level 4 (4 kV)

Dielectric

IEEE 1613

2 kV, 500 V

Impulse

IEEE 1613

5 kV

IEEE 37.90 IEEE 37.90

H.V. Impulse Dielectric Strength

Network Protection

Approvals and certification

• Stratum-1 NTP & SNTP time server • Multicast & Broadcast server capability • Optional MDS authentication

Signal Ports

2 kVAC

D.C. Power ports

2 kVAC

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Environmental type tests TEST

DESCRIPTION

IEC 60068-2-1

Cold Temperature

Test Ad

LEVELS -40°C, 16 hours

IEC 60068-2-2

Dry Heat

Test Bd

+85°C, 16 hours

IEC 60068-2-30

Humidity (Damp Heat, Cyclic)

Test Db

95% (non-condensing), 55°C, 6 cycles

IEC 60255-21-1

Vibration

2 g at 10-150 Hz

IEC 60255-21-2

Shock

30 g @ 11 mS

Product ordering PART NUMBER

DESCRIPTION

MultiSync 100-P

MultiSync 100 1588/C37.238 GPS Clock

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Product Listing

Single Function Relays – Product Listing Overcurrent

Synchronism Check



IFC Time Overcurrent Relay



MLJ MID Digital Synchronism Check Relay



IAC Time Overcurrent Relay



IJS Synchronism Check Relay



DIAC/DIFC/DSFC Single-Phase Digital Overcurrent Protection

Differential



PJC Instantaneous Overcurrent Relay

BDD Percentage Differential with Harmonic Restraint



CHC Instantaneous Overcurrent Relay



HFC Instantaneous Overcurrent Relay



IFCV Relay with Voltage Restraint



SGC Negative Sequence Overcurrent



BGFL Ground Fault Relay

STD Percentage Differential with Harmonic Restraint CFD High-Speed Differential Relay



PVD Differential Voltage Relay



IJD Percentage Differential Relay



SBD Differential Voltage Relay

Voltage & Frequency

Directional & Timing Relays



TOV MID Modular Voltage Relay



JBC/JBCG Phase and Ground Direction Overcurrent Relays



IFV Time Delay Voltage Relay

JBCV Directional Relays



SAM Static Timing Relay



IAV Time Delay Voltage Relay



CFVB Voltage Balance Relay NBV Voltage Unbalance Relay



SFF Static Digital Frequency Relay



ICR Phase Sequence and Undervoltage



Single Function & Aux. Relays



Go online for the full listing of Multilin Single Function & Auxiliary Relays GEDigitalEnergy.com/Multilin

Phase Voltage Relay

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Product Listing

Generator Relays

Breaker Relays



CEH Loss of Excitation Relay



HGA 18 Reclosing Relays



CEX Angle Impedance Relay



Capacitor Trip Device



GSY Generator Protection Relays



SBC Static Breaker Backup Relays



GGP Power Differential Relay

Single Function & Aux. Relays

Single Function Auxiliary Relays – Product Listing Multicontact Auxiliary Relays

High-Speed Trip & Contact Relays



HEA Multicontact Auxiliary Relay





HSA Multicontact Auxiliary Relay



HFA Multicontact Auxiliary Relay

Auxiliary or Annunciator Relay



RDB86 High-Speed Trip and Lockout Relays

HAA Auxiliary or Annunciator Relay

Series 95 Lockout Relays

Auxiliary Relays

Hinged Armature Auxiliary Relay



NAA Auxiliary Relay



HMA Hinged Armature Auxiliary Relay



NGA Auxiliary Relay



HGA Hinged Armature Auxiliary Relay

Go online for the full listing of Multilin Single Function & Auxiliary Relays GEDigitalEnergy.com/Multilin

492

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Substation Automation Substation Automation Overview Providing the control and automation to build a more reliable power grid. GE is delivering a smart, cost-effective short-cycle solution for digitized substations which is scalable to meet the varying needs of utilities across the globe.

Featured Products Product brochures for featured Multilin substation automation systems offered by GE.

Featured Products

Substation Automation – Product Listing D20 MX Gateway

D20MX Substation Controller

495

The Multilin D20MX Substation Controller is designed to execute communications and energy management applications for the monitoring and control of electrical substations. Backwards compatible with exiting D20 installed accessories, it enables simpler and more efficient compliance with NERC-CIP requirements while providing a cost-effective option for extending the life of aging D20 systems.

D400

Advanced Substation Gateway

509

GE’s Multilin D400™ is a secure, substation-hardened gateway that collects metering, status, event, and fault report data from serial or LAN based Intelligent substation devices. The D400 summarizes data from the substation devices and makes it available locally/remotely through a standard secure web browser (HTTPS).

D.20 RIO

Distributed I/O Controller

517

The Multilin D.20™ RIO Distributed I/O Controller is a stand-alone, small form factor device designed to provide distributed I/O capabilities for easy connection to the D400 gateway though any point in the substation LAN. The D.20 RIO provides an interface to the Multilin D20 Series of I/O modules.

D25

Substation Controller

529

Substation Automation

GE’s D25 is a flexible, modular, and upgradable automation controller, suitable for both large and small Substation Automation projects in either new or retrofit situations. The D25 provides the tools and flexibility necessary to create customized automation and control applications including; communications & data concentrator, automation controller, metering & sequence of events fault recording, and transformer monitoring & control.

D20/D200

Substation Controllers

533

The D20/D200 substation controllers offer an industry leading design embedded with high value Substation Automation applications that provide cost savings, increased reliability, and improved operational efficiencies in your substations. The D20/D200 devices act as the gateway to SCADA master stations for IEDs in the station, or for downstream substations or feeders. A large protocol library facilitates communication to most existing substation devices for improved visibility and remote control.

Go online for the full listing of Multilin Substation Automation products GEDigitalEnergy.com/Multilin

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GE

GE DigitalEnergy Energy Digital

Modular Substation Automation Systems Overview

Modular Substation Automation Systems

Today’s Environment More than ever, utilities around the globe are facing an increasing number of challenges related to maintaining aging assets, improving grid stability, reducing costs, and complying with regulatory policies. Aging Infrastructure: With the majority of electrical infrastructure approaching or at the end of its design life, innovative monitoring and control is required to ensure reliable power flow across the networks. Grid Stability: Generation / load imbalance is driving the need for advanced monitoring and control of network devices and loads to maintain grid voltage and frequency stability. Legacy Intelligent Electronic Devices (IEDs): Legacy IEDs are approaching or at the end of their design life, driving utilities toward replacements. Aging Workforce: The transfer of domain knowledge and expertise is impacted by experienced workers who are retiring. Changes in Environmental Regulation and Policies: Increasing awareness regarding environmental and climate change is influencing how solutions are implemented. Cost Reduction: Utilities need to limit capital and operating expenditures without impacting reliability and security of supply. Proliferation of Technology: Faster adoption and penetration of modern technology is driving utilities to make quicker business decisions in regards to infrastructure and ever-evolving technology options.

Substation Automation

During the planning phase of a substation project, GE works side-by-side with customers to ensure that the system addresses the organization’s business and technical objectives.

Business Objectives

Technical Objective

Increased asset utilization

System performance

Increased life extension

Safety

Cost reduction

Reliability

Reduced project duration

Network efficiency

Working in partnership with customers, GE’s engineers have developed the Modular Substation Automation System offering based on critical customer requirements to address both technical business objectives and unique application requirements. Customers have experienced several benefits as a result of deploying GE’s Modular Substation Automation Systems including: • A 30% reduction in project design cost compared with traditional substation solutions. • Reduced operating and maintenance costs through integration with multiple vendors using GE's open architecture and standards adherence.

Changing workforce

Adoption of open standards

Compliance to regulations, standards and policies

Cyber security

Reduced outage times during construction Ingress protection

• Reduced design costs using GE's architecture and tools to standardize the design for a range of substations.

Our Experience

GE’s Solution GE’s Modular Substation Automation Systems offering brings together an extensive portfolio of products, services and engineering excellence to deliver the next generation of substation systems for our customers that address the challenges of legacy substation systems. GE’s Modular Substation Automation Systems offering can be pre-designed, pre-packaged and pre-tested to suit our customers’ philosophy and needs.

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Designed with scalability in mind to support a broad scope of projects ranging from large transmission to small distribution substations, the systems are also flexible to support several applications including power generation, transmission and distribution, wind and solar collector substations, heavy industries, mining and oil and gas.

Pioneering key advancements for the past 100 years, GE continues to lead the way in protecting, monitoring and managing substation systems, providing industry-leading global experience to our customers. GE continues to be a world leader in substation automation by continually introducing advanced products and systems, and providing experienced engineering teams for system design and installation. Coupled with local knowledge, GE helps ensure the needs of customers are met.

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Modular Substation Automation Systems

GE’s Modular Substation Automation System Offering Summary GE’s Modular Substation Automation Systems include a wide range of solutions to suit customers’ specific requirements and provide benefits such as improved network reliability, improved service restoration, reduced operating and maintenance costs, and enhanced visibility and control.

Integrated Protection and Control, Modular Automation System

Integrated Automation System

A pre-engineered, pre-packaged and pre-tested system that delivers:

A pre-designed, pre-packaged and pre-tested system built on gateways, remote terminals units (RTUs) and communication devices that delivers:

• • • • •

A protection & control (P&C) system Communication systems Automation systems Process Bus system Cyber security compliance

Did you know? GE was one of the first to introduce the modular platform concept of protection relaying with the development of the

• Automation gateways • Secure communication • Modern HMI

Modular Protection and Control Systems with or without Process Bus A fully integrated, modular solution set comprised of: • • • • •

Pre-engineered protection modules SCADA gateways Legacy IED integration IEC 61850-9-2 Multilin HardFiber Bricks Panel mounted HMI

Did you know? GE has more than 100 years of experience in delivering substation systems.

Multilin™ Universal Relays (UR). Substation Automation

Did you know?

Did you know?

For over two decades GE has

GE is a major player in

provided advanced substation

global transmission and

automation systems using

distribution substation

modern IEDs, LAN/WAN

automation systems.

communications and HMIs.

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Modular Substation Automation Systems

Integrated Protection and Control, Modular Automation System GE’s Integrated Protection and Control Modular Automation System is a pre-engineered, pre-packaged and pre-tested system that is: • Designed using GE’s modular Multilin™ Universal Relay (UR) and URPlus relays, the system is connected with GE’s Multiln HardFiber system eliminating the extensive use of copper wires in the control room and in the field. Customers can realize a 50% saving in cabling , trenching and conduit and this system can be deployed faster than legacy methods. The system can be pre-packaged in a modular control house and dropped in or built to reside in a control room. • A communication architecture built on industry leading MultiLink™ Ethernet switches that can deliver higher network availability, redundancy with Parallel Redundancy Protocol (PRP) and high throughput. • An automation System built on GE’s cyber secure Multilin D400 gateway delivering IED station bus integration with capabilities to integrate the substation to an enterprise Energy Management or Distribution Management System. • Cyber security compliant across the entire system design.

Integrated Protection & Control System Capabilities Protection & Control

Substation Automation

• Line • Network • Bus • Transformer

Automation • Gateways • RTU’s • Meters • Bay Control

Communications

Process Bus System

Transformer Monitoring

• IEC 61850-9-2 Process Bus • Primary Equipment Interface • Hard Fiber Communications • Multiple I/O Types

• Dissolved Gas Analysis • Multi Gas Measurements • LTC Monitoring • Bushing Monitoring • Advanced Analytics

PO

WE

Operations

• WAN • LAN • Serial • Router and Switches • Dual Self Healing LAN

EnerVista Maintenance

CO N

TR

BU

ILD

IN

G

N

RL

IN

E

TIO STA

B

SU

High Voltage Equipment

Gateway

Wide Area Measurement

• XD CVT • XD CVT LAN • XD Circuit Breaker

• Extensive Protocol Support • Redundont Configuration • Hot Swappable

• PMU’s • PDC • IEEE c37.118

Key Benefits

Features

• Reduced engineering, testing and maintenance requirements with highly reliable and virtualized P&C schemes • Increased network communications reliability with built in redundancy and abstracted communication technology in the P&C system • Advanced cyber security automation complying to NERC® CIP standards and providing advanced substation interlocking and alarm systems • Improved situational awareness through the advanced HMI

• • • • • • • •

Modular and pre-packaged P&C engineered systems Drop in control houses Cyber security compliance Validated communication architecture Redundant fiber optic self-healing WAN and LAN (PRP) Virtualized protection and control schemes Substation human machine interface (HMI) for monitoring and control Substation automation and enterprise integration

• Up to 30% reduction in engineering resources, up to 70% reduction in design and construction resources and up to a 40% reduction in project cycle time

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Modular Substation Automation Systems

Integrated Automation System GE’s Integrated Automation System provides the next generation substation system with pre-designed, pre-packaged and pre-tested automation system designed for transmission and distribution-type applications in new substation builds and retrofit projects. Approximately 30% of global transmission and distribution systems around the globe have been automated using a variety of GE technology, allowing customers to accelerate project implementation and increase cost savings. Built on industry leading gateways, RTUs and communication products, such as GE’s MultiLink Ethernet switches, the Integrated Automation System provides: • A highly available and reliable network for connecting substation IEDs using MultiLink Ethernet switches. • Automation gateways that can integrate modern IEDs to legacy IEDs to electromechanical devices for collecting both operational and non operational data. • Flexible and secure WAN communications utilizing GE’s MDS™ industrial wireless devices and Lentronics™ JungleMUX Multiplexers for SCADA EMS integration as well as teleprotection applications. • A modern HMI which delivers real time view and control of the substation and IT assets complying to IEC® 61850 and other standards.

Integrated Automation System Components Features

To EMS IEC 60870-101/104, DNP 3.0 Gateway

HMI

Engineering Station IED Configuration Gateway NMS Configuration

• Highly interoperable automation system • Simplified configuration and redundancy • Merging of P&C, Automation and IT departments

D400

Enervista

Station Bus - P&C Multilink Ethernet Switch

• Virtualization of P&C schemes and interlocking • Interoperable with Process Bus • Multi vendor interoperability

D60

D60

C90

• Non conventional signal measurements • Virtualization of meaurement and control • Interoperable with Station Bus

Multilink Ethernet Switch

• Transformer monitoring • Dissolved gas analysis • Multi gas measurements • LTC monitoring

Modern Switchgear

NC CTs/PTs

• Bushing monitoring • Advanced analytics

Key Benefits • Improved service restoration • Enhanced network visibility and control • Secure and highly available communications network with PRP support that is simple and easy to configure • Pre-configured to accommodate legacy systems • Simplified system alarms and complex substation interlocking throughout the system • Compliant NERC CIP architecture

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Substation Automation

Process Bus - P&C PLUS

Modular Substation Automation Systems

Modular Protection and Control System with Process Bus GE's Modular Protection and Control System with Process Bus consists of a pre-built and pre-commissioned protection and control system based on the Multilin HardFiber system and includes protection and control schemes for transformer, bus bars, and feeders. The offering is designed for transmission, distribution, solar and wind interconnect and collector and industrial substation applications. This system uses pre-commissioned HardFiber Bricks in mounting cabinets connected to pre-commissioned relay panels using fiber optic cables. The system can help customers reduce costs for cabling, trenching and conduit as well as decrease installation and commission costs due to less labor-intensive installation. The modular approach of this system allows customers to drive down project costs and reduce project cycle times. Once installed, the system provides customers with reduced maintenance and total cost of ownership.

IEC 61850-9-2 Brick-Based Optional Design An IEC 61850-9-2 brick-based solution with pre-packaged plug-in protection and control, typically used in distribution applications to simplify the protection and control design and to provide overall accelerated project delivery cycles. A pre-designed packaged solution simplifies the protection and control design of a distribution substation by providing plug and play functionality using bricks.

Hard Fiber Brick wires direct to Breaker Control Cabinet

To other Hard Fiber Bricks

Fiber Optic across yard

Substation Automation

Breaker Control Cabinet

Transclosure or plug in building

This design eliminates high energy current signals from protection and control cabinets by using fiber optic cables. It is particularly useful for quick engineering, manufacturing and site installation of a protection and control system.

Gateway for SCADA Function, Fault Record Retrieval, Automation

The brick-based system design is available in 2-bay or 3-bay outdoor enclosure configurations to suit application needs. The bricks are installed at the primary equipment location or provided in NEMA 4 brick boxes for outdoor deployment. This design also features a built-in test panel to facilitate brick testing at the site. Gateway Panel

Relay Panel as Appropriate

Key Benefits • Decreases project costs, such as engineering design and site acceptance, resulting in substantial economic benefits • Reduces cycle time driving accelerated customer acceptance and project duration • Integrates multi-vendor legacy protection relays and devices to advanced technologies • Provides a platform for additional levels of automation, reducing cost and enhancing efficiency • Enables faster service restoration and improves system reliability through better visibility and control • Reduces total cost of ownership by using the modular designs, significantly lower than custom panel design

500

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Test Panel

Modular Substation Automation Systems

Modular Protection and Control Systems without Process Bus GE's Modular Protection and Control System without Process Bus provides a flexible and fully integrated modular solution set based on GE's Modular Packaged Solutions (MPS). Modular Packaged Solutions are comprised of engineering, design, manufacturing assembly, wiring, testing and commissioning support for protection and control of power system applications. Adhering to GE’s world class quality and control standards, MPS features seamless integration with legacy and multi-vendor devices and systems.

Steps to Customize Protection Panels with MPS Modules Step 1

Step 2

Step 3

Select pre-designed, configurable MPS modules for your application

Select auxiliaries from extensive GE device libraries

Select an enclosure for your panel from variety of available options

Select the MPS modules from the following typical application library to best fit your application needs. Configure your panels with one or more (typically up to three) MPS modules for your application and desired functionality.

Select auxiliary devices such as Ethernet switches, RTU gateways, meters, etc. to best fit your needs. GE provides a typical range of the above mentioned devices, but more options and devices are available for your protection and automation applications.

Select the enclosure from typical protection panel enclosures and racks to best fit your application. The selection below provides a typical range, but we can also support more types/designs as needed.

Demonstration of Modular Packaged Solutions for Protection Panel Design

Generator Backup MPS

Breaker Failure Relay MPS

Line Distance Relay MPS

Transformer Main Protection MPS

Line Differential Relay MPS

Generator Protection & Control Panel design using MPS modules

Substation Automation

Generator Main Protection MPS

Line Protection Panel design using MPS modules

Key Benefits • Decreases project costs, such as engineering design and site acceptance, resulting in substantial economic benefits • Reduces cycle time driving accelerated customer acceptance and project duration • Integrates multi-vendor legacy protection relays and devices to advanced technologies • Provides a platform for additional levels of automation, reducing cost and enhancing efficiency • Enables faster service restoration and improves system reliability through better visibility and control • Reduces total cost of ownership by using the modular designs, significantly lower than custom panel design

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Modular Substation Automation Systems

Packaged Solutions for a Wide Range of Applications Generation

Transmission

GE provides fully integrated protection, control and automation packaged solutions for a range of small to large size generators, ensuring safe operation, and protecting these key power system assets from a variety of fault conditions and anomalies. GE’s Packaged Solution’s generator protection and control solution features ANSI and IEC compliant main protection devices and auxiliary components and subsystems.

GE provides protection, control and automation packaged solutions for variety of power transmission applications such as HV/EHV line protection, large transformer protection, and high or low impedance bus protection systems to name a few. These solutions are designed and manufactured to address a multitude of customer challenges ranging from installation constraints to rugged environmental applications.

Generator Protection and Control Solution

Advanced Bus Protection and Control Solution • Pre-designed, configurable advanced protection schemes

• Fully integrated, tested packaged solution

• Bus differential protection and control package

• High quality workmanship and accelerated delivery cycles

• Engineered solutions for custom transmission applications

Substation Automation

• Leverages advanced GE protection relays

Advanced GE Generator Protection and Control Packaged Solution used for protection of large gas and steam turbines.

502

Advanced Low Impedance Bus Protection and Control Packaged Solutions used for complex bus topologies.

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Modular Substation Automation Systems

Distribution

Automation & Industrial

GE’s Packaged Solutions offer smart distribution applications minimizing customer downtime and improving safety and reliability in power distribution networks. The standard pre-designed modular packaged solutions reduce the total solution cost while providing state-of-the- art protection, control and automation capabilities.

GE provides a range of RTU automation and industrial protection and control packaged solutions for medium to large industrial and utility applications. These solutions are provided as indoor, outdoor or pole-top solutions and are used for green-field and brown-field installations.

Pre-designed Distribution Solutions

Automation and Industrial Solutions

• Pre-configured modular protection and control solutions for distribution applications such as feeder, transformer and breaker • Designed for indoor or outdoor applications • Library of designs for common distribution applications to pick from

• Customized RTU solutions for variety of applications • Supported by large host and IED protocol libraries • Fully configured, factory tested solutions reducing installation and commissioning time at site Substation Automation

Distribution Protection and Control Packaged Solutions.

Industrial RTU Automation and Protection Packaged Solutions examples.

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Modular Substation Automation Systems

GE Modular Substation Automaton Systems Core Technology Components Protection and Control

Multilin UR Platform

Multilin UR Plus

Multilin F60

The Mutlilin UR platform refers to the hardware, protection, software and communications features common to all UR family members. The UR platform is the building block for modern substation protection, control and data communication solutions.

Based on the Multilin UR platform, the Multilin URPlus delivers high-end solutions for complex protection, control and automation applications.

The Multilin F60, a member of the UR family of protection relays, provides feeder protection, control, monitoring and metering in one integrated package.

Substation Automation

Communications

Lentronics Fiber Optic Multiplexers

MultiLink Ethernet Switches

Lentronics is a leading global supplier of rugged telecommunications solutions for electric utility, pipeline, transportation and industrial applications. The Lentronics Multiplexer family offers T1, SONET and SDH standards based solutions for both short and long range applications over optical fiber and other media.

The MultiLink family is a line of industrial and substation hardened Ethernet switches that deliver secure, reliable communications. Designed for the protection and control industry, the MultiLink Ethernet Switches ensure networks are always available, fast, and secure.

MultiNet1000 Router

MDS Industrial Wireless Communications

The MultiNet1000 is purpose-built for extremely harsh environments such as power utility substations, and meets IEEE® 1613 and IEC 61850-3 specifications for EMI/ESD protection.

MDS is the world’s leading single-source, end-to-end wireless solution provider. From wellhead monitoring to utility substation automation, our wireless devices are packaged for industrial environments and have been rated and tested to harsh industrial specifications.

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Modular Substation Automation Systems

Gateways and RTUs

Multilin D400

Multilin D20MX

The Multilin D400 is a secure, substation-hardened gateway that collects metering, status, event, and fault report data from serial or LAN based Intelligent substation devices.

The Multilin D20MX Substation Controller is backwards compatible with earlier versions of D20 RTUs. The D20MX enables users who have standardized on Multilin D20 architectures to implement cost effective life cycle management programs, extending the life of legacy D20 infrastructure, while migrating to current Substation Automation and cyber security industry standards.

Management Software

Substation Automation

PowerLink Advantage

Power Management Control System

GE Power

PowerLink Advantage (PLA) from GE is a HMI solution for high point count requirements providing an up-to-date, live view of the substation in near real-time.

Power Management Control System (PMCS) is a highly customizable, fully integrated end-toend Energy Management Solution providing tools for Monitoring, Power Quality, Control and Automation and Cost Allocation.

GE Power is is an open, standards (IEC 61850) SCADA solution that is easy to configure. It is designed for substation automation and P&C applications.

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Modular Substation Automation Systems

GE’s Professional Services Process Based on years of experience and several deployments across multiple applications and industries, GE has developed a Professional Services Process . The process is comprehensive, application specific, and includes customer collaboration for successful project implementation. GE's Professional Services Process is based on a common set of building blocks, utilized and tailored for each customer’s unique communication network requirements. While GE uses well documented and repeatable processes, we realize that flexibility is also key to accommodate our customer’s specific requirements and needs unique to their environment.

Elements of a Successful Project

Open Communication and Team Work The most effective way to drive project performance is proactive communication with our customers. This is a priority for our projects team. A strong and collaborative relationship between the customer and GE increases the chances of a successful project.

A Well-Defined Execution Framework Project success depends on up-front planning as well as a mutually agreed upon execution framework that includes clearly defined deliverables.

GE's Global Capabilities

GE’s number one priority is helping customers successfully implement projects that meet their operational and economic goals. Based on our experience, we have identified a number of factors that are critical to the success of a well-implemented project:

Dedicated Project Management GE assigns a project manager at the beginning of each project to lead the team throughout the project lifecycle. The project manager acts as an extension of the customer’s team to coordinate and drive all aspects of the project to a successful outcome.

GE‘s dedicated engineering teams are located in regions around the world and bring a wealth of international experience to every project. Customers benefit from GE’s local systems subject matter experts who drive compliance with regional/local requirements ensuring our customers business and technical objectives are met. GE has an excellent track record in planning, executing and delivering a broad range of projects. GE’s systems subject matter experts work in state-of-the-art facilities that include design, research and development, manufacturing and testing capabilities. Customer are supported with 24/7 field and application support.

Substation Automation

GE’s Professional Services Process and Key Activities Definition Definition

Analysis Analysis

• Physical Site Audits

• Power Flow Analysis

• Site Survey

• Fault Level Analysis

• Equipment Audits

• Network Analysis

• Equipment Testing

• Communications Bandwidth Analysis

• Requirements Definition • System Concept Design

• Standards Compliance • Security Analysis • Failure Effects Predication

Design

Support

• Design, Selection & Layout for Protection, Automation and Communications

• Turnkey Projects

• Technical Services

• Procurement

• Consulting Engineering

• Integration

• Dissolved Gas Analysis

• HMI Scenes Design

• Standards Compliance

• Field Services

• Database System Design

• Equipment Testing/FAT

• Remote Monitoring

• Commissioning

• Returns Services

• Bill of Materials Planning

• As-Built Drawings

• Online Store

• Drafting • Test Plan Development • Commissioning Plan Development

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Implementation

GEDigitalEnergy.com

• System Optimization • Training

Modular Substation Automation Systems

Implementing a Project Below are highlights demonstrating the project implementation process customers experience once they have decided to engage with GE’s Systems Center of Excellence to implement a Modular Substation Automation System.

Phase 1: Defining Scope of Work The first phase of the project is to gather information about the customer’s project requirements. During the definition phase of a project, GE will: • Capture the strategic objectives of the project. • Meet with customers and key stakeholders to collect system requirements which can range from latency and throughput, specifications to required coverage areas, and end-points. • Provide customers with a requirements document and initial systems concept design.

Phase 2: System Analysis The analysis phase of the project allows engineers to validate the initial concept design and verify that it meets customer expectations. During this phase, GE can provide: • Protection and control system analysis to ensure reliable and efficient power flow • Automation system analysis to provide optimal network reliability and efficiency • Communications system analysis to ensure proper bandwidth and response times • Operator requirements analysis to ensure maximum situational awareness • Remedial action analysis to eliminate outages or minimize impact of outages • Asset management requirements • Provide customers with a requirements document and initial systems concept design.

Phase 3: Final System Design Development During the design phase, GE finalizes a system design that can be implemented to meet the customer’s scope of work and requirements. During this phase, GE can provide: • Protection and control of primary equipment design Substation Automation

• Automation system design • Communications system design • Substation gateway design • Substation operator HMI display and database design • Application selection

Phase 4: Project Implementation Regardless of the size or scope of a project, GE assigns a project manager to oversee all of the activities and associated details to ensure successful project implementation. During project implementation, GE can provide: • Procurement of all equipment and services • Panel construction • Integration of all equipment • Factory acceptance testing • Commissioning • Training

Phase 5: Supporting our Customers GE’s commitment to customer satisfaction is a primary goal – just because the project is complete, GE’s job is not done. A primary responsibility is continued support of the implemented system throughout its lifecycle, where GE provides: • Access to regional teams available for on-site troubleshooting and equipment testing and replacement • 24/7 field and applications support

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Digital Energy Systems Portfolio Summary Digital Energy has designed and delivered thousands of projects and systems in every region around the world addressing customer challenges across the energy value chain. GE’s projects and systems consist of components that provide robust technology solutions that are readily available with a proven track record of delivery, reducing both risk and complexity for customers.

Grid Automation Systems GE’s Substation Automation devices offer a seamless and scalable solution for automating and providing visibility to power system networks. Led by a team of seasoned industry experts, GE can develop, integrate and deliver a complete automation system that is tailored to a customer’s specific needs and requirements.

GE’s Grid Automation Systems Offerings Include: • Packaged protection and control for utilities and industrial substations • Substation automation for transmission and distribution substations • Industrial energy management system for Oil & Gas and Mining • Micro grid control systems for grid/off grid connected applications • Communications systems for utilities (LAN, WAN), industrial and specialized communications backhaul system for transportation and oil and gas • End-to-end AMI systems • Distribution Automation Systems delivering reliability and efficiency

Software Systems GE’s Software Solutions provides a range of innovative software technologies offering customers end-to-end visibility, management, control, and analytics capabilities. GE’s software offerings enable critical network assets with geospatial systems, mobile workforce applications, and communications management. GE’s PowerOn™ suite delivers end-to-end grid control for security and stability of supply, enabling operators to restore power faster when unforeseen problems cause outages.

GE’s Software Solutions Offerings Include: • Asset Management including Geospatial Information Systems • Asset Control including Energy, Distribution, Outage, and Demand Response Management Systems • Grid IQ™ Insight Analytics • Grid IQ Solutions as a Service (SaaS)

Power Delivery Systems GE's Power Delivery business provides high and medium voltage power equipment to support a wide range of applications. GE can deliver these solutions in a variety of ways that best support our customers needs, delivered as products, engineered equipment packages, or as complete turn-key projects.

GE’s Power Delivery Systems Offerings Include: • Electrical Balance of Plant • Flexible AC Transmission Systems (FACTS) • Utility and Industrial Substations

GEA-12776(E) English 150121

Multilin™ D20MX Simple to Advanced Substation Automation Control

Economical Life Extension

Distribution and transmission industries are under pressure to ensure that their grids are reliable and to prolong the usability of their assets. Data from these assets can be collected, aggregated and processed, to provide visibility of system conditions. The MultilinTM D20MX Substation Controller is a specialized computing platform designed to execute communications and energy management applications for the monitoring and control of electrical substations. The D20MX is capable of amalgamating data from multiple slave devices and D20 I/O modules connected via communication channels into a single database using various protocols. The D20MX can execute local logic, compile data, process it through one of multiple applications and report the results upstream to master stations through different server protocols.

• Backward compatible with earlier D20 RTU chassis (VME and non-VME), simplifying upgrades and reducing associated time and costs

The D20MX represents the next innovation in GE’s cyber secure RTU technology for NERC-CIP environments. The D20MX is built upon the field-proven Multilin D20 technologies and continues the tradition of reliable automation and control through high quality and long term product availability.

• Employs super capacitors instead of lithium batteries, extending operation and availability, retaining system clock and eliminating the need to plan for and replace dead batteries

Key Benefits • Reduces legacy D20 RTU upgrade expenditures by over 50% through backwards compatibility with existing D20 installed accessories, such as chassis, modems and D20 I/O peripheral modules • Minimizes operation and maintenance costs of existing D20-based SCADA infrastructure by leveraging existing designs, processes and infrastructure • Introduces a new and modern network security feature suite that enables effective compliance with NERC® CIP requirements through the application of native cyber security features built into the D20MX Substation Controller

Applications Data Concentrator Automatically consolidates collected information from intelligent electrical devices (IEDs), such as relays and meters, and communicates to SCADA, EMS, DMS and Data Historian systems

Protocol Converter Translates different data message formats between devices to support interoperability

• Modular hardware platform combines functions onto a single board, simplifies ordering, eliminates add-on expansion memory cards and cables, and decreases service time and maintenance effort

Cyber Security and Risk Management • Supports Cyber-Ark functionality for increased security while providing remote access • Supports open standard cyber security features that for NERC CIP interoperability • Syslog integration into enterprise system assists with audit compliance • SSH and SFTP provide secure firmware and configuration file transfer

Flexible and Reliable • Configurable redundant and dual LAN options with built-in dual Ethernet communication ports

Local Automation Platform

• Alias IP address provides simultaneous communications with both redundant and dual LAN devices

Implements popular distribution automation applications such as capacitor bank control, outage prevention programs, feeder resource optimization and control interlocking, inhibition and subgrouping

• Multiple and simultaneous SCADA protocols for communication to multiple masters • Robust, advanced automation applications based on more than two decades of successful experience

D20MX Substation Controller

Advanced Controller The Multilin D20MX Substation Controller collects, filters, and sorts data from a wide range of intelligent devices (RTUs, relays, meters) in the substation. The D20MX preserves original data time stamps for accurate sequence of event (SOE) logs, allowing data from large diverse geographic regions and time zones to be analyzed in extreme detail. Data can be presented simultaneously to multiple SCADA hosts. The D20MX comes with a built-in suite of protocols and security applications to facilitate integration with various substation devices and SCADA hosts. D20MX is the sixth generation of D20 CPUs designed to provide a smooth migration path for D20 users to extend the life of aging D20 systems. It introduces a new and modern network security feature suite that enables effective compliance with NERC-CIP requirements, using open and trusted standards and protocols that allow integration with modern cyber security systems and tools.

Advanced Substation Controller Connectivity Sample Enterprise Protocols: • DNP3 serial and Ethernet [TCP/UDP/IP] • Tejas V • HR6000/XA-21 • Modbus serial (RTU or ASCII)

SCADA

EMS

DMS

DATA HISTORIAN

• IEC 101/104 • LG-8979 • PG&E

D20MX Media Connectivity: • 7 serial ports (RS232) • Built-in dual Ethernet ports

Multilin D20MX

• (10/100/1000 Base TX or 100 Base FX) Dual D.20 communication ports

Sample Device Protocols:

Ethernet Switch

• DNP3 serial and Ethernet[TCP/UDP/IP] Substation Automation

• Modbus serial (RTU or ASCII) • IEC 101/104 • SEL Bay Controllers

• IRIG-B support

Protection Relays

IEDs/Meters

D20MX Controller Main Connectivity Applications GE P/N B021-0 B021-0 A068 A033-5 A185-0 A009 A101-0 A003 A135-0 A023

SERVER PROTOCOLS [DPA] DNP3 DPA DNP3 DPA Modbus DPA Tejas V DPA LG 8979 DPA PG&E DPA IEC 60870-5-101/104 DPA Harris 6000/XA-21 DPA Modbus TCP/IP DPA CDC TYPE I DPA

V1.1 • • • •

GE P/N B023-0 A059 A078-0 B060-0 A131-0 A018 A194-0 B080-0

CLIENT PROTOCOLS [DCA] DNP3 DCA Modbus DCA SEL DCA IEC 60870-5-101/104 DCA Modbus TCP/IP DCA Quantum Meter Scanner DCA COOPER 2179 DCA IEC 60870-5-103 DCA

V1.1 • •

510

V1.2

V1.3

V1.4

• • • • • • V1.2

V1.3

V1.4

• • • • • •

GE P/N A030 A035 A118 A184-0 B009 A123-0 A113

DATA TRANSLATION APPLICATIONS [DTA] Accummulator Freeze DTA Analog Reference DTA Failover DTA General Alarm DTA Mailbox DTA NGC General DTA Programmable Synchro Check Relay DTA

A036 A027 A088-0 A027-1 A083-0 A195 B099-0 B082-0 A041-1

Prologic Executor DTA SOE Logger DTA Substation Maintenance DTA Communications Watchdog Calculator DTA Redundant I/O DTA SNTP Client DTA LogicLinx Executor DTA Proportional Integrator Derivative Control DTA

B148 A017 A161-0 A121-0 A048 A104-0N A193-0 A186-0 B119-1N

Time Zone and DST Setting DTA DNP V1.00 DATA LINK DTA Secondary Master Trip/Close DTA Automatic Frequency Selection DTA Status Combination DTA Alarm Grouping DTA Top of the Hour Analog Averaging DTA Western Power Distribution (WPD) DTA LAN Redundancy Manager DTA

GEDigitalEnergy.com

V1.1 • • • • • • •

V1.2

V1.3

V1.4

• • • • • • • • • • • • • • • • • •

D20MX Substation Controller

D20MX Classic and Advanced Automation Applications APPLICATION ID

NAME

APPLICATION ID

D20MX CLASSIC APPLICATIONS

NAME

D20MX CLASSIC APPLICATIONS

A009

PG&E DPA

A041-1

Proportional Integrator Derivative Control DTA

A033-5

Tejas V DPA

A018

Quantum Meter Scanner DCA

A036

Prologic Executor DTA

A023

CDC Type I DPA

A113

Programmable Synchrocheck Relay DCA

A017

DNP V1.00 Data Link DTA

A185-0

8979 DPA

A194-0

COOPER 2179 DCA

D20MX ADVANCED AUTOMATION APPLICATIONS

A199-0

HR6000/XA-21 DPA

B082-0

Upgrade of Legacy D20 RTUs

Logiclinx Executor DTA

D20MX Upgrade Process

The Multilin D20MX is more than an RTU. It’s a commitment to the ongoing long term availability of GE’s automation products. Utilities have large investments in hardwired automation systems. Like everything else, this industrial equipment has a lifecycle that moves from infancy to normal operation, and eventually to the wear out stages. As a piece of equipment ages it fails more frequently, takes longer to repair, and eventually reaches the end of its life. Re-design and forklift replacements require utilities to re-engineer substation designs, replace field wiring, and retrain staff to manage and maintain the system, which is a costly endeavor.

D20MX UPGRADE SOLUTION

Full replacement of existing D20 Unit and existing I/O modules

Upgrade CPU to D20MX Retain existing I/O modules • Retain I/O infrastructure • Replace central • Minimize • Migrate to modern technologies

INSTALLATION COST Modify field wiring

Yes

Not required

Modify engineering drawings

Yes

Not required

Building expansion

May be required

Not required

Marshaling panels

May be required

Not required

OutagesOUTAGES

Yes

Minimal

Modify operation processes

Yes

Not required

Retrain operations personnelR

Yes

Minimal

Built-in cyber security features

Unknown

Yes

Proprietary solutions

Unknown

Modern open industry standards

MAINTENANCE

CYBER SECURITY

Substation Automation

The Multilin D20MX provides a cost-effective alternative to upgrades of legacy D20 RTUs. This means that the investments made in GE’s automation systems keep paying dividends beyond their originally projected end of life. Simply replace the failed or end of life Multilin D20 processor module with a Multilin D20MX and migrate the device configuration to extend the life of the existing D20 Controller. Add cyber security features for integration into NERC-CIP environments. As technology changes with market demands, GE continues to invest in a partnership with their customers through advanced modular design principals.

RTU UPGRADE SOLUTION

Integration of D20 Substation Controllers into NERC-CIP Environments If one of the current users of your D20MX leaves your company, you can lock down access to all the devices in your network from a central location. That user instantly loses access to every D20MX, while other users remain able to do their jobs without any adverse effects and costly password change programs.

The Multilin D20MX supports a comprehensive set of security functions to allow a seamless integration with existing IT department policies. Built-in cyber security features, such as Remote Authentication Dial-In User Service (RADIUS), Role Based Access Control (RBAC), and user activity logging, provide a complete security toolkit required to enable effective compliance with NERC-CIP requirements, using open and trusted standards and protocols, that allow integration with modern cyber security systems and tools.

AAA Network Access

RADIUS

Radius servers use the AAA concept to manage network access by following a few steps referred to as AAA transactions.

RADIUS is a client/server networking protocol that provides centralized authentication, authorization, and accounting (AAA) management for computers to connect and use a network service. With RADIUS each user in your system has their own unique identification login, allowing you to control who gets access to what devices from where. RADIUS provides centralized AAA management for computers to connect to the D20MX.

Authentication The user sends a request to gain access to a particular resource using access credentials, typically, in the form of user name and password.The RADIUS server verifies the user’s credentials and accepts or rejects access. The D20MX supports primary and secondary RADIUS servers. If for any reason the D20MX is not able to authenticate the user against the RADIUS servers, the D20MX verifies the user’s credentials against a local password file.

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D20MX Substation Controller

Authorization In a typical centralized user authentication system, access terms are defined on a per user basis. For example, the following authorization attributes may be associated for a specific user: • Specific D20MX IP address to be accessed by the user • Role ID assigned to the user, where role ID defines which commands and displays the user is able to access on the D20MX • Allowed time-of-day during which users can access the network

Accounting When access is granted to the user, their activity can be registered for security, system integrity monitoring and statistical purposes. For example, the following user’s activity can be recorded:

DESCRPTION

ADMIN

ENGINEER

OPERATOR

OBSERVER

CAN CHANGE PASSWORD

YES

NO

NO

NO

CAN CLEAR LOGIN BUFFER

NO

NO

NO

NO

CAN CHANGE SCADA

YES

YES

NO

NO

CAN DOWNLOAD FIRMWARE

YES

YES

NO

NO

CAN PERFORM OPERATIONAL CONTROL (E.G.: BREAKER OPERATIONS)

YES

YES

YES

NO

CAN VIEW OPERATIONAL DATA

YES

YES

YES

YES

• User information • Login time stamp

Advanced Automation

• Logout time stamp The D20MX provides accounting information by logging the user’s activity to a remote syslog server.

RBAC RBAC is achieved using RADIUS or the D20MX’s internal database, ensuring only authenticated and authorized users gain access to the system.

Substation Automation

When you configure the D20MX to use RADIUS, each D20MX user is identified by a role ID, which is an integer number provided by the RADIUS server. The D20MX makes your life easier by including a pre-configured default RBAC model. When using RADIUS, revoking user privileges system-wide is as simple as updating the centralized user database, saving you time and money.

Since releasing the first generation D20 back in 1988, GE’s automation experts have learned a lot. Through challenging projects and installations across the globe, the D20 has evolved into a leader in substation automation. The culmination of that experience is the sixth generation, the Multilin D20MX. The following are a sample of the advanced automation features available today.

Substation Maintenance If there is one thing operators hate, it’s false alarms. The D20MX can suppress reporting of input points while they are unavailable during maintenance. This allows users to disable groups of analog and digital input points by ignoring their actual data and quality changes within selected applications. While points are suppressed, a predefined suppression value and the point suppression quality flag are provided instead. This is useful during maintenance operations to prevent spurious OFFLINE alarms and inaccurate readings while devices are powered off or disconnected during the execution of maintenance activities.

Centralized Authentication and Authorization

USER 1. Login attempt

D20MX

NETWORK CONNECTION 2. D20MX RADIUS client sends user’s credentials to RADIUS server

3. Valid user – RADIUS server accepts user

4. Invalid user – RADIUS server rejects user

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RADIUS SERVER

D20MX Substation Controller

Accumulator Freeze Monitoring constantly incrementing and changing values, such as time of use, and energy consumption across a system, makes accurate comparisons of data a time-consuming effort. GE’s accumulator freeze application simplifies this process automatically by capturing the instantaneous value of accumulator records across the system at the same point in time, giving engineers and operators a clear understanding of the state of their system. A popular example of the use of accumulators is energy metering, where pulse streams from meter pulse generators is proportional to energy flow. This feature allows users to define groups of accumulator points whose values are frozen periodically or on demand.

Alarm Management The D20MX manages alarms based on real substation experience. This application allows user-defined logical grouping of individual digital inputs to generate general alarms based on the status of the signals monitored within each group. Alarm groups are user-definable, with up to 32766 groups allowed. Status inputs may belong to as many groups as required. The great flexibility of this application ensures that each group has its own meaningful description and configurable latching or non-latching operation modes. Latching alarms require operator acknowledgement for optimized management of critical conditions in the system.

System Redundancy Although the D20 family of RTUs is legendary for quality, GE has prepared for those rare cases when a processor is unable to function. Through time tested and utility accepted redundancy mechanisms, the D20MX is designed for high availability requirements. In redundant processor mode, one device stands waiting, ready to take over, should the other unit stop functioning.

Dual D20MX units can be deployed, creating a redundant system where accumulators are automatically synchronized between the two systems and configurations are synchronized on demand. Serial communication links are automatically switched between the units based on system health. The D20MX has redundant Ethernet , enabling automatic switchover between two sets of Ethernet switches, ensuring there is no single point of failure in the system.

Control Lockout The control lockout feature ensures that only a single master station can access a group of controls at one time, and can lock out groups of controls to allow for safer local maintenance. Users can create custom control groups. Any digital output can be included in any control group.

Analog Inputs Monitoring GE’s analog reference provides enhanced and simplified monitoring of analog input monitoring equipment. Operators define a reference value used to compare against monitored signals. The application reports failures in analog input hardware, allowing effective maintenance of the monitoring devices, reduced downtime and increased reliability of the system.

SGConfig Setup Software The Multilin SGConfig software integrates support for the complete portfolio of GE’s Substation Controllers, including the D20MX series. The SGConfig software introduces an updated graphical user interface while maintaining configuration processes and workflows available in the ConfigPro setup software.

Typical Architecture for Redundant D20 Substation Control System SCADA Masters

WAN RS232 Switch RS232 Communications

D20MX

D20MX

WIRED I/O

Ethernet Switch A

LAN A LAN B Substation IED

Substation IED

Substation IED

Ethernet Switch B

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Substation Automation

Convenient access to product documentation and screencasts is provided directly from the SGConfig software. (Screencasts are short instruction videos on popular setup processes.)

D20MX Substation Controller

Hardware Overview Fully Equipped Out-of-the Box

Backwards Compatibility

Previous generations of D20 RTUs required add-on system components and software to support Ethernet communications and optional memory expansion. The new D20MX is equipped by default with integrated memory, 10/100/1000BASE-TX or 100BASE-FX IEEE 802.3 compliant communications and a core load firmware with a comprehensive set of key substation automation applications.

The Multilin D20MX is an embedded single board computer powered by a 667 Mhz power PC CPU pin-for-pin compatible unit with existing D20 VME and non-VME D20 processors and accessories, such as chassis, D20 remote I/O peripherals, modems.

PCI mezzanine card site for future expansion

Compatible with classic VME and non-VME D20 chassis

Built-in 2 x 10/100/1000BaseTX or 2 x 100Base FX Ethernet ports

Integrated CPU, memory, Ethernet and media interface in a single D20MX processor

Super capacitor enables maintenance-free, battery-less operation

Technical Specifications SYSTEM PROCESSOR:

ELECTRICAL 667 MHz embedded PowerQUICC II Pro

MEMORY

Substation Automation

• 1024 MB of 266 MHz DDR2 RAM with ECC • 16 MB NVRAM for persistent event storage STORAGE

• 8 MB boot flash • 256 MB firmware flash OPERATING SYSTEM: VxWorks LED INDICATORS System status:

Power, Ready

Ethernet port status: Link and Activity status per port Power supply:

Power

IRIG:

Flashes when active

COMMUNICATIONS

ENVIRONMENTAL

RATED POWER SUPPLIES AC-DC: 100 to 240 V AC (±10%) 143 W output maximum Minimum/Maximum AC voltage: 90V AC / 265 V AC 100 to 300 V DC (±10%) 143 W output maximum Minimum/Maximum DC voltage: 88 V DC / 330 V

DC

DC-DC: 20 to 55 V DC (±10%) 135 W maximum Minimum/Maximum DC voltage: 18 V DC / 60 V DC PEAK INRUSH CURRENT AT 25 °C ON COLD START AC-DC : 50 A, max at 230 V AC DC-DC:

50 A, max at 230 V AC

RATED FREQUENCY: 50/60 Hz nominal (47 to 63 Hz) (AC/DC)

NETWORK CONNECTIONS

• Dual redundant Ethernet interface • Twisted Pair • 10/100/1000BaseTX (Isolated RJ-45 connector) • 100BaseFX (Fiber Optic: 1300 nm, 50/125 µm, 62.5/125 µm multi-mode duplex fiber cable, ST connectors) SERIAL COMMUNICATIONS

• D.20 Link, 2 channels • Data rate: 250 kbps • Surge protected to ±2000 V peak RS-232, 7 CHANNELS

• 5-signal (TXD, RXD, RTS#, CTS#, DCD#) DTE ports • Data rate: independently-selectable; refer to the application configuration guides. MAINTENANCE PORT

PHYSICAL OVERALL HEIGHT:

40.34 mm (1.588 in.)

WIDTH:

261.87 mm (10.31 in.)

DEPTH:

160 mm (6.3 in.)

D20MX WEIGHT:

0.7 kg (1.65 lb.)

FIBER CARD WEIGHT:

0.2 kg (0.35 lb.)

BATTERY SHIPPING RESTRICTIONS The D20MX does not contain a battery and is therefore not affected by US DOT or ICAO shipping restrictions. MATERIAL/FINISH: Galvannealed steel with black power coat KIT PACKAGE LENGTH: WIDTH:

49.5 cm (19.5 in.) 34.3 cm (13.5 in.)

HEIGHT:

15.2 cm (6 in.)

WEIGHT:

2.54 kg (5.6 lb.)

• RS-232, 1 channel/ 2 ports • 2-signal (TXD, RXD) • Data rate: 19200 (default)

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OPERATING TEMPERATURE: 0°C to +70°C Note: Do not operate the D20MX above 60°C for extended periods of time as this will shorten the life of the super capacitor and reduce the backup time of the real time clock. HUMIDITY RATING: 5% to 95% relative humidity, non-condensing ENVIRONMENTAL RATING INGRESS PROTECTION: IP30 (IEC 60529) INSTALLATION/OVERVOLTAGE CATEGORY: CAT II (2) POLLUTION DEGREE: 2 USE:

Indoor use only

OPERATING ALTITUDE: Maximum altitude 3000 m [9480 feet] above sea level MTBF (MIL-HDBK-217): D20MX Processor Board

• Non-VME with 10/100/1000BASE-TX copper: 449,616 hours at 40°C • Non-VME with 100BASE-FX fiber optic: 265,657 hours at 40°C SOFTWARE CONFIGURATION: Performed using SGConfig 7 and higher

D20MX Substation Controller

Standards & Protection EMISSION EN55011 (CISPR 11)

ISM RF equipment – Electromagnetic disturbance characteristics

Radiated Emissions 30 MHz to 1 GHz Conducted Emissions 150 kHz – 30 MHz

IMMUNITY IEC 61000-4-2

Electrostatic discharge (ESD) immunity test

IEC 61000-4-3

Radiated, radio-frequency electromagnetic field immunity test

IEC 61000-4-4

Electrical fast transient/burst immunity test

IEC 61000-4-5

Surge immunity test

IEC 61000-4-6 IEC 60255-22-6

Immunity to conducted disturbances, induced by radio-frequency fields

IEC 60255-22-1

1 MHz burst immunity test

IEC 61000-4-8

Power frequency magnetic field immunity test

IEC 61000-4-9

Pulse magnetic field immunity test

IEC 60255-22-1

Damped Oscillatory and Ring wave

IEC 61000-4-11

Voltage dips, short interruptions and voltage variations immunity tests

IEC 61000-4-16

Test for immunity to conducted, common mode disturbances in the frequency range 0 Hz to 150 kHz

IEC 61000-4-17

Ripple on DC input power port immunity test

IEC 61000-4-29+

Voltage dips, short interruptions and voltage variations on DC input power port immunity test. This standard only applies when using high voltage DC as the source (100 V DC to300 V DC).

SAFETY EC 61010-1

Safety requirements for electrical equipment for measurement, control and laboratory use - General requirements

IEC 60255-5

Insulation coordination for measuring relays and protection equipment – Requirements and tests

Dielectric and Resistance measurements not applicable due to design (TVS in circuit)

IEC 60068-2-1

Cold

2 hours non powered, soak at -40 °C, then warm to -20 °C and leave powered for 16 hours

IEC 60068-2-22

Dry Heat

16 hours powered at +70 °C

IEC 60068-2-6

Vibration (sinusoidal)

A logarithmic sweep from 10 Hz to 150 Hz to 10 Hz at 1 oct/ min for 1 sweep cycle in the 3 orthogonal axes. Acceleration level 1 g

IEC 60068-2-27

Shock - Operating Response Test Shock - Non-Operating With - Stand Test

Pulse shape: Half sine Pulse duration: 11 ms • Operating Response Test: Acceleration level: 5 g’s • Non-Operating Withstand Test: Acceleration level:15 g’s • 3 pulses per polarity per axis for a total of 18 pulses

IEC 60068-2-29

Bump – Non operating test

Pulse shape: Half sine Pulse duration: 11 ms Acceleration level: 10 g’s 1000 pulses per polarity per axis for a total of 6000 pulses

IEC 60068-2-30

Damp heat, cyclic (12 h + 12 h cycle)

Dropping on each face Dropping on each corner

IEC 60068-2-31

Drop and topple

Toppling (or pushover) For a total of 12 drops

IEC 60068-2-78

Humidity Testing

96 hours steady state humidity at 40 °C and 93% RH

ENVIRONMENTAL

Substation Automation

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Ordering Codes Multilin D20MX D20MX CPU Options

Power Supply

* A

C G

Modem Slots

*

*

*

*

U A C D E F

U A C D

U A C D

*

*

*

*

U

U

U A B C D

Serial Termination Panel

A B C

D20MX Firmware Options

U V H J

D20MX Classic Applications License

U A

D20MX Advanced Automation Applications License

U B

Future Feature Future Feature

U U

Description D20MX non-VME, dual 10/100/1000BASE-TX Ethernet Ports (front access) D20MX non-VME dual 100BASE-FX Ethernet Ports (front access) D20MX non-VME, dual 100BASE-FX Ethernet Ports (rear access) Not required 20-60VDC Input, 24V ISO Output 20-60VDC Input, 48V ISO Output 100-300VDC/85-264VAC Input, 24V ISO Output 100-300VDC/85-264VAC Input, 48V ISO Output Empty slot with cover plate Wesdac D20 202 bin modem Telenetics 14400 baud modem 2-wire dial up Telenetics 14400 baud modem 4-wire leased line D20MX dual 100BASE-FX ST Media Interface Card D20MX dual 100BASE-FX LC Media Interface Card 19" Rack Mount Serial IO Westerm Panel D20 Chassis Mounted Serial IO Westerm Panel D20 Chassis Mounted Serial IO Westerm Panel w/Extended Bracket (U) – Firmware Latest Release (19200 baud) (V) – Firmware Latest Release (9600 baud) (H) – Firmware v1.40 (9600 baud) (J) – Firmware v1.40 (19200 baud) Not required Classic applications required Not required Advanced Automation Applications Not required Not required

Upgrade Kits Order Codes D20MXK D20MX Kit Type D20MX CPU Options

Media Interface Card Options

D20MX Firmware Options

D20MX Classic Applications License

* A C

*

*

*

*

*

U

U

A C G U E F

U V H J

D20MX Advanced Automation Applications License Future Feature Future Feature

U A U B U U

Description Upgrade Kit for D20 Horizontal chassis D20MX CPU only D20MX non-VME, dual 10/100/1000BASE-TX Ethernet Ports (front access) D20MX non-VME dual 100BASE-FX Ethernet Ports (front access) D20MX non-VME, dual 100BASE-FX Ethernet Ports (rear access) Not required D20MX dual 100BASE-FX ST Media Interface Card D20MX dual 100BASE-FX LC Media Interface Card (U) – Firmware Latest Release (19200 baud) (V) – Firmware Latest Release (9600 baud) (H) – Firmware v1.40 (9600 baud) (J) – Firmware v1.40 (19200 baud) Not required Classic applications required Not required Advanced Automation Applications Not required Not required

Upgrade kits include the necessary items required to upgrade existing D20 RTUs including: • New D20MX CPU [526-3001 or 526-3003 or 526-3005] • Blank Plates [953-1014] • Multilin Products Documentation CD [581-0002] • Multilin D20MX Documentation CD [588-0075] • Ferrite Core for D20 Power Wiring [460-0073] • 0V Cable [975-1237] • Null Modem Cable [977-0529]

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12711E(E) English 150121

Multilin™ D400 Advanced Substation Gateway Secure, Consolidated Substation Communications GE’s Multilin D400 is a secure, substation-hardened gateway that collects metering, status, event, and fault report data from serial or LAN based Intelligent substation devices. The D400 summarizes data from the substation devices and makes it available locally/remotely through a standard secure web browser (HTTPS).

Advanced Automation • Built-in alarm annunciator • Built-in one line diagrams editor • IEC 61131 soft logic using LogicLinx™ • Analog/Digital data logging

It supports serial and/or LAN connections to SCADA masters. TCP/IP network connections are supported over the built-in Ethernet and the modem interface.

Security

Key Benefits

• Role Based Access Control (RBAC)

• Direct support for industry standard communication protocols (including IEC® 61850) ensures connectivity with new and legacy substation devices and master stations • Advanced security features including remote User Authentication, access control, and auditing to ensure compliance with NERC®/CIP® requirements

• Centralized user authentication • Full auditing including syslog • Secure access using SSH/SCP/HTTPS • Secure web server • Built-in firewall

• Full suite of SCADA® protocols allow for direct communications with Master Stations • Secure pass through / terminal services allow personnel to access all substation devices, remotely • Graphical configuration with drop downs and pre-configured device maps reduces setup and configuration time • Application flexibility with complete IEC 61131 SoftLogic Capabilities • Enable predictive maintenance with local or remote access to device status, annunciator, and data log • Substation hardened to relay standards for long service life in harsh substation environments

Applications • Advanced Gateway – Substation Data collection, concentration and visualization Advanced Automation

Connectivity • Multiple simultaneous SCADA protocols and firmware • Event notification via email/pager • Automatic record retrieval of IED files • Up to 16 RS232/RS485 serial ports and up to 64 virtual serial ports • VLAN communications • Parallel Redundancy Protocol [PRP]

• Advanced Automation – Automate substation procedures using IEC 61131 compliant tools • Fault Recording & Data Logging – Extract valuable data such as digital fault records and event files • Secure Remote Access – Securely access substation device locally and remotely

Hardware • Dual hot swappable power supplies • RS485, 2kV RMS rated ports • Built-in Ethernet switch • Dual Ethernet controllers option • Optional Multilin D.20™ RIO

D400 Advanced Substation Gateway

Overview

Multilin D400 Applications

GE’s Multilin D400™ is a secure, hardened, advanced substation gateway that collects metering, status, event, and fault report data from serial or LAN based intelligent substation devices. The Multilin D400 summarizes data from the substation devices and makes it available locally /remotely through a standard secure web browser (HTTPS). It supports serial and/or LAN connections to SCADA masters. TCP/ IP network connections are supported over the built-in Ethernet and the modem interface.

Enterprise Systems The collected substation device data is pre-processed and moved up to EMS and DMS SCADA systems providing centralized management of substation switches and breakers.

Substation

Advanced Gateway The Multilin D400 collects data from substation protection, control, monitoring, RTU, and intelligent devices, pre-processes the data and moves it up to EMS and DMS SCADA systems providing centralized substation management. Gateway features include:

D400

Applications:

• Data collection, concentration and visualization • IEC 61850 Gateway

Advanced Gateway

• Device Redundancy

Advanced Automation

Fault Recording

Secure Remote Access

• Built in Media Conversion

Substation Automation

Advanced Automation The Multilin D400 provides the computing platform necessary to automate substation procedures, such that intricate processes are carried out safely and efficiently by creating custom automation programs using IEC 61131 compliant tools, and perform basic math functions on data points using the built-in calculator tool. Automation features include:

Device data collected from Protection, Control, Monitoring, RTU, and other intelligent equipment.

• HMI, One Line Viewer and Annunciator • Mathematical Control Logic • Programmable Logic using LogicLinx • Accumulator Freeze • Analog Value Selection • Control Lockout • Double Point Association • Input Point Suppression • Redundant I/O • Alarm Management

Fault Recording/Data Logging Using pass-through connections, users can extract valuable nonoperational data such as digital fault recording (DFR) records, event and oscillography* files. The user can also access the historical log files and upload the archived data for trending and analysis. Fault recording features include:

Secure Remote Access The Multilin D400 allows maintenance and relay engineers to securely access substation devices, locally or remotely, through advanced visualization and communication tools, increasing productivity. Secure remote access features include:

• Data Logger

• Access to Operational and Non-operational Data

• Trend Viewer

• Pass-through/Terminal Server

• Data Base Exporter

• Role Based Access Control • Virtual Serial Ports

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D400 Advanced Substation Gateway

Advanced Gateway

• IEC60870-5-101/104 (server)

Data Collection, Concentration and Visualization

• SELFast Meter/SEL ASCII

The Multilin D400 advanced substation gateway, when operating as a SCADA host , collects, filters, and sorts data from a wide range of intelligent devices (RTUs, relays, meters) in the substation and preserves original data time stamp for accurate sequence of event. Data can be presented to multiple SCADA hosts. The D400 comes with a built-in suite of protocols and security applications to facilitate communication with various substation devices and SCADA hosts, including: • DNP3 serial and TCP/IP (client & server) • IEC 61850 (client) • Modbus™ serial & TCP/IP (client & server) • IEC60870-5-101/103/104 (client)

two systems. Serial communication links are automatically switched between the units based on system health.

• Hydran™ Host*

The D400 100Base-FX redundant Ethernet card enables automatic switchover between two sets of Ethernet switches ensuring there is no single point of failure in the system.

• GE modem • Generic ASCII protocols

IEC 61850 Gateway The IEC 16850 Client application allows the Multilin D400 to act as a powerful IEC 61850 data concentrator. The D400 also includes valuable features such as Dynamic Data Sets, Buffered Control Blocks, and Enhanced Security Controls.

Device Redundancy Dual Multilin D400 units can be deployed creating a redundant system where accumulators, SOE logs, and configurations are automatically synchronized between the

Built-in Media Conversion The Multilin D400 supports various communication media types—Serial: RS-232, RS-485, Glass Fiber, and Plastic Fiber; and Ethernet: 10/100Base-T, 10Base-FL, and 100Base-FX. Hot swappable communications modules eliminate the need for dongle type media converters used to convert to glass or plastic fiber, reducing total cost of deployment.

Advanced Substation Gateway Connectivity Enterprise Protocols: • • • •

Enterprise Systems

DNP3 Serial, DNP3 TCP/UDP Modbus Serial (RTU), Modbus TCP IEC60870-5-101 IEC60870-5-104

SCADA

EMS

DMS

Data Historian

Substation Automation

Multilin D400

D400 Media Connectivity: • 16 Serial Ports (RS232, RS485, Plastic/Glass Fiber) • Support for 2 Ethernet Cards (10/100 Bse-T, 100 Base-FX, 10/100 Base SX) • 2 Front USB Ports • Keyboard /Video /Mouse

Local HMI/ Single Line

Substation Devices

Device Protocols: • • • • • • • • • •

DNP3 Serial, DNP3 TCP/UDP IEC61850 Client Modbus Serial (RTU), Modbus TCP Hydran Client Generic ASCII Client SEL Binar/Fast Meter/Interleaving IEC60870-5-101 IEC60870-5-103 IEC60870-5-104 SNMP Client

Bay Controllers

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Protection Relays

Intelligent Devices/Meters

Ethernet Switches

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D400 Advanced Substation Gateway

Advanced Automation The Multilin D400 acts as the centralized, rugged computing platform in advanced automation systems. Using the calculator tool and/or GE’s programmable logic (LogicLinx), users can create custom automation programs for a variety of applications such as:

Define groups of accumulator points whose values are frozen periodically or on demand.

• Sequence Switching

Control Lockout

• Interlocking

Analog Value Selection Define a group of prioritized analog input points with the highest priority, valid input being reported to a single analog input point.

• Alarm Grouping

The Control Lockout feature ensures that only a single master station can access a group of controls at one time, and can lock out groups of controls to allow for safer local maintenance. Users can create up to 8 remote control groups and up to 256 local control groups. Any digital output can be included in one remote and one local group.

HMI, One Line & Annunciator

Double Point

The Multilin D400 supports a web based HMI/ Annunciator feature, that is accessible using a standard Internet browser or through a VGA monitor and USB keyboard/mouse attached directly to the unit. Users have access to all data points in the systems, alarm screens, communications status screens and dynamic one line diagrams, all through the secure web interface.

Associates two digital input points to form a double point indication. Also known as 4-state points.

• Auto-sectionalizing • Auto-reclosing • Load Tap Changer Control • Cap. Bank Control • Reactor Switching

Substation Automation

Accumulator Freeze

Input Point Suppression Suppress reporting of input points while they are unavailable during maintenance. This allows users to disable groups of analog and digital

Mathematical Control Logic Using the calculator tool, users can create advanced solutions that group, manage and control points to produce the required automation results. The calculator tool can perform mathematical, logical, or timer based operations on data points stored in the Multilin D400. Using a graphical interface, users can define logical expressions using mathematical functions such as; addition, multiplication, logarithm, greater than, less than, as well as other boolean functions.

Programmable Logic (LogicLinx) For more advanced applications, programmable logic (LogicLinx) software provides PLC functionality on the D400 platform. LogicLinx offers textual and graphical languages defined in the IEC 61131-3 standard for PLC programming environments, including Sequential Functions Chart , Instruction List , Structured Text, Ladder Diagram and Function Block Diagram. In addition, a wide range of arithmetic, boolean and logical operations are supported.

520

Web based HMI/Annunciator feature, that is accessible using a standard Internet browser or through a VGA monitor and USB keyboard/mouse attached directly to the unit.

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input points by ignoring their actual data and quality changes within selected applications. While points are suppressed, a predefined suppression value and the Point Suppressed quality flag are provided instead. This is useful during maintenance operations to prevent spurious OFFLINE alarms and false readings while devices are powered off or disconnected.

Redundant I/O Specify a secondary data point for any point that is used to report the value and quality when the associated primary point is invalid or questionable.

Alarm Management The D400 Alarm groups are user-definable, with up to 256 groups allowed. Each group has its own descriptive and display parameters. Alarms may belong to more than 1 group, or none at all. “Critical” and “Default” groups are built-in. SCADA points for the alarm groups remain on-line if component alarm points go offline. SCADA points are provided to acknowledge a group of alarms. Individual alarms must be acknowledged via the D400 GUI.

D400 Advanced Substation Gateway

Fault Recording/ Data Logging The Multilin D400 can automatically retrieve event and oscillography* files from devices such as Multilin UR Protective Relays, GE’s D25 Controllers, and IEC 61850 server devices. Using IEEE file naming standards, these event files are renamed and can be stored locally or securely sent to corporate servers using Rsync (SSH).

Data Logger The Analog Data Logger provides a variety of means to monitor and record analog input point value changes into data files that can be retrieved by the user. A variety of recording methodologies are supported including, Continuous (all changes), Periodic, Time Weighted, Out of Range and Triggered by a digital input point.

Trend Viewer All data recorded by the Analog/Digital Data Logger can be viewed by the Digital event recorder using the built in web-based Trend Viewer. Users can select the range of data to be used by time and date, alternately a real time streaming view can be displayed. Up to 8 data points (pens) can be displayed on a single view and support for curve fitting is available. Substation Automation

Database Exporter The Database Exporter tool allows users to save Analog Data Logger and Digital event recorder points from the Multilin D400 to your local PC, using the WEB interface, in comma-separated values (CSV) format.

Automatic Record Retrieval The Automated Record Retrieval Manager (ARRM) retrieves and stores record files from devices connected to the D400. ARRM uses the Distributed Network Protocol (DNP) and the IEC 61850 protocol to communicate with a variety of devices, and uses the Trivial File Transfer Protocol (TFTP) or MMS to transmit the files from the IED to the device over a Local Area Network (LAN) or serial connection.

Multilin D400 Fault Recording The D400 fault recording capability allows system event information to be collected and viewed using a web-based trend viewer.

FTP/SCP/SFTP

TFTP or IEC 61850 MMS

You can also retrieve downloaded records from the D400 using any FTP/SCP/SFTP client as needed or on a scheduled basis.

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Secure Remote Access Multilin D400 provides robust security environment, providing seamless integration with existing IT department policies. Role based Access Control, Secure Web Interface, Secure File Transfer, and extensive user activity logging provide a complete security toolkit required to achieve NERC-CIP compliance.

Non-operational Data Using pass-through connections, the utility user can extract valuable non-operational data such as digital fault recording (DFR) records and event files. The user can also access the historical log files and upload the archived data for trending and analysis.

Pass-through/Terminal Server A built-in terminal server emulator allows pass-through connections to be initiated to substation device (relay, meter, RTU or other device). Once the connection is established, the local event records can be uploaded from the substation devices and viewed remotely.

Substation Automation

Virtual Serial Ports Virtual serial ports eliminate copper wire communications to feeder bays when a serial-only device is located in the bay. A small terminal server can be placed in the bay and connected to the Ethernet network, allowing all Multilin D400 serial client applications to connect directly to the serial device.

Use device software to obtain non-operational data such as trending and event records through the D400’s secure remote access functionality.

Role Based Access Control

Built-in Firewall

Role Based Access Control is achieved using TACACS+, RADIUS or the D400’s internal database; ensuring only authenticated and authorized users gain access the system. When using TACACS+ or RADIUS, revoking user privileges, system wide, is as simple as updating the centralized user database.

Multilin D400 is equipped with a built-in firewall for enhanced gateway cyber security. D400’s firewall is designed to drop unsolicited or invalid routed packages.

Network security protocols: • HTTPS • Syslog • RADIUS • SSH

• SFTP

• SCP

• CHAP

• TACACS+

The firewall is preconfigured to block outbound traffic on external interfaces and inbound traffic on both internal and external interfaces. The D400 automatically generates rules allowing inbound traffic on internal interfaces for all configured services. The rules are user configurable for inbound/outbound traffic customization.

Secure Remote Access Engineering Systems

Secure Communications

Multilin D400 Advanced Substation Gateway provides substation hardened processing platform for secure data & device access:

Meeting industry standards ensures compatibility with communications and IT equipment . Supported Network Protocols include:

• • • •

• HTTPS • SSH • SCP

SCADA data concentrator Device configuration tools Remote device access Engineering tools

• Syslog • SFTP • CHAP

• RADIUS • TACACS+

Multilin D400 Device Connections

Bay Controllers

Protection Relays

Intelligent Devices

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D400 Advanced Substation Gateway

Configuration Software IEC 61850 Substation Device Loader A key benefit to using IEC 61850 based communications is the reduction in deployment costs for modern substation automation systems. The D400 IEC 61850 loader application guides users through a structured 4-step workflow to configure the IEC 61850 client application, reducing system configuration time. Available device data, based on logical nodes, can be retrieved from the IEC 61850 Substation Configuration file (SCL files such as ICD, CID, SCD) or directly from the intelligent substation device using the IEC 61850 self-description. The IEC 61850 device loader allows users to pick the specific logical nodes or data sets to be used for automation tasks or to be placed in the D400 database for upstream communications, reducing overall network traffic and system loading for increased system efficiency. Using the IEC 61850 Dynamic Data Sets allows the configuration software to define the exact data to be retrieved from a substation device when initializing communications with that specific device. This allows users to configure the data sets through a single application rather than manually configuring data sets in each separate device, reducing mapping errors.

The IEC 61850 client is configured using the D400 Device loader application.

Device Configuration

Substation Automation

Configuring the Multilin D400 to communicate with substation devices is simple and straightforward. Thanks to pre-configured map files, adding devices to the system only takes a few mouse clicks. Point maps can be customized to meet your specific needs, then applied for all devices requiring the modifications.

Creating One-Line diagrams is quick and easy using the built-in, drag and drop One-Line designer application. Configuring alarm and alarm groups is simplified using a tree view point selection tool.

Browser-based configuration: connecting and configuring substation devices is simple using pre defined drop down lists of device point maps.

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D400 Advanced Substation Gateway

Hardware Overview

Time Sync Support

The D400 is built on a flexible, high performance, expandable diskless and fan-less platform that is powered by a 1.6 GHz processor.

The D400 has extensive support for various time sync methodologies and will accept time sync signals from SNTP/NTP Servers, IRIG-B (un-modulated/modulated), and SCADA

Two Ethernet networks are supported with separate multiport switches. An IRIG-B format time protocol input/distribution module is also supported. Isolated serial port media is selected for each pair of ports.

protocols. The D400 can also distribute this time sync information through its built-in IRIG-B distribution interface, SCADA protocols, and/or through the RS232 ports directly.

Redundant Power Supplies The Multilin D400 has dual redundant , hot swappable power supplies, ensuring continuous uptime. Each power supply can be connected to a different source. As an example power supply 1 can be connected to Mains, while power supply 2 is connected to the battery system. Power Supply Health Monitoring raises a SCADA point alarm when either power supply fails. This allows an alarm to be transmitted to the EMS / OMS or DMS system, where a field personnel can be dispatched to replace the failed supply, all without service disruption.

Back Panel IRIG-B Distribution Slot

Network Slots 10/100 Base-T 100 Base-FX 10/100 Base SX Modem Interface

524

External Power Source Dual SCADA alarmed, hot-swappable power supplies 1) 18-75 VDC 2) 110-370 VDC/90-264AC

GEDigitalEnergy.com

Slot 13

Slot 11

Slot 10

USB KVM Slot

Slot 9

Slot 8

Slot 7

Slot 6

Slot 5

Slot 4

Slot 3

Slot 2

IRIG-B Input Slot

Slot 12

Serial Communication Slots

Plastic/Glass Fiber, RS232, RS485

Slot 1

Substation Automation

Redundant, hot-swappable power supplies.

Power Supply and System Fail Alarms

D400 Advanced Substation Gateway

Front Panel Power Supply

Redundant Power Supply

D400 Main Module

Substation Automation

Serial Port Status & LED Indicators

Power & Ready IRIG-B NET ACT/LINK

Serial Communication port for local maintenance Ethernet port for local network connection Two USB type A ports for portable memory device plug-in

GEDigitalEnergy.com

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D400 Advanced Substation Gateway

Technical Specifications Processor, Memory, and Storage 1.6 GHz Embedded CPU with 33 MHz PCI bus 1.0 GB of DDR2 SDRAM Industrial Grade Compact Flash Module (dual - 1.0 GB, expandable to dual 16 GB) RTDB

10,000 SOE reports archived in an embedded SQL database 16 MB NVRAM standard for persistent event storage guaranteeing no loss of events

Communications Ethernet – two Ethernet LAN supported (fiber and/or twisted pair)

10/100BaseT – 4 port integrated switch (isolated RJ-45 connector) 10Base-FL – redundant (fiber optic: 62.5/125 μm duplex fiber cable-ST connectors) Wireless IP radio ready (via PPP serial port) 100BASE-FX redundant (fiber optic 1300nm duplex fiber cable-ST connectors)

Serial Communications (16 channels of RS232/485/fiber optic)

Data rate, 300 to 115.2 Kbps RS-232 • Configurable for DCE/DTE operation • Galvanic isolation between channels • Can drive IRIG-B signal to RS-232 ports (with optional IRIG-B Input card present) RS-485 • 2 Wire/4 wire support • Galvanic isolation between channels • Glass or plastic serial fiber port on ST connectors

IRIG-B Input Module

TTL (un-modulated), fiber optic (un-modulated), BNC (1 kHz modulated), CPU time sync for internal database time stamping

Distribution Module

Can drive IRIG-B TTL signal for 16 Intelligent Devices

Signal Propagation

Propagated to all 16 RS-232 ports for devices such as SEL relays Propagated to the distribution module ®

KVM

Substation Automation

KVM Module

Three USB ports for connecting keyboard and mouse D-Sub 15 socket for connecting an industrial SVGA display 3.5 mm audio jack for substation alarms

Power Supply Input Options: 20–55 VDC (+/- 10%), 100-240 Vac/100-300 Vdc (+/- 10%), 135 Watts DC Supply, 127VA AC Supply

Physical Dimensions

19 Inch rack mount (482.59 mm) 2U (3.47” / 88.12 mm) in height 12.24“ (310.95 mm) in depth Mounting: 4 mounting holes, 2 slotted for easy installation

Environmental Operating Temperature: -20° to +65°C operating range Humidity: 5-95% relative humidity, non-condensing Ingress Protection: IP30

Maintenance Software OCM-Offline Configuration Manager** System Requirements: IBM PC or compatible computer, VT100 emulator ®

Configuration Software OCM-Offline Configuration Manager LogicLinx* Editor (if using LogicLinx)** Web Browser-Based Online Configuration

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D400 Advanced Substation Gateway

Standards and Protection CE Mark 2006/95/EC

LVD Directive

EN55011 (CISPR 11)

EMC Directive

EN61326

Electrical equipment for Measurement, control and laboratory use - EMC requirements

Emissions Standards EN55011 (CISPR 11)

ISM RF Equipment - electromagnetic disturbance characteristics

IEC 60255-25

Electromagnetic emission tests for measuring relays and protection equipment

IEC 61000-3-2

EMC-limits for harmonic current emissions (equipment input current <16A per phase)

IEC 61000-3-3

EMC limits-limitations in voltage changes, voltage fluctuations and flicker in public low-voltage supply systems, for equipment with input current <16A per phase & not subject to conditional connection

®

Immunity Standards IEC 61000-4-2, IEC 60255-22-2, IEEE C37.90.3

Electrostatic discharge (ESD) immunity test

IEC 61000-4-3, IEC 60255-22-3, IEEE C37.90.2* *(10V/m)

Radiated, radio-frequency electromagnetic field immunity test

IEC 61000-4-4, IEC 60255-22-4, IEEE C37.90.1

Electrical fast transient/burst immunity test

IEC 61000-4-5

Surge immunity test

IEC 61000-4-6

Immunity to conducted disturbances, induced by radio-frequency fields

IEC 60255-22-6

Electrical fast transient/burst immunity test

IEC 61000-4-8

Immunity to power frequency magnetic fields

IEC 61000-4-12

Oscillatory waves immunity test

IEC 60255-22-1, IEEE C37.90.1, Ontario Hydro A-28M-82

(Damped oscillatory and ringwave)

®

Safety Publications IEC 61010-1

Harmonized safety standard

IEC 60255-5

Insulation coordination for measuring relays and protection equipment requirements and tests

Power Supply Standards AC power supply interruptions

IEC 61000-4-16

Immunity to conducted, common mode disturbances in the frequency range 0 Hz to 150 Hz

IEC 61000-4-17

Ripple on D.C. power supply

IEC 61000-4-29+ (+ HVDC only), IEC 60255-11

Voltage dips, short interruptions and voltage variations on D.C. input power port immunity test

Substation Automation

IEC 61000-4-11

Environmental Standards IEC 60068-2-1

Environmental testing cold

IEC 600068-2-2

Environmental testing dry heat

IEC 60068-2-6, IEC 60255-21-1

Environmental testing vibration, Vibration tests (sinusoidal)

IEC 60068-2-27

Environmental testing shock

IEC 60068-2-29

Environmental testing bump

IEC 60068-2-30

Environmental damp heat cyclic (12+12 hour cycle)

IEC 60068-2-31

Environmental testing drop and topple

IEC 60255-21-2

Shock and bump tests

Communication Standards IEC 61850-3

Substation comm. standard

IEEE 802.3

CSMA/CD access method and physical layer specifications

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Ordering D400 CPU

Power Supply

* * M N P Q A B

Power Supply (Redundant) Serial Communications

*

*

-

*

*

*

*

-

*

*

*

*

-

*

*

*

*

-

*

*

*

*

*

*

U A B U

U U U U

U U U

1 2 3 4

1 2 3 4

1 2 3 4

1 2 3 4

1 2 3 4

1 2 3 4

1 2 3 4

D400 RS-232 IO Assy D400 RS-485 IO Assy D400 Glass Fiber Optic IO Assy D400 Plastic Fiber Optic IO Assy IRIG-B INPUT CARD NONE IRIG-B Distribution Card NONE ETHERNET 4 PORT 10/100 MB TP SWITCH ETHERNET FIBER OPTIC (HOT STANDBY) 2 PORT 10BaseFL/100Base-SX D400 100BASE-FX HOT STANDBY ETHERNET ETHERNET REDUNDANT 10/100 MB TP NONE

1 2 3 4

IRIG-B Input Card

A U

IRIG-B Distribution Card

B U

First Network Slot

1 2 5 4

Second Network Slot

U 1 2 5 3

USB KVM, Audio

U A

D400 Local HMI (one-line viewer D400 IEC 61850

U A U A

D400 LOGICLINX Executor License D400 Setup Software

U A A J

Automatic Record Retrieval Manager License

ETHERNET 4 PORT 10/100 MB TP SWITCH ETHERNET FIBER OPTIC (HOT STANDBY) 2 PORT 10/100 BASE-SX D400 100BASE-FX HOT STANDBY ETHERNET COM2 PORT (REQUIRES EXTERNAL MODEM) NONE USB KVM & Audio Card NONE Local HMI (Basic) NONE IEC 61850 Client Application NONE D400 LogicLinx™ Executor License NONE SGConfig v7.4 Firmware Version 2.75 Firmware Version 3.20 + Service Pack 2 Not Required Automated Record Retrieval Manager License ®

U A

D400 Image Firmware

Description 1.6 GHz CPU, 1.0GB DDR RAM, SINGLE ETHERNET 1.6 GHz CPU, 1.0GB DDR RAM, DUAL REDUNDANT ETHERNET 1.6 GHz CPU, 1.0GB DDR RAM, SINGLE ETHERNET, 16GB CF 1.6 GHz CPU, 1.0GB DDR RAM, DUAL REDUNDANT ETHERNET, 16GB CF 100-240 VAC (47-63 Hz), 100-300 VDC (± 10%) 20-55 VDC (± 10%) NONE 100-240 VAC (47-63 Hz), 100-300 VDC (± 10%) 20-55 VDC (± 10%) NONE

U A

Ordering Note: For the latest ordering information visit our online store at GEDigitalEnergy.com/onlinestore

VisitGEDigitalEnergy.com/D400 to: • View Specification Sheet • Download the instruction manual • Review applications notes and support documents • Obtain ordering information

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Passport.GEDigitalEnergy.com GEA-12806A(E) English 150120

Multilin™ D.20 RIO Distributed I/O Controller Utilities have large investments in hard wired automation systems. Like everything else, this industrial equipment has a life cycle that moves from infancy to normal operation, and eventually to the wear out stages. As a piece of equipment ages it fails more frequently, takes longer to repair, and eventually reaches the end of its life. Re-design and forklift replacements require utilities to re-engineer substation designs, replace field wiring, and re-train staff to manage and maintain the system, which is a costly endeavor.

Cost Effective D20 Upgrade

GE helps customers address these upgrade challenges with its Multilin D.20 RIO. The Multilin D.20 RIO Distributed I/O Controller is a stand-alone, small form factor device designed to provide distributed I/O capabilities for easy connection to the Multilin D400 substation automation gateway through the substation LAN. The D.20 RIO provides an interface to GE’s Multilin D20 Series of I/O modules for a cost effective upgrade solution.

• Secure real time browser access

Key Benefits • Reduced copper wiring between I/O modules and substation controllers by adding I/O near the monitored device and communicating to the Multilin D400 over the substation LAN • Easy installation of the small form factor D.20 RIO into existing control panels • Cost effective deployment of new and retrofit substation automation projects through compatibility of Multilin D400 Substation Gateways and Multilin D20 Input / Output peripheral modules

Applications • The D20 module interface enables users to maintain and leverage existing engineering designs, processes and automation infrastructure • Simplify implementation of distributed substation automation architectures by installing I/O where it’s needed and reducing copper wiring between I/O and substation controller

• Cyber security features for integration into NERC® CIP environments • Browser-based HMI interface • Secure remote engineering access • IEC® 61850 capabilities • Automatic record retrieval (fault records, SOE, settings files, any other file available in the IED)

Ease of Use • No special configuration tools are required, the device is connected via Ethernet using a standard web browser • The Multilin D400 automatically detects the D.20 RIO and establishes communications with the D20 modules • Intuitive user interface integrates the D20 I/O modules within minutes • Compatible with v3.X series of the D20 I/O PCommon code • No Substation LAN? No problem. Connect the D.20 RIO to the built in D400 Ethernet switch

Flexible Hardware • Product supplied with accessories for multiple mounting options (19” rack, DIN Rail, panel mount) • Support for dual D.20 communication links • Jumper configurable option for internal or external wetting of D20 peripherals

D.20 RIO Distributed I/O Controller

Cost Effective D20 RTU Upgrade Solution

Remote I/O Where You Need It

The Multilin D.20 RIO option with support for D.20 communications provides a cost effective alternative to upgrades of legacy D20 RTUs. Simply replace the failed or end of life Multilin D20 unit with a Multilin D400 Gateway and D.20 RIO module, plug the D.20 interface cable into the D.20 RIO, connect the D.20 RIO to the D400 or an Ethernet port in the substation LAN and you are ready to add modern functionality to the Multilin D400 series of Substation Gateways including:

The Multilin D.20 RIO Distributed I/O Controller is a small form factor standalone device that supports two D.20 link channels for communication with the D20 series of input/output modules.

• Cyber security features for integration into NERC® CIP environments • Secure real time browser access • Browser-based HMI interface

• Interface with standard D20 I/O (status, analog input, control and combination input) peripheral modules • Support for up to 30 I/O modules in a single D.20 RIO, or distributed over up to four D.20 RIO devices within the substation • Small form factor with multiple mounting options for installation flexibility: 19” Rack, panel mount or DIN Rail Use the Multilin D.20 RIO module to install input/output modules in the substation LAN. No substation LAN? No problem, connect the optional D.20 RIO device directly to the built-in D400 Ethernet switch.

• Secure remote engineering access • IEC® 61850 capabilities • Automatic record retrieval (fault records, SOE, settings files, any other file available in the IED)

D.20 RTU Upgrade Process TRADITIONAL AGING RTU UPGRADE SOLUTION

GE D400 + D.20 RIO UPGRADE SOLUTION

• Retain I/O infrastructure • Replace central controller only

Substation Automation

Full replacement

• Minimize upgrade cost • Migrate to modern technologies

INSTALLATION COST Modify field wiring

Yes

Not required

Modify engineering drawings

Yes

Not required

Building expansion

May be required

Not required

Marshaling panels

May be required

Not required

Yes

Minimal

Outages ADVANCED FUNCTIONALITY Advanced automation Cyber security features Optimized configuration methods Non-operational data management tools

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D.20 RIO Distributed I/O Controller

I/O Where You Need It, Minimizing Wiring Costs

3 1

1

2

1

Yard Equipment

Before Typical Hard Wired I/O

2 Wiring to field devices

After D400+D.20 RIO Distributed I/O

Wiring from field devices to D20 I/O module in local junction box

Field Wiring

3

Control Room

Individual copper wiring from field devices to control room

Centralized I/O architecture

Substation LAN communications, limited wiring

Wiring limited to few communication connections

Substation Automation

Technical Specifications COMMUNICATIONS

ENVIRONMENTAL

2 x 10/100 Base T Ethernet Channels 2 x D.20 link channels

Indoor use only -40°C to 70°C, 5 to 95% RH

POWER INPUT

RELIABILITY

D.20 RIO Unit: 22-55 VDC 24 VDC Output Power Supply Option: 85-264 VAC or 90-350 VDC 48 VDC Output Power Supply Option: 85-264 VAC or 90-350 VDC

158,000 hours MTBF at 40C per MIL-217F

DIMENSIONS 220 W x146 D x 43.5 H (mm) 8.66 W x 5.75 D x 1.71 H (inches) MOUNTING OPTIONS

CONFIGURATION SOFTWARE Built-in web browser based graphical user interface OTHER Up to four (4) Multilin D.20 RIO units per D400 unit Maximum number of D20 I/O modules per D.20 RIO: up to 30 Powered from D.20 RIO: 5 D20 I/O modules. For systems with more than 5 I/O modules, external power supply is required.

Supplied with required accessories for: 19” rack mount, 54.5 mm DIN Rail or panel mount

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User Interface Front Panel

D.20 Communication Status

Power and Device Status LAN Communication Status

Back Panel

Power supply options: • Input: 85-264VAC, 45-65Hz / 90-350 VDC. Output: 24VDC/3.5A • Input: 85-264VAC, 45-65Hz / 90-350 VDC. Output: 48VDC/5A

Ethernet Communications: 2 x 10/100Base T for D.20 communications with the D400 Gateway

D.20 Link: Dual D.20 link channels. Support for redundant peripheral systems

RS-232 Port: Maintenance and administrative procedures

Ordering DPDA000029: Multilin D.20 RIO, Power Input: 85 to 264 VAC, 45 to 65 Hz., or 90 to 350 VDC. Output: 24 VDC / 3.5 A

DPDA000030: Multilin D.20 RIO, Power Input: 85 to 264 VAC, 45 to 65 Hz., or 90 to 350 VDC. Output: 48 VDC / 5.0 A

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12805-(E) English 150120

Multilin™ D25 Substation Controller Substation Automation and Control in one Box GE’s D25 is a scalable, flexible, modular, and upgradable automation controller, suitable for both large and small substation automation projects in either new or retrofit situations. The D25 provides the tools and flexibility necessary to create customized automation and control applications including; communications & data concentrator, automation controller, metering & sequence of events fault recording, and transformer monitoring & control.

Key Benefits • Replaces multiple devices with a single unit. It’s unified design reduces wiring and maintenance costs • Retrieves data from legacy and third-party devices and runs diagnostics of primary equipment expanding future physical and functional station requirements • It can be equipped with two different built-in screens 1). Data Display Panel to show status of different points (digital or analog) to the operator and 2). Graphical Display Panel (GDP) allowing users to configure dynamic displays with one-line diagrams and alarm screens • Measures and records total harmonic distortion, harmonic spectrum, RMS trending, RMS profiling, voltage sags, swells and interruptions, allowing operators and analysts to examine the consistency of power going through the system and pinpoint problem area • Transfers fault records automatically via a LAN to the substation computer or directly to a remote PC through email ensuring relay settings are correct

Applications • Transmission substations – runs applications including interlocking, advanced load shedding, and fault recording via IEC® 61850 GOOSE through a dual redundant Ethernet • Distribution substations – handles all the automation • Generator substations – monitors and automates large set-up transformers and integrates transformer sensor data within existing SCADA systems

Automation and Control • Provides synchronism check including bypass function • Monitors voltage difference, phase angle difference, and slip frequency • Supports multiple buses per feeder allowing for dual-busbar schemes • Auto restoration accommodating up to 255 concurrent restorations • Built in LogicLinx®, an IEC 61850 compliant editing/debugging tool • Extensive, configurable alarming capability for AC analog values

Power Quality Metering • Records oscillography files including 1, 2, 2 ½, and 3 element metering • Digital fault recording up to 16 MB of fault data locally • Harmonic values (up to the 21st) on every AC Analog input • Monitors power quality profile RMS values for up to 6 AC circuits • Fully functional local HMI • Records AC analog values and stores them in COMTRADE format

Flexible I/O • Modular system allows an easy increase in I/O capability • Accommodates up to 96 digital inputs, 32 digital outputs, 32 analog inputs (DC) and 15 AC inputs • Monitors and records all I/O at a 1 ms resolution

D25 Multifunction Bay Controller/RTU

Substation Automation Controller GE’s D25 is a flexible, modular, and compact RTU, suitable for both large and small substation automation projects. Designed to act as a local data concentrator with its capabilities to communicate in more than 120 different SCADA protocols including IEC 61850. Along with a set of flexible, expandable and customizable I/O including A/C inputs, GE’s D25 can fulfill the role of a complete bay level controller RTU. The D25 provides advanced tools and the flexibility necessary for applications such as load shedding, digital fault recording, power quality monitoring, metering, transformer monitoring & control, or custom PLC logic.

D25 Communications Enterprise Systems The collected substation device data is moved up to EMS and DMS SCADA systems providing centralized management of substation switches and breakers.

Substation D25

Local HMI/ Single Line

The D25 provides the tools and flexibility necessary to create customized automation control applications including • Communications & data concentrator • Automation controller • Metering, sequence of events & fault recording • Tranformer monitoring & control

Substation Automation

Communications and Data Concentrator

Protection Relay

Transformer Diagnostics

Power Quality Meter

Motor Manager

Third party device

Protocol Conversion With a communications suite that supports over 120 protocols, including IEC® 61850, Modbus®, DNP, SPABus, Courier, and IEC 101/103/104, the D25 supports the translation of multiple protocols over multiple communication ports enabling easy integration of new and existing devices into supervisory and control systems (SCADA).

Flexible IEC 61850 The D25 IEC 61850 server application allows data from the unit to be modeled and presented as IEC 61850 Logical Node data. The data can come form any of the D25’s internal applications or from devices connected using supported communication protocols. This powerful conversion tool allows data from non-IEC61850 devices to be modeled into 61850 data for transmission upstream, eliminating the need to replace older or legacy devices for IEC 61850 compliance. KEMA ® certified as a IEC 61850 compliant device, the D25 includes additional IEC 61850 features such as Security Controls and Buffered Control Blocks , which do not exist in most baylevel equipment.

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With native support for IEC 61850 GOOSE, the D25 provides Peer-to-Peer communications between D25s and other GOOSE enabled devices in the system. GE’s D25 supports both fixed and configurable GOOSE messaging (data sets), ensuring connectivity to a wide range of protection devices including the Multilin UR & URPlus Families of protection & control devices. GE’s D25 meets IEC 61850 Class P2/3 performances levels required for timely interlocking schemes.

Local Remote Unit (LRU) Local Remote Unit (LRU) allows the D25 device to abstract a portion of its database and make it available to selected master stations, with the D25 presented as multiple slave devices. The same concept applies to slave devices (or servers), where the D25 can act as multiple master stations and retrieve data as needed. The flexibility and LRU concept allow the D25 to act as a gateway and data concentrator.

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Ethernet-ready The D25 supports standard communication methods over Ethernet, including Telnet and TFTP, but more importantly GE’s D25 units can also extend your LAN to legacy devices by providing a virtual connection to devices that do not have Ethernet capability, enabling you to perform remote configuration changes over a Ethernet network.

Advanced Automation & Control Synchronism Check The D25 supports the Synchcheck functions, including a synchronism bypass function for any or all of the following conditions: • Dead Line – Live Bus • Dead Bus – Live Line • Dead Bus – Dead Line The D25 monitors the voltage difference, phase angle difference, and slip frequency to ensure proper breaker closure per specific user-defined settings.

D25 Multifunction Bay Controller/RTU

Flexible Substation Communications & Control

Enterprise Systems

CT/VT Connections Status Control Device Communications

Dynamic Bus Switching

Auto Restoration Focused on improving power system reliability, the D25 enables advanced auto restoration schemes. Applicable to groups of two feeders joined by a Tie Switch with each having one breaker and up to three feeder switches, the D25 can accommodate up to 255 concurrent restorations with separate definitions on each feeder. This application makes the D25 a powerful auto-restoration device that is fully flexible and customizable.

Load Shedding The D25 can be equipped with a robust and configurable load shedding algorithm. The application monitors digital input states and digital output requests related with zones and groups in order to automatically control selected

Mathematical Control Logic Using the Calculator tool, users can create advanced solutions that group, manage and control points to produce the required automation results. The calculator tool can perform mathematical, logical, or timer based operations on any data points stored in the D25. Using a graphical interface, users can define logical expressions using mathematical functions such as addition, multiplication, logarithm, greater than, less than, as well as other boolean functions.

Programmable Logic (LogicLinx™) For more advanced applications, GE’s programmable logic (LogicLinx) software provides PLC functionality on the D25 platform. LogicLinx offers textual and graphical languages as defined in the IEC 61131-3 standard for PLC programming environments, including Sequential Functions Chart, Instruction List, Structured Text, Ladder Diagram, and Function Block Diagram. In addition, a wide range of arithmetic, Boolean and logical operations are supported.

AC Analog Alarming When deployed in advanced AC Monitoring applications, the D25 provides extensive and configurable alarming capability for AC analog values such as configurable hysteresis parameters.

Metering, Sequence of Events & Fault Recording With a high-density of communication channels, analog, and digital I/O modules, the D25 provides real-time data acquisition and recording functions. The D25 is capable of recording oscillography files and performing 1, 2, 2 ½, and 3-element metering on separate or bussed feeders, up to a maximum of four threephase feeders delivering system visibility for utility operators and maintenance staff

Sequence of Events The D25 manages and preserves all events and original I/O time tags, with 1 ms accuracy, using a state-of-the-art database. Data accuracy is critical to ensure accurate and reliable fault analysis, to enable a more stable power system through positive corrective actions.

Digital Fault Recording When activated by user-configurable trigger conditions, the D25 Digital Fault Recording

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Substation Automation

The D25 supports multiple buses per feeder, where each bus is defined by a set of PTs and a digital input (referred to as Active Bus Indication) that indicates when the bus is active on that feeder. The D25 monitors the Active Bus Indications to determine which set of PTs to use for the feeder. This unique ability allows for dual-busbar schemes to be reconfigured dynamically, maintaining a system-metering scheme without requiring an external voltage selection scheme.

feeders, optimizing system loading for improved system reliability and asset life. All application timing and other configuration parameters are customizable and can be changed online.

D25 Multifunction Bay Controller/RTU

software captures current and voltage waveforms as well as status from analog and digital channels. Up to 250 digital status inputs can be recorded and combined with 240 cycles of waveform data in standard COMTRADE files. The software stores up to 16 MB of fault data locally for subsequent retrieval via multiple protocols such as TFTP or DNP3.

Harmonic Spectrum The D25 can provide harmonic values (up to the 21st) on every AC Analog input and make it available to a control center. Values such as total harmonic distortion are also calculated and made available.

Power Quality

Substation Automation

The D25 can monitor power quality and profile RMS values for up to 5 separate AC circuits. It has the ability to detect and report shortduration and extended-duration voltage swells, sags, harmonics, harmonic distortion, and interruptions and also records the RMS voltage profiles of those events as COMTRADE format files for simplified power system analysis and troubleshooting

Transformer Fault Recorded by a D25

• Winding Hottest Spot Model

Fluxbuster™ AC analog inputs

• Insulation Aging Model

This technology enables accurate post-fault analysis. The D25 can monitor and record current waveform levels up to 42 nominal values. This guarantees accurate recording of symmetrical fault current waveforms. The Fluxbuster technology does not sacrifice accuracy in order to provide a wide input range unlike many other protection devices. The Fluxbuster technology provides unparalleled accuracy of up to 0.3% of nominal (0.3% of nominal from 2% – 195% measurement range and 1.0% of nominal from 195% – 4200% measurement range).

Graphical Display Panel (HMI)

• Cooling Control Model

This easy-to-use touch screen panel can be configured as a fully functional local HMI with features such as interlocking, password control, metering, and SOE / alarm annunciator screens. Individual screens in the graphical display can be customized to meet the unique requirements for each application.

• Minute Average Apparent Power Model

AC Profiling Record any AC analog value and store it in COMTRADE format. Record definitions can be customized for almost any scenario and can be triggered by a digital input. Data can be captured for as long as 5400 cycles, providing a complete, accurate view of the system.

• OLTC Temperature Differential Model • Moisture Model • On-Line Dynamic Loading Model The dynamic loading model incorporates outputs from the other models as well as key The dynamic loading model provides the system operator with a perspective of the overloading capabilities of the transformer. Among other transformer sensors, the D25 provides seamless integration with GE’s Hydran* to optimize equipment output and extend asset life.

Hardware

Transformer Monitoring

Flexible Modular I/O

The D25 utilized in Transformer Monitoring applications is a condition analysis and management system for critical power transformers. This system measures key transformer data, implements continuous on-line analysis models, and communicates critical information through the communication options supported by the D25.

The D25 includes a modular system to increase its I/O capacity. It can accommodate up to 96 digital inputs, 32 digital outputs, 32 analog inputs (DC), and 15 AC inputs to monitor 3-phase circuits. The D25 can also support single/double digital points and accumulators.

On-line analysis models include: • Load Current Model

All I/O is monitored and recorded at a 1 ms resolution. To ensure data accuracy, the D25 can be time synchronized through IRIG-B, SNTP, or most SCADA protocols.

• Cooling System Efficiency Model

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High Current Control Card The D25 can be equipped with a digital output module comprising of 32 relays, each rated at 10 A for 5 seconds and 4 A continuously. This can eliminate the need for separate interposing relays, reducing cost and saving valuable space within cabinets.

Scalable Analog Adapters The D25 includes an optional customizable 32-point analog input card with multiple analog adapters. This enables you to pick and choose multiple types of DC analog inputs to meet a wide range of current and voltage requirements. Adapters can be changed in the field simply by plugging a different adapter on the module..

D25 Multifunction Bay Controller/RTU

Digital Inputs 96 inputs are available with chatter filter to eliminate unwanted alarms. Single-point, double-point and accumulators can be configured using digital inputs. The wetting voltage of digital inputs can also be selected to meet site-specific requirements.

Manage Redundant I/O The D25 is capable of managing redundant I/O based on the operational status of each device. The D25 can also maintain control functionality by redirecting a command to the final destination. This feature is unique within the GE Digital Energy suite of devices and allows for an easier integration with master stations.

Back Panel Easily replaceable fuses

Time Synchronization Input & Serial Communications Channels (RS 232 or RS 485, software selectable)

Dual Redundant Fiber or Copper Ethernet Link

Digital Inputs (3 groups of 32 inputs)

Substation Automation

DC Analog Inputs supporting voltage & current inputs of different ranges

5 AC Inputs (Variety of CT/PT options available

GEDigitalEnergy.com

32 Digital Outputs

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D25 Multifunction Bay Controller/RTU

Technical Specifications Port Configurations AC Analog Inputs:

0, 3, 6, 9, 12 or 15 inputs

DC Analog Inputs:

0 or 16 inputs

Digital Status Inputs:

0 to 96 inputs in increments of 32

Control Outputs:

0, 16, or 32 trip/close pairs or 32 isolated high current outputs with 8 optional current supervision

Host Comm Ports:

2 serial (38.4 Kbps) or 2 Ethernet 10 Mbps and 100 Mbps options are available

IED Comm Ports:

2 (38.4 Kbps)

Time Sync:

1 IRIG-B Input

Configuration Port:

1 Maintenance port

Display:

1 D25 Display Port (9600 bps)

Power Requirements Input Options:

20-60 Vdc 60-150 Vdc/85-135 Vac 50/60 Hz (CE) 150-350 Vdc/187-265 Vac 50/60 Hz (CE)

Maximum Power Consumption:

65 W

Maximum Inrush Current on Cold Start:

18 A (peak Amps)

Maximum Inrush Current under Dynamic Conditions 1:

45 A (peak Amps)1

Substation Automation

Communication Ports Maintenance Port:

WESMAINT II+ DB-9-F, RS-232 @ 9600 bps

D25 Display Port:

DB-9-F, RS-485 @ 9600 bps

UTC Time Port:

DB-9-F, RS-232/RS-422

Standard Serial Comm. Ports (2):

DB-9-F, RS-232/485 up to 38400 bps

Optional Comm. Ports (2):

DB-9-F, RS-232/485 up to 38400bps, software configurable or Ethernet; 10/100TX, 10FL and 100FX options are available

AC Analog Value Measurement

Burden:

16x 1A & 5A CT – Less than 0.2VA @ nominal input. 42x 1A CT – Less than 0.05 VA @ nominal input. 42x 5A CT – Less than 0.1 VA @ nominal input.

Accuracy2 :

16x 1A & 5A CT- ±0.5% of nominal 42x 1A & 5A CT- ±0.3% of nominal Frequency ±0.03 Hz Phase angle ±0.5°

General AC Features RMS Data:

RMS magnitudes and phase angles for measured inputs. Supports L-L or L-N PT connections with calculation of L-L or L-N magnitudes and phase angles

Metering:

Electrical Power supports 1, 2, 21/2 and 3 element metering providing active, reactive, and apparent power; power factor per phase and circuit totals. Also provides displacement power factor angle per phase

Power Quality:

THD and harmonic spectrum data to the 21st harmonic for each AC input

Electrical Energy:

Import and export accumulators for kWh, kVAh, kVArh

Unbalance Detection:

Symmetrical component circuit unbalance detection and maximum deviation from average methods

Alarming:

High and low alarms on any analog data with qualifications of one power cycle or more

Line Frequency:

50/60 Hz

Oscillography:

Waveform and event recording on up to 15 AC analog channels simultaneously with concurrent capture of up to 250 digital input points Analog sample rate: 64 samples/cycle Record length: 240 cycles with programmable pre- and post-capture times

Per-cycle Data Logging:

Capturing selected AC values and digital data every power cycle

Protection:

3-step definite time over-current protection and breaker failure protection on all configured circuits

Accuracy 2:

Active/reactive/apparent power ±0.96% of nominal Power factor ±2.85% of FS Active/reactive energy ±2% of reading Apparent energy ±0.5% of reading

DC Analog Value Measurement

Configuration Options:

Direct AC analog inputs from CTs and PTs. Supports up to six 3-phase circuits Scaling factors are provided to allow fine-tuning of the nominal values of the AC inputs to match the actual nominal values of the field sources.

Configuration Options:

Scaling factors are provided to allow fine-tuning of the nominal values of the DC inputs to match the actual nominal values of the field sources

Analog Inputs:

16 DC analog optically isolated differential inputs

Analog Inputs:

15 AC analog inputs organized in groups of three (3) inputs, Transformer isolated

Sampling Rate:

Sampling Rate:

64 samples per Power Line Cycle

A/D Resolution:

13 bits plus sign

40 samples/second @ 50 Hz; 50 samples per second @ 60 Hz; 2 samples are averaged before captured in the database (effective reporting rate is 20 samples/sec @ 50Hz, 25 samples/ sec @ 60 Hz

A/D Resolution:

14 bits plus sign

AC Voltage Inputs Nominal PT Input Options:

63.5 Vrms, 69.3 Vrms, 110 Vrms, 120 Vrms, 220 Vrms

Measurement Range:

0% to 250% of nominal

Overload Voltage:

250% of nominal continuous 350% of nominal for one (1) minute

Input Burden:

5K to 250Ω (1 to 20 mA)

Burden:

Less than 0.1 VA @ nominal input

Accuracy:

±0.10% of full scale

Accuracy 2:

±0.5 % of nominal ±0.01 Hz

Temperature Coefficient:

±30 ppm/°C

Frequency: Phase angle:

±0.5°

DC Voltage

DC Current Nominal Input Range Options:

AC Current Inputs Nominal CT Input Options:

1 A rms or 5 A rms

Measurement Range:

2% to 1600% of nominal for value measurement 2% to 4200% (asymmetrical) of nominal for DFR and protection

Thermal Overload:

538

4 times nominal – continuous 30 times nominal – 10 seconds 100 times nominal – 1 second 10 minute duty cycle for inputs greater than 4 times nominal

±1 mA, ±5 mA, ±10 mA, or ±20 mA

Nominal Input Range:

±5 Vdc

Measurement Range:

±6 Vdc

Overload Voltage:

±30 Vdc (NM) continuous, ±200 Vdc (CM) continuous

Input Impedance:

More than 10 MΩ

Accuracy:

±0.05% of full scale

Temperature Coefficient:

±15 ppm/°C

GEDigitalEnergy.com

D25 Multifunction Bay Controller/RTU

Technical Specifications Digital Inputs

Auxiliary Digital Outputs

General;

Up to 96 optically isolated (5000 Vrms), organized in cards of 32 inputs

Radio Keying Output Relay Contact:

1 Form A

Digital Input Options:

One of: 12, 24, 48, 120, 250 Vdc ±20%, bipolar inputs 1.2 to 10 mA, maximum power dissipation is 0.5 W per input

Auxiliary Control Output Relay Contacts:

1 Form A

Burden: Contact Debounce:

Three-level programmable software filtering for debounce and chatter

System Fail Relay Contacts:

1 Form B

Configurable Input Types:

Digital input, Sequence of Events with time-tagging accuracy of 1 ms, Change of State, Up to 8 digital inputs as Pulse Accumulator

Maximum Switching Power:

60 W (resistive), 125 VA

24 Vdc or 48 Vdc (depends on supply ordered), isolated, external wetting optional

Maximum Switching Voltage:

75 Vdc or 50 Vac

On-Board Wetting Supply (not available with graphical display):

Maximum Switching Current:

2A

Maximum Carrying Current:

2A

Breakdown Voltage:

1500 V (coil to contact)

Digital Outputs (D25KE) Standard Digital Outputs:

16 or 32 relay outputs switch one side of the controlled load; single component failure protection and detection preventing false control of any coil driver output; selectcheck- before execute security; master trip/master close bus scheme

Configurable Output Types:

Latching (On/Off), Trip/Close, Raise/Lower, Programmable pulse duration from 5 to (231-1) ms in 1 ms intervals

Output Relay Contacts:

1 Form A

Maximum Switching Power:

60 W or 125 VA (resistive)

Maximum Switching Voltage:

75 Vdc or 50 Vac (DB-25) 120 Vdc (FACE-40)

Maximum Switching Current:

2A

Maximum Carrying Current:

2A

Operate Time:

5 ms

Release Time:

5 ms

Breakdown Voltage:

1500 Vac for one minute (coil to contact)

Isolation between Adjacent Outputs:

300 Vdc (with compression terminal block), 100 Vdc (with DB-25 connectors)

Interposing Relay Option:

Groups of 8 digital outputs can be directly interfaced to D20KI module

Alphanumeric:

Backlit LCD with keypad

Graphical:

Backlit LCD with touch screen, 320 X 240 pixels, 4.76” X 3.58”

Physical Specifications Dimensions:

19” (48cm) Width, 8.75” (22cm) Height, 9” (23cm) Depth

Weight:

31 lbs. (14.1kg) maximum

Operational Temperature:

-20°C to +70°C (without display), 0°C to +60°C (with alphanumeric display), 0°C to +50°C (with graphical display)

Storage Temperature:

-40°C to +90°C (without alphanumeric display), -20°C to +70°C (with alphanumeric display), 0°C to +70°C (with

graphical display) 0 to 95% relative humidity, non-condensing

Environmental Rating:

IP20

Installation/Overvoltage category:

Class II

Pollution Degree:

2

32 isolated digital outputs with single component failure protection and detection, preventing false control of any coil driver output; select-check-before execute security 8 outputs with optional current supervision seal-in function

Configurable Output Types:

Raise/lower, Programmable pulse duration from 5 to (231-1) ms in 1 ms intervals

Output Relay Contacts:

8x 1 Form C 16x 1 Form A 8x 1 Form A with optional current seal-in function

Maximum Make Current:

10 A for 5 seconds

Maximum Continuous Carrying Current:

4A

Maximum Break Current:

10 A @ 28 Vdc 0.85 A @ 60 Vdc 0.45 A @ 120 Vdc 0.3 A @ 300 Vdc

EN55011

Limits and methods of measurement of electromagnetic disturbance characteristics of industrial, scientific and medical (ISM) radio-frequency equipment

EN61000-3-2

Limits for Harmonic Current Emissions (applicable for AC power supply only)

EN61000-4-2

ESD/Immunity Test

EN61000-4-3

Radiated, radio-frequency, electromagnetic field immunity Test

EN61000-4-4

Electrical Fast Transient/Burst Immunity Test

EN61000-4-5

Surge Immunity Test

EN61000-4-6

Immunity to conducted disturbances induced by radio-frequency fields

EN61000-4-8

Voltage Dips, Short Interruptions and Voltage Variations Immunity Tests (applicable for AC power supplies only)

EN61000-4-11

Oscillatory Waves Immunity Test

EN61000-4-12

Product safety

EN61010-1

Cold

IEC® 600068-2-1

Dry heat

Min. 60 mA Max. 200 mA

IEC 600068-2-2

Vibration

IEC 600068-2-6

Damp heat, cyclic (12+12-hour cycle)

Operate Time:

7 ms

IEC 600068-2-30

Drop and topple

Release Time:

10 ms

IEC 600068-2-31

Test for Immunity to Conducted, Common Mode

Isolation Between Adjacent Outputs:

300 Vdc

EN61000-4-16

Disturbances in the Frequency Range 0 Hz to 150 kHz (steady state frequency).

Simultaneously Operated Outputs:

Maximum 16, includes maximum 4 with current supervision

Maximum Switching Voltage:

300 Vdc or 300 Vac

Current Sensing Level for Seal-In Function:

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539

Substation Automation

Humidity Rating:

Product Compliance

High Current Digital Outputs (D25HC KE) Standard Digital Outputs:

Available Displays

Ordering D25 Front Panel

Power Supply

Communications

DC Input

Control Output* Status Boards (1,2,3)

Memory Expansion 3 Analog Inputs (Groups 1 - 5)

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* * * * 5 6 8 9 1 2 3 4 5 U 3 4 5 6 U 2 4 8 A X R S T O 5 H V W L M 1 J Y G 6 F

*

*

*

*

U 1 2 3 4 5 6

U 1 2 3 4 5 6

U 1 2 3 4 5 6

-

*

*

*

*

U A B C D E F G H I J

U A B C D E F G H I J

U A B C D E F G H I J

-

*

*

U A B C D E F G H I J

U A B C D E F G H I J

*

*

-

*

9 S

U 3

Digital Signal Processor

Boot ROM* IEC 61850

U 1 2 U B U 1

Description No Display LCD Display Graphics Display Panel Multi-Language Graphics Display Panel 60-150 VDC, 120 VAC, 24 V Field output 250 VDC, 220 VAC, 24 V Field output 20-60 VDC, 48 V Field output 60-150 VDC, 120 VAC, 48 V Field output 250 VDC, 220 VAC, 48 V Field output NONE D25 10BASE-FL XCOM CARD (Two Fiber Optic Redundant Ports) 10BASE-T XCOM Card (Two Copper Redundant Ports) Serial XCOM Card STD (Two extra RS232/485 ports) D25 100FX and 10/100TX XCOM Card, Two multimode ST Fiber Optic Ports and Two RJ45 Ports None DC Analog Input 16 Channels, +/-5V Input DC Analog Input 16 Channels, +/-1MA Input DC Analog Input 16 Channels, +/-10MA Input DC Analog Input 16 Channels, +/-20MA Input DC Analog Input 16 Channels with no Socketed Analog Adaptors DC Analog Input 16 Channels with Socketed 1MA/1V I/P Analog Adaptors DC Analog Input 16 Channels with Socketed 1.2MA/1V I/P Analog Adaptors DC Analog Input 16 Channels with Socketed 1.5MA/1V I/P Analog Adaptors DC Analog Input 16 Channels with Socketed 2MA/1V I/P Analog Adaptors DC Analog Input 16 Channels with Socketed 20MA/1V I/P Analog Adaptors DC Analog Input 16 Channels with Socketed 5MA/1V I/P Analog Adaptors DC Analog Input 16 Channels with Socketed 1MA/5V I/P Analog Adaptors DC Analog Input 16 Channels with Socketed 1.1MA/5V I/P Analog Adaptors DC Analog Input 16 Channels with Socketed 1.25MA/5V I/P Analog Adaptors DC Analog Input 16 Channels with Socketed 1.5MA/5V I/P Analog Adaptors DC Analog Input 16 Channels with Socketed 2MA/5V I/P Analog Adaptors DC Analog Input 16 Channels with Socketed 2.5MA/5V I/P Analog Adaptors DC Analog Input 16 Channels with Socketed 12.8MA/5V Analog Adaptors DC Analog Input 16 Channels with Socketed 20MA/5V I/P Analog Adaptors DC Analog Input 16 Channels with Socketed I/P VOLTAGE Analog Adaptors DC ANALOG INPUT 16 CHANNELS, Analog Adaptors, I/P 10V KE: 32 T/C OR 16 R/L FACE-40 High Current KE 32 T/C w 8 SEAL-IN FACE 40 None 32-Channel, 12 V Wetting 32-Channel, 24 V Wetting 32-Channel, 48 V Wetting 32-Channel, 120 V Wetting 32-Channel, 250 V Wetting 32-Channel, 24 V Wetting 10MA Current None D25 MEMX 20MB Card None 5A CT 1A CT 120 V PT 110 V PT 69.3 V PT 63.5 V PT 220 V PT 5A CT, High Precision Current Inputs 1A CT, 42XLN (FLUXBUSTER), CE MARK 5A CT, 42XLN (FLUXBUSTER), CE MARK NONE Dual DSP-50 (Compatible with Generation 4 of Firmware) D25 AIF DSP II Card (Compatible with Generation 3 of Firmware) None Factory Selected D25G4 BOOTROM IEC-61850 Not Enabled IEC-61850 Enabled

Ordering Notes: *Additional ordering options available online To view the latest options available for the D25 please visit our online store for more details.

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12808(E) English 150122

IEC 61850 Process Bus IEC 61850 Process Bus

542

Process Bus is the concept of simplifying the design of protection and control systems by installing data acquisition units in the switchyard and sending process measurements and control via digital messages over a fiber optic communications network. IEC 61850 process bus simplifies protection and control systems, reducing design, installation and maintenance costs.

HardFiber Brick • Perfoms all measurement and control for primary apparatus • Suitable for outdoor installation – IP-66, -40°C to 85°C • Error-proof copper and fiber installation via standard connectors

Outdoor Fiber Cables • Point-to-point fiber communications and fused power supply • Cut to length, pre-terminated cables require no field splicing • Extremely rugged: run in cable trays, pull through conduits, direct bury

Cross Connect Panel • Breaks out fiber communication channels from Bricks and devices • Mapping is ‘hard-fibered’ using simple patch cord connections • No firmware, settings, or maintenance required

Universal Relay IEC 61850 Process Card • Communications interface between the relay and up to 8 Bricks • Communicates with Bricks to operate primary power systems apparatus • Secure real-time system health monitoring

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IEC 61850 Process Bus

IEC 61850 Process Bus Introduction The protection and control system for the modern electrical network is a process control system. Protective relays use process measurements, such as current, voltage, and equipment status, to determine the need to take control actions, such as tripping or closing a circuit breaker during a fault event. The standard design for process control in electric utilities places protective relays in a control house; a completely centralized data acquisition and control system. Data for each individual measurement point and control point is an analog signal carried between the switchyard and the control house using a pair of copper wires, with this example requiring 15 pairs of copper wires. These wires may be terminated numerous times between the primary equipment in the switchyard and the protective relay, with this feeder requiring as many as 100 terminations. The resulting design is complex, and very labor intensive to design, document, install, and commission.

IEC 61850 Process Bus

Process bus is the concept of simplifying the design of the protection and control system by installing data acquisition units in the switchyard close to process measurement source, and sending process measurements and control via digital messages over a communications network. The rationale behind implementing process bus is to reduce the total time to design and install protection and control systems by simplifying and standardizing the physical interface between protection relays and process measurement points in the switchyard. A protection and control systems differs from industrial process control systems in the requirements for operating speed and reliability, along with more severe environmental concerns for the digital acquisition units in the switchyard. Protection and control systems must identify faults and take control actions in a few cycles, using currents and voltages from different points in the switchyard. These measurements must be precisely time synchronized. Therefore process bus systems must transmit explicitly time synchronized raw sampled values of current and voltage waveforms to protective relays.

542

The IEC global communications standard IEC 61850 “Communications networks and systems in substations” defines, in Part 9, the message formats and time synchronization requirements for transmitting raw sampled values over digital communications. However, IEC 61850 focuses on transparency and standardization of data communications. The standard does not define Implementation issues such as suitable architectures, reliability, data sharing, maintainability, testability, and scalability.

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IEC 61850 Process Bus

Application goal of IEC 61850 process bus

Process bus technical attributes

The application goal of process bus is to simplify and standardize protection and control systems by designing out all copper signaling. With copper wiring as the interface to protective relays, the interface for each relay varies from project to project, and application to application. Each wiring design, and each termination of a copper wire is custom designed for the project, and custom installed, by hand, in the field, for the project. This method results in high labor requirements for engineering, drafting, installation, and commissioning, in a business environment where there is an increased focusing on maximum utilization of capital and labor.

A practical process bus system designed around IEC 61850 Part 9 communications, must be complete and comprehensive for all protection and control applications, fit for purpose for the utility switchyard, simple and intuitive to design and install, open and non-proprietary, scalable, reliable, testable, and maintainable. The architecture of a process bus system determines how all these desirable attributes will be met.

What process bus promises is the ability to meet business objectives of reducing capital costs for construction, speeding up construction processes, and fully utilizing labor resources. At its heart, process bus is a technical way of providing a mission-critical function of P&C, while meeting a business goal of designing out all copper signaling from a switchyard, to achieve considerable cost savings by simplification of engineering, drafting, construction, commissioning and ownership. However, the architecture and components define if an IEC 61850 process bus system will truly meet business objectives and application goals.

In a possible architecture, the process interface unit (PIU) provides all data acquisition and control points. The PIU is the landing point for all copper wiring and analog signals in the switchyard. The PIU then converts all signals into digital signals for communicating through fiber optic cables to protective relays in the control house. It is also possible to define PIUs that only transmit sampled values, or only provide equipment status and control points. The process bus communications network can follow any of the standard architectures for communications networks, from a star (point-to-point) topology, to a redundant ring topology. The choice of the communications network topology determines design constraints and the ability to best meet the desirable business improvement from designing out copper wiring. Whatever communications architecture is chose, process bus provides a standard physical interface to protective relays. The physical design of the protection and control system is identical for every project: PIUs connected to a fiber optic cable. The only variability in design is where to locate PIUs, and how to lay out the communications network.

IEC 61850 Process Bus

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IEC 61850 Process Bus

Process bus architecture The design of the process bus system, then, determines the success of the system. Some key attributes require a more detailed discussion.

Comprehensible and complete architecture

Scalability

Any component of the system, including PIUs, protective relays, communication infrastructure, datasets, time synchronization, and so on can be designed only after a complete architecture is created demonstrating the ultimate shape of the system. The architecture needs to be simple and intuitive for all affected disciplines in the user’s organization. It needs to follow today’s proven protection fundamentals and be fit for purpose – addressing the right problem with the right solution. The primary goal is to deliver switchyard data to the protection & control devices and to return commands from the latter to the switchyard devices. Not all the process data is needed by all protective relays. The limited data requirements of each relay are clearly and unambiguously dictated by the virtually fixed power equipment arrangement.

A successful system needs to be scalable, from a single zone of protection to an entire substation, with the capability to continue expanding one zone at a time as required. An expansion or modification should not raise any network congestion concerns, or other problems. The system must be both feasible and economically attractive in both retrofit and green-field situations.

Reliability When increasing the number of electronic devices and connections in a system, the system’s reliability decreases with the increasing device count. This can be demonstrated using typical Mean Time To Failure (MTTF) data and running calculations on hypothetical process bus architectures. Results clearly show that each additional element in the system will increase the failure frequency. In a properly designed architecture compensating measures, which often increase system complexity and cost, should not be required to make up for artificially reduced reliability.

IEC 61850 Process Bus

Minimal co-dependencies Today, a single zone of protection can be taken out of service for upgrades, troubleshooting, periodic testing or maintenance without impacting the rest of the secondary system and without an outage in the primary system (for applications where there is a redundant protection system). A zone of protection can be engineered and deployed with minimal interactions with respect to other secondary systems. This separation has proved an indispensable foundation of practical protection engineering, and needs to be retained in the next generation solutions. Without proper consideration, a firmware upgrade for a single digital component of the system may result in unexpected system behavior and ultimately may trigger a firmware upgrade to adjacent devices. Such domino effects created by co-dependencies are undesirable, may introduce latent failure modes and ultimately would become obstacles in acceptance of the system.

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Testability and maintainability The system needs to be provisioned to facilitate testing and maintenance. Testing is defined here as verification and re-verification of a complete protection and control system after it has been deployed – initial commissioning, repair, periodically or after a major work such as protection system expansion, firmware upgrade or component replacement . Maintainability is defined as the existence of simple, safe and trusted means of performing firmware and setting changes and replacing faulty elements of the system. Addressing testability and maintainability is possible only by fundamentally engineering these facilities into the system at the beginning, not as afterthoughts in an organically developed solution.

Cyber security The system needs to be secure from a cyber security point of view. The high data rates of the process bus traffic and the requirement of very high availability of this data create challenges for known cyber security solutions such as intrusion detection or encryption. Cyber security issues, if left unattended, may either slow down adoption of the solution by creating the need to augment it later for compliance, and/or may create extra cost and effort for the user when deploying and running the system. The best solution is to develop an architecture which does not introduce issues related to cyber security in the first place.

GEDigitalEnergy.com

HardFiber System IEC 61850 Process Bus Solution The HardFiber System is a IEC 61850 Process Bus Solution that allows the mapping of measurements made in the switchyard to protection relays located in the control house using secure communications. The HardFiber System addresses the key technical and logistic challenges affecting the labor required for substation design, construction and maintenance. The HardFiber System was designed to reduce the overall labor associated with the tasks of designing, documenting, installing and testing protection and control systems. By specifically targeting copper wiring and all of the labor it requires, the HardFiber System allows for greater utilization and optimization of resources with the ultimate goal of reducing the Total Life Cost (TLC) for protection & control.

Key Benefits • Eliminate majority of copper wiring to better utilize resources for the design, building, commissioning and maintenance of power system protection and control • Robust and simple architecture for deploying IEC 61850 process bus • Extremely rugged hardened switchyard interface suitable for harsh environments • Built as an extension of the Universal Relay (UR) family of products, is available for a wide array of protection applications • Limits exposure to cyber security threats to physical interruption • Improves employee safety by limiting the number of high-energy signals in the control building • Save up to 50% in P&C labour costs

Applications • Retrofit and greenfield installations for power generation, transmission and distribution systems • Generator, Transformer, Transmission Line, Bus, Feeder, Motor, Capacitor Bank, Wide Area Network protection • Distributed bay control • Digital fault & sequence of event recording • Substation automation • Air-insulated and GIS stations

Reduces the Cost of Field Wiring • Changes protection and control wiring to connectorized components • Brick is simple settings-free I/O devices that requires no configuration • Allows entire protection and control system to be tested during factory acceptance tests

Simplifies Maintenance Testing • Designed for redundant Bricks for redundant analog measurements in one UR • Continuous cross-checking of redundant measurement signals eliminates the need for routine testing of analog measurements • Reduces maintenance testing to simple verification of contact I/O

Addresses Lifecycle Management • Removes the cost and effort of field wiring for future relay replacement projects • URs and Bricks can be replaced independently of each other • Bricks are simple I/O devices that can be replaced without engineering projects • Reduces protection and control replacement costs by 80% over conventional relays

HardFiber System

An Industrial Revolution for Protection & Control The HardFiber Process Bus System represents a true breakthrough in the installation and ownership of protection and control systems, by reducing the overall labor required for substation design, construction, and testing. This innovative solution addresses the three key issues driving the labor required for protection and control design, construction and testing: • Every substation is unique making design and drafting a one-off solution for every station • Miles of copper wires needs to be pulled, spliced and terminated • Time consuming testing and troubleshooting of thousands of connections must be performed by skilled personnel The HardFiber System was designed to address these challenges and reduce the overall labor associated with the tasks of designing, documenting, installing and testing protection and control systems. By specifically targeting copper wiring and all of the labor it requires, the HardFiber System allows for greater utilization and optimization of resources with the ultimate goal of reducing the Total Life Cost (TLC) for protection & control.

Key Benefits of the HardFiber System The underlying driver for the HardFiber System is the reduction of Total Life Costs of protection and control through labor and resource optimization. This optimization is achieved by replacing individual, labor-intensive, individually terminated copper wires with standardized physical interfaces and open digital communications

• Reduces up to 50% of labor for protection & control • Replaces extensive copper wiring with preterminated copper and fiber cables • Reduces specialized on-site labor by shifting spending to readily available materials • Improves employee safety by leaving potentially dangerous high-energy signals in the switchyard • Reduces the chances for operational mistakes made during isolation and restoration for routine maintenance

• Built on the Universal Relay (UR) family, allowing for fast transition into most protection and control applications including: • • • • • • • •

Generator protection Transformer protection Transmission Line protection Bus protection Feeder protection Motor Protection Capacitor Bank protection Wide-Area network protection

IEC 61850 Process Bus

Save Up To 50% Of Your Protection & Control Labor... Traditional Substation Materials • Relays • Copper Cabling • Terminal Blocks • Test Switches • Misc. Materials

+

Labor • Head Office Engineering and Drafting • Construction & Installation • Commissioning and Testing • On-going Maintenance

=

Traditional substation designs require large amounts of skilled labor to create engineering drawings, pull and terminate miles of copper cables, and test and troubleshoot thousands of connections.

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GEDigitalEnergy.com

HardFiber System

The Challenges of Copper Wiring With the introduction and progression of microprocessor-based protection and control devices, there has been the continued integration of discrete functions into a single device. This integration has delivered cost savings in terms of materials, but the installation uses the same labor-intensive technology dating back to electromechanical relays.

Copper wiring is installed in a substation to integrate the protection and control devices by providing a set of signal paths to move raw information, in the form of analog currents and voltages, representing the status of and controlling the operation of the primary power system. These copper wires have an extremely low signal density, and the installation details are highly dependent on each specific application.

The process of designing, installing and testing all of these copper connections is exceedingly labor-intensive, with most of the labor requirements being the on-site labor. This labor is almost exclusively manual, with very little opportunity of automation or optimization. The end result is a very labor-intensive and error-prone process that adds significant time and cost to every project and makes longterm maintenance and changes difficult to implement.

Extensive amounts of copper cables need to be distributed from each switchyard apparatus back to the control house

Many connections need to be made in each apparatus in the high voltage equipment switchyard

Thousands of terminations need to be connected and tested for each protection and control device found in the control house

Designing... Documenting... Installing... Testing...

Materials • Relays • Cabling • Patch Panel

+

Labor • Head Office Engineering and Drafting • Construction & Installation • Commissioning and Testing • On-going Maintenance

=

IEC 61850 Process Bus

HardFiber Substation

CUT P&C LABOR 50%

The HardFiber System replaces labor-intensive processes with quick installation, off-the-shelf equipment and made-to-order cables.

GEDigitalEnergy.com

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HardFiber System

Brick - Hardened Switchyard Interface

Outdoor Fiber Cables

• Performs all measurement and control for primary apparatus • Suitable for outdoor installation - IP-66, -40°C to 85°C • Error-proof copper and fiber installation via standard connectors

• Point-to-point fiber communications and fused power supply • Cut to length, pre-terminated cables require no field splicing • Extremely rugged: run in cable trays, pull through conduits, direct bury

HardFiber - Save Up To 50% On Protection & Control Labor

IEC 61850 Process Bus

1

1

2

2

1 Before

• Low density copper needs 1000s of terminations

• Outdoor cables carry copper wires to control building

• Manual, one-by-one installation by highly skilled workers

• Miles of copper wire throughout a typical switchyard

Traditional breaker wiring

After

HardFiber

Traditional cable trenches

• Eliminate 33% of breaker terminations

• Reduce copper cabling needed by 40%

• Easy replacement of Bricks reduces maintenance

• Pre-terminated fiber cables ensure high quality

All copper wiring ends at the Brick

548

Outdoor fiber cable replaces copper wiring in trenches

GEDigitalEnergy.com

HardFiber System

Cross Connect Panel

Universal Relay IEC 61850 Process Card

• Breaks out fiber communication channels from Bricks and devices • Mapping is ‘hard-fibered’ using simple patch cord connections • No firmware, settings, or maintenance required

• Communications interface between the relay and up to 8 Bricks • Communicates with Bricks to operate primary power systems apparatus • Secure real-time system health monitoring

3

4

IEC 61850 Process Bus

3

4 • Thousands of hand wired terminations into a rack

• Thousands of connections to protection and control devices

• Labor-intensive using specialized workers

• Manual wiring prone to errors and extended testing

Thousands of individual copper wires from switchyard

Fiber cross connect panels replace copper terminations

Labor-intensive copper wiring on relay panels

• Eliminate 90% of control building terminations

• Power system protection behaves as today

• Fewer high energy signals improve employee safety

• Built on established Universal Relay platform

Only fiber connections at the relay via the UR IEC 61850 Process Card

GEDigitalEnergy.com

549

HardFiber System

What is IEC 61850 Process Bus?

Adhering to existing practices:

Added benefits:

Process Bus is a term used to describe a protection and control system that uses a digital communications architecture to carry information between the switchyard and protection and control devices in the control building. This information consists of sampled values, equipment status and output commands. IEC 61850 is the international standard that defines the specific communication protocol for Process Bus implementations used for protection and control applications.

• Providing a complete system with all the necessary components for measurement, control, and protection

• Reduce dedicated on-site labor with prefabricated material to reduce costs

• Covering all utility substation protection applications

• Is as reliable as existing protection and control systems

• Being understood and deployed by the current utility workforce

• Uses an open IEC 61850 Process Bus architecture that can supports multi-vender applications

Copper connections from apparatus are made directly to Bricks and end in the switchyard

• Is practical to commission and maintain

• Is scalable and can be integrated into existing substation designs

HardFiber Process Bus System The HardFiber System is a KEMA tested IEC 61850 Process Bus Solution that allows the mapping of measurements made in the switchyard to protection relays located in the control house using secure communications. The HardFiber System addresses the key technical and logistic challenges affecting the labor required for substation design, construction and maintenance. This unique system provides a total labor saving solution and yet still adheres to the practices used today for protective relaying and control.

A single fiber optic connection replaces dozens of wires on a protection relay

IEC 61850 Process Bus

A single fiber patch cord makes all of the connections between relays and Bricks

The HardFiber System uses IEC 61850 to communicate measurements and commands between Bricks and relays in the control building over dedicated point-topoint fiber optic connections that avoids cyber-security issues altogether.

550

GEDigitalEnergy.com

HardFiber System

System Architecture The architecture of the HardFiber System is driven by the mapping of signals between the primary apparatus and the protection and control devices. The measurement of field signals and respective mapping of these signals, using the open IEC 61850 communications protocol, back to the control house is done through a hardened interface device called the HardFiber Brick.

Each Brick transmits measurements and accepts controls from up to 4 separate protection and control devices.

Using made-to-order Outdoor Fiber Cables connecting the Brick to a Cross Connect Panel in the control house provides fast and error-proof installation without the need for on-site splicing or terminating.

Keeping true to the existing topology of traditional substations, each protection and control device included in the zone of protection will be connected directly to Bricks through dedicated fiber optic connections. This simple, purpose-driven architecture that uses the IEC 61850 open standard for communications, provides dedicated pointto-point connections between the Brick and protective relays without introducing any issues relating to data synchronization, setting management or Cyber-Security.

IEC 61850 Process Bus

The HardFiber System can easily be incrementally scaled to include new equipment as stations evolve. Duplicated Bricks in the switchyard provide a drastic improvement in reliability and security over today’s technology.

GEDigitalEnergy.com

551

HardFiber System

Scalability

Reliability, Dependability, Security

The Challenge for Utilities

The true test of any system, including a Process Bus system, is its ability to incrementally scale up to meet specific applications without adversely affecting the other devices in the system. Today’s protection and control systems are already naturally scalable.

The HardFiber System provides an unprecedented level of diagnostics and selfchecking, allowing critical protection and control systems to do something that they have never done before – operate without routine maintenance.

Modern electricity companies deal with many individual challenges every day with one of the largest being the ability to address the constant inflationary pressures on both labor and materials while still having to manage their demand for increase in load by their customers.

The challenge for communication-based protection systems becomes making extensions and modifications without disrupting the in-service protection and control system.

Internal diagnostics and self-tests within each Brick monitor dozens of critical internal subsystems and provide this information several hundred times per second. Duplicate Bricks can be provisioned to acquire each input signal twice, allowing protection and control devices to continuously crosscheck critical protection measurements before executing commands via fully redundant outputs.

The HardFiber IEC 61850 Process Bus System is a solution that addresses these very concerns and provides utilities with a means to reduce the labor associated with substation construction and expansion, and at the same time uses technologies and methodologies familiar to existing resources and skill sets.

With the HardFiber redundant architecture, each protection and control device can be configured to maximize dependability and security, addressing specific application requirements.

IEC 61850 Process Bus

By recognizing that the mapping between power system signals and protection and control devices is fundamentally driven by the topology of the underlying substation, the HardFiber System is optimally partitioned and connected to allow for additions, modifications and upgrades to the system – without risking interruption or degradation to critical in-service protection.

Dedicated Digital Cores within each Brick allows for application additions and modifications without affecting other devices accepting information from the Brick

552

GEDigitalEnergy.com

HardFiber System

Technical Specifications BRICK INPUTS AC CURRENT Number of Inputs CT rated secondary Nominal frequency Relay burden Conversion range Current withstand AC VOLTAGE VT rated secondary Number of Inputs Nominal frequency Relay burden Conversion range Voltage withstand

4 or 8 1A or 5A 50 Hz or 60 Hz < 0.2 VA at rated secondary 0 to 46 × CT rating RMS symmetrical 20 ms at 250 times rated 1 sec. at 100 times rated Continuous at 3 times rated 25.0 to 240.0 V 4 or 0 50 Hz or 60 Hz < 0.25 VA at 120 V, 60 Hz 0 to 260 V RMS continuous at 260 V to neutral, 1 min./ hr at 420 V to neutral

Operate time Min. number of operations Control mode

<4ms 10,000 Separate close and open commands. Under conflicting commands, the output shall open

GEDigitalEnergy.com

Commands IEC 61850 8-1 Commands to Brick sent as properly configured GOOSE messages as defined in “Multilin Technical Description for Interoperability” BRICK OUTDOOR FIBER CABLES OPTICAL CHARACTERISTICS Optical Fibers 4 Fiber Type Graded Index, Multimode (50/125 mm) Specification MIL-PRF 49291/1-01 Maximum Distance 500 m (1650 ft) ELECTRICAL PROPERTIES Power Conductors (2) Size 1.31 mm2 (16 AWG) Voltage Rating 600 VAC Shield Aluminium/polyester tape Drain Wire 0.33 mm2 (22 AWG) stranded tinned copper MECHANICAL PROPERTIES Jacket FR LSZH polyurethane, rodent resistant Cable O.D. 12 mm (0.5 in) nominal Maximum Installation 1780 N (400 lbs) Tension Maximum Operating 670 N (150 lbs) Tension Minimum Bend Radius 25 cm (10 in) (Installation) Minimum Bend Radius 12 cm (5 in) (Operating) Cable Weight 164 kg/km (110 lbs/1000 ft) ENVIRONMENTAL Storage Temperature -40° to +85°C Operating -40° to +85°C Temperature BRICK COPPER CABLES ELECTRICAL PROPERTIES Voltage Rating 600V Conductor Information Cable Type Conductors Outputs (CUB) 16 x 1.31 mm2 (16AWG) Inputs (CUC) 29 x 1.31 mm2 (16 AWG) CC55 AC Input Cable 16 x 3.31 mm2 (12AWG) (CUD-CC55) CV50 AC Input Cable 8 x 3.31 mm2 (12AWG),8 x (CUD-CV50) 1.31 mm2 (16AWG) CC11 AC Input Cable 16 x 1.31 mm2 (16AWG) (CUD-CC11) CV10 AC Input Cable 16 x 1.31 mm2 (16AWG) (CUD-CV10) MECHANICAL PROPERTIES Jacket FR PVC Cable Sizes Cable Type Cable O.D. Outputs (CUB) 18 mm (0.7 in) Inputs (CUC) 25 mm (1.0 in) CC55 AC Input Cable 23 mm (0.9 in) (CUD-CC55) CV50 AC Input Cable 23 mm (0.9 in) (CUD-CV50) CC11 AC Input Cable 18 mm (0.7 in) (CUD-CC11) CV10 AC Input Cable 18 mm (0.7 in) (CUD-CV10) INDOOR FIBER CABLES OPTICAL PROPERTIES Optical Fibers 4 Fiber Type Graded Index, Multimode (50/125 mm MECHANICAL PROPERTIES Jacket FR LSZH polyurethane Cable O.D. 8 mm (0.3 in) nominal Maximum Installation 2180 N (490 lbs) Tension Maximum Operating 490 N (110 lbs) Tension Minimum Bend Radius 13 cm (5 in) (Installation) Minimum Bend Radius 6 cm (2.5 in) (Operating) Cable Weight 50 kg/km (34 lbs/1000 ft) ENVIRONMENTAL Storage Temperature -40° to +85°C Operating -40° to +85°C Temperature

* Maximum interruption duration for which Brick operation is unaffected. The Brick complies with type tests applicable to power supply terminals. ** Maximum duration between application of rated power supply voltage and Brick ready to provide full service.

553

IEC 61850 Process Bus

CONTACT INPUTS (18) Wetting power Brick internal 24VDC power supply External contacts dry contact, dry solid state contact Voltage threshold 6±1VDC Speed Refreshed at sampling rate Current Draw > 2.5 mA at 6VDC, 5 mA at 0VDC UNIVERSAL DC INPUTS (3) MODE RTD Types (3-wire) 100 Ω Platinum, 100 & 120 Ω Nickel Sensing current 2.5 mA Range –50 to +250°C Accuracy ±2°C External lead 25Ω maximum per lead resistance MODE DCMV Type differential input Range ±5VDC Input impedance ≥500k Ω. Accuracy ±0.2mVDC or 0.1% of reading, whichever is greater MODE DCMA Current input (mA DC) 0 to –1, 0 to +1, –1 to +1, 0 to 5, 0 to 10, 0-20, 4-20 0 to 20, 4 to 20 External resistor 200 Ω ± 0.2 Ω Conversion range –1 to + 20 mA DC Accuracy ±0.2% of 1mA or 0.2% of reading, whichever is greater MODE POTENTIOMETER Range 2k Ω to 20k Ω Sensing voltage 5V Accuracy ±5mVdc BRICK POWER SUPPLY Nominal DC voltage 110V to 250V Min/Max DC voltage 88V to 300V Nominal AC voltage 100 to 240V at 50/60Hz Min/Max AC voltage 88/264V at 25 to 100Hz Power consumption <25W VOLTAGE INTERRUPTION Hold-Up time* 0 ms Brick recovery time** 1 ms Voltage withstand 2* Highest Nominal Voltage for 10ms, 220Vac+20% continuously BRICK OUTPUTS SOLID-STATE OUTPUT RELAY (4) Operate and release <100us time Maximum voltage 280VDC Maximum continuous 5 A continuous at +45°C, current 4 A continuous at +65°C Make and Carry 300A DC, 0.03s, 25oC Current 30A DC, 0.2 s (ANSI C37.90) 20A DC, 1 min, 25oC Breaking Capacity UL508 Utility App. Industrial App. (Autoreclose Scheme) Operations/ 5000 ops/1 s-On, 5 ops/ 10000 ops/ Interval 9 s-Off 0.2 s-On, 0.2 s-On 0.2 s-Off, 30 s-Off 1000 ops/0.5 s-On, within 1 0.5 s-Off minute Break 3.2 A at L/R=10 ms 10 A at L/ 10 A at L/ Capability 1.6 A at L/R=20 ms R=40 ms R=40 ms (0 to 250 30 A at L/R= 30 A at L/R= VDC) 0.8 A at L/R=40 ms 4ms 4ms LATCHING RELAY (1) Maximum voltage 280VDC Maximum continuous 6A current Make and carry for 30A as per ANSI/IEEE C37.90 0.2s Breaking capacity (L/R=40 ms) DC Voltage DC Current 24 V 1A 48 V 0.5 A 125 V 0.3 A 250 V 0.25 A

FORM-C RELAY (2) Maximum Voltage 280VDC Maximum continuous 8A current Make and carry for 30A as per ANSI/IEEE C37.90 0.2s Breaking capacity (L/R=40 ms) DC Voltage DC Current 24 V 1A 48 V 0.5 A 125 V 0.3 A 250 V 0.2 A Operate time <8ms Min. number of 10,000 operations BRICK COMMUNICATIONS Brick transceiver 1310nm TX/1550 nm RX, 100Mb/s, bidirectional 1-Fiber 50/125um, complies with IEEE 802.3 100 Base-BX-U MULTI-MODE MODULE Optical transmit power -14dbm~-8dbm Maximum optical input -8dbm power Optical received -30dbm sensitivity Terminus Socket terminus M29504/5 BRICK ENVIRONMENTAL TEMPERATURE RANGES Storage -40 to +85ºC Continuous Operating -40 to +70ºC OTHER Altitude up to 2000m Installation Category II IP rating IP66, NEMA 4X BRICK TYPE TESTS Cold IEC 60068-2-1, 16 h at –40ºC Dry heat IEC 60068-2-2, 16 h at +85ºC Humidity IEC 60068-2-30, 55ºC, >95%, Variant 1, 6 days Temperature/humidity IEC 60068-2-38, -10°C to +65°C cyclic IP rating IEC 60529, NEMA 250 Solar radiation IEC 60068-2-9, MIL-STD-810F Method 505.4 procedure II worldwide deployment Vibration IEC 60255-21-1 2G class 2 Shock and bump IEC 60255-21-2 class 2 Seismic IEC 60255-21-3, ANSI/IEEE C37.98 Insulation ANSI/IEEE C37.90, IEC 60255-5 Impulse 5kV impulse Dielectric strength 3kVAC/1min for AC inputs, 2.3kVAC/1min for others Insulation resistance 100MΩ at 500VDC Electrostatic discharge ANSI/IEEE C37.90.3, IEC 60255-22-2 Class 4, 8kV C/15kV A Fast transient IEC 60255-22-4 2.5kV at 5kHz, 4kV at 2.5kV IEEE C37.90.1 4kV for common mode test and transverse mode test IEC 60255-22-1 2.5kV for common mode test, 1 kV for differential mode test IEEE C37.90.1 2.5kV for common mode test and transverse mode test IEC-1000-4-12 2.5kV for common mode test and differential mode test Surge IEC 60225-22-5, 4kV for common mode test, 2kV for transverse mode test Magnetic Field Immunity IEC 61000-4-8 1000A/m for 3s, 100A/m for continuous IEC 61000-4-9 1000A/m Radiated immunity IEC 60255-22-3 35V/m at 80/160/450/900MHz IEC 60255-22-3 35V/m from 80M~1000MHz IEC 50204 35V/m at 900/1890MHz IEEE C37.90.2 35V/m from 25M~1000MHz IEC 60255-22-6 35V/m from 150k~80MHz IEC 61000-4-16 30V, 300V/1s from 0~150kHz Electromagnetic IEC 60255-25/CISPR11/22 class A emission BRICK PRODUCTION TESTS Products go through an environmental test based upon an Accepted Quality Level (AQL) sampling process APPROVALS CE CE LVD 2006/95/EC: EN/IEC 61010-1: 2001 / EN60255-5 2000 CE EMC 89/336/EEC: EN 60255-26 2004-08 IEC 61850 COMMUNICATIONS Sampled Values IEC 61850 9-2 Max. Sampling Rate 128 samples/cycle SV Datasets per SV 8 Frame SV Fast Dataset 11 Analogue values (Type INT32) SV Dataset Data Items Samples Per SV Frame Fast Analogue Values: 11 (INT32) Status Indications: 3 x 32 (Packed 8 List per IEC 61850 8-1 8.135) Slow Analogue Values: 6 (INT16) Status Indications: 32 (Packed 1 List per IEC 61850 8-1 8.1.3.5)

HardFiber System

Dimensions

IEC 61850 Process Bus

Brick

554

GEDigitalEnergy.com

HardFiber System

Dimensions Cross Connect Panel Front

Back

IEC 61850 Process Bus

Outdoor Brick Cable

GEDigitalEnergy.com

555

Ordering Brick Brick

-

4

-

HI

- **** Brick base unit, 4 digital cores, 125/250 VDC nominal power supply

CT/VT Inputs CC55 5A/5A 8xCT Inputs CV50 5A 4xCT & 4xVT Inputs CC11 1A/1A 8xCT Inputs CV10 1A 4xCT & 4xVT Inputs

Cross Connect Panel XPC

-

16

-

HI

HardFiber Cross Connect Panel, 16 positions, 125/250 V DC Distribution

Fiber Cables FOA

Cable Length 001 500

-

0000

-

M*** Outdoor Brick connection cable, four fiber optic cores plus copper DC supply 1 meter to 500 meters (3 feet to 1650 feet)

FOR

-

0000

-

M***

Indoor relay fiber cable, four fiber optic cores

Cable Length 003 005 010 015 020 025 030 040 050

Brick Copper Cables CUB

-

0000

-

M*** Contact Output Cable

CUC

-

0000

-

M***

CUD

-

****

-

M***

Cable Length

Cable Length

002 005 010 020

002 005 010 020

CT/VT Inputs CC55 CV50 CC11 CV10 Cable Length 002 005 010 020

2 meters (6 feet) 5 meters (16 feet) 10 meters (32 feet) 20 meters (64 feet)

Contact & Transducer Input Cable

2 meters (6 feet) 5 meters (16 feet) 10 meters (32 feet) 20 meters (64 feet)

AC Input Cable

5A/5A 8xCT Inputs 5A 4xCT & 4xVT Inputs 1A/1A 8xCT Inputs 1A 4xCT & 4xVT Inputs 2 meters (6 feet) 5 meters (16 feet) 10 meters (32 feet) 20 meters (64 feet)

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12835(E) English 150122

Digital Metering Digital Metering Overview GE’s broad portfolio of accurate digital metering solutions cover applications from power metering, building automation and sub metering to power quality metering with waveform capture and transient recording.

Product Selector Guide A reference table highlighting the feature set for each digital meter, allowing for quick and easy identification of products to assist in choosing the correct product for the specific application.

Product Listing Complete product brochures for Multilin Digital Meters.

Product Selector Guide

Digital Metering – Selector Guide Multilin™ Digital Metering Selector Guide – Power Quality Meters

Features

EPM 2200

EPM 6000

EPM 6010

PQMII 0.40%

EPM 7000

EPM 9450

EPM 9650

EPM 9800

EPM 9900

ENERGY AND MEASUREMENT ACCURACY Active Energy Measurement Accuracy Energy Accuracy Meets or Exceeds ANSI Class Energy Test Pulse for Accuracy Certification

0.5%

0.2%

0.2%

0.20%

0.04%

0.04%

0.06%

0.06%

C12.20 Class 0.5

C12.20 Class 0.2

C12.20 Class 0.2

C12.20 Class 0.2

C12.20 Class 0.2

C12.20 Class 0.2

C12.20 Class 0.2

C12.20 Class 0.2

•

•

•

•

•

•

•

•

POWER AND ENERGY MEASUREMENT Voltage, Current, Frequency, Power Factor

•

•

•

•

•

•

•

•

•

Power (kW, kVAR, kVA)

•

•

•

•

•

•

•

•

•

Bi-Directional Power

•

•

•

•

•

•

•

•

•

Energy (kWh, kVARh, kVAh)

•

•

•

•

•

•

•

•

•

Demand

•

•

•

•

•

Demand-Time-of-Use Support

•

Auto-calibrating

•

•

•

•

•

•

•

•

•

•

•

• •

POWER QUALITY •

•

•

•

•

Sags & Swells

Harmonics - THD

•

•

•

•

•

•

•

•

Harmonics-Spectrum Analysis

•

•

•

•

•

•

Crest-Factor

•

Subcycle Transient Detection

•

•

•

•

K-Factor

•

•

•

•

•

•

•

EN50160 Flicker & Compliance EN61000-4-30 Class A Reporting

•

DATA LOGGING Historical Logging

•

•

•

•

•

•

Event Logging

•

•

•

•

•

•

192KB

4MB

512KB

4MB

4MB

1GB

•

•

•

•

•

•

64

512

512

512

512

1024

•

•

•

Maximum Logging Memory Event-Driven Waveform Capture Maximum Waveform Capture Rate Samples/Cycle Time Synchronization via IRIG-B Transient Recorder Samples/Cycle

• 166,000

Digital Metering

AUTOMATION AND I/O KYZ Pulse Output

•

•

•

Alarm Annunciation via Relay

•

•

•

•

•

•

•

•

•

•

•

•

Analog Input (Max)

1

0

32

32

32

32

Analog Output (Max)

4

8

32

32

32

32 40

Digital Input (Max)

4

8

40

40

40

Digital Output (Max)

4

4

16

16

16

4

Control Relay (Max)

4

4

16

16

16

12

2

4

4

4

4

6

•

•

•

•

•

•

•

•

•

•

•

•

•

COMMUNICATIONS AND PROTOCOLS Communication Ports (Max)

1

2

RS-485 / Modbus RTU

•

•

2

Ethernet Port / Modbus TCP

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•

Front Communication Port

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•

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•

•

•

•

•

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USB Port DNP 3.0

•

•

Embedded Web Server

•

BACnet/IP

•

•

Modem

•

DISPLAYS AND MOUNTING Multi-function/Touch Screen Display Color Touch Screen Display Enclosure

• •

•

•

•

•

For a full listing of all Multilin Digital Metering products, please visit our website Passport.GEDigitalEnergy.com 558

GEDigitalEnergy.com

•

•

Product Selector Guide

Multilin™ Digital Metering Selector Guide – Submetering

Features

EPM 4600

EPM 6100

EPM 7100

ENERGY AND MEASUREMENT ACCURACY Active Energy Measurement Accuracy Energy Accuracy Meets or Exceeds ANSI Class Energy Test Pulse for Accuracy Certification

0.5%

0.2%

0.2%

C12.20 Class 0.5

C12.20 Class 0.2

C12.20 Class 0.2

•

•

•

POWER AND ENERGY MEASUREMENT Maximum Number of Circuits Measured

24

1

1

Voltage, Current, Frequency, Power Factor

•

•

•

Power (kW, kVAR, kVA)

•

•

•

Bi-Directional Power

•

•

•

Energy (kWh, kVARh, kVAh)

•

•

•

Demand

•

•

•

Demand-Time-of-Use Support

•

•

DATA LOGGING Historical Logging Maximum Logging Memory Time Synchronization (Modbus, Line Frequency)

•

•

32MB

2MB

•

•

AUTOMATION AND I/O KYZ Pulse Output Relay Outputs/Status Inputs

•

•

•

2|4

COMMUNICATIONS AND PROTOCOLS Communication Ports (Max)

3

2

2

WiFi Capable

•

•

•

RS-485 / Modbus RTU

•

•

•

Ethernet Port / Modbus TCP

•

•

•

Front Communication Port

•

•

•

USB Port

•

Color Touch Screen Display

•

Digital Metering

For a full listing of all Multilin Digital Metering products, please visit our website Passport.GEDigitalEnergy.com

GEDigitalEnergy.com

559

Featured Products

Digital Metering – Featured Products EPM 9900

Advanced Power Quality Metering System with Transient Recorder

561

Precision Measurement, 10MHz Transient Recorder, Advanced Communication, and up to 1GB of memory. With a color touch screen display and high speed (1024 samples/cycle) waveform recorder EPM 9900 meter is perfect for industrial and utility substation automation applications where both power quality monitoring and extremely high accuracy are required.

EPM 9450/9650

Advanced Power Quality Metering Systems

565

High Performance Power Meter and Data Acquisition Node. Perfect for industrial, commercial and utility applications, with advanced features available such as Transformer Loss Compensation, onboard time of use and high speed waveform capture. Options include increased memory capacity for data logging, EN50160 Flicker and compliance monitoring.

EPM 7000

Power Quality Meter

569

The EPM 7000 meter provides revenue class (0.2%) three phase power metering with optional Ethernet, relay, status, and analog output communication modules. This flexible meter can be used for a wide range of high accuracy applications including disturbance recording and power quality studies.

PQM II

Power Quality Meter

573

Continuous Metering of three-phase systems with waveform and data logging. The PQM II is a digital metering device that provides continuous monitoring of a three-phase system. It provides metering of current, voltage, real and reactive power, energy use, cost of power, power factor and frequency.

EPM 6000/6010

Multifunction Power Metering System

577

The industry’s highest performance revenue grade panel meters, the EPM 6000 family of meters has a superior cost to performance ratio and significantly outperforms other metering products many times its price.

Digital Metering

EPM 2200

Power Metering System

581

Full Featured Metering with Advanced Power Measurement. The EPM 2000 meter measures more than 40 electrical power parameters providing a low-cost, multifunction monitoring solution for industrial and power generation applications.

EPM 4600

Multi-Feed Power and Energy Metering Solution

585

The Multilin EPM 4600 Multi-feed Power and Energy Meter is a submetering solution that allows owners and operators to quickly, accurately and centrally measure power and energy usage of specific areas to reduce operating expenses. The EPM 4600 provides comprehensive data logging and trending capabilities and includes a broad range of communication options including Wi-Fi, Ethernet RS485 or USB for easy integration in both existing or new infrastructures.

EPM 6100/7100

Energy Submeter with Data Logging and WiFi The EPM 6100/7100 are powerful tools for monitoring and managing energy usage within factories, businesses and across campuses. Featuring 0.2% accuracy, as well as RS485, RJ45 Ethernet or WiFi communications. Optional data logging and alarm recording capabilitiesenable advanced analysis and predictive maintenance of the power system.

Go online for the full listing of GE Meters & Submeters

560

GEDigitalEnergy.com

589

Multilin™ EPM 9900 High Performance Power Quality and Transient Recorder Meter The EPM 9900 is one of the most advanced monitoring products on the market today, providing you with the total picture of energy usage and power quality from any metered point in a power distribution network. Precision Measurement, 10MHz Transient Recorder, Advanced Communication, and up to 1GB of memory.   With a color touch screen display and high speed (1024 samples/cycle) waveform recorder EPM 9900 meter is perfect for industrial and utility substation automation applications where both power quality monitoring and extremely high accuracy are required.

Monitoring & Metering • 0.06% Energy Accuracy • 10MHz Transient Recorder (over 166,000 samples/cycle) • 8 Channel Waveform Recorder • Voltage Surge, Sag and Transient Recording

Key Benefits

• Current Fault Signatures and Analysis

• Auto-calibrating metrology means the meter maintains its accuracy over temperature and time

• Up to 1 GB of Memory

• Large memory makes it possible to view years of circuit’s history

• EN61000-4-30 Class A Support

• Capture the fastest events with 10MHz transient recording • Ideal for monitoring industrial power centers, data centers, and hospitals due to high accuracy disturbance recording (up to 1024 samples/cycle) and extremely high accuracy 0.06% Watt/Hr metering • Operators can quickly extract recorded data with download speeds 20 times faster than existing technology • Flexible communications supporting simultaneous Modbus, DNP and IEC 61850 for a multitude of metering applications

Advanced Communications • Standard 10/100BaseT Ethernet Port • Expandable Serial Ports (Dual RS485 Ports)

• Standardize setup, commissioning, ongoing maintenance using 61580 settings files

• Modbus ASCII, Modbus TCP, DNP 3.0 Level 2, IEC 61850

• Increased communications flexibility with simultaneous Modbus, DNP and IEC 61850

• 8 Simultaneous Connections via Ethernet

• Upgradable through modular I/O and field upgradable firmware allowing the meter to be easily adapted for changing applications

• Optional Second Ethernet Port

Applications

• Up to 40 Digital Status Inputs

• Advanced power quality monitoring • Revenue class energy and power billing with 0.06% accuracy • Control of external devices using output modules

• Up to 16 Relay Outputs

EPM 9900 Advanced Power Quality Meter

EPM 9900 Meter Face-Mounted Coms and Display

ANSI Optical Port

Watt/hr Pulse

256-Color LCD Display Touch-screen Overlay Backlight Button

VAR/hr Pulse

EPM 9900 Meter Rear Mounted Communication

Digital Metering

Upgradeable and Powerful Inputs and Outputs

Optional Upgrade Cards

Standard 10/100 BaseT Ethernet RJ45 Port (Auto-detecting Tx and Rx)

2-ports: RS485 and 4 Pulse Outputs

IRIG-B Satellite Clock: 1 msec Time Sync

Optional Second Ethernet Port

Color-coded Voltage Inputs 8 High-Speed Status Inputs

562

Slots 3 and 4 Provide up to 12 Relay Outputs

GEDigitalEnergy.com

EPM 9900 Advanced Power Quality Meter

Technical Specifications INPUT VOLTAGE RANGE

UPDATE TIME

SHIPPING

• (5-347)VAC, Line to Neutral • (10-600)VAC, Line to Line

• 1 Second — Revenue Accurate Readings • 100 msec — High Speed Readings

VOLTAGE INPUT WITHSTAND CAPABILITY

CONTROL POWER REQUIREMENTS

Total shipping weight: approx. 5 lbs (2.3 kgs) Shipping container dimensions: 16” x 13” x 11” (40.64cm x 33.02cm x 27.94cm)

• Voltage Inputs isolated to 2500VAC • Meets ANSI C37.90.1 (Surge Withstand Capability)

• AC: 100-240VAC • HI: 90‐265VAC or 100‐240VDC • LD: 18-60VDC (24-48VDC Systems) • Burden: 25VA Max

INPUT CURRENT RANGE • 5 Amp Inputs 4x continuous programmable to any CT range • Fault Current recording to 80 Amps peak secondary based on 5 Amp full scale

COMPLIANCE

FREQUENCY RANGE 45Hz–69.9Hz COMMUNICATION FORMAT

CURRENT INPUT WITHSTAND CAPABILITY (AT 23°C) • 100 Amps for 10 Seconds • 300 Amps for 3 Seconds • 500 Amps for 1 Second BURDEN • Voltage Inputs: 0.072W/Phase Max at 600 Volts, 0.003W/Phase Max at 120 Volts • Current Inputs: 0.008VA per Phase Max at 20 Amps ISOLATION All inputs to outputs are isolated to 2500 VAC TEMPERATURE RATING • Operating Temperature: (-20 to +70)°C • Humidity: Up to 95% RH Non-condensing • Storage Temperature: (-30 to +80)°C SENSING METHOD • Up to 1024 Samples per Cycle (Programmable) • Voltage Transient: 10MHz ±1.8kV ±10% • 16 Bit A/D Resolution – Multiple Converters • True RMS

• Programmable parity and stop bits • Communication Protocols: Modbus TCP/IP, ASCII/ RTU, DNP 3.0, IEC 61850 Edition 1 • ANSI Optical Port • USB 1.1/2.0 Virtual COM Port • RJ-45 Ethernet Port 10/100BaseT • 2 RS485 Ports (optional)

• ANSI C12.20 Class 0.2 and IEC 62053-22 (Accuracy) • ANSI C62.41 (Burst) • ANSI/IEEE C37.90.1 – Surge Withstand • IEC 1000-4-2 – ESD • IEC 1000-4-3 – Radiated Immunity • IEC 1000-4-4 – Fast Transient • IEC 1000-4-5 – Surge Immunity • EN61000-4-15 – Flicker Meter • EN61000-4-7 – Harmonics • EN61000-4-30 – Class A • CE Marked • UL and cUL Listed, File E250818

Accuracy Rating This unit complies with and exceeds ANSI C12.20 and IEC62053-22 accuracy requirements. Parameter

100 msec*

1 second*

Display Resolution

0.10% 0.10% 0.10% 0.03 Hz 0.10% 0.10% 0.10% 0.10% 0.10% N/A N/A N/A N/A

0.05% 0.05% 0.025% 0.01Hz 0.06% 0.10% 0.08% 0.08% 0.08% 0.20% 0.06% 0.08% 0.08%

5 Digit 5 Digit 5 Digit 5 Digit 5 Digit 5 Digit 5 Digit 5 Digit 3 Digit 3 Digit 16 Digit 16 Digit 16 Digit

GEDigitalEnergy.com

Digital Metering

Voltage (L-N) Voltage (L-L) Current Frequency kW @ Unity PF kW @ 0.5 PF kVA kVAR (0.5 – 0.9 PF) PF Harmonic Magnitudes kW-hours kVA-hours kVAR-hours

563

Ordering PL9900

Control Power

**

*

AC HI LD

Frequency

*

*

*

**

**

**

6 5

Current Inputs

5A 1A

Software

A B C

Slot 1

S X

Slot 2

E1 E2 X

Slot 3

R1 D1 X

Slot 4

R1 D1 X

Description

100 - 240 90-265 VAC or 100-370 VDC 18-60VDC (24-48VDC Systems) 60 Hz 50 Hz 5 Amps 1 Amp 128MB memory with 512 samples/cycle 1GB memory with 1024 samples/cycle, IEC 61850 Communications Protocol 1GB memory with 1024 samples/cycle, IEC 61850 Communications Protocol and 10MHz Transient Recording 2-ports RS485 and 4 Pulse Outputs Empty Slot Second Ethernet Port, 10/100BaseTX, RJ45 Second Ethernet Port, 100FX, Multimode, ST connector Empty Slot 6 Relay Outputs 16 Status Inputs Empty Slot 6 Relay Outputs 16 Status Inputs Empty Slot

NOTE: Each I/O for Slots 1 through 4 can be ordered as a separate upgradable part. Consult the online store your factory for details.

External Output Modules PL9000

PL9000

*

*

1 1 2 2

*

8 8 8 8

PL9000

*

M M O O

A A M M

*

*

A A A A

*

*

O O A A

*

I I I I

*

N N O O

4 8 N N

*

1 2 3 4

*

0 0 0 0

*

*

*

*

4 4

R P

O O

1 1

0 0 0 0

0

*

0

0

Analog Output Modules

*

0

0

Analog Input Modules

O O 4 8

0 0 0 0

0

0 0 0 0

0

0 0 0 0

0

4 Channel 0-1 mA Analog Outputs 8 Channel 0-1 mA Analog Outputs 4 Channel 4-20 mA Analog Outputs 8 Channel 4-20 mA Analog Outputs

8 Channel 0–1mA Analog Inputs 8 Channel 0–20mA Analog Inputs 8 Channel 0–5V DC Analog Inputs 8 Channel 0–10V DC Analog Inputs

0

Digital Output Modules 4 Channel Control Relay Outputs 4 Channel KYZ Solid State Pulse Outputs

PL9000

M

B

I

O

0

0

0

0

0

Auxiliary Mounting Bracket (Required for using external modules)

PL9000

P

S

I

O

0

0

0

0

0

Auxiliary Power Supply (Must be ordered with external modules)

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12791(E) English 150120

Multilin™ EPM 9650 & 9450 High Performance Power Quality Analysis Device

Monitoring & Metering

Ideal for industrial, commercial, and utility applications, the performance enhanced EPM 9650 & 9450 Power Quality Meters provide a comprehensive set of features required for the highest levels of Power Quality analysis and communications.

• Current, voltage, real and reactive power, energy use, cost of power, power factor and frequency

The EPM 9650 & 9450 meters provide the total picture of power usage and power quality for metered points within a distribution network, allowing users to make power related decisions quickly and effectively.

• Laboratory grade 0.04% Watt-Hour accuracy

Key Benefits • High-performance power quality and revenue class metering for critical power applications • EN50160 flicker with p to 512 waveform samples per cycle and high-speed transient recording for complete power quality monitoring • Fast response time to power quality events for diagnostics and maintenance

• Flicker and waveform recording • Real-time PQ monitoring and harmonic magnitude analysis to 255h order

Control • Programmable setpoints for alarms and 90 millisecond relay activation for high speed updates and control

• Built-in GPS clock sync capability for accurate time stamping of events and alarms for synchronized system monitoring

• Expandable external outputs

• Exceeds ANSI C-12 and IEC 687 specifications for accuracy with auto calibration using temperature compensation

• Multiple analog, digital and relay outputs

• Software and hardware triggers record waveform events, allowing the meter to be used for fault analysis, system apparatus monitoring and many other applications

Communications

• Real time phasor analyzer monitors phase angles between the voltages and currents

• On-board Ethernet and Modbus/TCP capability

Applications

• 8 built-in, high-speed, digital inputs

• High-speed RS485 and RS232 Com Ports

• Revenue class metering and load aggregation for energy management

• Multiple protocols including Modbus and DNP3.0 level 2

• Transformer loss compensation

• Built-in modem with dial-out capability

• High-performance power quality monitoring of critical loads

• Web Server & Gateway

EPM 9000 Series Power Quality Meter

User Interface

8 High-Speed Status Inputs

3 Communication Ports

IRIG-B Input Heartbeat (Test Pulse)

External Output Modules

On-Board Modem or Ethernet TCP/IP

RS-232

Rugged Metal Case 4 Current Inputs Multifunction LED Display Universal Power Supply

4 Voltage Inputs

Touch screen LCD display

Typical Wiring

Digital Metering

4 Wire Wye: 3 Element Direct Voltage

L+

N-

CHASIS

Vaux.

Vref.

Va

Vb

Vc

Ia LO

HI

Ib

HI

LO

Ic LO

HI

In

3 Wire: 3 Element Direct Delta

HI

L+

N-

CHASIS

Vaux.

CT SHORTING SWITCH

Ia

Vc

HI

Ib

HI

LO

Ic LO

HI

In

HI

LO

CR TEST BLOCK

CTs

LINE

SUPPLY POWER (DEPENDENT ON EQUIPPED POWER SUPPLY OPTION)

CT SHORTING SWITCH CR TEST BLOCK

CTs

LOAD C B

C B A

A

SWITCHGEAR CHASSIS GROUND

566

Vb

FUSES 0.25A

SUPPLY POWER (DEPENDENT ON EQUIPPED POWER SUPPLY OPTION)

N

Va

LO

FUSES 0.25A

LOAD

Vref.

LO

SWITCHGEAR CHASSIS GROUND

GEDigitalEnergy.com

LINE

EPM 9000 Series Power Quality Meter

Technical Specifications DEMAND MONITORING

INPUTS

OUTPUT MODULES

Measured values:

Phase A/B/C/N current (A) 3 phase real power (kW) 3 phase reactive power (kvar) 3 phase apparent power (kVA)

INPUT VOLTAGE RANGE 150V phase to neutral, 300V phase to phase* 300V phase to neutral, 600V phase to phase *To be used also with PTs for extended input voltage.

Measurement type:

Thermal exponential 1 – 9999 sec, steps of 1 sec Block interval/rolling demand time in interval (programmable): 1 – 9999 sec, steps of 1 sec

INPUT CURRENT RANGE 5 amp inputs 2x continuous programmable to any CT range Fault current recording to 60 amps peak secondary based on 5 amp full scale Note: 1 amp and 0.25 amp current inputs available as special order

ANALOG TRANSDUCER SIGNAL OUTPUT 4 Analog Outputs, 0–1mA, self-powered, scalable, bi-directional 8 Analog Outputs, 0–1mA, self-powered, scalable, bi-directional 4 Analog Outputs, 4–20mA, self-powered, scalable 8 Analog Outputs, 4–20mA, self-powered, scalable

POWER SUPPLY CONTROL POWER Input options:

90–276 Volts AC/DC 18–60 Volts DC

Frequency:

20–400Hz

Burden:

20 VA max

1 Sec 0.05% 0.05% 0.025% 0.01 Hz 0.06% 0.1% 0.08% 0.0% 0.08% 0.2% 0.04% 0.08% 0.08%

Programmable

FREQUENCY RANGE Fundamental 45-75 Hz

Ordering Specifics:

Up to 4 Analog Output modules can be used with each unit

BURDEN Voltage inputs: 0.05VA Max Current inputs: 0.005VA Max

DIGITAL DRY CONTACT RELAY OUTPUTS 4 Relay Outputs, 5 amps, 125, AC/DC, Form C

Maximum Pulse Speed:

20 pulses per second Ordering Up to 4 modules can be used Specifics: BUILT-IN DIGITAL INPUTS 8 Digital Status Inputs Wet/Dry Auto-Detect Up to 300 Volts DC

Programmable parity and stop bits

Ports:

4 Communication ports 2 slave ports

Port 1:

RS-232 or RS-485 selectable

Protocol:

Modbus® Modbus ASCII/RTU and DNP 3.0

DISPLAY

Media:

All ports use 2-wire RS-485 communication

Baud rate:

56K bps

TOUCH SCREEN LCD DISPLAY Touch screen graphical display 320 x 240 pixels CCFL backlit Displays data from up to 8 meters 4.7” x 3.5” aperture (12.1cm x 9.1cm)

Modem:

56K Modem with dial-out capability

Ethernet:

10/100 base T with Modbus/TCP Protocol

Functions:

Read/write setpoints Read actual values

Isolation:

All Com Ports are additionally isolated from each other

Up to 95% non-condensing

No of Channels

Temperature:

-40° C to +80° C ambient

7 7 7 7 3 1

PACKAGING

CONSTRUCTION Constructed in a metal case. All hardware is stainless steel.

4 Meg RAM 1808K 400K 96K 64K 32K 32K 1568K

DIGITAL SOLID STATE PULSE OUTPUTS 4 Solid State Pulse, Outputs, Form A or C KYZ Pulses

Format:

Humidity:

2 Meg Record Size 58 Days 42 Days 512 256 N/A N/A 8

ORDERING SPECIFICS: MULTIPLE MODULES CAN BE USED

Shipping box:

16” x13” x11” (40.64cm x 33.02cm x 27.94cm)

Ship weight:

Approx. 12 lbs (5.4 kgs)

4 Meg Record Size 602 Days 66 Days 1024 1024 512 512 96

LED DISPLAY 3-line multi-function LEDs RS-485 master Displays data from a single meter

TYPE TESTS TYPE TESTS AS PER UL® & CE® Emissions: EN55011 Immunity: EN50082 Accuracy ANSI C12.20 Class 0.2 and IEC687 Communication: 2500 volts AC 60 Hz Isolation: Voltage Input Optically isolated to 2500VDC withstand: Current Input 100 amps for 10 Seconds withstand: 300 amps for 1 Second Surge withstand: ANSI/IEEE C37.90.1 Surge:

ANSI C62.41

ESD:

IEC 1000-4-2

Radiated Immunity:

IEC 1000-4-3

Fast Transient:

IEC 1000-4-4

Surge Immunity:

IEC 1000-4-5

Flicker Meter:

IEC 868

Flicker Meter:

IEC 61000-4-15

TYPE TESTS Emissions: ISO: UL & cUL: CE: Industry Canada Revenue Metering:

GEDigitalEnergy.com

Digital Metering

No of **Max. No Cycles of Cycles Record per Record per Screen* Event 16 8 Pre / 56 6080 32 4 Pre / 28 3040 64 4 Pre / 12 1520 128 1 Pre / 7 760 256 1 Pre / 3 760 512 1 Pre / 3 760 * Post Event Screen (Calculations at 60Hz.) 2 Meg RAM 176K 256K 48K 16K N/A N/A N/A

Self-Calibrating

Scaling:

ENVIRONMENTAL

DATA LOGGING

EPM 9650 Log Storage Options Historical Log 1 Historical Log 2 Out of Limit CBEMA Log Relay Output Log Input Status Log Waveform Recording Number of Events

Calibration:

COMMUNICATIONS

ANSI C12.20 Class 0.2 and IEC687 Measures harmonic magnitudes to the 255th order for each voltage and current channel Real-time harmonics resolved to the 128th order

Samples per Cycle

0.1% of Full Scale

ISOLATION All inputs and outputs are isolated to 2500 Volts

UPDATE TIME 200 millesec — high speed instant readings 1 second — Revenue accurate

Display Resolution 5 Digit 5 Digit 5 Digit 00.001 Hz 5 Digit 5 Digit 5 Digit 5 Digit 3 Digit 3 Digit 16 Digit 16 Digit 16 Digit

Note: Readings are in percent of reading where applicable (more accurate standard), not in percent of full scale (less accurate standard). Accuracy: harmonics:

Common Mode

Accuracy:

SENSING METHOD Up to 512 samples per cycle (programmable) 16 Bit A/D resolution – dual converters True RMS

METERING MEASURED VALUES MEASUREMENTS 200 Millisec* Voltage (L-N) 0.10% Voltage (L-L) 0.10% Current 0.10% Frequency 0.03 Hz KW @ Unity PF 0.10% KW @ .5 PF 0.10% KVA 0.40% VAR 0.10% PF 0.10% Harmonics N/A KW/Hours N/A KVA/Hours N/A KVAR/Hours N/A

Wiring:

EN55011 Manufactured to an ISO9001 registered program Recognized under e200431 Conforms to EN 55011/ EN 50082 Approval:#AE-1069

567

Ordering Meters EPM 9450 - High performance power meter & data acquisition node PL9450

*

*

*

A

*

0

0

0

0

Frequency 0 1 System Voltage A B Control Power 0 1 Features Options A Communications 0 1 2

Description 60 Hz 50 Hz 120/208 volts connection 277/480 volts connection 90-276 volts AC/DC power supply 18-60 volts DC power supply Basic unit with 512 K memory, 8 digital inputs, 8 cycle of waveform (up to 512 samples/cycle), 100 days data log. 4 communication port User-selectable RS 485 Modbus and DNP - no modem or Ethernet connection 10/100 BaseT Ethernet, web server and gateway capability Internal 56k modem connection with pass-through port

EPM 9650 - High performance power meter & data acquisition node with memory PL9650

*

*

*

A

*

0

0

0

0

Frequency 0 1 System Voltage A B Control Power 0 1 Features Options A B Communications 0 1 2

Description 60 Hz 50 Hz 120/208 volts connection 277/480 volts connection 90-276 volts AC/DC power supply 18-60 volts DC power supply Advance unit includes basic unit, with 2 Meg memory, Up to 96 days of data logging, up to 64 cycles of waveform recording Flicker includes advance unit plus Flicker with 4 Meg memory, 602 days of data logging 4 Communication ports User-selectable RS 485 Modbus and DNP - no modem or Ethernet connection 10/100 BaseT Ethernet, web server and gateway capability Internal 56k modem connection with pass-through port

Accessories PL9000 * * *

* * * * 0 0 1 M A O N 4 O 1 M A O N 8 O 2 O M A O N 4 2 O M A O N 8

Analog Output Modules 4 Channel 0-1 mA Analog Outputs 8 Channel 0-1 mA Analog Outputs 4 Channel 4-20 mA Analog Outputs 8 Channel 4-20 mA Analog Outputs

PL9000 * * *

Analog Input Modules 8 Channel 0–1mA Analog Inputs 8 Channel 0–20mA Analog Inputs 8 Channel 0–5V DC Analog Inputs 8 Channel 0–10V DC Analog Inputs

8 A I 8 A I 8 A I 8 A I

* * * * 0 0 1 0 0 0 0 0 2 0 0 0 0 0 3 0 0 0 0 0 4 0 0 0 0 0

PL9000 * * *

* 0 0 0 0 0 Digital Output Modules 4 R O 1 4 Channel Control Relay Outputs 4 P O 1 4 Channel kyz Solid State Pulse Outputs

PL9000 * * *

* 0 0 0 0 0 Digital Input Modules 8 D I 1 0 0 0 0 0 8 Channel Digital Status Inputs

PL9000 M B I

O

0

0 0

0

0

Auxiliary Mounting Bracket (One set per module group)

PL9000

O 0

0 0

0

0

Auxiliary Power Supply (For more than 4 modules)

P S

I

PL9000 * * *

* * * * * * P 4 0 N P L U S 0 P 6 0 N 0 0 0 0 0 P 6 0 N 1 0 0 0 0

9000 Series Meter Display Module Three line LED Display Touch-Screen LCD Display with 6-ft cable Touch-Screen LCD Display with 15-ft cable

PL9000 * * *

9000 Series Meter Software Communicator Software, Single User License Communicator Software, Five User License Communicator Software, Multiple User, Single Site License

* 0 0 0 0 0 N C M 1 N C M 5 N C M S

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12823-(E) English 150121

Multilin™ EPM 7000 Power Quality & Energy Cost Management

Monitoring & Metering

The EPM 7000 Power Quality meter provides revenue class (0.2%) three phase power metering with optional Ethernet, relay, status, and analog output communication modules. This flexible meter can be used for a wide range of high accuracy applications including disturbance recording and power quality studies.

• Meets ANSI C12.20 and IEC 687 (0.2% Accuracy)

The EPM 7000 is a highly accurate meter providing 0.1% accuracy for voltage and current. The unit’s real-time clock provides time stamping of all logs as they are created. Up to 4MB of data can be logged for analysis of historical trends, limit alarms, I/O changes power quality recording and sequence of events.

• Hz, W, VAR, VA , Wh, VARh, Vah

Key Benefits • Four Quadrant Energy and Power Measurement, complying with ANSI C12.20 (0.2%) accuracy • Analyze power quality over long periods of time to improve network reliability through high resolution event and disturbance recording • Ideal for monitoring industrial power centers, data centers and hospitals due to high accuracy disturbance recording (up to 512 samples/cycle) • Retrieve archived data, capture past events and analyze disturbances through high resolution data recording (up to 4MB of data logging) • Flexible communications options including dual Ethernet provides simultaneous Modbus and IEC 61850 to provide easy to access meter values, simplified configuration and seamless integration into new or existing automation systems • Upgradable through modular I/O and field upgradable firmware allowing the meter to be easily adapted for changing applications

Applications • Four quadrant energy and power monitoring for feeders, transformers, reactors and generators • Power monitoring of LV and MV industrial power systems and motor control centers • Energy monitoring for commercial buildings and distribution utility applications

• Current and Voltage measurements: Ia Ib Ic In, Va Vb Vc Vab Vbc Vca • Demand: W VAR VA and Power Factor • Voltage and Current Angles, Load Bar

Power Quality • Harmonics to the 40th order & total harmonic distortion • Disturbance recording and waveform capture • Sag and Swell

Data Logging • Up to 4MB of Memory • Disturbance Recording • Power Quality & Load Studies

Communications • IEC 61850, Edition 1 • Standard RS485 Modbus (DNP 3.0 and Modbus RTU or ASCII) • Optional 100BaseT Ethernet (Modbus/DNP or Modbus/IEC 61850) • IrDA Port • Intuitive faceplate programming

Software • Embedded web server • GE Communicator • EnerVista™ Integrator • EnerVista™ LaunchPad

EPM 7000 Power Meter

Expandable I/O Cards

E1

E2

C1

RS1

PS1

F1

F2

E1:

C20:

F1:

• 100BaseT Ethernet Card (Modbus, DNP)

• Four Channel 4-20mA Outputs

• Fiber Optic Interface with ST terminations

• 12 simultaneous Modbus TCP/IP connections

• Assignable to any parameter

• 5 simultaneous DNP over TCP/IP connections

• 0.1% of full scale

• Daisy Chain switchable built-in logic mimics RS485 half duplex bus

• Network Time Protocol (NTP) support (Network Clock Sync)

• 0 – 500Ω, no accuracy losses

• Embedded web server, Smartphone access compatible

• ST terminated

• Loop Powered up to 24VDC

• Modbus and DNP 3.0 Protocols available

RS1:

F2: • Fiber Optic Interface with Versatile terminations

• Available support for dual Ethernet Ports available

• Two Output Relays/ Two Status Inputs

E2:

• Trigger on user set alarms

• Daisy Chain switchable built-in logic mimics RS485 half duplex bus.

• IEC 61850 Ethernet Card

• Set delays and reset delays

• Versatile terminated

• Simultaneous Modbus and IEC 61850

• Status Inputs – Wet/Dry Auto Detect (Up to 150VDC)

• Modbus and DNP 3.0 Protocols available

• 250VAC/30VDC – 5A Relays, Form C

• IEC 61850 Support including:

• Requires Software Option D or higher for limit based alarms and control

-- Configurable .CID file -- 5 Simultaneous MMS Clients

PS1:

-- Multiple Logical Nodes -- Polled Operation Mode (Queried Reports) -- Buffered and Unbuffered Reports

• Four Pulse Outputs / Four Status Inputs • Programmable to any energy parameter and pulse value

Embedded Web The EPM 7000 with Ethernet (E1, E2 options) includes a secure web server that is viewable from a variety of web browsers. The web server supports multiple simultaneous connections to view the following information: • Voltage and Current Reading

C1:

• Normally Open Contacts, Form A

• Power and Energy Readings

• Four Channel Bi-directional 0-1mA Outputs

• 120mA continuous load current

• Power Quantity Information

• Assignable to any parameter

• Status Inputs – Wet/Dry Auto Detect (Up to 150VDC)

• General Meter Information

• 0.1% of Full Scale

• Can function for manual relay control and limit based control

• 0 to 10KΩ • Range ±1.20mA Digital Metering

C20

• Requires Software options D or higher for limit based alarms and control

User Interface Reading Type Designator

Large .56” LEDs Tx Rx Indicator LEDs

Screen Selectors RS 485

IRDA

Communication

Port Vh Pulse % Load Bar

Removable Cards

Current “Gills” Auto Scale Indicator

570

Universal Voltage Inputs

GEDigitalEnergy.com

EPM 7000 Power Meter

Dimensions and Mounting

Software Options Software Option

Measured Values

A

The above plus data-logging The above plus Harmonic Analysis The above plus Limit and Control The above plus Waveform Capture

F T he above plus Waveform Capture and Additional Memory

Avg

Max

Min

•

• • •

• • •

• • • • •

• • • • •

• • • • • • • • • • • • • • • • • • • • • • • • • •

• • • •

Digital Metering

B C D E

Real-Time

Voltage L-N Voltage L-L Current Per Phase Current Neutral % of Load Bar Voltage Angles Current Angles Watts VAR VA PF Frequency +Watt-hr -Watt-hr Watt-hr Net +VAR-hr -VAR-hr VAR-hr Net VA-hr 2 MB Data-Logging Harmonic Analysis Limit and Control Functions Waveform Capture at 64 samples/cycle 3 MB total Data-Logging Waveform Capture at 512 samples/cycle 4 MB total Data-Logging

Waveform Options Software Option

Samples per cycle

Pre Event Cycles

Post Event Cycles

Max Waveform per Event

Number of Stored Events

E

16

32

96

256

85

32

16

48

128

85

64

8

24

64

85

128

4

12

32

170

256

2

6

16

170

512

1

3

8

170

F

GEDigitalEnergy.com

571

Technical Specifications VOLTAGE INPUTS

POWER SUPPLY

KYZ PULSE

• • • •

• HI : 90-265VAC and 100-370VDC

• • • • • •

20-576 Volts Line to Neutral 0-721 Volts Line to Line Universal Voltage Input Input Withstand Capability – Meets IEEE C37.90.1 (Surge Withstand Capability) • Programmable Voltage range to any PT ratio • Supports: 3 Element WYE, 2.5 Element WYE, 2 Element Delta, 4 Wire Delta Systems • Burden: 0.014W at 120 Volts

• LDC Option: 18-60VDC (24-48VDC Systems)

STANDARD COMMUNICATIONS • • • • • • • •

2 Com Ports (Back and Faceplate) RS485 Communications Port Through Backplate Protocol Modbus RTU or ASCII Com Port Baud Rate: 9600 to 57.6K Com Port Addresses: 001-247 8 Bit, No Parity IrDA - Through Faceplace • Modbus RTU, ASCII or DNP 3.0, IEC 61850 Protocols

• Input Wire Gauge Max (AWG 12 / 2.5 mm2)

CURRENT INPUTS • Class 10: (0.005 to 11)A, 5 Amp Nominal • Class 2: (0.001 to 2)A, 1A Nominal Secondary • Fault Current Withstand: - 100 Amps for 10 Seconds - 300 Amps for 3 Seconds - 500 Amps for 1 Second • Continuous current withstand: - 20A for Screw Terminated or Pass Through Current Connections • Programmable Current to Any CT Ratio • Burden 0.005VA Per Phase • Max at 11 Amps • Pickup Current: 0.1% of Nominal Class 10: 5mA Class 2: 1mA • Pass Through Wire Gauge Dimension: 0.177” / 4.5mm

• All Inputs and Outputs are Galvanically Isolated to 2500 Volts AC

SENSING METHOD • True RMS • Sampling at 400+ Samples per Cycle on all channels measured readings simultaneously • Waveform up to 512 Samples/cycle • Harmonics resolution to 40th order

Measured Parameters Voltage L-N Voltage L-L Current +/- Watts Mwatts +/- Wh

Accuracy% of Reading 0.1% 0.2% 0.1% 0.2%

Display Range

0.2%

+/-VARs MVARs +/-VARh

0.2%

5-8 Digits Programmable 0-9999 VARs, kVARs,

VA VAh

0.2% 0.2%

PF Frequency %THD % Load Bar

0.2% +/- 0.03 Hz +/- 2.0% +/- 1 Segment

0.2%

DIMENSIONS & SHIPPING • Weight: 2lbs • Basic Unit: H4.85x W4.82 xL4.25 inches • Mounts in 92mm Square DIN or ANSI C39.1 Round Cut-outs • Shipping Container Dimensions: 6” cube

ENVIRONMENTAL

METERING ACCURACY

ISOLATION

Type Form C Contact On Resistance: 35Ω Max Peak Voltage: 350VDC Continuous Load Current: 120mA Peak Load Current: 350mA (10ms) Off State Leakage Current @ 350VDC: 1µA

0-9999 V or kV 0-9999 Scalable V or kV 0-9999 Amps or kAmps 0-9999 Watts, kWatts,

5-8 Digits Programmable 0-9999 VA, kVA, MVA 5 –8 Digits Programmable +/- 0.5 – 1.0 45 –65 Hz 1 to 99.99% (0.005 to 6) A

Storage: Operating: Humidity: Faceplate Rating:

-20° C to +70° C -20° C to +70° C to 95% RH Non-Condensing NEMA12 (Water Resistant) Mounting Gasket Included

COMPLIANCE • • • • • •

IEC 687 (0.2% Accuracy) ANSI C12.20 (0.2% Accuracy) ANSI (IEEE) C37.90.1 Surge Withstand ANSI C62.41 (Burst) IEC1000-4-2: ESD IEC1000-4-3: Radiated Immunity

• IEC1000-4-4: Fast Transient

APPROVALS ISO: UL: CE:

Manufactured to an ISO9001 registered program Listed under E250818 Conforms to European CE standards

UPDATE RATE • Watts, VAR and VA-100msec • All other parameters 1sec

Ordering PL7000

*

Enclosure

ENC120 ENC277

Frequency Current Inputs Software

*

*

*

*

*

*

5 6 5A 1A A B C D E F

Power Supply

HI LDC

I/O Modules

X E1 E2 C1 C20 RS1 PS1 F1 F2

X E1 E2 C1 C20 RS1 PS1 F1 F2

Description

Standard unit with display, all current/voltage/power/frequency/energy counters measurement, % load bar, RS 485 and IRDA communication ports and one front test pulse output. NEMA1 Rated - Indoor, Single Meter Enclosure, 120V NEMA1 Rated - Indoor, Single Meter Enclosure, 277V 50 Hz AC frequency system 60 Hz AC frequency system 5 Amps 1 Amp Multimeter Function Only Data Logging Memory, 2 MB of Memory Power Quality Harmonics, 2 MB of Memory Limits and Control, 2 MB of Memory 64 Samples/Cycle Waveform Recording, 3 MB of Memory 512 Samples/Cycle Waveform Recording, 4 MB of Memory 90-265VAC/100-370VDC 18-60VDC None 100BaseT Ethernet* 100BaseT Ethernet with IEC 61850 Protocol Four Channel Bi-directional 0-1mA Outputs Four Channel 4-20mA Outputs Two Relay status Outputs / Two Status Inputs Four Pulse Outputs / Four Status Inputs Fiber Optic Interface with ST terminations Fiber Optic Interface with Versatile Terminations * Each I/O Modules can be ordered as a separate upgradable part

EPM 7000 is available without a display as the EPM 7000T. Please see the online store for ordering information.

GEA-12822(E) English 150217

Multilin™ PQM II Power Quality & Energy Cost Management

Monitoring & Metering

The Multilin PQMII provides accurate and reliable three-phase power metering with an optional Ethernet and fiber communications module in a compact horizontal form factor. The PQM II is ideally suited for metering of distribution feeders, transformers, generators, and motors.

• Current and Voltage measurements (Ia Ib Ic In, Va Vb Vc Vab Vbc Vca

The PQMII provides continuous metering for current, voltage, real and reactive power, energy use, cost of power, power factor and frequency. Waveform capture and voltage disturbance recorder continuously monitors power quality. With programmable setpoints and 4 assignable output relays, control functions and capabilities can be added for specific applications.

• True PF Crest and K factor

Key Benefits

• Power Factor

• Power quality metering with waveform capture and historical data logging for detailed energy and disturbance analysis

Power Quality

• Easy to program and use with keypad and large illuminated, 40 character display

• Harmonic analysis through 63rd with THD and TIF

• Multiple communication ports for simplified integration with DCS and SCADA systems

• Total harmonic distortion

• Added network flexibility with support for DNP3.0 and Modbus communications protocols

• Disturbance recording and waveform capture

• V I unbalance • Hz, W, VAR, VA • Wh, VARh, Vah, W cost • Demand: W VAR VA

• Digital and analog I/Os for control and alarm functions • Voltage disturbance recording capability for analysis of electrical sag and swell events, enabling stable, clean power • Flexible control for demand load shedding, and power factor

Data Logging • Event Recorder – up to 150 events • Waveform capture

Applications

• Data Logger – up to 98,000 events

• Metering of distribution feeders, transformers, generators, capacitor banks, and motors

• Voltage Disturbance Recorder (VDR) – up to 500 events

• Suitable for Medium and Low Voltage systems • Commercial, Industrial, or Utility applications

Communications • Front RS232 serial port • Two rear RS485 serial ports with Modbus and DNP 3.0 protocol • Ethernet connectivity via MultiNet • External dial-in modem capabilities

Control • Load shedding • Power factor control • Pulse input totalizing

PQM II Power Quality Meter

Typical Wiring ALTERNATIVE CT/VT CONNECTIONS

LOAD A

PHASE A CT PHASE B CT PHASE C CT

C N

N

PHASE B CT

LINE

B PHASE C CT

C

C

VT cn

OPTIONAL NEUTRAL CT

N 3

4

V2 V3 VN

9

10

5A

1A

11 12 COM

PHASE A

VOLTAGE INPUTS

5A

13 14 15 16 1A

COM

PHASE B

5A

1A

17 COM

PHASE C

5A

COM

1A

NEUTRAL

OBSERVE CT & VT POLARITY

Perferrred 4 wire configuration 600V MAX

4 WIRE WYE DIRECT/120 VOLTAGE NO VT LINE A

VT bn

VT an

PHASE B CT

B PHASE C CT

C

C OPTIONAL NEUTRAL CT

N

1

N

2

V1

V1

3

4

V2 V3 VN

9

10

5A

1A

11 12 COM

13 14 15 16 1A

COM

PHASE B

5A

1A

17

PHASE C

5A

1A

COM

NEUTRAL

LINE A

ANY VOLTAGE LOAD A

PHASE A CT PHASE B CT

B

B PHASE C CT

C

10 1A

11 12 13 14 15 16 17 COM

PHASE A

USE HEAVY GAUGE WIRE

L

7

+ N _

6

SAFETY GROUND

5

FILTER GROUND

g

5A

1A

COM

5A

N

N

VT cn

SWITCHGEAR GROUND BUS

3

4

VOLTAGE INPUTS

9

10

5A

1A

11 12 COM

PHASE A

5A

13 14 15 16 1A

COM

PHASE B

5A

1A

17

5A

1A

43

COM

NEUTRAL

CURRENT INPUTS

A

B PHASE C CT

C

V2 V3 VN

9

10

5A

1A

11 12 COM

PHASE A

VOLTAGE INPUTS

5A

13 14 1A

COM

PHASE B

15 16 5A

1A

17 18 19 COM

PHASE C

5A

1A

COM

CURRENT INPUTS

Preferred 3 wire configuration

LINE A

600V MAX LOAD L

PHASE A CT PHASE B CT

B

N PHASE C CT

C

1 V1

2

3

4

V2 V3 VN

9

10

5A

1A

11 12 COM

PHASE A

VOLTAGE INPUTS

5A

13 14 1A

COM

PHASE B

15 16 5A

1A

17 18 19 COM

PHASE C

5A

1A

SINGLE PHASE DIRECT NO VTs LINE L

LOAD L

PHASE CT

N

N

1 V1

2

3

VOLTAGE INPUTS

574

4

V2 V3 VN

9

10

5A

1A

11 12 COM

PHASE A

5A

13 14 15 16 1A

COM

PHASE B

5A

1A

17 COM

PHASE C

18 19 20 5A

1A

COM

NEUTRAL

23

_

22

4+

25 24

SW1

31

SW2

30

SW3

29

SW4

COM2 RS485 TO/FROM DEVICE

4-20mA TRANSDUCER

TO PLC OR SCADA SYSTEM

COM3 RS232 (FRONT) RS232 INTERFACE PQM 1 2 3 4 SGND 5 6 7 8 9 TXD RXD

COMPUTER 1 2 3 4 5 6 7 8 9

8 3 RXD 2 TXD 20 7 SGND 6 4 5 22

9 PIN CONNECTOR 25 PIN CONNECTOR

1) Relay contact state shown with control power not applied.

600V MAX

+

COM

NC

NOTES:

CURRENT INPUTS

49

26

20 COM

NEUTRAL

COM

27

AUX3

33 +24VDC

2 or 3 CTs see above

50

3+

32

3 WIRE DIRECT/120 VOLTAGE NO VTs

51

_

28

DRY CONTACT SWITCH INPUTS

NEUTRAL

46

+

COM1 RS485 TO/FROM DEVICE

47

2+

35 COM

20

COM

1+

AUX2

PROGRAMMABLE SWITCH INPUTS

Digital Metering

V1

4

48

NC

34 3

+ _

36 NO

38 COM 37

2

USE SHIELDED TWISTED PAIR WIRE

21

39 NO

2 or 3 CTs see below

COM

SHIELD

B C

VT ab VT cb

1

AUX1

40 NC

LOAD

2 PHASE CTs

A

41 COM

ANY VOLTAGE

OUTPUT RELAYS

LINE

NC

42 NO

*Note: Accurate only with balanced phase voltages 3 WIRE DELTA/60 VOLTAGE 2 VTs

ALARM

44 COM

18 19 20

COM

PHASE C

ANALOG IN

2

V2 V3 VN

1A

Multilin PQM II Power Quality Metering System

ANALOG OUT

1

5A

NEUTRAL

PHASE C PHASE B CURRENT INPUTS

45 NO

V1

18 19 20

1A COM

C OPTIONAL NEUTRAL CT

VT an

8

CURRENT INPUTS

4 WIRE WYE/60 VOLTAGE 2 VTs (2-1/2 ELEMENTS)

9 5A

18 19 20

COM

CONTROL POWER

PHASE A

VOLTAGE INPUTS

5A

4

3

V 2 V3 VN VOLTAGE INPUTS

CONTROL POWER 90-300 VDC 70-265 VAC 50/60 Hz 2

VT cn

LOAD A

PHASE A CT

1

N

18 19 20

CURRENT INPUTS

B

LOAD

9 WIRE RS 232

V1

2

RS 485 S ERIAL

1

COM 1

VT bn

A

B

C OPTIONAL NEUTRAL CT

VT an

PHASE A CT

A

B

COM 2

B

4-20m A

LINE A

ANY VOLTAGE

4 WIRE WYE/120 VOLTAGE 3 VTs

ANY VOLTAGE

4 WIRE WYE/120 VOLTAGE 3 VTs

CAUTION: USE HRC FUSES FOR VT PRIMARY TO ENSURE ADEQUATE INTERRUPTING CAPACITY.

Transducer Option Control Option

CURRENT INPUTS

GEDigitalEnergy.com

PERSONAL COMPUTER

RS232

PQM II Power Quality Meter

Technical Specifications MONITORING UNDERVOLTAGE MONITORING Required voltage: 20 V applied Pickup level: 0.50 – 0.99 in steps of 0.01 x VT Dropout level: 103% of pickup Time delay: 0.5 – 600.0 in steps of 0.5 sec Phases: Any one/any two/all three (programmable) phases have to go below pickup to operate Level accuracy: Per voltage input Timing accuracy: -0/+1 sec OVERVOLTAGE MONITORING Pickup level: 1.01 – 1.25 in steps of 0.01 x VT Dropout level: 97% of pickup Time delay: 0.5 – 600.0 in steps of 0.5 sec Phases: Any one/any two/all three (programmable) phases have to exceed pickup to operate Level accuracy: Per voltage input Timing accuracy: -0/+1 sec UNDERFREQUENCY MONITORING Required voltage: 20 V applied Pickup level: 20 – 70.00 in steps of 0.01 Hz Dropout level: Pickup +0.03 Hz Time delay: 0.1 – 10.0 in steps of 0.1 sec Level accuracy: ±0.02 Hz Timing accuracy: ±3 cycles OVERFREQUENCY MONITORING Required voltage: 20 V applied Pickup level: 20 – 70.00 in steps of 0.01 Hz Dropout level: Pickup -0.03 Hz Time delay: 0.1 – 10.0 in steps of 0.1 sec Level accuracy: ±0.02 Hz Timing accuracy: ±3 cycles

SAMPLING MODES SAMPLES/INPUTS SAMPLED DURATION CYCLE AT A TIME (CYCLES) 64

ALL

2

16

ALL

continuous

256

1

1

Demand Monitoring Measured values:

Measurement type:

Phase A/B/C/N current (A) 3f real power (kW) 3f reactive power (kvar) 3f apparent power (kVA) Thermal exponential 90% response time (programmable): 5 – 60 min, steps of 1 min Block interval/rolling demand time in interval (programmable): 5 – 60 min, steps of 1 min A: 10 – 7,500 in steps of 1 kW: 0.1 – 6,500.0 in steps of 0.1 kvar: 0.1 – 6,500.0 in steps of 0.1 kVA: 0.1 – 6,500.0 in steps of 0.1

kWh kvarh kVAh Power factor

±0.4% ±0.4% ±0.4%

1 kWh 1 kvarh 1 kVAh

0– 999,999.99 kVA 232 kWh 232 kvarh 232 kVAh

1%

0.01

±0.0 – 1.0

Frequency

0.02 Hz

0.01 Hz

20.00 – 70.00 Hz

kw demand kvar demand kva demand Amps demand

±0.4%

0.1 kw

±0.4%

0.1 kvar

±0.4%

0.1 kva

999,999.99 kw 999,999.99 kvar 999,999.99 kva

±0.2%

1A

0 – 7,500 A

Amps THD

±2.0%

0.1%

Volts THD

±2.0%

0.1%

0.0 – 100.0% 0.0 – 100.0%

Crest factor

±0.4%

—

1 – 9.99

AC CURRENT Conversion: True RMS, 64 samples/cycle CT input: 1 A and 5 A secondary Burden: 0.2 VA Overload: 20 x CT for 1 sec 100 x CT for 0.2 sec Full scale: 150% of CT Frequency: up to 32nd harmonic Accuracy: ±0.2% of full scale, true RMS AC VOLTAGE Conversion: True RMS, 64 samples/cycle VT pri/sec: Direct or 120 – 72,000 : 69 – 240 Input range: 20 – 600 VAC Full scale: 150/600 VAC autoscaled Burden: <0.1 VA Frequency: up to 32nd harmonic Accuracy: ±0.2% of full scale, true RMS SWITCH INPUTS Type: Dry contact Resistance: 1,000 ž max ON resistance Voltage: 24 VDC @ 2 mA Duration: 100 ms minimum ANALOG INPUT Range: 4 – 20 mA Accuracy: ±1% of full scale Relay output: Programmable 4 – 20 mA Internal burden resistance:250 ž PULSE INPUT Max inputs: 4 Min pulse width: 150 ms Min off time: 200 ms

COMMUNICATIONS COM1/COM2 type: RS485 2-wire, half duplex, isolated COM3 type: RS232, 9PIN Baud rate: 1,200 – 19,200 bps Protocol: ModBus® RTU and DNP 3.0 level 2 Functions: Read/write setpoints Read actual values Execute commands

POWER SUPPLY

METERING MEASURED VALUES PARAMETER

0.01 kVA

ACCURACY (% of full scale)

RESOLUTION

RANGE 20% of VT – 100% of VT 1% of CT – 150% of CT

Voltage

±0.2%

1 VOLT

Current

±0.2%

1A

Voltage unbalance Current unbalance

±1%

0.1%

0 – 100.0%

±1%

0.1%

0 – 100.0%

kW

±0.4%

0.01 kW

kvar

±0.4%

0.01 kvar

0– 999,999.99 kW 0– 999,999.99 kvar

CONTROL POWER Input: Power: Holdup:

90 – 300 VDC 70 – 265 VAC 50/60 Hz 10 VA nominal, 20 VA maximum 100 ms typical @ 120 VAC/VDC

ENVIRONMENTAL

OUTPUTS ANALOG OUTPUTS Accuracy: ±1% of full scale reading

OUTPUT 0 – 1 mA(T1 Option)4 – 20 mA (T20 Option) Max load 2400 Ω 600 Ω Max output 1.1 mA 21 mA Isolation:± 36 VDC isolated, active source OUTPUT RELAYS Voltage

Make/Carry Continuous

Make/ Carry 0.2 SEC

Break

30 VDC 120 Resistive VDC 250 VDC 30 VDC Inductive 120 (Vr = 7ms) VDC 250 VDC 120 VDC Resistive 250 VDC 120 VDC Inductive PF = 0.4 250 VDC Configuration Contact material

5

30

5

5

30

0.5

5

30

0.3

5

30

5

5

30

0.25

5

30

0.15

5

30

5

5

30

5

5

30

5

30

5

5

FORM C NO/NC SILVER ALLOY

PULSE OUTPUT Parameters: +ve kWh, –ve kWh, +ve kvarh, –ve kvarh, kVAh Interval: 1 – 65000 in steps of 1 Pulse width: 100 – 2000 ms in steps of 10 ms Min pulse interval:500 ms

TYPE TESTS Dielectric voltage withstand: Impulse voltage withstand: Insulation resistance: Damped Oscillatory: Electrostatic Discharge: RF immunity: Fast Transient Disturbance: Surge Immunity: Conducted RF Immunity: Radiated & Conducted Emissions: Sinusoidal Vibration: Shock & Bump: Power magnetic Immunity: Pulse Magnetic Immunity: Voltage Dip & interruption: Ingress Protection: Environmental(Cold): Environmental(Dry heat): Relative Humidity Cyclic: EFT:

Operating Temperature:

-10C to +60C

APPROVALS

Humidity:

operating up to 95% (non condensing) @ 55C

ISO:

Pollution Degree:

2

Ingress Protection:

IP40 (front), IP20 (back)

cULus e83849 NKCR/7: CE:

EN60255-5 EN60255-5 EN60255-5 IEC61000-4-18 / IEC60255-22-1 EN61000-4-2 / IEC60255-22-2 EN61000-4-3 / IEC60255-22-3 EN61000-4-4 / IEC60255-22-4 EN61000-4-5 / IEC60255-22-5 EN61000-4-6 / IEC60255-22-6 CISPR11 / CISPR22 / IEC60255-25

Digital Metering

Pickup level:

±0.4%

INPUTS

POWER FACTOR MONITORING Required voltage: 20 V applied Pickup level: 0.50 lag – 0.50 lead in steps of 0.01 Dropout level: 0.50 lag – 0.50 lead in steps of 0.01 Time delay: 0.5 – 600.0 in steps of 0.5 sec Timing accuracy: -0/+1 sec

Metered values Trace memory Harmonic spectrum

kVA

IEC60255-21-1 IEC60255-21-2 IEC61000-4-8 IEC61000-4-9 IEC61000-4-11 IEC60529 IEC60068-2-1 IEC60068-2-2 IEC60068-2-30 IEEE / ANSI C37.90.1

Manufactured to an ISO9001 registered program UL508, UL1053, C22.2.No 14 EN60255-5, EN61000-6-2

PACKAGING Shipping box: 8 1/2” L x 6” H x 6” D (215 mm x 152 mm x 152 mm) Ship weight: 5 lbs (2.3 kg) NOTE: LCD contrast impaired below -20° C

Please refer to the Multilin PQMII Power Quality Meter Instruction Manual for complete technical specifications

GEDigitalEnergy.com

575

PQM II Dimensions

A B

1.73" (44)

3.47" (88)

(6) - 0.218" Dia. HOLES (6.00) 7. 24" (184)

746750A1.dwg

Ordering PQM II * * * Description

PQM I I Basic unit with display, all current/voltage/power measurements, 1‑RS485 comm port, 1 RS232 comm port T20 Transducer option; 4 isolated analog outputs 0 – 20 mA and 4 – 20 mA, assignable to all measured parameters, 4 – 20 mA analog input,



T1 Transducer option; 4 isolated analog outputs 0 – 1 mA, assignable to all measured parameters, 4 – 20 mA analog input,

2nd RS485 comm port 2nd RS485 comm port

C Control option; 3 additional programmable output relays (total of 4), 4‑programmable switch inputs Power analysis option; harmonic analysis, triggered trace memory waveform capture, event record, data logger, voltage disturbance A recorder (VDR) Modifications:

Control Power:

MOD 501:

90 – 300 VDC/70 – 265 VAC standard 20 – 60 VDC/20 – 48 VAC (MOD 501)

MOD 504: MOD 525:

20 – 60 VDC/20 – 48 VAC control power Removable terminal blocks Harsh Environments Conformal Coating

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12821-(E) English 150217

Multilin™ EPM 6000 & 6010 High Accuracy Power & Energy Measurement

Monitoring & Metering

The Multilin EPM 6000 & 6010 Series are one of the industry’s highest performance revenue grade panel meters. The EPM 6000 offers a superior cost to performance ratio and significantly outperforms other metering products many times its price. These meters allow users to gather data on voltage, current, power and energy usage throughout a facility. With Ethernet communications and BACnet support (EPM 6010), these meters integrate seamlessly with new or existing LAN networks to provide vital date for energy management systems.

• True RMS multi-function measurements including voltage, current, power, frequency, and energy

Ideally suited for environmental initiatives, LEED certified projects and smart energy projects the EPM 6000 & 6010 provides the metrology and revenue testable energy accuracy required by these applications.

• Meets ANSI C12.20 (0.2%) and IEC 687 (0.2%) accuracy classes • Future field upgradable for added functionality without removing installed meter • Load percentage graphical bar for instant load visualization

Key Benefits

• Samples at 400+ times per cycle and has 24-bit A/D conversion

• High accuracy multi-function power meter for energy management systems

• Total Harmonic Distortion (%THD)

• Compact, easy-to-install, program, and use • 0.2% revenue class certifiable energy and demand metering • Flexible application fitting both ANSI and DIN cutout • Large 3 line 0.56” bright LED display for better visibility and longer life

Advanced Communications

• User programmable for different system voltages and current measurements

• Modbus TCP Protocol through 10/100BaseTX via RJ45 (Ethernet Option)

• Optional Ethernet port for simplified integration into new or existing LAN infrastructures and multipoint connectivity

• Front IrDA Port for laptop communications

• Rapid integration into BACnet management systems (EPM 6010 only)

• Pulse output for accuracy testing and energy

• Replaces multiple analog meters saving space and installation costs

• BACnet/IP 100BaseT Ethernet support (EPM 6010)

• Meter Enclosure option enabling customers to extend metering capabilities without costly downtime or engineering efforts

• 40 pre-defined BACnet objects facilitate rapid integration (EPM 6010)

Applications • Continuous metering of electrical loads such as generator panels and switchgear • Provides remote status when used with EnerVista suite of software • Low and medium voltage applications • LEED Projects & HVAC efficiency monitoring • Energy metering systems in building automation and building management systems

• Embedded web-server, allows BACnet/ IP interface to be remotely configured and BACnet objects can be remotely viewed via web browser (EPM 6010)

EPM 6000 & 6010 Power Meter

Dimensions and Mounting

User Interface - EPM 6000 Large .56” LEDs

Only 3.25”

Reading Type Designator Tx Rx Indicator LEDs

Screen Selectors

IRDA Port RS 485

Vh Pulse

Communication

% Load Bar

Digital Metering

Auto Scale Indicator

Current “Gills”

Universal Voltage Inputs

User Interface - EPM 6010 Only 3.25”

Large .56” LEDs Reading Type Designator Screen Selectors

KYZ Pulse Output

IRDA Port

10/100 BaseT via RJ45 Connector

Vh Pulse % Load Bar

Auto Scale Indicator

578

Current “Gills”

GEDigitalEnergy.com

Universal Voltage Inputs

EPM 6000 & 6010 Power Meter

Technical Specifications VOLTAGE INPUTS

POWER SUPPLY

PULSE OUTPUT

Universal Voltage Input • 0-416 Volts Line To Neutral, 0-721 Volts Line to Line • Input withstand capability – Meets IEEE C37.90.1 (surge withstand Capability) • Programmable voltage range to any PT ratio • Supports: 3 element WYE, 2.5 element WYE, 2 Element Delta, 4 Wire Delta Systems • Burden: 0.36VA per phase max at 600V, 0.014VA at 120 Volts • Input wire gauge max (AWG 12 / 2.5mm2 )

• Universal AC/DC Supply - 90 to 265 Volts AC and - 100 to 370 Volts DC. • Optional 24 to 48 Volts DC Supply. Burden: 10VA max

Front panel Wh infared test pulse Back panel Wh pulse output

CURRENT INPUTS • Class 10: 0 to 11 Amps Secondary / 5 Amps Nominal / 10Amps Max • Class 2: 0 to 2 Amps Secondary / 1 Amp Nominal / 2 Amps max • Fault Current Withstand: - 100 Amps for 10 Seconds - 300 Amps for 3 Seconds - 500 Amps for 1 Second • Programmable Current to Any CT Ratio • Burden 0.005VA per phase Max at 11Amps • 5mA Pickup Current • Frequency 50 Hz or 60 Hz+/- 3Hz above and below nominal range • Pass through wire gauge dimension: 0.177” / 4.5mm

COMMUNICATIONS • 2 Com Ports: IrDA and either RS485 or Ethernet • IrDA (Through Faceplate) - Protocol Modbus ASCII - Com Port Baud Rate: 56.7k - Address: 1 • RS485 Output (Back Plate) - Protocol Modbus RTU, Modbus ASCII or DNP 3.0 - Com Port Baud Rate: 9600 to 57.6K - Com Port Address: 0-247 - 8 Bit, No Parity • Ethernet (Back Panel) - 10/100BaseT via RJ45 connector - Protocol Modbus TCP BACnet OBJECTS Whr Net

Volts B-N

Total Whr

Volts C-N

Positive VARh

Volts A-B

Negative VARh

Volts B-C

Positive Watts, 3-Phase, Average Demand

ISOLATION

Volts C-A

Positive VARs, 3-Phase, Average Demand

• All Inputs and Outputs are galvanically isolated to 2500 Volts AC.

Amps A

Negative Watts, 3-Phase, Average Demand

Amps B

Negative VARs, 3-Phase, Average Demand

Amps C

Positive Watts, 3-Phase, Max Average Demand

Total Watts

Positive VARs, 3-Phase, Max Average Demand

Total VARs

Negative Watts, 3-Phase, Max Average Demand

UPDATE RATE

Total VA

• Watts, VAr and VA-100msec • All other parameters-1second

Negative VARs, 3-Phase, Max Average Demand

Total PF

VAs, 3-phase, Average Demand

Total VAh

VAs, 3-phase, Max Average Demand

Total VARh

Volts, A-N %THD

VARh Net

Volts, B-N %THD

Frequency

Volts, C-N %THD

Neutral Current

Amps, A %THD

Whr Received

Amps, B %THD

Whr Delivered

Amps, C %THD

SENSING METHOD • True RMS • Sampling at 400+ Samples per Cycle on all channels measured readings simultaneously • Harmonic % THD (% of total harmonic distoration

METERING ACCURACY Measured Parameters

Accuracy% of Reading

Display Range

Voltage L-N

0.1%

0-9999 Scalable V or kV

Voltage L-L

0.1%

0-9999 V or kV Scalable

Current

0.1%

0-9999 Amps or kAmps

+/- Watts

0.2%

0-9999 Watts, kWatts, MWatts

+/-Wh

0.2%

5 to 8 Digits Programmable

+/-VARs

0.2%

0-9999 VARs, kVARs, MVARs

+/-VARh

0.2%

5 to 8 Digits Programmable

VA

0.2%

0-9999 VA, kVA, MVA

VAh

0.2%

5 to 8 Digits Programmable

0.2%

+/- 0.5 to 1.0

0.01 Hz

45 to 65 Hz

PF Frequency %THD %Load Bar

5% 1-120%

Weight: 2 lbs Basic Unit: H4.85 x W4.82 x L4.25 Mounts in 92mm DIN and ANSI C39.1 Round Cutouts Shipping Container Dimensions: 6” cube ENVIRONMENTAL -20°C to +70°C Storage Operating -20°C to +70°C Humidity to 95% RH Non- Condensing Faceplate Rating NEMA 12 (Water Resistant) Mounting Gasket Included COMPLIANCE IEC 687 (0.2% Accuracy) ANSI C12.20 (0.2% Accuracy) ANSI (IEEE) C37.90.1 Surge Withstand ANSI C62.41 (Burst) IEC1000-4-2 – ESD IEC1000-4-3 – Radiated Immunity IEC 1000-4-4 – Fast Transient IEC 1000-4-5 – Surge Immunity APPROVALS ISO Manufactured to an ISO9001 registered program Listed under E200431 UL/cUL CE Conforms to European CE standards

Digital Metering

Volts A-N

DIMENSIONS & SHIPPING

There are 40 pre-defined BACnet Objects in the EPM 6010’s BACnet/IP protocol

0-200% 10 Digit Resolution Scalable

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579

Ordering PL 6000 *

*

*

*

*

Description



Standard unit with display, all current/voltage/power/frequency/energy counters measurement, % load bar, RS 485 and IRDA communication ports and one front test pulse output.

Hz 5 6 Amps 5A 1A Pulse 0 THD Power Supply LDC Communications S E

50 Hz AC frequency system 60 Hz AC frequency system 5 Amps 1 Amp No THD option THD, Limit Alarms 24 to 48 V DC power supply to substitute standard AC/DC power supply RS485 Communications Port (Modbus and DNP) Ethernet 10/100BaseT via RJ45 (Modbus TCP)

Example - PM 6000 for 60Hz system with 1 Amp secondary current with THD, Limit Alarms. PL600061ATHD EPM 6000 is available without a display as the EPM 6000T. Please see the online store for ordering information.

Ordering PL6010 Frequency

Current Inputs Software Power Supply

* 5 6

*

*

*

5A 1A THD HI LDC

Description 50Hz - BACnet/IP Communicating Multimeter 60Hz - BACnet/IP Communicating Multimeter 5 Amps 1 Amp THD, Limits Alarms & One KYZ Pulse Output AC/DC Power Supply (90-265)VAC or (100-370)VDC Low Voltage DC Power Supply (18-60)VDC

Example – EPM 6010 for 60Hz system with 5 Amp secondary and an AC/DC Power supply. PL601065ATHDHI EPM 6010 is available without a display as the EPM 6010T. Please see the online store for ordering information.

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Multilin™ EPM 2200 High Accuracy Power and Energy Measurement The Multilin EPM 2200 Power Meter measures more than forty electrical power parameters providing a low-cost, multifunction monitoring solution for industrial and power generation applications.

Monitoring & Metering

Compact in size, the EPM 2200 can be easily mounted in a panel for generator monitoring, substation automation, and industrial applications. This advanced power meter can also provide data to RTUs, PLCs and other control devices.

• Measures 3-phase, real-time aps and volts

Key Benefits • Economical meter for circuit monitoring of main feeders, branch circuits and gensets • Ultra compact, easy to install, program and use • Fits both ANSI and DIN cutouts • Highly visible, long life, large 3 line 0.56” bright LED display • Application flexibility with user programmability for different system voltages and current measurement requirements.

• 0.5% Accuracy • Future field upgradable for added functionality (communications option required) • Options support for Power, Energy, Frequency, and Power Factor measurements

Advanced Communications • 3 Line, 0.56” bright red LED display

• Optional Modbus communications to ease integration with new or existing networks

• Intuitive programming through front panel display

• Universal voltage and current inputs (up to 416V L-N) ensuring proper meter safety when wiring directly to high voltage systems.

• Optional RS485 Modbus communications (up to 57.6k Baud and Pulse output)

• Meter Enclosure option enabling customers to extend metering capabilities without costly downtime or engineering efforts

Applications • Monitoring & metering of electrical loads such as generator panels, feeders, and switchgear • Low and medium voltage applications

Meter Enclosure • Factor pre-wired, installation ready • Compact footprint for easy installation • Comprehensive factory testing of meter and enclosure • NEMA1 tested and UL/cUL certified

EPM 2200 Power Meter

Features

Software Option

The EPM 2200 meter measures more than 40 electrical power parameters providing a low-cost, multifunction monitoring solution for industrial and power generation applications. EPM 2200 can easily be mounted in a panel for generator monitoring, substation automation and more. The meter can also provide data to RTUs, PLCs and other control devices.

Metering The following electrical parameters are measured and displayed locally on the LED display and can be remotely accessed from the EPM 2200.

Universal Voltage and Current This meter allows voltage input measurements up to 416 Volts Line to Neutral and 721 volts Line to Line. This insures proper meter safety when wiring directly to high voltage systems. The unit will perform to specification on 69 Volt, 120 Volt, 230 Volt, 277 Volt and 347 Volt power systems.

Universal Voltage and Current Inputs

Digital Metering

The meter allows voltage inputs measurements up to 416 Volts Line to Neutral and 721 Volts Line to Line. This insures proper meter safety when wiring directly to high voltage systems. The unit will perform to specification on 69 Volt, 120 Volt, 230 Volt, 277 Volt and 347 Volt power systems.

A1 Voltage and Current

B1 The above plus: Power and Frequency

C1 The above plus: Energy

Max

Min

Voltage L-N

Measured Values

Real-Time •

Avg

•

•

Voltage L-L

•

•

•

Current Per Phase

•

•

•

•

Current Neutral

•

% of Load Bar

•

Voltage Angles

•

Current Angles

•

Watts

•

•

•

•

VAR

•

•

•

•

VA

•

•

•

•

PF

•

•

•

•

Frequency

•

•

•

+Watt-hr

•

-Watt-hr

•

Watt-hr Net

•

+VAR-hr

•

-VAR-hr

•

VAR-hr Net

•

VA-hr

•

Unique Current Input Connections

Communications

EPM 2200 meter uses two current input wiring methods.

Through an optional high speed Modbus communications interface, the meter can also provide data to RTUs, PLCs and other control devices at Baud rates ranging from 9600 baud to 57.6 kbaud.

• Method One - CT pass through. Directly pass the CT through the meter without any physical termination on the meter. This insures that the meter cannot be a point of failure on the CT circuit. This is preferable to utility users when sharing relay class CTs. No Burden is added to the secondary CT circuit. • Method Two - Current “Gills.” The meter additionally provides ultra-rugged termination pass through bars allowing the CT leads to be terminated on the meter. This also eliminates any possible point of failure at the meter. This method is also a preferred technique for ensuring relay class CT integrity does not get compromised. No terminal blocks are required and this stud based design ensures that CTs will not open under a fault condition.

Solid Construction with Mounting Versatility The EPM 2200 has a rugged design for harsh environment . This is especially important in power generation, utility substation, and critical user applications. The structural and electrical design of this meter was developed based on the recommendations and approvals of many of our utility customers.

Current Input Connections

Method One

Method Two Nickel Plated Brass Current “Gill”

Inherently Safe Design

582

CT wires pass through meter (dia. 0.77” / 4.5mm)

GEDigitalEnergy.com

CT wires terminate to meter

EPM 2200 Power Meter

EPM 2200 can easily be mounted in a panel for generator monitoring, substation automation and more. The unique dual design combines ANSI and DIN mounting structure and allows easy installation for both new metering applications and retrofit of existing analog meters. The unit mounts directly in an ANSI C39.1 (4” Round form) or an IEC 92 mm DIN square form.

Simple Installation and Programming EPM 2200 is intuitive so that a new user can easily program and set-up the meter. All wiring inputs are color coded with clear labeling to avoid cross wiring mistakes by installers. The meter has built in programmable auto scroll features to display multiple values without having to press keys.

RS485 COM Port and Pulse Counter

EPM2200 with RS485 and KYZ pulse output

Dimensions and Mounting

Digital Metering

GEDigitalEnergy.com

583

User Interface

Only 3.25”

Large .56” LEDs Reading Type Designator

Tx Rx Indicator LEDs Screen Selectors

RS 485 Communication

Vh Pulse % Load Bar

Universal Voltage Inputs

Current “Gills”

Auto Scale Indicator

Technical Specifications VOLTAGE INPUTS Universal Voltage Input • 0-416 Volts Line To Neutral, 0-721 Volts Line To Line • Input withstand capability – Meets IEEE C37.90.1 (surge withstand Capability) • Programmable voltage range to any PT ratio • Supports: 3 element WYE, 2.5 element WYE, 2 Element Delta, 4 Wire Delta Systems • Burden: 0.0144VA/Phase at 120 Volts • Input wire gauge max (AWG 12 / 2.5mm2 ) CURRENT INPUTS • Class 10: 5 Amps Nominal / 10Amps Max • Fault Current Withstand: 100 Amps for 10 Seconds 300 Amps for 3 Seconds 500 Amps for 1 Second. • Programmable Current to Any CT Ratio • Burden 0.005VA per phase Max at 11Amps • 5mA Pickup Current • Frequency 50 Hz or 60 Hz+/- 3Hz above and below nominal range • Pass through wire gauge dimension: 0.177” / 4.5mm ISOLATION • All Inputs and Outputs are galvanically isolated to 2500 Volts AC. SENSING METHOD • True RMS • Sampling at 400+ Samples per Cycle on all channels measured readings simultaneously

UPDATE RATE • All parameters up to 1 second

PULSE OUTPUT • Optional KYZ pulse on back plate

POWER SUPPLY • 90-265 VAC @50/60Hz • Consumption 5VA COMMUNICATIONS • Optional RS485 Communications Port - Through Backplate - Protocol Modbus RTU or ASCII - Com Port Baud Rate: 9600 to 57.6K - Com Port Addresses: 001-247 - 8 Bit, No Parity



ENVIRONMENTAL Storage: Operating: Humidity: Faceplate Rating:

METERING ACCURACY

Measured Accuracy% Parameters of Reading Display Range Voltage L-N 0.2% Voltage L-L 0.4% Current 0.2% +/- Watts 0.5% +/-Wh 0.5% +/-VARs 1.0% +/-VARh 1.0% VA 1.0% VAh 1.0% PF 1.0% Frequency +/- 0.01 Hz % Load +/- 1 segment

0-9999 V or kV 0-9999 V or kV 0-9999 Amps or kAmps 0-9999 Watts, kWatts, MWatts 5 to 8 Digits Programmable 0-9999 VARs, kVARs, MVARs 5 to 8 Digits Programmable 0-9999 VA, kVA, MVA 5 to 8 Digits Programmable +/- 0.5 - 1.0 45-65 Hz 10 Segment Scale

DIMENSIONS & SHIPPING • Weight: 2 lbs • Basic Unit: H4.85 x W4.82 x L4.25 • Mounts in 92mm DIN and ANSI C39.1 Round Cut-outs • Shipping Container Dimensions: 6” cube



-20° C to +70° C -10° C to +60° C to 95% RH Non-Condensing NEMA12 (Water Resistant) Mounting Gasket Included

COMPLIANCE • IEC 62053-22 (0.5% Accuracy) • ANSI C 12.20 (0.5% Accuracy) • ANSI (IEEE) C37.90.1 Surge Withstand • ANSI C62.41 (Burst) • IEC 1000-4-2: ESD • IEC 1000-4-3: Radiated Immunity • IEC 1000-4-4: Fast Transient • IEC 1000-4-5: Surge Immunity

APPROVALS ISO: Manufactured to an ISO9001 registered program UL: Recognized under UL USA (#E250818) cUL: Recognized under UL Canada CE: Conforms to European CE standards

Ordering PL 2200

*

*

Option A1 B1 C1 Communications X S

Description Volts and Amps Meter Volts, Amps, Power and Frequency Volts, Amps, Power, Frequency and Energy Counters None RS485 + Pulse

Example1: EPM 2200 support Voltage and Current measurement with no communications. PL2200A1X Example 2: EPM 2200 support Voltage, Current, Power, and Frequency measurement and Energy counters measurement with RS485 communication. PL2200C1S

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Multilin™ EPM 4600 Consolidated, Cost Effective, Multiple Point Metering

Energy Awareness

The Multilin EPM 4600 Multi-feed Power and Energy Meter is a submetering solution that allows owners and operators to quickly, accurately, and centrally measure power and energy usage of specific areas to reduce operating expenses.

• Multiple circuit capability identified usage of specific groups or processes

The EPM 4600 empowers users with greater energy awareness leading to improved tenant attraction and retention and greater overall energy efficiency throughout facilits.

• Advanced load profiling and logging with up to 2400 days (32 MB) of logged energy information

Key Benefits • Simple space and cost saving installation with the capability of measuring 8 – three phase or 24 – single phase inputs • Powerful Ethernet, Wi-Fi, RS485 and USB communications allowing easy installation in existing or new infrastrucure • Class 0.5% revenue grade accuracy measurements with comprehensive logging capabilities providing intelligent insight to bill individual sub-tenants for energy usage • 4 KYZ pulse counting inputs to aggregate energy information from other devices such as gas, water and steam meter sources and 2 relay outputs for control applications • Identification of departmental usage costs to specific groups or processes to reduce energy Inefficiencies and carbon footprint through end user awareness and ownership of energy savings • Support energy management initiatives such as peak demand reduction by identifying peak energy usage periods and initiating energy reduction control schemes at a detailed user level

Applications • Multi-feed Power & Energy metering in; Commercial Buildings, Institutions (i.e.: Universities / Colleges), Data Centers, Hospitals, LEED Projects, and Tenant Sub-metering • Industrial Circuit Cost Allocation • Load Management & Load Curtailment applications

• 0.5% Revenue grade accuracy per circuit

Space Saving Installation • Simple, space, and cost saving installation with capability of measuring 8 – three phase or 24 – single phase inputs • Powerful Ethernet, Wi-Fi, RS485 and USB communications capabilities allowing easy installation existing or new infrastructures & networks • User-friendly, optional touch screen, color display for remote viewing of metering information

Energy Management • Reduce Peak Demand by identifying Peak Periods and initiating Energy Reduction Control schemes • Provide accountable, detailed, metrics-based end user awareness to drive ownership of energy savings

EPM 4600 Power Meter

Wiring Diagrams 3

N N

2

LINE

LINE V3

V2

V1

VL N

1

1

N

CT Shorting Block EI# SB-6CT

CT Shorting Block EI# SB-6CT I1-LO

I1-LO

I1-HI

I1-HI

I2-LO

I2-LO

I2-HI

I2-HI

I3-LO

I3-LO

I3-HI

I3-HI

Earth Ground

Earth Ground Only three circuits are shown. Duplicate for additional circuits.

Only one 3 phase circuit is shown. Duplicate for additional circuits.

Earth Ground

Earth Ground

FUSES 3 x 0.1A

Short Voltage inputs together

FUSE 3A

V2 V1 N

VL

FUSE 3A

V3

N

L(+) N(-)

L(+) N(-)

Power Supply Connection

Power Supply Connection

LOAD

LOADS

Three Phase, 4-Wire WYE System with 3 CTs: EPM4600-T

Single Phase, 2-Wire Direct: EPM4600-S

One 3 Phase circuit shown. Multiply by up to 8 circuits. Note: All Voltages must be common per phase on each circuit.

3 Circuits are shown. Multiply by up to 24 circuits. Note: All Current must originate from a common Voltage source.

3 N

1

2

N

1

2 LINE V3

V2

V1

LINE N

CT Shorting Block EI# SB-6CT

V2

V1

N

CT Shorting Block EI# SB-6CT

I1-LO

I1-LO

I1-HI

I1-HI

I2-LO

I2-LO

I2-HI

I2-HI

I3-LO

Earth Ground

Earth Ground

Only one 3 phase circuit is shown. Duplicate for additional circuits.

Only one circuit is shown. Duplicate for additional circuits.

Earth Ground

Earth Ground

FUSES 3 x 0.1A

FUSES 2 x 0.1A

V3 V2

FUSE 3A

V2 V1 N

Earth Ground

V1 N

FUSE 3A

Digital Metering

I3-HI

L(+) N(-)

L(+) N(-)

Power Supply Connection

Power Supply Connection

LOAD

LOAD

Three Phase, 4-Wire WYE System with 3 PTs, 3CTs: EPM4600-T

Single Phase, 3-Wire Direct with 1 CT: EPM4600-S

One 3 Phase circuit shown. Multiply by up to 8 circuits. Note: All Voltages must be common per phase on each circuit.

1 Circuit is shown. Multiply by up to 24 circuits. Note: All Current must originate from a common Voltage source.

Note: The EPM 4600 Instruction Manual provides additional installation information and wiring diagrams.

586

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EPM 4600 Power Meter

0.19in 4.8mm 7.60in [193.1mm]

0.80in [20.4mm] 3.03in [76.9mm]

EPM 4600 Dimensions EPM 4600 Front Dimensions

EPM 4600 Side Dimensions

0.12in [2.9mm]

0.80in [20.4mm]

4.36in [110.6mm]

30 [1.18] 3.43 0.13

4.50in [114.3mm] centered

7.60in [193.1mm]

0.19in 4.8mm

3.03in [76.9mm]

7.62in [193.5mm]

0.28in [7.2mm]

6.7 [0.26] 10.98in [278.9mm] centered 11.28in [286.5mm]

0.81in [20.5mm]

3.18in [80.6mm]

Technical Specifications

22.1 0.87

TEMPERATURE RATING

SHIPPING

• Storage: (-20 to +70)°C / (-4 to +158)°F • Operating: (-20 to +60)°C / (-4 to +140)°F • Humidity: to 95% RH Non-Condensing

• 7.6(L) x 11.28(W) x 4.36(H) in/ 19.3(L) x 28.65(W) x 11.07(H) cm Weight: 7 lbs • Display Weight : 0.62 kg/1.36 lb. or less (main unit)

SENSING METHOD • RMS • Sampling at 400+ Samples per cycle on all channels Measured Readings Simultaneously UPDATE TIME

WIRING

• Every 60 Cycles

• Supports: 3 element Wye, Single Phase 2 and 3 Wire • Input wire gauge: AWG 12-26 (0.08-2.5)mm2

POWER SUPPLY

• All inputs to outputs are isolated to 2500 VAC

COMPLIANCE • UL Listing: UL61010-1, CAN/CSA C22.2 No. 61010-1, UL file number E250818 • IEC 62053-22 (0.5% Class) • ANSI C12.20 (0.5% Accuracy) • ANSI (IEEE) C37.90.1 Surge Withstand • ANSI C62.41 (Burst) • EN61000-6-2 Immunity for • Industrial environments: 2005 • EN61000-6-4 emission Standards for Industrial environments: 2007 • EN61326 EMC Requirements: 2006

9.5 [0.37] 17.2 [0.67]

ISOLATION

COMMUNICATION 17.5 RS485 (COM[0.69] 1 AND COM 3) • Baud Rate: 9,600 to 57,600 32.8 • Address: 001-247 [1.29] • 8 Bit, Even, Odd, No Parity • Modbus RTU, Modbus ASCII ETHERNET/WI-FI (OPTIONAL FOR COM 1) • RJ45 or 802.11b Wireless • 10/100BaseT Ethernet • Modbus TCP USB (COM 2) • Port Baud Rate:30.6 57,600 • Modbus ASCII [1.20]

98.1 [3.86]

CURRENT INPUTS 17.5 • Class 10: (0 to 10)A, 5A nominal, 10A Maximum [0.69] • Class 2: (0 to 2)A, 1A nominal, 2A Maximum 32.8 • Programmable Current to any CT Ratio [1.29] • Current Inputs Burden: 0.005VA Per Input • Max at 11A • Pickup Current: 0.1% of nominal -- Class 10: 5mA -- Class 2: 1mA • Continuous Current Withstand: 20A

• (90-300) Volts AC @50/60Hz or (150) Volts DC

METER ACCURACY • Voltage L-N 0.3% of reading @ (69 to 480)V • Voltage L-L 0.5% of reading @ (120 to 600)V • Current Phase: 0.3% of reading @ (0.15 to 5)A • W/Wh: 0.5% of reading @ (0.15 to 5)A @ (69 to 480)V @ +/- (0.5 to 1) lag/lead PF • VAR/VARh: 1.0% of reading @ (0.15 to 5)A @ (69 to 480)V @ +/- (0 to 0.8) lag/lead PF • VA/VAh/PF: 1.0% of reading @ (0.15 to 5)A @ (69 to 480)V @ +/- (0.5 to 1) lag/lead PF • Frequency: +/- 0.01Hz

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587

Digital Metering

• 0-576V Line to Neutral 163 • 0-721V Line to Line [6.41] • Universal Voltage Input 15.3 117.7 [0.60] • Input withstand capability: Meets IEEE [4.63] C37.90.1 (Surge Withstand Capability) • Programmable Voltage Range to any PT Ratio • Voltage Inputs Burden: -- 0.09Va/Phase Max at 600 Volts, -- 0.014Va at 120 Volts

88.4 [3.48] 129.4 [5.09]

VOLTAGE INPUTS

EPM 4600 3.5” Display Dimensions

EPM 4600 5.7” Display Dimensions

30 [1.18]

97.6 [3.84]

22.1 0.87

88.4 [3.48] 88.4 129.4 [3.48] [5.09] 129.4 [5.09]

22.1 0.87 22.1 0.87

72.6 72.6 [2.85] [2.85] 97.6 97.6 [3.84] [3.84]

163 [6.41] 117.7 [4.63]

55 [2.16]

55 [2.16] 55 [2.16]

0.22 0.86 0.22 0.86

0.22 0.86

31.5 [1.24]

163 163 [6.41] [6.41] 117.7117.7 [4.63] [4.63]

15.3 [0.60]

15.3 15.3 [0.60] [0.60]

15.3 15.3 16.2 16.2 15.3 16.2 [0.60] [0.60] [0.63] [0.63] [0.60] [0.63]

31.5 31.5 [1.24] [1.24]

10.98in [278.9mm] centered 11.28in [286.5mm]

72.6 [2.85]

88.4 [3.48] 129.4 [5.09]

3.43 3.43 3.43 30 30 0.13 0.13 0.13 [1.18] [1.18]

6.7 [0.26]

6.7 [0.26] 6.7 [0.26]

• Installation: Standardized 22mm circular cutout • QVGA (320x240) • 65K LED Backlight - 50,000 MBTF • UL, CE and RoHs Compliant • NEMA Type 4X (Indoor use) • Operating: 0 to +50°C • Power Consumption: 6.8W • 24 VDC Power Input

0.28in [7.2mm] 0.28in [7.2mm]

Display Dimensions

3.5” AND 5.7” DISPLAYS

4.50in

4.50in [114.3m centered 4.50in [114.3m centered

7.60in [193.1

7.60in [193.1 7.60in [193.1

3.18in [80.6mm]

4.36in [110.6mm]

0.81in [20.5mm]

3.18in [80.6mm] 3.18in [80.6mm]

4.36in [110.6mm] 4.36in [110.6mm]

0.81in [20.5mm] 0.81in [20.5mm]

Display Specifications

10.98i10.98i n n [278.9m [278.9m m] m] centered centered 11.28i11.28i n n [286.5m [286.5m m] m]

17.5 17.5 [0.69][0.69] 32.8 32.8 [1.29][1.29]

17.5 [0.69]

17.5 17.5 [0.69] [0.69]

17.5 [0.69]

32.8 32.8 [1.29][1.29]

32.8 [1.29]

Ordering EPM 4600 Unit

Three Phase

S

Single Phase

Frequency

*

*

*

*

Description

5

50 Hz AC Frequency System

6

60 Hz AC Frequency System

Current Inputs Software

10A

Up to 10A Current

02A

Up to 2A Current A

Transducer

B

Basic Logging-2MB Memory

C Communications

30.6 30.6 [1.20][1.20]

118 [4.64]

40.1 40.1 [1.57][1.57]

Advanced Logging-32MB Memory S

Serial (RS485) Modbus

W

WiFi, RJ45 100BaseT Ethernet

EPM 4600 Displays PL4600

*

Displays

DIS3500

3.5” Touch Screen Display with Installation Kit

DIS5700

5.7” Touch Screen Display with Installation Kit

9.5 [0.37]

9.5 9.5 [0.37][0.37]

118 118 [4.64][4.64]

Description

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30. [1.2

17.2 [0.67]

* T

98.1 [3.86] 98.1 17.2 [3.86] [0.67] 17.2 [0.67] 98.1 [3.86]

PL4600 Feed Configuration

40.1 [1.57

Multilin™ EPM 6100 & 7100 Energy and Demand Submeter with Data Logging and Wi-Fi

Monitoring & Metering

The EPM 7100 & 6100 Power Quality Meters are powerful tools that allow customers to monitor and manage their energy usage within factories, businesses, or across campuses. These meters are multi-function meters that feature ANSI C12.20 (0.2% class) accuracy and RS485, RJ45 Ethernet, or IEEE 802.11 WiFi Communication connections, making the meter easy to deplay in modern or older communications networks.

• Voltage: Va Vb Vc Vab Vbc Vca

The EPM7100 features extensive data logging and alarm recording capabilities, enabling advanced analysis and predictive maintenance of the power system.

Key Benefits • Flexible WiFi option eliminates the need for expensive wiring • 0.2% accurate revenue class meter provides highly reliable measurements • Extensive data logging and alarm recording allows for predictive maintenance and performance analysis (EPM 7100)

• Current: Ia Ib Ic In • Frequency: Hz W VAR VA • Reactive Power: Wh VARh Vah • Demand: W VAR VA • 2MB of Data Logging Capacity • Power Factor • Voltage and Current Angles • Bright Red LED Display with Three .56” Lines • % of Load Bar for Analog Meter Perception

Communications • Standard RS485 Modbus (Modbus RTU or ASCII)

• Multifunction capability allows for a variety of voltage, current, and energy metering measurements

• IrDA Port

• Direct interface with most building management systems reduces integration costs

• Optional Ethernet 10.100BaseT or WiFi

• Easy installation reduces setup time and costs

• Intuitive Faceplate Programming

• Energy monitoring to increase OEMs efficiency

Applications • Allocate energy usage throughout multi-tenant settings, such as industrial and university campuses, office towers, apartment complexes and shopping centers • Submetering in Government, military and airport facilities

EPM 7100 & 6100 Power Metering

Dimensions and Mounting 7.53” 191.26mm

3.70” 93.98mm

7.53” 191.26mm

3.70” 93.98mm

5.60” 142.24mm

MOUNTING PLATE

5.60” 142.24mm

MOUNTING PLATE

7.90” 200.66mm

7.90” 200.66mm

0.50” 12.72mm

7.90” 200.66mm

7.90” 200.66mm

0.50” 12.72mm 3.11” 78.99mm

5.95” 151.13mm

Antenna Length: 4.4” (111.8mm)

3.11” 78.99mm

5.95” 151.13mm

Antenna Length: 4.4” (111.8mm)

Front Cover Support Front Cover Support

Screw Screw

Opened Opened

Closed

Digital Metering

Closed

Screws Screws

Seal Housing Seal Housing

590

GEDigitalEnergy.com

EPM 7100 & 6100 Power Metering

User Interface

Wireless Antenna

Easy View LED Display WiFi Ethernet IrDA for Laptop PC Communication

RJ45 Ethernet/ Modbus TCP

High Accuracy Measurement Circuitry

KYZ Pulse

Voltage & Current Connections

% of Load Bar for Current Loading

RS485 Modbus

Technical Specifications ENVIRONMENTAL RATING

COMMUNICATION FORMAT

• 20-576 Volts Line to Neutral • 0-721 Volts Line to Line • Universal Voltage Input • Input Withstand Capability – Meets IEEE C37.90.1 (Surge Withstand Capability) • Programmable Voltage Range to Any PT Ratio • Supports: 3 Element WYE, 2.5 Element WYE, 2 Element Delta, 4 Wire Delta Systems • Burden: 0.36VA per Phase Max at 600V, 0.014VA at 120 Volts

• Storage: -20 to +70°C • Operating: -20 to +70°C • Humidity: to 95% RH (Non-condensing)

• RMS • Sampling at 400+ Samples per cycle on all channels measured readings simultaneously

• 2 Com Ports • RS485 Port • IrDA (Through Faceplate) • Protocol Modbus RTU, Modbus ASCII • Com Port Baud Rate: (9600 to 57,600) • Com Port Address: 0-247 • 8 Bit, No Parity • Modbus RTU or ASCII Protocols

UPDATE RATE

ETHERNET

• Watts, VAR and VA - Every 6 cycles (e.g., 100ms @ 60Hz) • All other parameters – Every 60 cycles (e.g., 1s @ 60Hz) (1 second for Current Only measurement, if reference voltage is not available)

• 802.11b Wireless • 10/100BaseT Ethernet (RJ45) • Modbus TCP Protocol

CURRENT INPUTS • Class 10: 5 Amp Nominal, 10 Amp Maximum • Class 2: 1 Amp Nominal, 2 Amp Secondary • Programmable Current to Any CT Ratio • Burden 0.005VA per Phase Max at 11Amps • 5mA Pickup Current for Class 10 • 1mA Pickup Current for Class 2 • Current Surge Withstand: 100A/10 Seconds at 23°C

SENSING METHOD

POWER SUPPLY • (90 to 400) Volts AC and (100 to 370) Volts DC. Universal AC/DC Supply • Burden: 16VA max.

Digital Metering

VOLTAGE INPUTS

DIMENSIONS AND SHIPPING • Weight: 4 lbs • 7.9H x 7.5W x 3.1D in 20.1H x 19.1W x 7.9D cm COMPLIANCE: • IEC 687 (0.2% Accuracy) • ANSI C12.20 (0.2% Accuracy) • ANSI (IEEE) C37.90.1 Surge Withstand • ANSI C62.41 – Burst • IEC1000-4-2 – ESD • IEC1000-4-3 – Radiated Immunity • IEC 1000-4-4 – Fast Transient • IEC 1000-4-5 – Surge Immunity • UL Listed on E250818

ISOLATION • All Inputs and Outputs are galvanically isolated to 2500 Volts AC

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Ordering PL6100

*

Frequency

5 6

Current Inputs

*

*

HI

PL7100

*

Frequency

5 6

*

*

Description

Standard Unit with display. All current/voltage/power/energy counters measurement, % load bar, RS485 and IrDA ports and one front test pulse output.

50 Hz AC Frequency System 60 Hz AC Frequency System 5 Amps 1 Amp No THD Option With THD and Limit Alarms

0 THD

Power Supply I/O Modules

Software Power Supply I/O Modules

*

5A 1A

Software

Current Inputs

*

*

S W

90-400 VAC / 100-370 VDC Serial Port Communication Wireless or LAN Based Ethernet

*

Description

S W

50 Hz AC Frequency System 60 Hz AC Frequency System 5 Amps 1 Amp Multifunction Meter with 2MB Data Logging 90-400 VAC / 100-370 VDC Serial Port Communication Wireless or LAN Based Ethernet

5A 1A B HI

Standard Unit with display. All current/voltage/power/energy counters measurement, % load bar, RS485 and IrDA ports and one front test pulse output. 2 MB of data logging memory.

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Device and Configuration Software Software Overview EnerVista is an industry-leading suite of software tools designed to simplify working with GE’s protection & control, substation automation, distribution automation, metering, and other field devices. Our modular suite of software tools significantly reduces effort and streamlines operations such as creating and validating settings files, integrating devices with automation systems, and monitoring and controlling devices to protect end assets.

Product Listing Product brochures for Multilin Device and Configuration Software.

Product Listing

Device and Configuration Software – Product Listing Launchpad

Device Setup & Document Management Toolset

595

Launchpad is the powerful toolset management engine for all of the support resources needed for GE Multilin products, including setup software, manuals and firmware files. The Launchpad subscription mechanism ensures that all of your necessary files are kept up-to-date and most importantly you only receive updates on the information you are interested in. The Enervista™ Setup tools provide a consistent look-and-feel for all GE Multilin devices, shortening the learning curve needed to be productive.

Viewpoint Engineer

Logic, IEC61850 System Configuration and Real-Time Monitoring

599

Viewpoint Engineer is the most advanced tool for protection & control engineers and commissioning staff available. Use the full-featured Graphical Logic Designer to build and annotate complex Flexlogic™ and then observe it in real-time with the Graphical Logic Monitor. Use the System Designer option to design and annotate IEC61850 communication schemes, including ICD file import and SCD file export for non-GE IEDs.

Viewpoint Maintenance Security Auditing, Device and Asset Health Reporting and Fault Data Retrieval

605

Comprehensive Security Report outlines changes to device settings, including the MAC address if the change was made via Ethernet for compliance with NERC Critical Infrastructure Protection standards. Device and Asset Status Reports detail current and historical health for both the IED and the asset being protected.

Viewpoint Monitoring

Easy-to-Use Monitoring and Data Recording

609

Viewpoint Monitoring provides simplified visualization of real-time data from all GE Multilin using ready-made Plugand-Play screens. Built-in data logger, alarm annunciator and time synchronization round out this HMI package. Third-party devices can be incorporated using either generic Modbus RTU or Modbus TCP/IP or IEC61850 and optional OPC/DDE server connectivity can link to existing facility DCS or SCADA systems.

Integrator

OPC Connectivity to Automation and Historian Applications

Software

Seamless integration of GE Multilin and generic Modbus devices into existing DCS, SCADA systems and other data consumer applications (data historians, data visualization tools) using standard open OPC/DDE connectivity.

594

GEDigitalEnergy.com

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EnerVista

Launchpad Device Setup, Document & Site Management Toolset

Key Features

The EnerVista™ Launchpad software is a powerful toolset used for the complete support and management of Multilin products. Support applications including product software, manuals, and setting files management used to ensure your important files are kept up-to-date and easily accessible. Site Management allows you to properly maintain your asset and devices by providing real-time diagnostic data and reports.

• Configure and access all your Multilin devices from a single application

Key Benefits • Provides a simple and intuitive method for configuring all Multilin devices • Ensures setup software, manuals and other support documentation is available to you and is always up to date • Supplies all the tools necessary for analyzing faults to get your equipment back up and running • Provides Asset and Device management capability at the click of a button

• Create and edit setting files offline or in real-time directly to your relays and meters • Manage all of your support documents in a single reference library • Provides an intuitive device health logic tool, which helps you to maximize your device capability. • Receive automatic firmware, software, and hardware upgrade notices. Keep informed with the latest innovation and technology on your device when you register your Multilin products. • Contains real-time metering, fault diagnostic and maintenance data for each connected device.

LaunchPad

Site Management

Software & Document Management

• Organize your protection devices with one interface

• Instantly identify, download, and install new versions of setup software when available with a single click

• Automated power system monitoring directly from Launchpad • A management toolset for all Multilin devices settings • Receive comprehensive Site and Device reports from Launchpad

• Directly install new setup software and support documents without having to navigate to the website

Device Management & Health Logic The device metering window provides system critical and diagnostics data such as Current, Voltages, and Event Records at your finger tips. The device health logic monitors defined setpoints and actual values, then returns results in a graphical, user friendly display. This tool will help you maintain the minimum required setting and assist you to maximize your relay capabilities. The 4 categories that are monitored are: Software

1. Device Security – This tool will prevent unauthorized access to your relay setpoint file. 2. Protection - This tool ensures your relay is configured with the minimum required protection settings. 3. Fault Diagnostics – This feature monitors the main diagnostics tool in your relay and indicates when they are configured. 4. Device Status - Ensures your protection relay is online and ready to protect your valuable assets.

Device Health logic

Device Metering Window

596

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LaunchPad

Easily Configure and Manage your Multilin Setting Files The setting file management tool comes standard with EnerVista Launchpad and provides a single platform to configure your Multilin protection device setting files. Additionally, you will have the ability to link related documents, such as specifications and equipment data sheets, to their respective protection device useful for day-to-day operation. • Retrieve your device setting files and organize them according to the asset being protected • Manage documents such as data sheets, and engineer white papers related to your protection device assets • Access and save setpoint files for your devices regardless if the device is offline or online

Site Reports Enervista Launchpad software can be used to generate comprehensive site reports for your install base and provide recommendations useful to determine upgrade and maintenance schedules for your assets and protection devices. With the click of a button, you can download critical data, which includes: • Hardware upgrades and replacement recommendations • Firmware upgrade recommendations, if applicable • Complete Installed based configured by age and device type

Device Setup Organize your installed base devices with a single user-friendly interface. Save precious time when establishing communications to your protection devices. Whether you have a small or large installed base, individual or networked connection, Device Setup will help you organize and manage your valuable assets: • Manage your asset by organizing your site and protection device configurations • Allows seamless communication with multiple devices

GEDigitalEnergy.com

Software

• Provides resources related to your protection scheme and individual protection device

597

A Complete Up-To-Date Reference Library EnerVista™ Launchpad will make sure that all necessary documents, setup programs and software tools are up-to-date by automatically retrieving them from our web site or Product CD, or by sending you an email whenever new information is available.

Manage all of your Support Documents in a Single Desktop Library Launchpad offers a complete library of document resources that is automatically updated and organized for you. The Document Library includes: • Manuals

• Drawings

• Application Notes

• Support Documents

• Service Bulletins

• FAQ’s

• Guideform Specifications

• Brochures

Launchpad’s subscription application will keep you up-to-date on the new product resources as soon as they are available. Launchpad will allow you to sign up to receive notification about new information by one of the following methods: • Alerting you whenever you open up EnerVista™ Launchpad • Emailing you about the new resource available • Automatically downloading new documents into Launchpad All critical information about Multilin products will be up to date and at your fingertips

Create Templates to Reduce Configuration Time The template creation tool included with EnerVista™ Launchpad will greatly reduce the amount of time required to configure relays that are performing similar functions. The example below demonstrates how the time required to configure 10 similar relays can be reduced by up to one third using Launchpad templates.

Traditional Device Configuration Method 4 Hours

+

2 Hours

+

Calculate Protection Settings

Create Relay Control Logic

1 Hour Enter Protection Settings

+

1 Hour Check Settings for Errors

+

2 Hours Compare Files for Discrepancies

= 10 Hours per Relay x 10 Relays

__________ = 100 Hours

Launchpad Template Configuration Method 4 Hours Once only Create Control Logic for all Relays

+

2 Hours Calculate Protection Settings

+

1 Hour Enter Protection Settings

4 Hours

+ 3 Hours per Relay x 10 Relays

__________ = 34 Hours

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EnerVista

Viewpoint Engineer System Configurator and Commissioning Toolset

Key Features

Viewpoint Engineer is a set of tools that will allow you manage, configure, and test your UR and URPlus relays at a system level in an easy to use graphical drag-and-drop environment. This software will streamline the steps required to configure devices, commission relays and manage the assets in your power system .

• Configure UR, URPlus and MM300 relays in an intuitive Graphical environment.

Key Benefits

• Evaluate the status of Flexlogic™ equations and Remote I/O messaging in real time

• Reduce the amount of time required to create complex logic schemes • Configure your IEC61850 devices at a system level using a single application • Program Remote I/O communications for multiple relays in an intuitive graphical interface • Simplify commissioning by identifying the status of the relay logic in real-time • Test protection relaying at a system or substation level rather than as an isolated device • Provides a means for managing all documentation about all assets in your substation • Decreases the number of support documents engineers require for commissioning and maintenance • Full online functionality including uploading and downloading of settings files, actual values and event record metering and monitoring, and firmware updates

• Program Remote I/O relay communication settings for multiple devices in one simple step

• Annotate UR, URPlus and MM300 settings and store this documentation in the setting file. • Link support documents to the System Designer Project to create a single location for substation asset management • Reduce integration time by automatically detecting and configuring your UR devices

EnerVista Viewpoint Engineer

System Designer Design Control Logic at a System or Substation Level The System Designer allows you to inter-connect the control logic distributed across multiple UR and URPlus devices by programming Remote I/O messages in an intuitive, graphical drag-&-drop environment.

System Level Settings Configuration • Design automation logic distributed across multiple UR and URPlus devices • Configure Remote I/O messaging in both the Sending and Receiving devices in one simple step • View “Virtual Wiring” communication diagrams in a manner that is similar to hard wiring schematics

Multiple Setting Files Created • Configure the settings for multiple UR and URPlus devices at one time • A separate setting file will be created for each UR device used in the System Logic Designer Configure Remote I/O communications for multiple relays in one easy drag-&-drop step

Connectivity Report The connectivity report provides a detailed report of all peer-to-peer mappings between the settings files associated with a project, including: • IEC61850 GSSE/GOOSE and UCA2 GOOSE messaging • Direct I/O configured between the UR relays. The report will be generated as a PDF for simple archiving and emailing. A sparate PDF report will be generated for each UR or URPlus device

Document System Level Setting Diagrams • Annotate Remote I/O System diagrams to describe Inter-Relay messaging for testing engineers

Software

• Documentation of Remote I/O System diagram stored in a project folder for permanent archiving

Viewpoint Engineer will create a separate setting file for each UR or URPlus device that is configured in the System Designer. These setting files will contain all communication settings needed for Remote I/O communications

600

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EnerVista Viewpoint Engineer

IEC61850 Configurator Import ICD and Generate SCD files using a single application The IEC61850 enables system level configuration of the communications between all IEC61850 devices.

Importing ICD Files • Import ICD files from any IEC61850 Compliant device • Create a library of ICD files, organized by device location, device type, or project • View file information in an easy to understand ICD viewer

Create SCD Files • Organize files by creating projects. Project files contain all subnet communication parameters as well as the associated device ICD files • Configure the communications between relays by having the IED’s subscribe to the appropriate transmission GOOSE messages • The saved project becomes the SCD file needed to generate the GOOSE reception settings files for the IED’s in the system

IED 1 Software

IED 2

SCD File

IED 3

IEC61850 Configurator

Settings Files

Device ICD Files

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EnerVista Viewpoint Engineer

Asset Manager Manage all Assets in Your Substation or Power System The Asset Manager will provide you with a tool to archive and manage critical information about any asset in your substation. All information in your power system can be stored in a Project Folder that can be shared between engineers and act as a single repository for any information required for your installed equipment.

Central Link to all Critical Information • Create a Project folder that will act as a single location to reference all information about equipment in a substation • Create an intuitive layout and navigation interface for your project by importing existing schematics or using the drawing tools provided • Link documents, drawings, or setting files for all substation equipment into the project for complete system asset management • Launch directly from the Asset Manager into the System Designer or Graphical Flexlogic™ Designer for programming your devices

Create a Project that will identify, document, and archive information about all assets in your substation (relays, breakers, t ransformers etc.)

Graphical Flexlogic™ Designer Design Flexlogic™ with Drag-&-Drop Ease Simplify the process of creating complex control logic for substation automation in your UR, URPlus, and MM300 relays to perform functions such as advanced tripping, reclosing, interlocking, and transfer schemes.

Simplified Control Logic Creation • Create FlexLogic™ with drag-and-drop ease

Software

• Connect outputs of Flexlogic™ equations directly to contact outputs and LEDs • Configure logic over multiple worksheets to keep logic structured and organized

Design and document relay control logic in an intuitive drag-and-drop interface

Documentation of Settings • Annotate control logic with documentation and graphics • Store all settings documentation directly in the relay’s setting files

Powerful Intuitive Complier MM300, Universal Relay, and URPlus

• Optimizes Flexlogic™ equations to use as few lines as necessary • Detects and alerts user of errors and problems in Flexlogic™ design

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EnerVista Viewpoint Engineer

Logic Analyzer Real-Time Feedback of Flexlogic™ Status When connected to your UR, URPlus, and MM300 relays, Viewpoint Engineer will provide real-time feedback of the status of the Flexlogic™ inputs, logic gates, timers, latches and outputs for every equation in the relay.

Simplified Troubleshooting • Follow the operation of your relay through each step of the Flexlogic™ equations • Detect problems in wiring or programming by viewing the status of all inputs in one screen • Determine which inputs are causing each logic gate to be asserted • Identify the logic that is causing the relay to not act as expected

Relay internal logic represented visually to simplify commissioning and troubleshooting

Real-Time Feedback of Peer-to-Peer Message Status Connecting Viewpoint Engineer to the local area network allows you to receive real-time feedback of the status of Remote I/O messages from both the relay sending the message and the relay receiving the Remote I/O message.

Simplified System Troubleshooting • Determine the status of all Remote I/O messages sent to other devices in the network • Verifies that Remote I/O signals are received and interpreted correctly by the intended devices • Reads settings from UR and URPlus devices on the network and automatically creates a Remote I/O System Diagram • Analyzes the settings in all UR and URPlus devices and verifies correct programming between sending and receiving devices

Analyze the status of Remote I/O messages from both the Sending and Receiving devices in Real- Time

Software

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Viewpoint Engineer Software Selection Guide

*

*

*

VPE Viewpoint Engineer for UR Relays VPE - UR Plus Viewpoint Engineer for UR Plus Relays VPE - MM300 Viewpoint Engineer for MM300 Relays

1 5 10 50

Single License 5 Pack 10 Pack 50 Pack

S

No System Designer System Designer Option/IEC61850 Configurator

G1

Additional 1 Year Updates

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EnerVista

Viewpoint Maintenance Troubleshooting and Reporting Tools

Key Features

Viewpoint Maintenance is a must-have tool for any integrators or electrical staff involved in power system protection and maintenance. This software increases the security of your relays, reports your device’s operating status and simplifies the steps to troubleshoot your device.

• Security Audit Trail tracks settings and configuration changes, who changed them, and the time and method of the change

Key Benefits

• Single button click to download and compile all fault diagnostics into a single zip file for easy sharing with engineers who can help assess system problems

• Reduce the time required to perform maintenance on your device • Increase the security of your relays by identifying relay settings that have been changed • Avoid costly downtime by reducing the time required to collect data for troubleshooting faults • Improve maintenance scheduling by prioritizing service needed for your power system equipment • Identify potential system problems before they become critical

• Retrieve critical system information that will help asses potential system faults • On-line and hard copy reports for easy viewing • Easily identify the file name of the settings file loaded on the relays • Support for the following GE Multilin IEDs: MM300, 350, 369, 469, 489, 745, 750/760, PQM II, B30, C30, C60, C70, C90 Plus, D30, D60, D90 Plus, F35, F60, G30, G60, L30, L60, L90, M60, N60, T35, T60*

* Consult the latest Viewpoint Maintenance release notes for a complete list of devices supported by this function.

EnerVista Viewpoint Maintenance

Security Audit Trail* The Security Audit Trail feature in Viewpoint Maintenance is the first of it’s kind, automatically tracking the details of settings changes to your relays along with the MAC address of the user who changed them. This traceability helps map out where a problem may have occurred and will help improve maintenance procedures to prevent them from happening again. This is also a valuable tool for ensuring the system configuration is the same as when it was commissioned.

Security Audit Trail Features: • Date and time of hardware, firmware or setting changes made to your relays

• Printer-friendly option to view hard copy reports

• Logging of the MAC address of computers making settings changes

• Ability to identify the name of settings files for accurate identification

Software

• Track method of how settings changes were made (i.e. keypad, serial port, Ethernet)

• Filter by date to identify changes to settings over time

Supported in the following GE IED devices: UR, UR Plus, 350, 369, 745

* Consult the latest Viewpoint Maintenance release notes for a complete list of devices supported by this function.

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EnerVista Viewpoint Maintenance

Device Status Reports* Reduce the time required to perform maintenance on your device by receiving a report that shows the health and operating status of your relays, meters, and the power system being monitored.

Status Reports Include: • Current operating condition of the GE Multilin device

• Operating history of the monitored devices

• Operating status of the equipment being protected

• Maintenance issues that need to be addressed

• Critical device settings that have not been programmed

• LED simulated view of equipment targets and alarms detected

Software

* Consult the latest Viewpoint Maintenance release notes for a complete list of devices supported by this function.

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Comprehensive Fault Diagnostics* Reduce time required to collect data for troubleshooting a fault with Viewpoint Maintenance. There is no need to access the setup program for the device or sift through settings to figure out what data is needed. With the click of a button, Viewpoint Maintenance will gather the required information including pertinent settings files, oscillography, events, fault reports, data logger and health reports and package it into a single zip file to allow for easy sharing with engineers to assist with your fault analysis.

Fault Diagnostics Features: • Effortlessly collect the data required to diagnose a fault • Automatically package all pertinent information into a .zip for easy file sharing • Eliminate costly hours of troubleshooting by filtering data at the click of a button

At the click of a button Viewpoint Maintenance will gather all required information including pertinent Settings Files, Oscillography, Events, Fault , Data Logger and Health Reports...

• Assess why and how the fault occurred to improve preemptive maintenance procedures • Avoid costly downtime and customer interruptions • Reduce the amount of time required to troubleshoot a fault to get your system back up and running

...Viewpoint Maintenance then automatically packages and compresses these files into a single .zip file...

...and stores the zipped file on your hard drive for easy emailing to your engineers or instantly emails to GE Tech support

Viewpoint Maintenance Software Selection Guide * VPM

*

1 5 10 50



EnerVista™ Viewpoint Maintenance Single License 5 Pack 10 Pack 50 Pack

G1

Additional 1 Year Updates

* Consult the latest Viewpoint Maintenance release notes for a complete list of devices supported by this function.

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EnerVista

Viewpoint Monitoring Easy to Use Monitoring and Data Recording

Key Features

EnerVista™ Viewpoint Monitoring is an easy to setup, powerful and simple to use data monitoring and recording software application for electrical systems.

• Monitor up to 1000 devices (20000 data points) or 5000 devices (65000 data points)

With minimal configuration required to communicate with field devices directly, Viewpoint Monitoring provides an overall view of the entire power system and collects critical real-time and historical disturbance data to assist with analyzing past or impending power system events.

Key Benefits • Easy start up and configuration saves time and cost by integrating devices using preprogrammed memory maps • Automatically generated, user friendly monitoring screens provide instant remote equipment visibility • Reduced integration time through automatic detection and configuration of UR devices • Reduced fault analysis effort by centralizing critical fault data digitally • Perform load analysis by recording and trending power equipment load levels • Remote viewing of Viewpoint Monitoring systems using ViewNodes

• User friendly drag-and-drop construction of single-line monitoring screens • Pre-configured memory maps of GE Multilin devices • Single-line monitoring and control • Trending of up to 500 power system data points with 1 minute resolution • Communicate with third-party Modbus compliant field devices • Plug-and-Play analysis of power system equipment • Automatic collection of events and waveforms from GE Multilin devices • Annunciator alarming with visual, audio and email notification • Diagnose waveform fault data recorded in power system devices

EnerVista Viewpoint Monitoring

Plug-and-Play Monitoring Instantly View Device and Asset Monitoring Screens EnerVista Viewpoint Monitoring’s Plug-and-Play screens are a series of pre-configured modules for analyzing the health and status of your power system equipment. Viewpoint Monitoring will detect the devices you are using and automatically generate monitoring screens that are tailored to your devices as well as wiring configurations. This saves hours of engineering effort and enables quick setup to monitor protection devices.

Auto-Discovery of Devices Viewpoint Monitoring reduces integration time and decreases errors when configuring devices by automatically detecting and configuring UR devices.

Viewpoint Monitoring Advantage Viewpoint Monitoring Reduces Commissioning Effort Saving Time and Cost The following is an example of connecting and communicating with a 469 Motor Protection Relay to monitor relay and motor data:

Equipment Overview

OVERVIEW

Trip Analysis

Power Metering

ALARMS

LEARNED

Operating condition of your motor

Active Alarms detected by the relay

Learned motor and RTD data

Status of your GE Multilin Relay

Latched Alarms that require clearing

Learned motor load

METERING

TRIP

MAINTENANCE

All metering quantities (Amps, Volts, Power, Demand)

Cause of the last motor trip

Trip counters and motor starts

Motor temperature monitored by the RTD’s

Pre-trip data

Total motor running hours

With other HMIs Software

1 Hour Select data points for use in your system

+

10 Hours

+

Type in all required mnemonics

1 Hour Scale the values

+

10 Hours

+

Test memory map to ensure loaded accurately

3 Minutes Type in IP address of your device

+

8 Hours Create your monitoring screens

= 33 Hours per Relay x 10 Relays

__________ = 330 Hours

With Viewpoint Monitoring 3 Minutes

Viewpoint Monitoring automatically creates memory maps and monitoring screens

Type in IP address of your device

610

= 3 Minutes per Relay x 10 Relays

__________ = 30 Minutes

GEDigitalEnergy.com

EnerVista Viewpoint Monitoring

Plug-and-Play Motor Monitoring Use Viewpoint Monitoring to Monitor Motor Protection Equipment Instantly created overview screens provide insight on motor operating conditions and the status of Multilin™ relays. There are additional available monitoring screens that show the value of all metering quantities, the motor temperature monitored by the RTDs and any alarms that have been detected by the relay. Vital information and insight such as the cause of the last motor trip, operating information the relay has learned about the motor and any maintenance issues that may need addressing can be determined using historical data shown on available screens. Instantly view critical information such as: • Number of motor starts • Learned motor starting current • Motor running hours • History of motor trips • Real time power quantities (amps, motor load) • Motor temperature

Supported Devices: M60 Motor Protection System 469 Motor Protection System 369 Motor Protection System 269 Motor Protection System 239 Motor Protection System

MM200/MM300

Motor Management System

MM2/MM3 Intelligent MCC Controller SPM Synchronous Motor Protection System

View motor status using digital inputs, analog inputs and RTD inputs.

RRTD Remote RTD Module

Plug-and-Play Transformer Monitoring Use Viewpoint Monitoring to Monitor Transformer Protection Equipment The operating condition of the transformer and the status of the GE Multilin relay are shown through instantly pre-created overview screens. Additional monitoring screens allow further analysis of transformer status by viewing the metering, power, demand, energy and harmonic data that is being measured by the associated relay. Instantly view critical information such as: • Transformer energization status Software

• Real time power quantities (amps, transformer loading, demand) • Current harmonic analysis • Accumulated loss of life • Tap changer position • Hottest transformer winding temperature

Supported Devices: T60 Transformer Protection System

745 Transformer Protection System

T35 Transformer Protection System Monitor total harmonic content in each phase for all windings.

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EnerVista Viewpoint Monitoring

Plug-and-Play Generator Monitoring Use Viewpoint Monitoring to Monitor Generator Protection Equipment Instantly created overview screens provide insight on generator operating conditions and the status of GE Multilin relays. Further generator analysis can be performed with additional monitoring screens that monitor the value of all metered quantities, the generator temperature monitored by RTD’s and any alarms that have been detected by the relay. Additional screens also provide historical information indicating cause of the last generator trip, operating information the relay has learned about the generator and any maintenance issues that may need addressing. Instantly view critical information such as: • Generator loading • Real time power quantities (amps, volts) • Cause of trip data • Generator running hours • History of generator trips • Generator temperature

Supported Devices: G60 Generator Protection System

489 Generator Protection System

G30 Generator Protection System

Improve maintenance efficiency by analyzing trip operations.

Plug-and-Play Feeder Monitoring Use Viewpoint Monitoring to Monitor Feeder Protection Equipment Instantly created overview screens provide insight on feeder operating conditions and the status of GE Multilin relays. Additional monitoring screens are available for analyzing all metering quantities, along with the power, demand and energy values that may be measured by the relay. If supported by the relay, synchronism screens will also be available for helping to determine if it is safe to close the breaker and energize the feeder. Instantly view critical information such as: • Breaker status • Accumulated breaker arcing current

Software

• Real time power quantities (amps, volts, demand, energy) • Synchronism data

Supported Devices: 850 Feeder Protection System

F650 Feeder Protection System

F60 Feeder Protection System

735/737 Feeder Protection System

F35 Multiple Feeder Protection System

MIFII Feeder Protection with Recloser

750/760 Feeder Protection System

350 Feeder Protection System

Easily monitor synchronism levels needed for reclosing of circuit breakers.

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GEDigitalEnergy.com

EnerVista Viewpoint Monitoring

Plug-and-Play Breaker Monitoring Use Viewpoint Monitoring to Monitor Breaker Equipment Predefined screens allow instant setup and viewing of critical breaker information such as: • Breaker status • Number of breaker trip operations • Real time current, voltage and power levels

Supported Devices: MVT MicroVersa Trip Unit

GTU EntelliGuard TU Trip Unit

EMVT

Entellisys Low-Voltage Switchgear

Enhanced Microversa Trip unit

Monitor breaker equipment with predefined screens.

Plug-and-Play Power Quality Monitoring Use Viewpoint Monitoring to Monitor Power Quality Equipment and Measure Usage Instantly view critical information such as: • Power quality and equipment status • Load unbalances using real time and maximum and minimum values • Consumption and cost of energy using inputs from revenue meters • Amount of total harmonic distortion on the power system

Supported Devices: PQM / PQM II

EPM 7000/7100

EPM 2000/2200

EPM 9450/9650

EPM 5200/5300/5350

EPM 9800

EPM 6000/6100

EPM 9900

Power Quality Meter Electronic Power Meter Electronic Power Meter Electronic Power Meter

Electronic Power Meter Electronic Power Meter Electronic Power Meter Electronic Power Meter

Instantly view the power quality status for critical devices.

Plug-and-Play Backup Power Monitoring Software

Use Viewpoint Monitoring to Monitor Critical Backup Assets Instantly view critical information such as: • Availability of normal and emergency power sources • Status of power source connections • Real time voltages and frequency • Switch status, timer settings and control switch position • Stored events and exerciser schedules

Supported Devices: MX150 Controller

MX350 Controller

MX200 Controller

Lan Pro UPS

MX250 Controller

SG-Series UPS Monitor the status of critical backup assets.

GEDigitalEnergy.com

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EnerVista Viewpoint Monitoring

Single-Line Monitoring and Control View the Power System Status on Customizable Single-Line Diagrams Viewpoint Monitoring provides the tools to easily create customized single-line diagrams providing monitoring and control. This powerful tool will communicate with supported devices and put the facility’s energy system at your fingertips from either a local or a remote location.

Easily Create Customized Single-Line Monitoring Screens • Create single-line diagrams using user-friendly, drag-and-drop tools with standardized symbols and components representing power system assets (transformers, breakers, CT’s and PT’s) • Import graphics to customize single-line diagrams and increase usability • Display power system values and status with minimal configuration through pre-loaded memory maps • Create customized or “virtual” monitoring points using the powerful Formula Editor

Easily create customized screens to monitor the power system state.

Monitor Power System Devices • Provide a system-wide view of the power system on one single-line monitoring screen • Analyze the magnitude of all critical power quantities measured by devices • Generate alarm warnings when measured values exceed configurable critical levels • Create links to multiple monitoring screens to analyze power system equipment with greater detail

Monitor the motors status and loading throughout the facility from a centralized location locally or remotely.

Software

Control Power System Equipment from Remote Locations • Send commands to devices to control and change the status of power system equipment (breakers, switches, isolators) • Enforces required two-step verification process to the operator sending the command • Validates user’s permissions by requiring passwords to be sent to protection relays or other devices before operation occurs

Monitor the status of the entire power system and control components from one screen.

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EnerVista Viewpoint Monitoring

Automatic Event and Waveform Retrieval Automated archiving of event and waveform data from GE Multilin devices ensures availability of detailed information for diagnosing power system events.

Event Logging The event records from GE Multilin devices can be automatically downloaded from each device and stored in a centralized, system-wide, sequence of event record. Viewpoint Monitoring will continually poll each GE Multilin device to see if any new events have been added to that device’s event record. Once a new event has been detected, the event record will be downloaded and the new events will be stored in the system-wide sequence of events record.

Waveform Archiving The waveform (oscillography) files from GE Multilin devices can be automatically downloaded from each device and stored on your hard drive. Similar to Event Logging, Viewpoint Monitoring will continually poll each GE Multilin device to see if any new waveform files have been created. Once a new waveform has been detected, the file will be downloaded by Viewpoint Monitoring to the centralized data repository.

Event Viewing The Event Viewer centrally stores and displays information about preset and configured systems events. Each event in the record contains the following information: Event Time Event Type Source Name Source Type Event Cause This data can be sorted by any of the fields indicated above. Create comprehensive, centralized, system-wide sequence of event records for analysis of power system faults.

Waveform Viewing View and analyze waveform fault data that has been recorded from a power system device in a time-based, phasor quantity or tabular view. This Waveform View utility provides functionality to: Convert waveforms that were stored in Comma Separated Value (.CSV) format to COMTRADE compatible files (e.g. SR Family, PQM) Merge and overlay waveforms that were recorded from multiple devices Identify the harmonic content in the monitored parameters

Software

View and analyze waveform fault data retrieved from devices.

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EnerVista Viewpoint Monitoring

Trending Reports Create a Historical Archive of Monitored Data from Multiple Devices

Historical Record of Monitored Data

Data Logging

Trend up to 5000 data points

• Log and trend the value of monitored analog or digital points

Record data with 1 minute resolution

• View logged data for a pre-configured, customized recorded time period

View data in time based graphical or tabular format

Records • Create up to 100 customized records • Store up to 50 points per record for 5000 points logged in total

Chart • View logged data in a pre-configured, customized date range for trending analysis

Archiving Data • Manually archive recorded data for storage onto network data repositories to reduce risk of data loss and decrease data storage requirements on local workstations

Exporting and Printing Data • Export data into an Excel format for easy data manipulation and analysis • Print data that is logged in trending reports in a printer-friendly format Log power level data from multiple devices at one time.

Third-Party Device Support Viewpoint Monitoring supports communication with third-party devices that use Modbus RTU or Modbus TCP/IP communications protocols. This flexibility allows the use and provides monitoring functionality for other non-GE Multilin devices that may be found in the facility. Viewpoint Monitoring provides support for third-party devices as follows:

Single-Line Diagrams • Read the status of digital point

Software

• Read the value of analog data • Send commands to control power system equipment

Annunciator Panel • Present an alarm when analog value surpasses a preset level or condition • Present an alarm when a digital point(s) change state

Trending Reports • Log the value of analog points over prolonged time periods • Log the status of digital points on a device

616

Easily integrate third-party devices into single-line diagrams, annunciator alarms, and trending reports.

GEDigitalEnergy.com

EnerVista Viewpoint Monitoring

Annunciator Alarming Receive Instant, Reliable Notification of System Alarms from Devices on the Network Viewpoint Monitoring Annunciator Alarming actively monitors measured values and generates alarms. Alarms can be configured to be activated whenever a digital status changes state, or an analog value changes beyond any programmed threshold. Alarms can be delivered through multiple visual, audio, or e-mail notification channels. Furthermore, the Monitoring and Alarm Sentry ensures annunciators and alarms are always active.

Audio Notification

Instant Alarm Notification

• Separate sounds for alert status and alarm status • Audio notification of alarms and alerts continue until the alarm state is acknowledged by an operator

Create alarms on any monitored analog or digital data point Receive alarm warnings through audio, visual or email notification

Visual Notification • Annunciator screen shows the status of the monitored point • The alarmed point will flash in a color chosen by the user until the alarm is reset by the operator

Email Notification • Alarming of any monitored point can automatically generate an email to notify users of the alarm • A different email address can be entered for each monitored point

Monitoring and Alarm Sentry • Ensures annunciators and alarms are always active, even when the annunciator screens or the Viewpoint Monitoring software is closed in error

Reliable, Instant Alarm Notification • Create alarms on monitored digital and/or analog data points • Configured alarm warnings delivered through audio, visual or email notification channels

Reliable, instant notification of system alarms in a single visual dashboard view.

EnerVista Viewpoint Monitoring ViewNodes – Remote Monitoring and Control Remotely monitor and control Viewpoint Monitoring using EnerVista Viewpoint Monitoring ViewNodes • Connect remotely to a Viewpoint Monitoring system over a network Software

• Implement security access and control by thorough user accounts with configurable permissions • Provide complete access to: - Plug-and-Play screens - One-Line diagrams - Annunciator panels / trending reports - Events - Waveforms • Connect up to 10 ViewNodes to a single Viewpoint Monitoring system

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EnerVista Viewpoint Monitoring

OPC Server Option Viewpoint Monitoring can send the data that is being read from the relays and meters to any third-party OPC compliant automation or monitoring system. With Viewpoint Monitoring’s pre-configured memory maps of GE Multilin devices the time, effort and cost required to import essential data into your monitoring, automation and control systems is significantly reduced. Integrate the data retrieved by Viewpoint Monitoring into a larger monitoring or automation system. • Send up to 65000 data points to an OPC Client • Supports the entire library of devices that comes with Viewpoint Monitoring • Provides the ability to send data from third-party devices added to the Viewpoint Monitoring database Integrate the data retrieved by Viewpoint Monitoring into a larger monitoring or automation system.

Technical Specifications System Requirements - EnerVista Viewpoint Monitoring v7.10 REQUIREMENT

Supported Operating Systems

• Windows 7 (SP1 or later) – 32 or 64 bit • Windows Server 2008 R2 (SP1 or later) - 64 bit

Supported Databases

• SQL Server 2012 • SQL Server 2012 Express

Computer and Processor

Recommended workstation: • Intel® Core™ 2 Duo CPU or higher • CD-ROM drive • Mouse (minimum two buttons) • Keyboard • Speakers (to support audible alarms)

Memory

2 GB of RAM (minimum)

Hard Disk

500 MB of free hard disk space for installation (additional space required for project configuration)

Display

17” monitor, minimum resolution 1280 x 1024, minimum 16-bit color

Connectivity

Ethernet (10BASE-T)

Other

N/A

Software

COMPONENT

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EnerVista Viewpoint Monitoring

Technical Specifications (Cont) Supported Devices DEVICE FAMILY

DEVICE

FIRMWARE

DEVICE FAMILY

DEVICE

FIRMWARE

ATS

MX150

5.4x, 6.0x

Generator

489

1.3x to 4.03x

MX250

5.4x, 6.0x

D30

3.0x to 7.2x

MX350

1.2x

D60

2.6x to 7.2x

UPS

UPS, UPS LP, UPS SG

1.0

D90Plus

1.8x

Trip Units/Switchgear

Spectra MicroVersa Trip

5.1x

L30

5.6x to 7.2x

Enhanced MicroVersa Trip C

4.1x

L60

2.6x to 7.2x

Enhanced MicroVersa Trip D

4.1x

Line Current Differential Protection

L90

2.6x to 7.2x

GTU (EntelliGuard TU Trip Unit)

7.0x

Transformer

745

2.4x to 5.2x

ELVS (Entellisys)

4.0x to v5.0x

T35

2.6x to 7.2x

MET

12.02.02

T60

2.6x to 7.2x

PQM

3.3x to 3.6x

345

1.3x to 1.5x

PQMII

1.0x to 2.2x

239

2.3x to 2.7x

EPM 1000

3.8x

269+

6.0x

EPM 2000

1.0x

339

1.3x to 1.5x

EPM 2200

1.0x

369

1.6x to 3.6x

EPM 4000

3.8x

469

2.5x to 5.2x

EPM 5000P

2.4x

MM200

1.0x to 1.2x

EPM 5200P

2.4x

MM300

1.2x to 1.5x

EPM 5300P

2.4x

MMII

4.0x to 5.2x

EPM 5350P

2.4x

MMIII

1.0x to 1.2x

EPM 6000

1.0x

RRTD

1.4x, 1.5x

EPM 6000T

1.0x

SPM

2.0x, 2.1x

EPM 6100

1.0x

M60

2.6x to 7.2x

EPM 7000

1.0x

Network

N60

3.4x to 7.2x

EPM 7000T

1.0x

Bus

B30

2.6x to 7.2x

EPM 7100

1.0x

B90

4.8x to 7.2x

EPM 9900

1.0x

C30

2.6x to 7.2x

EPM 9450Q

2.1x

C60

2.6x to 7.2x

EPM 9650Q

2.1x

C90Plus

1.6x to 1.8x

EPM 9800

6.1x

MRPO

1.0

ML 2400

3.0x

FIRETRACER

1.0

350

1.2x to 1.5x

VERSAMAX

1.0

F35

2.6x to 7.2x

F60

2.6x to 7.2x

F650

1.6x to 5.4x

MIF 2

4.0

735/737

1.5x

750/760

3.6x to 7.4x

850 Feeder

1.10x

G30

4.4x to 7.2x

G60

2.6x to 7.2x

Meters/Switches

Distribution Feeder

Motor

Specialized

Misc.

Software

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EnerVista Viewpoint Monitoring v7.10 Software Selection Guide EnerVista Viewpoint Monitoring VP Package

-

* * * * -

* -

* -

* Description

X

X

X

X

None

0

1

0

0

100 Devices / 5000 Points License, Version 7.10

0

3

0

0

300 Devices / 30000 Points License, Version 7.10

0

5

0

0

500 Devices / 65000 Points License, Version 7.10

1

0

0

0

1000 Devices / 20000 Points License, Version 7.10

U 1

0

3

Device/Point Upgrade 100 Devices / 5000 Points to 300 / 30000 Points, Version 7.10

U 1

0

5

Device/Point Upgrade 100 Devices / 5000 Points to 500 / 65000 Points, Version 7.10

U 1

1

0

Device/Point Upgrade 100 Devices / 5000 Points to 1000 / 20000 Points, Version 7.10

U 3

0

5

Device/Point Upgrade 300 Devices / 30000 Points to 500 / 65000 Points, Version 7.10

U 3

1

0

Device/Point Upgrade 300 Devices / 30000 Points to 1000 / 20000 Points, Version 7.10

U 5

1

0

Server Installation

Device/Point Upgrade 500 Devices / 65000 Points to 1000 / 20000 Points, Version 7.10 -

X

None

S

OPC

Windows Server Installation -

X

None

O

Version Upgrade

OPC Option -

X

None

U 1 Additional Year of Version Upgrades

EnerVista Viewpoint Monitoring ViewNodes VP ViewNodes

* * * * -

* -

* -

* Description

V

X

X

X

I

E

W -

-

-

EnerVista Viewpoint Monitoring Version 7.10 ViewNode

EnerVista Viewpoint Monitoring 61850* VP 61850 OPC

-

* * * * -

* -

I

X

6

1

8

-

* -

* Description VP Monitoring 61850 - 50 Devices

-

X

None

O

Version Upgrade

OPC Option -

X

None

U 1 Year Version Upgrades

*NOTE: - EnerVista Viewpoint Monitoring 61850 is a separate application from EnerVista VP Monitoring and provides support for 61850 protocol only. - OS Compatibility: Windows XP - 32 bit - Devices: Supports up to 50 devices; up to UR v5.5x. For complete details refer to EnerVista Viewpoint Monitoring 61850 release notes.

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12809(E) English 150121

EnerVista Integrator Comprehensive Communication Engine for Rapid Integration EnerVista™ Integrator enables seamless integration with GE’s MultilinTM devices for new or existing automation systems through tested, pre-configured memory maps. EnerVista Integrator reduces the setup and commissioning efforts required to obtain device, event and waveform data by over 90% for integration with an HMI, SCADA or DCS system.

Key Benefits

Key Features • Easy device setup through device communications • Rapid retrieval of device, event and waveform data from GE Multilin devices for communication to OPC clients • Comprehensive, factory tested memory maps for GE Multilin devices • Scalable communication options for high device or point counts - up to 1000 Devices or up to 65000 points respectively

• Reduces the effort and cost to integrate GE Multilin devices into new or existing HMI, SCADA or DCS systems

• Reliable aggregation of event records from multiple GE Multilin devices into a single system wide Sequence-of-Event (SOE) record

• Provides comprehensive, accurate and high quality, device, event and waveform data from devices • Archives and centralizes fault data from relays and meters for fault analysis • Supports integration of third-party (non-GE) Modbus devices into OPC compliant monitoring systems

EnerVista Integrator will efficiently link the information from GE Multlin and non-GE devices to monitoring, control and data collection systems

EnerVista Viewpoint Monitoring

Powerful Pre-Configured OPC Server EnerVista Integrator is designed to provide seamless integration of GE Multilin devices into any new or existing monitoring or control system. With tested, preconfigured memory maps for GE Multilin devices, EnerVista Integrator eliminates significant effort required for programming all of the mnemonics associated with HMI, SCADA and DCS system integration, significantly reducing the commissioning time and cost.

Pre-Configured Memory Maps and Intelligence EnerVista Integrator’s pre-configured and verified memory maps for most GE Multilin Devices, reduces commissioning effort by over 90% compared with traditional configuration methods:

With Other Communication Servers 1 Hour

+

10 Hours

Select system data points for use

+

Enter required mnemonics

2 Hour Scale the values

+

16 Hours Test memory map to ensure accuracy

+

1 Hour Connect to device

+

= 32 Hours per

2 Hours Verify retrieved values from device

Relay x 10 Devices

__________ = 320 Hours

With EnerVista Integrator 1 Hour Connect to device

EnerVista Integrator contains pre-configured memory maps and intelligence to automatically retrieve supported device values, events and waveforms

= 1 Hour per

Relay x 10 Devices

__________ = 10 Hours

Time/Commissioning Effort Savings Over 90% in Time/ Commission Effort Savings.

320 Hours - 10 Hours

__________ = 310 Hours

For a sample configuration of 10 Devices:

Communication Based Device Setup Configuring GE Multilin devices in EnerVista Integrator is achieved through establishing communication with the device.

Software

• Supports user-friendly, intuitive configuration of devices similar to EnerVista Viewpoint Monitoring and EnerVista Setup software • Provides configuration settings for both serial or Ethernet communications • Tests communications to ensure accurate device configuration

Third-Party Devices EnerVista Integrator supports third-party (non-GE) devices that utilize Modbus RTU or Modbus TCP/IP, providing a simple way to incorporate all devices into a monitoring and control system. • Supports addition of Modbus RTU or Modbus TCP/IP third-party devices • Provides direct configuration of Modbus mnemonics • Results in reduced integration time for multiple installations of EnerVista Integrator by importing and exporting mnemonics files

622

User-friendly, intuitive setup similar to Enervista ViewPoint Monitoring/Setup software to connect devices via OPC

GEDigitalEnergy.com

EnerVista Viewpoint Monitoring

Automatic Event and Waveform Retrieval

Event Viewing

Automated archiving of event and waveform data from GE Multilin devices ensures that there is always comprehensive data available for diagnosing power system events.

The Event Viewer centrally stores and displays information about preset and configured systems events. Each event in the record contains the following information:

Event Logging

Event Time

The event records from GE Multilin devices can be automatically downloaded from each device and stored in a system wide sequence of events record. EnerVista Integrator will continually poll each GE Multilin device to see if any new events have been added to that device’s event record. Once a new event has been detected, the event record will be downloaded from the device to the system wide sequence of events record.

Event Type Source Name Source Type Event Cause This data can be sorted by any of the fields indicated above.

Create a comprehensive, centralized, system wide sequence of event records for analysis of power system faults.

Waveform Archiving The waveform (oscillography) files from GE Multilin devices can be automatically downloaded from each device and stored in a central data repository using Integrator. Similar to Event Logging, EnerVista Integrator will continually poll each GE Multilin device to see if any new waveform files have been created. Once a new waveform has been detected by EnerVista Integrator, the file will be downloaded from the device to the centralized data repository.

Waveform Viewing View and analyze waveform fault data that has been recorded from a power system device in a time-based, phasor quantity or tabular view. This Waveform View utility provides functionality to: Convert waveforms that were stored in Comma Separated Value (.CSV) format to COMTRADE compatible files (e.g. SR Family, PQM) Software

Merge and overlay waveforms that were recorded from multiple devices Identify the harmonic content in the monitored parameters

View and analyze waveform fault data retrieved from devices.

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Technical Specifications System Requirements - EnerVista Integrator COMPONENT

REQUIREMENT

Supported Operating Systems

• Windows 7 (SP1 or later) – 32 or 64 bit • Windows Server 2008 R2 (SP1 or later) - 64 bit

Supported Databases

• SQL Server 2012 • SQL Server 2012 Express

Computer and Processor

Recommended workstation: • Intel® Core™ 2 Duo CPU or higher • CD-ROM drive • Mouse (minimum two buttons) • Keyboard • Speakers (to support audible alarms)

Memory

2 GB of RAM (minimum)

Hard Disk

500 MB of free hard disk space for installation (additional space required for project configuration)

Display

17” monitor, minimum resolution 1280 x 1024, minimum 16-bit color

Connectivity

Ethernet (10BASE-T)

Other

N/A

Please visit our website for a full list of Multilin devices supported by EnerVista Integrator www.GEDigitalEnergy.com/Intergrator

EnerVista Integrator Software Selection Guide EnerVista Integrator Licenses EVINT

*

License Option

0100

100 Devices/5000 Points License OPC Server with Event and Waveform Server

0300

300 Devices/30000 Points License OPC Server with Event and Waveform Server

0500

500 Devices/65000 Points License OPC Server with Event and Waveform Server

1000

1000 Devices/20000 Points License OPC Server with Event and Waveform Server

EnerVista Integrator Device/Point Count License Upgrades EVINT-UPG

*

Upgrade option

1-3

Upgrade from 100 Devices/5000 Points to 300 Devices/30000 Points

1-5

Upgrade from 100 Devices/5000 Points to 500 Devices/65000 Points

1-10

Upgrade from 100 Devices/5000 Points to 1000 Devices/20000 Points

3-5

Upgrade from 300 Devices/30000 Points to 500 Devices/65000 Points

3-10

Upgrade from 300 Devices/30000 Points to 1000 Devices/20000 Points

5-10

Upgrade from 500 Devices/65000 Points to 1000 Devices/20000 Points

DIGITAL TOOLS THAT SIMPLIFY THE PRODUCT LIFECYCLE - Online OR ON iPad. GET YOUR GRID PASSPORT AT

Passport.GEDigitalEnergy.com GEA-12712C(E) English 150121

EnerVista PowerLink Advantage Powerful and Scalable SCADA HMI Platform

Key Features

Comprehensive view and control of the substation to increase operator efficiency

• User-friendly, full-featured graphics editor with extended graphics functionality, including support for image importing to create customized displays

PowerLink Advantage (PLA) from GE Digital Energy is a Human Machine Interface (HMI) solution for high point count requirements providing an up-to-date, live view of the substation in near real-time. The system is designed to perform “Master” functionality to one or more field devices and provides a means to remotely control and obtain data from them. As a local substation HMI, PC-based Small Master Station, PLA aggregates and intelligently presents relevant real-time and historical data in easy to understand, customizable graphical format with features such as alarm and dynamic text displays to increase operator efficiency. PLA has optional features such as Power Quality and Digital Fault Recording capabilities that can be added to further extend system awareness and provide indispensable information for in-depth analysis and informed decision making. Furthermore, PowerLink Advantage provides additional language support for French, Russian and Spanish user interfaces through available language packs.

Key Benefits • Fast, easy configuration and powerful tools decrease setup and configuration effort • Centralized monitoring, SCADA control and data collection for greater resource efficiency and fault analysis • Highly scalable system implementation capabilities with real-time data acquisition and control • Full integration of data into the utility enterprise, including plant archives and advanced data handling capabilities and analysis • Centralized onsite and remote access/viewing capabilities • User interface presentation in multiple languages

• PowerLink Advantage Configuration Toolkit (PACT) provides an intuitive and intelligent environment to easily create and configure database points and devices • Enhanced security options and configurable user and group role-based security • Advanced data handling capabilities and analysis via SQL Server® 2008 R2 and the GE CIMPLICITY v8.1 HMI engine • Comprehensive alarm management offering superior filtering, sorting, stacking and organizing • Flexible, wide array of trend displays, including XY plots • Support for industry standard DNP3 protocol over communications such as serial, TCP/IP, UDP/IP • Communications channel redundancy

EnerVista PowerLink Advantage

Features Comprehensive, Customizable Displays PLA aggregates information from gateways and field devices and intelligently presents relevant near real-time and historical data in an easy to understand, customizable graphical format with features such as alarm and dynamic text displays to increase operator efficiency. Typical customizable displays include: • Communications Summary • One-line Diagrams • Alarm Viewer • Historical Alarm Viewer • Trending • Detail Pages • Operator Access Log • Operator Notes

One-line screens for monitoring status, control and tagging

PLA provides a complete, scalable, feature rich, secure solution to optimize resource efficiency and ensure reliability

Single Computer PowerLink Advantage Architecture

Control Center

PowerLink Advantage (HMI) Server/Viewer

Modem

Ethernet Switch

Software

Ethernet LAN

Serial Connection

Substation RTU/ Gateway Third Party Devices

Protection Relay

Protection Relay

Serial Connection

Protection Relay

PLA integrates devices in the substation providing a complete, centralized view

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Power Quality Meters

EnerVista PowerLink Advantage

Powerful and Scalable Functionality PLA provides a wide array of powerful and scalable SCADA and operational functionality to operate and maintain substations at peak reliability and efficiency. SCADA: • Full SCADA functionality • Real-time data acquisition and control with per-point quality and status flags Operations: • Interlocking • Point tagging and forcing • Time synchronization for field devices • Operator notes • Diagnostic Tools for serial and Ethernet communications • Multi-Monitor support Full SCADA functionality with real-time data acquisition and control

Redundant PowerLink Advantage Architecture PLA Operator Workstation (Run-time Viewer - Dual Monitor)

PLA Operator Workstation (Run-time Viewer - Dual Monitor)

PLA Engineering Workstation (Development Viewer)

Rack KVM

Control Center

Maintenance Laptop KVM Switch

PLA Development Server (Primary)

Ethernet LAN - A

Ethernet Switch (LAN-A)

PLA Runtime Server (Standby)

Router/ Firewall

Ethernet Switch (LAN-B)

Ethernet LAN - B

Software

Substation RTU/ Gateway Third Party Devices

Bay/Automation Controller

Fast Load Shed Controller

Protection Relays

Protection Relays

Power Quality Meters

Protection Relay

Power Quality Meters

PLA server redundancy to ensure continuous uptime

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EnerVista PowerLink Advantage

Configuration PLA provides a user-friendly, full-featured graphics editor to easily create customizable displays and a database configuration tool Powerlink Advantage Configuration Toolkit (PACT) to reduce setup and configuration time. The user-friendly, online graphics editor contains extended graphics functionality, including support for image importing to create customized displays.

• Windows graphic editor • Windows spreadsheet styles • Smart Objects (animated) library • On-line screen configuration • User Built Displays with animated pre-defined PLA library or user custom created symbols The PowerLink Advantage Configuration Toolkit (PACT) provides an intuitive and intelligent environment to easily create and configure database points and devices.

Create screens quickly using preconfigured objects in the online graphics editor

Easy creation and comprehensive configuration of devices and database points PACT

Alarm Management

Software

Identifying and addressing exception conditions with the system is a key Operator responsibility. PLA provides a multitude of alarm notification and management functionality to increase operator awareness, decrease response time and improve system reliability. • Visual and audible notification • Historical logging • Millisecond resolution time stamping • Group, area and priority categories • Advanced filtering with primary, secondary, tertiary and quaternary sort keys • Stacking • Comments • Graphic links Active alarm viewer to increase operator awareness, decrease response time and improve system reliability

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EnerVista PowerLink Advantage

Trending PLA provides aggregates trending data from substation devices and presents them in a clear visual format that is fully customizable to facilitate quick identification of potential issues or to assist in problem analysis. • Customizable with selectable colors, gridlines and scaling • Real-time and historical displays • Dynamic trending • XY plots • Full database connectivity • Support up to 300 logged points per logging table

Dynamic trending to clearly visualize substation activity

Security PLA provides enhanced security options and configurable user and group role-based security. The security configuration allows access and operational permissions to be set for individual users and for user groups. Furthermore, PLA has an operator access log to trace operators access and aid in security reporting.

Customizable security access and operational permissions settings for individual users and for user groups

Communications

Software

PLA supports industry standard communications using DNP3 protocol over Ethernet and serial TCP/IP, UDP/IP. Furthermore, PLA also provides advanced communications and timestamp functionality. • Polling and/or unsolicited messaging • Communications channel redundancy • Multiple channels per device with auto-failover • Support for dual communication links • Support device UTC timestamp • Support for automatically checking the status of each alternate communications channel at a configurable frequency

Monitor communications status with substation devices

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EnerVista PowerLink Advantage

Optional Features

GE Automation Projects

Redundancy

Complete Solution for Complex Substation Automation Systems

Redundancy ensures system availability in the event of a hardware failure. PowerLink Advantage can be configured with redundancy so that a secondary system is ready to take over operations automatically should the primary system fail. During a failure, all main PowerLink Advantage functions are transferred to ensure that critical data acquisition, alarming, logging and security operations continue.

GE Automation Projects delivers a complete solution for utilities and Industrial customers to address challenges in managing all aspects of increasingly complex substation automation systems:

• Protection, Control and Automation • Communications

Multiple Viewer Stations

• Cyber / Physical Security

Multiple Viewer Stations provide client-server connectivity from additional computers on the LAN.

• Data Management

Remote Desktop (Terminal Services)

• Standards-based Solutions

Remote Desktop (Terminal Services) licenses provide access from remote computers (requires Windows® Server operating system).

In today’s enterprise there are many publishers and subscribers of data. While all the requirements of a traditional substation automation system project are relatively unchanged with respect to solid power engineering practices for protection control and automation, there are many new requirements being introduced to the integration of systems and devices at the substation level, and the need to achieve interoperability and integration many enterprise applications for the purposes of security, data warehousing, and compatibility with international standards such as IEC 61850.

System Sentry System Sentry improves system availability by constantly providing realtime information about the health of the PowerLink Advantage system. It provides detailed performance data at any given moment for every resource ranging from available hard drive space to CPU usage. System Sentry also provides configurable, automated alerts for problem conditions and the tools for problem determination to restore system functionality.

Digital Fault Recording Display and Analysis Digital Fault Recording Display and Analysis is a tool within DirectView providing advanced waveform viewing through capabilities to set multiple cursors and markers; waveform superimposition and waveform comparison functions. It also provides functionality to visualize harmonic spectrum and perform zero sequence current calculations. IEEE® COMTRADE file compatible.

• Enterprise System Operations

Comprehensive Solutions and Services Offerings GE delivers a complete modern substation automation solution based with deep knowledge and expertise in best in class products; configuration tools, and industry standards with the following offerings: Automation Projects – Managed Solutions The GE Automation Projects team provides complete end-to-end system solutions including Hardware, Software and Resources from initial evaluation to ongoing Maintenance and Support. Automation Projects – Technical Services

Alarm Cast Alarm Cast provides integration of PowerLink Advantage alarms for remote notification through a variety of channels such as internet, mobile and PC media including pagers, SMS, email, ODBC, UCP and more. The notification can contain key operational information and conditions.

From initial Site Evaluation to ongoing maintenance of the system, the GE Automation projects team provides services for the complete lifecycle of a solution. • Site Evaluation • Consultation

Reporting Software

• Substation Engineering

PLA makes it easy to generate the reports based on a timed or event basis. The report viewer allows quick, convenient access to any report.

• System Design • Project Management • Procurement

Power Quality Event Viewer

• System component assembly

Power Quality Event Viewer provides sag, swell and interruption plots.

• Configuration and Commissioning Services

DirectView

• System Testing

DirectView provides a Digital Fault Recording (DFR) COMTRADE file viewer and analysis application. DFR COMTRADE files are automatically retrieved from compatible field devices connected via Ethernet LAN.

630

• Training • Lifecycle Support of System

GEDigitalEnergy.com

EnerVista PowerLink Advantage

System Requirements – Development/Runtime Server COMPONENT

REQUIREMENT

Supported Operating Systems

• Windows® XP Pro SP3 – 32 bit • Windows® Server 2008 SP2 – 32 bit • Windows® 7 -32 bit

Computer and Processor

Minimum: • Pentium® IV 3 GHz processor or higher • DVD-ROM drive • Mouse (minimum two buttons) • Keyboard • Speakers (to support audible alarms)

Recommended (Server): • Processor: Quad-core Intel® Xeon® processor E3-1200 product family or Dual-core Intel® Core™ processor i3-2100 product family • 8 GB Memory • 500 GB 7.2K RPM SATA 3.5” Hot Plug Hard Drive • RAID Controller, RAID 1, 2 HD • Network Adapter: Intel PRO 1000PT 1GbE Single Port NIC, PCI (for single LAN), Intel PRO 1000PT 1GbE Dual Port NIC, PCI (for Dual LAN) • USB Keyboard and Optical Mouse

Memory

2 GB of RAM (minimum), 8 GB (recommended)

Hard Disk

4 GB of free hard disk space for installation (additional space required for project configuration)

Display

Minimum 17” monitor, with 1280 x 1024 resolution, 16-bit color

Connectivity

Ethernet (10/100/1000BASE-T) Single Port (for single LAN), Dual Port (for Dual LAN)

Other

N/A

Software

GEDigitalEnergy.com

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System Requirements – PLA Viewer COMPONENT

REQUIREMENT

Supported Operating Systems

• Windows® XP Pro SP3 – 32 bit • Windows® Server 2008 SP2 – 32 bit • Windows® 7 -32 bit

Computer and Processor

Minimum: • Pentium® IV 3 GHz processor or higher • DVD-ROM drive • Mouse (minimum two buttons) • Keyboard • Speakers (to support audible alarms)

Recommended: • Processor: Intel® Core™2 Quad; Intel® Core™2 Duo; Intel® Pentium® Dual Core; Intel® Celeron® Dual Core; Intel® Celeron® • 4 GB Memory • 500 GB 7.2K RPM SATA 3.5” Hard Drive • Network Adapter: Ethernet 10/100/1000 Single Port (for single LAN), Dual Port (for Dual LAN) • USB Keyboard and Optical Mouse

Memory

2 GB of RAM (minimum), 8 GB (recommended)

Hard Disk

4 GB of free hard disk space for installation (additional space required for project configuration)

Display

Minimum 17” monitor, with 1280 x 1024 resolution, 16-bit color

Connectivity

Ethernet (10/100/1000BASE-T) Single Port (for single LAN), Dual Port (for Dual LAN)

Other

N/A

North America/Worldwide

Europe/Middle East/Africa

Asia

215 Anderson Ave. Markham, ON, Canada L6E 1B3 Toll Free (NA Only): 1-800-547-8629 Tel: 905-294-6222 Fax: 905-201-2098 email: [email protected]

Avenida Pinoa 10-48170 Zamudio (Vizcaya), Spain Tel: +34 94 485 88 00 Fax: +34 94 485 88 45 email: [email protected]

Floor22-24, No 900 Yishan Rd. Scientific Building C Shanghai, 200233, China Tel: +86-21-2401-3208 Fax: +86-21-5423-5080

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CyberSentry™ SEM Security Event Manager

Practical Interface

GE’s CyberSentry SEM Security Event Manager is an integrated cyber security management and monitoring software for protection, automation and control devices. CyberSentry SEM is specifically designed to help utilities and energy intensive industrial companies manage security risks.

• Functional tabbed structure saves users time searching for options

Standing guard 24/7, CyberSentry SEM monitors for configuration changes and cyber security issues. CyberSentry SEM also monitors and reports cyber security issues of grid automation and communications devices and to help utilities prove their compliance to North American Electric Reliability Corporation (NERC) standards. 

Key Benefits • Manages cyber security in protective relaying and automation systems with a straightforward, yet powerful set of software tools designed specifically for power systems and grid automation experts. • Simplifies security reporting for NERC CIP audits with easy-to-use templates and workflows that document all activity, to ensure a safe and secure system. • Modernizes security logs from aging relays and other grid automation electronics, translating events into industry standard syslog format and interfacing to the latest cyber security systems to avoiding costly and premature upgrades. • Shields against human errors during routine protection testing and maintenance, by raising alarms when changes to relay configurations occur, preventing costly outages. • Alerts system owners to unwanted changes in devices that could occur as the result of an insider or external cyber attack.

Applications • Transmission and generation utilities covered by NERC CIP cyber security compliance regulations

• Simple annunciator-style security dashboard shows alarm states for prompt response from systems experts

Customizable Logging • Syslog security event streaming for enterprise Security Information and Event Management (SIEM) integration • Choice of activities to log for complete control

Intelligent Monitoring • Multiple classes of security event notices to quickly distinguish type of risk • Simple definition of approved operations • Predefined security event detection for common security and compliance program requirements

Alarm Activation

• Industrial power producers and users with mission critical cyber assets

• Email notification for quick action and containment

• Independent power producers with digital relays, grid automation devices, switches and communications infrastructure

• Assignment of workflows for quick action to resolve issues

• Municipal and co-op utilities managing power systems of all sizes

• Process tracking from open to close of incidents for NERC CIP audit requirements

Audit Reporting • Generate reports based on event type, security parameter category and open/closed status • Selectable inclusion of action detail and history for more complete reports

Device and Configuration Software

CyberSentry SEM

Overview

Define Legitimate Operations Through ACPs

Power and control systems experts need reliable tools to provide notification of cyber security issues. CyberSentry SEM guards assets by tracking authorized activities and logging them to fulfill audit requirements. Using industry standard syslog technology, CyberSentry SEM also modernizes security logs from aging relays and other grid automation devices, to fit into the latest cyber security system, avoiding costly and premature upgrades.

Authorized Configuration Profiles (ACPs) let users define “normal” operations and configuration changes, to monitored cyber assets, within approved variances. ACPs allow users to perform everyday functions as they require, without triggering nuisance alarms for expected operations. When CyberSentry SEM detects a change that is not allowed within an ACP, it alerts the responsible parties that there has been some irregular behavior in the system. Irregular behaviour can be a strong indicator of a cyber attack and should be examined and corrected as part of a cyber security risk mitigation program.

NERC CIP Compliance Clearly defined processes, that deal with any and all events indicating a cyber security breach, establish confidence that devices are secured. Official reports which detail actions taken, should provide evidence that efforts have been made to reduce, prevent and contain security events. CyberSentry SEM provides a simple and powerful solution for managing and documenting cyber security events and actions. It delivers a system for ensuring that key equipment connected to the power grid is being effectively monitored, which is fundamental in any critical infrastructure protection and security program.

Secure Configuration Management

User-Friendly Security Dashboard

Simplified Reporting

Designed specifically for power systems and grid automation experts, CyberSentry SEM manages cyber security in protective relaying and automation systems with a straightforward, yet powerful set of software tools. View security information in a centralized dashboard, detailing threats and risks. Navigate through data with ease. Determine what’s important before it becomes an issue.

Save time and effort with rapid security report generation and creation. These records are invaluable during security audits. CyberSentry SEM generates detailed reports related to possible threats identified by the software. These include failed logins and changes to settings related to communications or device functionality.

CyberSentry SEM is designed to monitor changes to device configurations. When changes are detected, a workflow and alarm can be triggered to ensure the correct steps are taken in change management. This virtual watchdog helps avoid false trips and other major power system impacts that could result from a simple mistake during necessary, but routine maintenance.

CyberSentry SEM Security Dashboard The CyberSentry SEM security dashboard offers unparalleled convenience in a centralized, user-friendly environment. The tabbed structure along the top of the screen provides easy navigation to system setting options, while the main dashboard presents an uncomplicated view of system status.

Tabbed Structure

Main Dashboard

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CyberSentry SEM

Specialized Workflows and Documentation Be ready for action when a problem occurs. Customizable workflows come pre-configured to ensure readiness for common cyber threats and audits.

Device and Configuration Software

The straightforward options available with CyberSentry SEM help identify processes that should be in place as well as common methods for addressing gaps. These workflows can be tailored to fit existing internal procedures or used straight out of the box.

Enhanced Resolution Traceability Prove actions have been taken and organizational commitment to security is in place through detailed records of action. Build an effective audit trail simply and effectively.

Comprehensive Security Documentation CyberSentry SEM is a substation or control center level security solution to aid in simplifying NERC CIP cyber security compliance. It maintains a detailed history of changes to all configurations and creates audit-friendly workflows and records. Users can even customize the report with their own company logo.

The CyberSentry SEM security dashboard displays alarm notifications in a single view, enabling operators to take quick action.

This sample CyberSentry SEM report for a loss of communication event is an example of the documentation that users have, to prove they are tracking their system and know what is happening.

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635

Technical Specifications

Ordering

CyberSentry SEM Device Support

CSEM

Supports enhanced integration with the following GE Multilin networking devices:

TM

• UR — firmware versions 5.4x to 6.0x

relays and

-

*

-

*

Description

1

1 License

5

5 Licenses

10

10 Licenses 025

25 Maximum Devices

• URPlus — firmware versions 1.7x and 1.8x

050

50 Maximum Devices

• ML2400 — firmware version 4.01

100

100 Maximum Devices

150

150 Maximum Devices

Also supports the following third-party devices: • Modbus devices • Simple Network Management Protocol (SNMP) devices

Operating System • Windows® 7 (32-bit) with the latest service pack and patches

Hardware Requirements • 2.3 GHz (or better) Intel/AMD processor • 4 GB RAM (minimum 2 GB) • 1.0 GB free space on hard drive • Minimum screen resolution SXGA • CD/DVD drive • Ethernet connection • Keyboard and mouse

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Value Added Services Value Added Services Overview GE provides training, consulting, modular packaged solutions and integrated energy managment systems that are scalable and cost effective, to meet the varying needs of utilities and industrial power consumers across the globe.

Product Listing

Value Added Services Listing PMCS Integrated Energy Management Solution Power Management Control System (PMCS) is a highly customizable, fully integrated end-to-end Energy Management Solution providing industry specific functional solutions for Monitoring, Power Quality, Control and Automation and Cost Allocation. Access GE Multilin and third-party devices and systems in realtime for graphical representations of substation equipment status, energy trends, remote control of devices and automated responses to system conditions. By optimizing methods used to control both processes and equipment, energy efficiency is realized to utilize assets more effectively and efficiently.

Advanced Training Services GE Digital Energy offers you a comprehensive solution for your Power System Protection, Control and Automation learning needs. Our learning event material is built to suit a wide range of students whether they be maintenance personnel, engineers or consultants. No matter what your background or depth of understanding, our trainers tailor each learning event to deliver relevant training for you. Select from a range of options as we offer learning solutions for audiences that prefer either instructor led or self-paced learning.

Consulting Services GE Multilin offers a wide range of services to assist you with solutions to your Power Protection challenges. Our team of experienced Consulting Services Engineers can help you with end-to-end solutions or specific activities including designing, commissioning and maintaining protective relaying systems and power system protection devices.

Packaged Solutions GE’s Packaged Solutions provide fully integrated, modular solution sets comprising of engineering, design, manufacturing assembly, wiring, testing and commissioning support for protection, control and automation of power system applications. Adhering to the world class quality control standards, GE’s Packaged Solutions are built on an advanced GE product base, and feature seamless integration with legacy and multi-vendor devices and systems.

Go online for the full listing of Multilin Protection & Control services

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PMCS Integrated Energy Management Solution Unlock the Full Potential of Power Networks Through Integration Power Management Control System (PMCS) is a highly customizable, fully integrated end-to-end Energy Management Solution providing industry specific functional solutions for Monitoring, Power Quality, Control and Automation and Cost Allocation. Access GE Multilin and third-party devices and systems in real-time for graphical representations of substation equipment status, energy trends, remote control of devices and automated responses to system conditions. By optimizing methods used to control both processes and equipment, energy efficiency is realized to utilize assets more effectively and efficiently.

Complete Solution The solution can range from a simple remote monitoring system to a full featured, engineered automated control system. PMCS is delivered by the GE Integrated Energy Management Solutions (IEMS) team who provides complete integration service capabilities along with software and hardware components. • Consultation Services

Monitoring

Power Quality

Cost Allocation

Control & Automation

• IEMS Managed Solutions • IEMS Project Services • Solution Training

Basic Simple Energy Monitoring

Advanced Full Featured Energy Management System

Informed Decisions Throughout various industries from Oil & Gas to Data Centers, end operators encounter incredible challenges in understanding all aspects of increasingly complex facilities loaded with an array of equipment and processes. PMCS provides a clear and accurate perspective on the facility to make informed, timely decisions when overcoming challenges such as: • Energy costs escalating out of control • Revenue robbing process downtime • Premature equipment failure • Materials/Inventory loss and process stoppage due to power outages • Expensive system capacity upgrades

• Maintenance • Support

PMCS Integrated Energy Management Solution

Key Benefits PMCS delivers a highly customized, comprehensively integrated Energy Management Solution with the following key benefits: • Improved predictive maintenance for less downtime – Identify maintenance tasks and make scheduled corrections to asset damage and downtime. Redundant configurations are also available to ensure maximum uptime and reduce outage risks.

• Higher productivity – Free up maintenance and repair personnel to perform other needed duties. • Improved power quality – Identify sources of “dirty” power and take corrective action to save wear and possible damage to critical production equipment and other loads.

• Faster problem determination – Quickly pinpoint the root cause of problems using tools such as time-tagged alarms, sequence of events logs and triggered waveform capture.

• Increased scalability - Open, comprehensive protocol and device support to easily integrate and expand existing systems and/or include a multitude of third-party devices in the system solution.

• Increased safety – Provide a centralized source of information, reducing the need for physical contact with equipment and reduce shop-floor or substation presence.

Complete, End-to-End, Integrated, Industry Solutions from HMI to Field Devices.

Industry

DATA CENTERS

OIL & GAS

MINING

FOOD & BEVERAGE

INSTITUTIONAL & COMMERCIAL

WATER/ WASTEWATER

GE PMCS HMI MONITORING

POWER QUALITY

COST ALLOCATION & REPORTING

Real-Time Metering

Network Communication

Alarms

Trending

One Line

Device

Events

Waveforms

Value Added Services

Site Plan

Other Switchgear, System Devices, Systems, etc.

Switch/Protocol Converter Power Meters Protection Relays Breaker Trip Unit

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GEDigitalEnergy.com

Energy Consumption

CONTROL & AUTOMATION

Control

Load Shed

PMCS Integrated Energy Management Solution

Monitoring Energy monitoring brings together information from disparate devices and provides a window to the system, keeping users completely and accurately informed of status. Through the PMCS Monitoring module, end users can easily identify system information down to the device level in real-time both locally and remotely through customized views which aggregate and scale information to best suit the user’s needs. PMCS Monitoring truly brings the facility’s energy interface to the user. A birds-eye graphical site diagram provides a model representation of the complete facility. By selecting location specific items on the screen users can quickly gain more detail of specific, customized, dynamic one line schematics for the site location and even individual installed devices and monitored values. The PMCS Monitoring module captures voltage, current, power, energy and demand data from various field devices such as meters, relays and breaker trip units providing insight on the status of main power feeders, branch circuits and electrical equipment.

Facility overview and site plan.

Typical monitored values include: • RMS current

• KVA and KVAh

• Current demand

• KVAR and KVARh

• Peak current

• Power factor

• RMS voltage

• Frequency

• KW and KWh

• Event records

• Peak KW demand Along with monitoring values, PMCS provides event and alarm management capabilities alerting operators through a multitude of channels for specific conditions and allowing them to acknowledge alarms remotely. PMCS also provides customized monitoring views to track and trend real-time energy consumption to give various users both at the enterprise and operator level perspectives for decision making. One Line overview of entire network.

Value Added Services

Site plan screens.

One Line with asset details.

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PMCS Integrated Energy Management Solution

Power Quality The Power Quality functional module collects data from integrated devices to determine power quality metrics and capture disturbances on the electrical network such as total harmonic distortion, individual harmonic distortion and sub-cycle transients. This previously unknown information is presented in a clear visual format to facilitate quick identification of dirty power sources and tracking of the resulting negative effects on other equipment. By employing mitigation techniques, the overall lifespan of electrical assets is increased and overall process downtime is reduced. Through the data logging and trending capabilities of PMCS, power quality information and events can be easily analyzed to highlight the frequency, duration and severity of problems. Specifically, PMCS has the capability to perform event triggered waveform recording, sag and swell analysis, and out-of-limit logs to provide an accurate system-wide depiction of power disturbances.

Monitor and perform waveform analysis using updated device data.

Value Added Services

Essential where there is a high mix of non-linear loads and expensive equipment , PMCS Power Quality brings visibility to previously hidden network events, allowing preventative action before costly process shutdown.

Monitor and perform waveform analysis using updated device data.

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PMCS Integrated Energy Management Solution

Cost Allocation & Reporting The PMCS Cost Allocation and Reporting module is an essential tool for managing energy usage and identifying areas for cost savings. The Cost Allocation module provides functionality for the automated creation of power usage reports and capability to supply individual energy reports and bills for a variety of groupings by aggregating specific energy data. For example, billing can be generated with a variety of detail by device, by department/cost center, or by floor.

Energy and Demand Report

Start Date

End Date

3/11/2013 12:04 AM

3/12/2013 11:59 PM

Report Generated on 5/22/2013 9:59:40 AM

Switchgear USS 1A-1 Capacity: 665 kW Voltage: 480/277VAC Location: Basement SWGR RM 1A

The format of the reports and bills are fully customizable and can match the same format found in utility bills, including values such as total energy and peak demand power use based on time of use schedules, seasonal rate schedules and regionally specific rate structures. PMCS brings accountability to the facility by providing the capability to allocate costs based on usage and specifically identify usage for particular areas of the facility. This focuses the scope and increases the effectiveness of energy management strategies by providing measurable results. Energy Used: 70.20 kWH

Cost Allocation also provides an easy to use utility configurator, which helps in understanding the costs that appear on the utility bill. Energy management strategies can be developed and tested to see the impact of load shedding, peak demand shaving, shifting rate schedules or even changing utility suppliers.

Average Demand: 1.47 kW Peak Demand: 7.44 kW Peak Demand Date/Time: 3/12/2013 9:44:53 PM

Generate energy and demand reports.

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Value Added Services

Track energy consumption.

Real-time metering.

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PMCS Integrated Energy Management Solution

Control & Automation The PMCS Control and Automation module provides capabilities to implement energy management solutions with automated strategies by interfacing directly with facility devices (GE and non-GE) controlling on-site generators, utility feeds and the power distribution network. The Control and Automation module along with GE devices allows the creation and implementation of customized control and automation schemes to protect assets and ensure optimal energy efficiency and value.

Close Control Pop-Up Relay Designation Breaker Designation Relay Contact Positions

• Implement fast load shedding strategies by isolating local system anomalies to prevent catastrophic system failure and plant shutdown.

Open/Close Buttons

• Reduce the chaotic effects of utility power outages by employing automatic transfer schemes that shed non-critical loads, switch to stable power feeds and control start-up of generators. • Reduce energy charges with automated shedding of non-critical loads during peak rate times. • Reduce peak demand surcharges through automated staging of equipment during process start-up.

Warning Pop-Up

Perform remote control safely and securely.

Integrated Energy Management Solutions (IEMS) Deep Industry Expertise and Comprehensive Energy Services Offerings GE Digital Energy brings together more than 20 years of both functional and industry specific expertise and experience to deliver complete, end-to-end energy solutions from consulting and design to delivery, maintenance and support. Through a comprehensive and industry diverse resource base of experienced energy professionals, the GE Integrated Energy Management Solutions (IEMS) team focuses on solutions to optimize client energy assets to help clients drive business value and growth through their core industry expertise. For more information contact [email protected].

INDUSTRY ALIGNED SERVICES OFFERINGS

Value Added Services

DATA CENTERS

644

OIL & GAS

MINING

FOOD & BEVERAGE

Consulting Services

• System analysis and design

IEMS Managed Solutions

• Complete managed solutions (services, software, hardware devices) • Maintenance and support service level agreements

IEMS Project Services

• Project management • Site evaluation and consultation • Integrated system design

INSTITUTIONAL & COMMERCIAL

• Audits

Solution Training

• Post-implementation solution training

Maintenance

• Solution expansion and upgrades • System maintenance and performance tuning

Support

• Solution specific support

GEDigitalEnergy.com

• Testing • Implementation

• Enterprise IT system integration

WATER/ WASTEWATER

MINING

FOOD & BEVERAGE

INSTITUTIONAL & COMMERCIAL

WATER/ WASTEWATER

DATA CENTERS

OIL &Integrated GAS MINING FOOD & BEVERAG PMCS Energy Management Solution

Functional Applications Load Shed

Power Quality

Challenge A major food and beverage corporation needs to control electrical energy demand to key manufacturing equipment to stay under peak demand levels and to ensure service continuity to critical loads on other automated assembly line operations. Loss of power to the critical assembly line operations would cause significant loss of raw materials and a lengthy restart process subject to regulatory inspection.

PMCS Solution GE’s Multilin Load Shedding solution provides immediate business benefits through reducing downtime and eliminating the need to restart processes. It keeps critical processes running by identifying when there is a lack of power and dynamically shedding least critical loads to keep processes essential to the business running. Moreover, GE Digital Energy’s Load Shedding solution provides ongoing risk reduction for outages and automates outage processes when load shedding is required.

Challenge A leading data center is concerned about the power quality of the electrical network and has requirements to analyze the energy usage throughout the facility as well mitigate risks due to critical equipment outages. Their customers have critical uptime requirements and service level agreements.

PMCS Solution Using PMCS, data can be obtained from a wide array of points from Utility feeds down to the health of individual devices. Leveraging and analyzing this data through PMCS reporting allows simulations and informed decisions based on facts, eliminating the guesswork and implementation of trial and error solutions. By monitoring and trending key data points from devices the lifespan of electrical assets are also more accurately predicted, thereby reducing risk of critical equipment outage.

Key Benefits

Key Benefits

• User friendly and manageable solution allowing dynamic changes to system settings and load priorities

• Remote capture of disturbances on the electrical network such as harmonic distortion and sub-cycle transients

• System intelligence to shed only necessary loads based on generation and real-time load consumption values

• Quick identification of dirty power sources and tracking of the resulting negative effects on equipment

• Very fast load shedding system to prevent plant shutdowns as a result of generation loss

• Support preventative action before costly process shutdown

• Advanced protection schemes to increase the reliability and availability of power as well as protect and monitor critical assets such as transformers, generators and motors • Reduction in operation and maintenance costs through use of IEC 61850 communication standards • Automatic reports generation to facilitate record keeping and further analysis and optimization • Highly customizable, scalable and easily integrated solution for a variety of applications

Value Added Services

Monitor power quality.

Easily configure, maintain and monitor load shed status.

GEDigitalEnergy.com

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OIL & GAS

MINING

FOOD & BEVERAGE

INSTITUTIONAL & COMMERCIAL

WATER/ WASTEWATER

Functional Applications (cont’d) Key Benefits

Motor Control

• Advanced protection sensitivity through a flexible thermal model

Challenge

• Enhanced motor health diagnostics

Within a petrochemical refinery facility, motors provide the lifeline to driven equipment required to maintain critical processes with significant uptime during production and operations. A failure of one of these critical motors could be detrimental to personnel safety, production and have serious environmental consequences. From a business perspective, a motor failure can lead to significant risks and costs associated with impacts such as production downtime, loss of materials, asset repair/replacement and safety and environmental liability. Thus ensuring motors are running efficiently and reliably is fundamental from both an operational and business perspective.

• Multiple communication options including embedded IEC 61850 • Seamless integration into SCADA and DCS systems

Solution GE’s Multilin PMCS Motor Protection Solution which includes the M60 Motor Protection device, provides advanced condition monitoring and asset life reporting to avoid expensive repairs, process interruption and losses because of motor failure. The solution offers comprehensive protection and control solutions for medium to large sized three-phase motors and includes advanced automation and communication capabilities, extensive I/O options and powerful fault recording features that can simplify postmortem fault analysis and help minimize motor downtime.

Monitor the status of critical facility assets to prevent downtime.

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Advanced Training Services Protection, Control and Automation Learning & Development Training GE is committed to providing the high quality training you need to be safe, efficient and successful. The skills learned through our courses will maximize your organization’s potential by ensuring a skilled workforce that is able to work and react quicker and more efficiently.

GE’s Digital Energy Learning & Development Advantage GE offers you a comprehensive solution for your Power System Protection, Control and Automation learning needs. Through attendance at one of our learning centers, students experience learning in state-of-the-art facilities, providing live testing labs, interactive demonstrations and enriched media content, or engage in one of our learning experiences remotely via tele-presence. These state-of-the-art facilities offer regularly scheduled learning events with open enrollment and provide an environment that is best suited for your learning needs. • Tablet Technology: Students attending our courses are equipped with tablets allowing them to store multiple references in one easy place and interact with our Facilitators. • Manufacturing Facility: See how it all comes together. We invite you to tour our facility and meet our team of experts responsible for the assembling, quality assurance and testing of all our products. • Tele-presence Technology: Any time. Any where. Any way. Our tele-presence capabilities allow us to connect with those who wish to learn from abroad. • Industry Experts: Our team of experts provides training from different perspectives. • Customer Experience Center: Learn about our history and today’s state-of-the-art products, services and solutions. • Practical Workshops: Our courses provide you with the best of both worlds as participants gain a combination of theoretical and hands-on learning when attending our product training sessions, through our lab workbooks.

Instructor Led • Instructor Led Learning: Whether you are interested in attending classes at our GE Learning & Development Centers, or preferred location of your choice, our facilitators provide a learning experience like no other. As they combine lecture based training with handson application (where applicable), students are able to expand their knowledge in an environment conducive to learning. • Virtual Classroom: Stay seated and connect with your peers through our virtual classroom sessions. These sessions are facilitated by a live instructor, allowing you the opportunity of reaching out throughout your learning. • Webinars: Designed for those who are interested in gaining further knowledge regarding our products and theory based modules, our live webinars offer students the opportunity to attend our two hour online sessions to discuss specific topics with a live instructor.

Self Paced • Computer Based Training (CBT): On their own or combined with another learning avenue, our Interactive Learning CDs enrich the education experience. • eLearning (coming soon!) : Stay connected as we continue to communicate updates regarding our catalogue of online courses.

Learning Events Path Our learning events are organized into a three-tier Learning Path, covering Principles & Fundamentals, Product Applications and Integrated Systems. Depending on your background and the solutions you implement, only a subset of the Learning Path may be right for you and/or your business.

Principles & Fundamentals

Product Applications

Integrated Systems

Designed for recent graduates entering the field of power system protection, control and automation as well as seasoned professionals who want to stay up-to-date on the latest industry trends and technology. Our principles & fundamentals learning opportunities come in three flavors:

Gain the knowledge and skillset required to implement GE protection, control and automation products in your real-world applications. We offer standardized learning and development opportunities on a wide range of our products for both industrial and utility applications. These courses include:

Our powerful software solutions will translate individual IEDs and gateways from standalone products into an integrated system to simplify power monitoring and management capabilities.

1. Theoretical courses address the fundamental nature of modern day power systems and the protection principles our products employ to mitigate inherent risks.

• Review application-specific theory

2. Hands-On Essentials courses are focused on implementing communication standards and protocols on hardware platforms.

• Hands-on lab assignments

• Installation and wiring configuration • Setup/interface software

Through integrated systems training, students are offered learning and development opportunities on our EnerVista™ Suite courses, and provide training on viewing simplified realtime data, event recording, building complex FlexLogic™ and more, to simplify every aspect of their workflow process.

3. Courses taught by leading industry experts offer great value to those wanting to stay up-to-date with the latest industry trends, technology and best practices.

Online Store Easily find and order protection, control and substation automation learning courses

store.GEDigitalEnergy.com

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Consulting Services GE Multilin offers a wide range of services to assist you with solutions to your Power Protection challenges. Our team of experienced Consulting Services Engineers can help you with end-to-end solutions or specific activities including designing, commissioning and maintaining protective relaying systems and power system protection devices.

Designing Wide Area Protection Schemes • High-speed Digital Teleprotection

Design of Protection & Automation Solutions

• Transmission/Distribution Remedial Action Schemes (RAS)

From new power systems to the upgrade of existing systems, trust the experience of GE Multilin to evaluate, design and deliver.

• System-Wide Peer-to-Peer Communications using IEC61850 GSSE/GOOSE

Performing Protection System Studies • Arc Flash Studies • Load Flow & Fault Studies

Creating Automatic Transfer Schemes

• System & Relay Coordination Studies

• Developing Custom Logic and Settings Files

• System Transient Studies using EMTP and RTDS

• In-house Verification Testing

Reviewing Relay Logic & Settings Files • Recommending changes to meet IEEE, NERC Standards • Improving IED Utilization

Designing Customized Protection & Automation Systems • Creating Relay Settings Files • Developing Engineering Drawings • Equipment Selection • End-to-End Solutions

Power System Modeling and Protection Performance Testing

Protection Scheme Performance Verification

At our in-house RTDS Lab, GE Multilin engineers create highly accurate computer models of your power system and its components (based on EMTP) in order to perform real-time closed loop testing. System behavior can be simulated and analyzed under a variety of fault conditions.

• Parallel performance testing of different protection philosophies

Literally thousands of fault scenarios can be run on your system model using automated test scripts. Our engineers analyze the results and manually step you through any abnormal or unexpected system operations. We then assist with recommendations on alternate protection schemes, equipment selection, and optimizing relay settings and control logic. RTDS test results and our recommendations for system improvement, are provided in a detailed report along with the relay event records and oscillography files. GE Multilin can help you understand how your power system and its protection and control devices will respond to failure situations. Gain the assurance and peace of mind of knowing that your protection and control functions will operate as required when you need them most.

Real Time Digital Simulator (RTDS) Testing • Time-domain (transient) modeling of large power systems • Playback of large COMTRADE files for protection testing • Flexible AC Transmission Systems (FACTS), wind generator modeling

• Validate protective relaying schemes against customer power system • Testing of GE and non-GE protection IEDs • Scheme testing using IEC61850 GOOSE/GSSE • Complete test reports and documentation including event sequence and oscillography

On-Site Field Services Have the experts who design and build your relays help you evaluate, test and commission your protection and control system. Our team of knowledgeable field engineers can test and verify that your protection devices are connected properly and will operate as designed.

Site/System Surveys • Document Existing Protection and Control Systems • Recommendations Report

Protection System Commissioning • Relay & Panel Testing • Wiring Verification

Protection System Field Troubleshooting • Fault Data Collection & Analysis • Recommendations & Solutions • Upgrading Relay Firmware • Uploading Relay Settings Files

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Packaged Solutions Value Added Solutions for Protection, Control and Automation Applications GE’s Packaged Solutions provide fully integrated, modular solution sets comprising of engineering, design, manufacturing assembly, wiring, testing and commissioning support for protection, control and automation of power system applications. Adhering to the world class quality control standards, GE’s Packaged Solutions are built on an advanced GE product base, and feature seamless integration with legacy and multi-vendor devices and systems.

Key Benefits

Flexible and Expandable • Pre-designed modular solutions for ease of expansion, installation and testing • Accelerated delivery cycle for protection, control and automation applications by leveraging modularity and standardization

• Provides overall project cost savings, potentially up to 15% of the total CapEx spend including engineering and site acceptance costs, resulting in substantial economic benefits for the project

Total Quality Solution

• Reduces cycle time driving accelerated customer acceptance and project turnaround period

• Use of standardized manufacturing processes, resulting in reduced variability and high quality solutions

• Integrates multi-vendor legacy protection relays, devices and automation sub-systems • Provides integrated platforms for additional levels of automation, cost optimization and enhanced process efficiency • Enables faster service restoration and improves system reliability by providing improved visibility and control of the power infrastructure

• Designed, engineered, manufactured and tested in a strict ISO 9001 and Lean 6-Sigma quality controlled environment to provide enhanced system reliability

Application Specific Solutions

Cost Effective Solutions

Generation

• Fully validated and factory tested solutions, helping in reducing the commissioning and site acceptance costs

Packaged Solutions offer fully integrated sub-system solutions for protection and control of generators with sizes ranging from tens of KWs to hundreds of MWs

Transmission Pre-designed modular protection, control and automation solutions for transmission system assets such as transmission lines, bus-bars, large transformers and capacitor banks

Distribution

• Leverage GE’s advanced multi-function devices to improve application convergence and reduce device redundancies

Comprehensive Solution

Expandable modular solutions for assets within a distribution substation, e.g. transformers, breakers, cap-banks, as well as assets outside of the ‘substation fence’, e.g. reclosers and switches

• Featuring state-of-the-art GE protection, control, automation technology with advanced communications, security and interoperability

Power Utilization & Automation

• Suitable to interface legacy multi-vendor products and subsystems

Packaged Solutions offer a wide variety of modular metering, automation, industrial process protection and control solutions for commercial and industrial customers

Packaged Solutions

Packaged Solutions for the Full Transmission

GE provides fully integrated protection, control and automation packaged solutions for a range of small to large size generators, ensuring safe operation, and protecting these key power system assets from a variety of fault conditions and anomalies. GE’s Packaged Solution’s generator protection and control solution features ANSI and IEC compliant main protection devices and auxiliary components and subsystems.

GE provides protection, control and automation packaged solutions for variety of power transmission applications such as HV/EHV line protection, large transformer protection, and high or low impedance bus protection systems to name a few. These solutions are designed and manufactured to address a multitude of customer challenges ranging from installation constraints to rugged environmental applications.

Generator Protection and Control Solution

Advanced Bus Protection and Control Solution

• Leverages advanced GE protection relays

• Pre-designed, configurable advanced protection schemes

• Fully integrated, tested packaged solution

• Bus differential protection and control package

• High quality workmanship and accelerated delivery cycles

• Engineered solutions for custom transmission applications

Advanced GE Generator Protection and Control Packaged Solution used for protection of large gas and steam turbines.

Advanced Low Impedance Bus Protection and Control Packaged Solutions used for complex bus topologies.

Value Added Services

Generation

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Packaged Solutions

Range of Smart Grid Applications Distribution

Automation & Industrial

GE’s Packaged Solutions offer smart distribution applications minimizing customer downtime and improving safety and reliability in power distribution networks. The standard pre-designed modular packaged solutions reduce the total solution cost while providing state-of-the- art protection, control and automation capabilities.

GE provides a range of RTU automation and industrial protection and control packaged solutions for medium to large industrial and utility applications. These solutions are provided as indoor, outdoor or pole-top solutions and are used for green-field and brown-field installations.

Pre-designed Distribution Solutions

Automation and Industrial Solutions

• Pre-configured modular protection and control solutions for distribution applications such as feeder, transformer and breaker

• Customized RTU solutions for variety of applications

• Designed for indoor (NEMA 1) or outdoor (NEMA 4 or NEMA 12) applications • Library of modular designs for common distribution applications to pick from

• Supported by large host and IED protocol libraries • Fully configured, factory tested solutions reducing installation and commissioning time at site

Value Added Services

Distribution Protection and Control Packaged Solutions.

Industrial RTU Automation and Protection Packaged Solutions examples.

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Packaged Solutions

Packaged Solutions Offerings

Extending value by offering value add solutions and services Modular Packaged Solutions

Retrofit Solutions

• Library of repetitive pre-configured, pre-wired and tested modular solutions

• Pre-engineered retrofit solutions for legacy and automation Protection and Control devices such as DGP, ALPS, LPS, DLP and other legacy multi-vendor P&C products

• Ideal for simple repetitive applications , e.g. Feeder Protection and Control, Transformer Monitoring Solution and Generator Protection

• Pre-wired, pre-terminated modules ready to integrate, test and commission

Engineered Solutions

Project Solutions

• Engineered Solutions for complex Generation, Transmission, Distribution and Automation applications

• Protection and Control engineering and design • Engineered packaged solutions

• Fully engineered, wired, tested, integrated solutions ready for site testing and commissioning

• Special project requirements including commissioning and site testing support for protection, control and automation applications

Modular Packaged Solutions

Modular Protection, Control and Automation Solutions GE’s Modular Packaged Solutions (MPS) are a comprehensive set of predesigned, fully integrated protection, control and automation modules for generation, transmission and distribution applications. The MPS are well suited to provide optimization of protection, control and automation designs for green field and brownfield substations. The MPS module design philosophy allows for flexibility in design, engineering, installation, commissioning and upgrades throughout the life of your protection and control system.

Key Benefits Reduced Total Cost of Ownership and Maintenance • Predesigned, modular solution for ease of panel design, expansion, installation and testing

Value Added Services

• Reduced total cost of ownership by using the modular designs, significantly lower than custom panel design

Quality Solutions • Designed, assembled, wired and tested under high assurance and quality control standards • Each MPS solution is provided with complete documentation for ease of site installation and testing

Scalable, Flexible and Quick Turnaround • Choose protection, metering and control modules from a wide selection of MPS designs • Standard module offerings with quick turnaround lead-time in range of 6-8 weeks from order to shipment for common applications • Simple selection of modules and enclosures/racks for panel design • Factory tested and verified to help expedite the field testing and commissioning

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Steps to design your own protection panel using MPS assemblies Step 1 Select pre-designed, configurable MPS modules for your application Select the MPS modules from the following typical application library to best fit your application needs. Configure your panels with one or more (typically up to three) MPS modules for your application and desired functionality.

Step 2 Select auxiliaries from extensive GE device libraries Select auxiliary devices such as Ethernet switches, RTU gateways, meters, etc to best fit your needs. GE provides a typical range of the above mentioned devices, but more options and devices are available for your protection and automation applications.

Step 3 Select an enclosure for your panel from variety of available options Select the enclosure from typical protection panel enclosures and racks to best fit your application. The selection below provides a typical range, but we can also support more types/designs as needed.

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Packaged Solutions

Step 1: Select Pre-designed, Configurable MPS Modules Generator Protection Applications Generator Protection MPS

devices)

Applications • Small to medium generator applications • Pumped storage generators • DG interconnect protection per IEEE 1547

19” rack-mount MPS assembly featuring: • Multilin™ G30 based advanced MPS with typical functions e.g. Generator Stator Differential, Restricted Ground fault, Reverse power and optional vibration and thermal overload • Built-in one Breaker Control Switch and one Lock Out Relay (option to add more) • Built-in 19” rack-mount test-switch assembly for relay testing • Pre-wired, fully tested MPS module ready to be installed in a P&C panel • Built-in advanced communications and optional IEC 61850 and advanced cyber security

Typical Small/Medium Generator Scheme with Low Impedance Grounding

• Available in IEC designs (with IEC auxiliary

Advanced Generator Protection MPS Applications • Large Generators typically driven by gas/ stream turbines • Pumped storage generators used as pumping motors

19” rack-mount pre-wired MPS assembly featuring:

Value Added Services

• Multilin G60 based advanced generator protection MPS with typical functions e.g. Generator Transformer differential , 3rd Harmonic Neutral Under-voltage, Loss of excitation, Phase distance and optional 100% Stator Ground fault • Built-in EPM 9900 meter, with option to add GE bus metering • Built-in one Breaker Control Switch and one Lock out relay (option to add more) • Built-in 19” rack-mount test-switch assembly for relay testing, with option to add more, as required • Pre-wired, fully tested MPS module ready to be installed in a P&C panel

Typical In-zone Transformer Generator Scheme for Large Generators

• Built-in advanced communications and optional IEC 61850 and advanced cyber security • Available in IEC designs (with IEC auxiliary devices)

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Packaged Solutions

Transformer Protection Applications Advanced Transformer Protection MPS Applications • Power Transformer, HV windings protection and control • Transformers in ring bus or break-and-a-half schemes • Transformer asset monitoring using Hottest Spot, Loss-of-Life and Aging factor

19” rack-mount MPS assembly featuring: • Multilin T60 based advanced MPS with typical transformer functions e.g. Differential, over current and short circuit, ground fault, directional overcurrent, Volts per Hertz, overvoltage, power swing blocking and optional synchrocheck • Built-in one Breaker Control Switch and one Lock out relay (option to add more) • Built-in 19” rack-mount test-switch assembly for relay testing • Option to add EPM energy meter as needed

Typical Transformer Protection Scheme for Large Transformers

• Pre-wired, fully tested MPS module ready to be installed in a P&C panel • Built-in advanced communications and optional IEC 61850 and advanced cyber security • Available in IEC designs (with IEC auxiliary devices)

Distribution Feeder Protection Applications Basic Feeder and Bay Control Unit MPS Applications • Primary feeder protection on solidly grounded, high impedance grounded or resonant grounded systems • Bus blocking/interlocking, and bus transfer schemes • Simple utility and industrial feeder topologies

Value Added Services

19” rack-mount MPS assembly featuring: • Multilin F650 with typical functions e.g. Phase directional overcurrent, Neutral directional overcurrent, synchrocheck, reclosing and voltage/power metering • Option to add redundant meter, if needed • Built-in one Breaker Control Switch and one Lock out relay • Built-in 19” rack-mount test-switch assembly for relay testing • Pre-wired, fully tested MPS module ready to be installed in a P&C panel

Typical Single Feeder Protection Application

• Can be provided in an enclosed NEMA 4 rated outdoor enclosure • Available in IEC designs (with IEC auxiliary devices)

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Advanced Feeder Protection MPS Applications • Primary feeder protection on solidly grounded, high impedance grounded or resonant grounded systems • Back-up protection for transmission lines, feeders and transformers • DG interconnect protection

19” rack-mount MPS assembly featuring: • GE F60 based advanced MPS with typical functions e.g. Phase directional overcurrent, Neutral directional overcurrent, synchrocheck, reclosing and built-in voltage and power metering, Voltage and frequency elements for transfer schemes • Built-in one Breaker Control Switch and one Lock out relay (option to add more) • Built-in 19” rack-mount test-switch assembly for relay testing • Option to add EPM energy meters as needed • Pre-wired, fully tested MPS module ready to be installed in a P&C panel • Built-in advanced communications and optional IEC 61850 and advanced cyber security

Typical Directional Overcurrent – Dual Breaker Protection Scheme

• Available in IEC designs (with IEC auxiliary devices)

Transmission Line Protection Applications Distance Protection MPS

1

Applications • Overhead lines including series compensated lines and underground cables

3Y

• Single and dual-breaker circuits, with single/ three pole auto-reclosing

52

• Backup protection for generators, transformers and reactors

• Multilin D60 with advanced functions e.g. Power swing detection, single-pole tripping, synchrocheck and reclosing

3Y

52

• Option to add meter(s) to the MPS, if needed • Built-in one Breaker Control Switch and one Lock out relay

3Y

21P 21G 67P 67N 3

• Built-in 19” rack-mount test-switch assembly for relay testing

V

50BF

3

S

25

2

79 2

• Pre-wired, fully tested MPS module ready to be installed in a P&C panel • Available in IEC designs (with IEC auxiliary devices)

Value Added Services

19” rack-mount MPS assembly featuring:

1

Typical Stepped Distance – Dual Breaker Protection Scheme

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Line Current Differential Protection MPS Applications • Overhead lines including series compensated lines and underground cables

1

• Single and dual-breaker circuits, with single/ three pole auto-reclosing • 3 terminal line configurations, with channel redundancy and DTT

3Y

• Wide area system monitoring and control

52

19” rack-mount MPS assembly featuring: • Multilin L90 based advanced MPS with typical functions e.g. Phaselet based Line differential and multiple communication options, 5 zone distance protection with pilot schemes, 2 and 3 terminal applications, optional breaker-anda-half configuration, Peer-to-Peer or MasterSlave modes of operation, Direct Transfer Trip (DTT), Tapped transformer applications • Built-in one Breaker Control Switch and one Lock out relay (option to add more)

3Y

52 87L

3Y

50BF 2

3

• Option to add EPM energy meters as needed

• Built-in advanced communications and optional IEC 61850 and advanced cyber security

67P 67N

21P 21G 25

• Built-in 19” rack-mount test-switch assembly for relay testing • Pre-wired, fully tested MPS module ready to be installed in a P&C panel

85

3

79

85

2 Identical relay on other line terminals

1

Typical Line Current Differential – Dual Breaker Protection Scheme

• Available in IEC designs (with IEC auxiliary devices)

Bus Protection Applications Low Impedance Bus Protection MPS Applications

ZONE 1

• Single Bus, Breaker and half bus bar configurations, Double Bus and Triple Bus with and without bus couplers

Value Added Services

• The Low Impedance Bus MPS supports up to 8 feeders; can be designed to support re-configurable multi-section bus-bars with up to 24 feeders

1

2

3

Typical Single Bus Bar, 8 Feeders or less, 1 Zone Protection

19” rack-mount MPS assembly featuring: • Multilin B90 with advanced bus protection functions e.g. Phase segregated scheme, 4 zones with dynamic bus replica, CT saturation detection, up to 8 feeders with one B90 (No Breaker Failure function) • Built-in one Lock out relay • Built-in 19” rack-mount test-switch assembly for relay testing; option to add more for more than 8 feeders • Pre-wired, fully tested MPS module ready to be installed in a P&C panel • Available in IEC designs (with IEC auxiliary devices)

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Packaged Solutions

Step 2: Select Auxiliary Options from Extensive GE Device Libraries Substation Automation Devices

Metering Devices

T erminal Blocks & Test Switches

Ethernet Switches

Step 3: Select Enclosure Options Variety of open racks and enclosures to pick from featuring NEMA 1, NEMA 4 or NEMA 12 and Zone 3 or Zone 4 Seismic ratings

Value Added Services

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Packaged Solutions

Demonstration of Modular Packaged Solutions for Protection Panel Design

Generator Main Protection MPS

Breaker Failure Relay MPS

Line Distance Relay MPS

Transformer Main Protection MPS

Line Differential Relay MPS

Generator Backup MPS

Generator Protection & Control Panel design using Modular Packaged Solutions (MPS) Modules

Line Protection Panel design using MPS modules

Engineered Solutions

Custom Engineered Solutions for Protection, Control and Automation Applications Engineered Solutions for Utility and Industrial Power Systems GE’s Packaged Solutions offerings include custom engineered protection, control and automation solutions for customer specific applications. These solutions leverage GE Packaged Solutions modular designs while providing full flexibility to integrate multi-vendor legacy products and technologies.

Value Added Services

Generator Protection and Control Solution Suitable for medium to large sized generators, typically +100MW, generally driven by steam or gas turbines. This solution is built on an industry leading UR platform, and is a free-standing, fully integrated, pre-designed, assembled, wired and tested solution. Thorough in-house testing and pre-configurations enable accelerated site acceptance testing and commissioning.

Base Package Features:

Optional Features:

• A standard NEMA 1 ANSI grey panel enclosure

• A NEMA 12 panel enclosure for harsh environment applications

• Multilin G60 based main and backup generator protection

• Seismic Z4 compliant enclosure for seismic sensitive areas

• Multilin C60 Circuit Breaker management relay

• Second GSU unit protection relay system

• Multilin T60 based main transformer protection

• Backup digital metering for critical applications

• Advanced relays with built in powerful FlexLogic engine

• Interfaces to multivendor legacy devices for retrofit applications

• Modular design to expand protection functions as needed

• Built-in fully integrated bus/feeder protection system

• Digital Generator Metering (1% KW, 0.5% V, I)

• Customized panel for customer specific applications

• FT test switches and LORs for testing and local control

• Power system studies and relay settings design

• Auxiliary devices and switches

• Factory Acceptance Testing and Site Testing assistance

• Panel design and engineering, assembly, wiring

• Generator protection commissioning support and training

• PTP and relay power-up functional testing

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Low Impedance Bus Differential Protection and Control Solution Suitable protection system for complex bus topologies with multiple feeders, sectionalizer and bus couplers. The solution features the Multilin B90 low impedance bus protection relay system standardized design libraries for application on a variety of bus topologies, and for indoor and outdoor applications.

Distribution Protection & Control Solution GE’s Distribution Protection and Control Solution is suitable for feeder and breaker protection applications. This solution is modular and engineered with full protection and control logic implementation for outdoor switchyard applications.

RTU Automation Solutions GE Packaged Solutions provides a number of RTU automation solutions for transmission and distribution SCADA applications. The solution features a direct interface to the SCADA Master Stations and provides effective communications between IEDs over multiple communication protocols. GE’s solution features a direct interface to switchyard equipment and devices. The automation packaged solutions, featuring advanced Multilin D20/ D20MX/D200/D400 RTU units, are available for indoor, outdoor and pole-top applications. These solutions provide the largest host and IED protocol library in the industry applications. The solutions are customizable and flexible to meet utility specific hardware termination requirements.

Key Features: • Brushed Aluminum enclosure for outdoor applications • Advanced Multilin F60 feeder protection relay with high impedance down conductor protection function • Solution designed for extreme hot weather and seismic conditions • Built-in communication to upstream SCADA system

Retrofit Solutions

Pre-designed, Integrated Retrofit Solutions for Legacy Protection and Control GE’s Retrofit Solutions are comprehensive modernization and upgrade solution sets for a variety of legacy protection and control relays and subsystems. The GE Packaged Solutions provide one-to-one retrofit upgrade solutions leveraging state-of-the-art microprocessor-based protection devices for advanced protection and control functionality. These solutions are pre-designed, pre-wired and integrated to replace an older device in an existing panel without any changes in customer side wiring. The customer gets a substantial benefit of deploying these solutions by retaining their existing infrastructure and yet getting latest features and functionality.

Key Benefits Predesigned, modular solution for ease of installation and testing in an existing protection panel

Retrofit Solution Example Generator Protection: DGP Retrofit Solution - DGPR

Convergence: Ability to provide the protection and control functions required for large power system assets in one relay platform to replace multiple single function devices

Total Quality Solution: Designed, assembled, wired and tested under high quality assurance and quality control standards. Each retrofit solution type is provided with complete documentation with as-built drawings, wiring matchup details for ease of site installation and testing

The Multilin DGPR Solution is a pre-designed, fully integrated retrofit solution for a GE legacy Generator Protection DGP Relay. The DGPR Solution is designed for a one-to-one replacement of a DGP relay with a Multilin G60 based retrofit module. The DGPR Solution is well suited for large hydro, gas and steam turbine generators, providing state-of-the-art modern protection and control functionality for these critical power system assets.

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Value Added Services

Simplified Retrofit Designs:

DGPR Ordering:

DGPR LPSO retrofit not required LPSO retrofit included DGP Generator Protection Relay

DGPR Retrofit Module

Solution Features: • A Multilin G60-N04-HKH-F8M-H6H-M8M-P6B-U6C-WRH relay • 4 FT switches for trip and CT circuit isolation

G60 Settings not required G60 settings required Wiring Matchup table not required Wiring table included

• Gage 11 metal structure to mount G60 relay and test switches

– XX – XX – XX Base Module DGP retrofit only

D0 D1 S0 S1

Provided with a 3 RU plate to cover for LPSO G60 relay settings not provided Settings converted from original DGP settings (optional) W0 No wiring match-up table provided W1 Derived from customer existing panel wiring diagram

• Internally integrated wiring to connect relay through the FT test switches

Notes:

• Install documentation to assist with mounting in a generator protection panel

* P  lease contact your local sales channel for a custom design instead of the standard module proposed above

• G60 relay settings, based on DGP settings (optional)

** Visit our website for details on the UR G60 relay: http://gedigitalenergy.com/multilin/catalog/g60.htm

Project Solutions

Comprehensive Protection, Control and Automation Projects GE Packaged Solutions offer projects in the area of Protection, Control and Automation. The typical scope for such a project would be to engineer a P&C and/or automation system, supply of packaged solutions, assistance and support for site acceptance testing and commissioning.

Features & Benefits Complete engineering and design of protection, control and automation schemes for generation, transmission and/or distribution and industrial automation applications. Our team of P&C and automation experts will work with the customer in defining the complete project scope, protection, control and automation requirements, and finally a fully compliant design. Following are the key features and benefits of leveraging GE Smart Substation’s packaged solutions projects portfolio: • Full capability for in-house design, engineering and development of Packaged Solutions applications for P&C and Automation • Capability and proven experience in project management, sourcing and material procurement, construction, panel wiring and testing • Available technical site support for commissioning and site acceptance testing • Fully integrated Lean 6-Sigma and ISO 9001 quality standards and processes We have successfully delivered a large number of P&C and automation projects in various geographies, and continue to support our customers for various state-of-the-art applications.

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Product Upgrades & Replacement Upgrade Your Fleet to Gain the Latest Protection & Control Capabilities GE Digital Energy provides the tools needed to upgrade your fleet of protection, control, automation and communications devices. By replacing legacy products with the latest advanced offerings, users can gain the benefits of hardware and technology advancements, communications capabilities, asset health diagnostics and fault recording and analysis capabilities. With a dedicated service team, highly skilled and trained engineers and technicians can assist with facility wide audits to identify all devices in the field and recommend product upgrade strategies. With advanced training centers and flexible on-site or online training programs, customers can ensure maximum benefits are achieved when upgrading.

Universal Relay (UR) 7 Platform Designed as a modular and highly flexible platform, the Multilin UR makes it easy to upgrade your existing fleet of devices. Upgrade from an older hardware version to the latest UR 7 platform to obtain all the latest in design, technology and protection capabilities. Simply replace some of your old modules with the new UR 7 compatible modules without having to replace the chassis or make new cut-outs panel doors.

8 Series Platform Raising the bar on protection and control capabilities the Multilin 8 Series provides the latest in protection, control, and communications capabilities all within a draw-out design. Designed to fit existing Multilin SR cut-outs, the Multilin 8 Series is the right choice for Feeder, Motor, and Transformer protection. Using GE’s intuitive and industry leading ease-of-use software tools, setting file conversion is simplified, reducing system downtime and costs associated with upgrade projects.

Application Specific Upgrades From power plant to the power consumer, GE offers a wide range of upgrade solutions to ensure customers can take advantage of the latest in technology and protection and control capabilities. With GE’s EnerVista software and hardware upgrade kits, transitioning to a more modern device is simplified, reduce time, effort and costs associated with upgrade and expansion projects.

Product Upgrades & Replacement

Platform Upgrades Upgrades & Replacement

Multilin SR Relays

M family to Multilin 3 Series For feeder, motor, and transformer applications, replace your M or M II device with the latest Multilin 3 Series of protection and control solutions. Upgrade to gain the latest in communications options, asset monitoring capabilities, programmable logic, and flexible configuration options including drawout or non-drawout case options.

Application Specific Upgrades Generator Protection Solutions

DGP Generator Protection Relay to G60, G30, 489, and G650 The DGP is a digital system that provides protection, monitoring, control, and recording functions for AC generators in a wide range of sizes, driven by steam, gas or hydraulic turbines. Upgrade to one of GE’s more advanced Multilin protection & control devices, depending on your application needs including: • Multilin G60 for generators of any size • Multilin G30 for small to medium sized generators or for applications needing in-zone transformer protection • Multilin 489 for primary, backup and co-generator applications with 25, 50, or 60 Hz synchronous or induction generators • Multilin G650 for distributed generation management where distributed I/O is required to interact with the prime mover control system



LPS-O™ Generator Backup Protection to D60 or G60 LPS-0 provides backup protection for generators and transmission lines, offering single or three phase tripping capabilities. Upgrade to GE’s latest UR Platform for Line Distance or Generator protection, depending on the application. Take advantage of the latest communications standards by digitizing substation signals and communications through IEC 61850 Process Bus. • Multilin D60 Line Distance Protection System • Multilin G60 Generator Protection System

Go online for the full listing of Multilin Protection & Control product upgrades GEDigitalEnergy.com/Multilin/upgrades

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Transformer Protection Solutions DTP Transformer Protection to T60, T35 The DTP offered high-speed differential and backup instantaneous differential three-phase protection for power transformers with two, three or four windings. Upgrade this relay to GE’s latest Multilin UR family, either the T60 or T35 Transformer Protection Systems, depending on the application requirements. • Multilin T60 Transformer Protection for high-speed, 2 to 6 winding transformer applications • Multilin T35 Transformer Protection for cost effective differential protection for transformers with up to 6 sets of CTs

Line & Bus Protection Solutions

ALPS Line Protection to L90, L60, D90Plus, D60, D30 ALPS digital protection relay provides distance protection for HV or EHV transmission lines. It has been applied on or adjacent to series compensated lines and for single of three phase tripping applications. The Multilin UR family of line and distance protection devices offers more capabilities and flexibility to meet specific application requirements. • Multilin L90 Line Differential System – Line protection system with segregated line current differential and complete distance protection • Multilin L60 Line Phase Comparison System – delivers sub-cycle phase comparison and distance protection • Multilin D90Plus Line Distance Protection System – Sub-cycle line distance protection system and bay controller • Multilin D60 Line Distance Protection – High-speed transmission line protection with flexibility for three or single pole tripping • Multilin D30 Line Distance Protection System – cost effective, three pole primary and back-up distance protection



LPS-D Transmission Protection to L90, L60, D90Plus, D60, D30 The LPS-D protective relay provided main or back-up distance protection of transmission lines, suitable for single or three phase tripping applications. The Multilin UR family of line and distance protection devices offers more capabilities and flexibility to meet specific application requirements. • Multilin L90 Line Differential System – Line protection system with segregated line current differential and complete distance protection • Multilin L60 Line Phase Comparison System – delivers sub-cycle phase comparison and distance protection • Multilin D90Plus Line Distance Protection System – Sub-cycle line distance protection system and bay controller • Multilin D60 Line Distance Protection – High-speed transmission line protection with flexibility for three or single pole tripping • Multilin D30 Line Distance Protection System – cost effective, three pole primary and back-up distance protection



BUS1000/2000 Busbar Protection to B90, B30, B95Plus The BUS1000/2000 was a solid state, high-speed protection system for phase-to-phase and phase-to-ground faults on busbar installations of any voltage. The Multilin UR and URPlus families offer the most up-to-date capabilities for low impedance busbar differential protection. • Multilin B90 Low Impedance Bus Differential System – Comprehensive and scalable bus and breaker fail protection for LV, HV, and EHV busbars for upto 24 feeders • Multilin B30 Bus Differential System – Cost effective bus protection and metering for up to six feeders • Multilin B95Plus Bus Protection System – Distributed low impedance busbar protection system utilizing the HardFiber IEC 61850 process bus technology

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Upgrades & Replacement



Feeder & Breaker Protection Solutions

DFP100/200 Feeder Protection to F60, F35, 850 The DFP100/200 was a digital relay that provides distribution feeder protection, control, metering and monitoring. The DFP200 provided comprehensive protection functions including a high impedance fault detection function that distinguished between a downed conductor and other arcing faults. GE’s feeder protection solutions offer significant advancements for feeder protection applications including Hi-Z protection, applications with multiple feeders, and the latest in high reliability and redundant communications capabilities. • Multilin F60 – High performance feeder protection in a modular design for high impedance fault detection • Multilin F35 – Feeder protection and power metering for up to six feeders in one integrated device • Multilin 850 – Primary or back-up protection for underground or overhead medium voltage feeders in industrial or distribution utility applications in a drawout design



DBF, DBT, DRS Breaker Failure, Supervision and Recloser to C60, C90Plus The DBF breaker failure relay provided phase and ground backup protection. The DBT provided supervision to ensure integrity of the breaker’s tripping and closing coils. The DRS provided both single and three pole reclosing for one or two breakers. Replace these with GE’s latest UR or URPlus family of Breaker Protection or flexible automation controllers. • Multilin C60 Breaker Protection System – integrated breaker monitoring and control for substation automation, delivering fast, deterministic execution of programmable logic • Multilin C90Plus Automation Control System – powerful automation controller with the ability to provide a substation alarm concentrator, annunciator, control, and breaker protection and monitoring, all in a single device



Electromechanical to 3 Series Relay Replace your single function IAC time-overcurrent, IFC Time-overcurrent, SLR Reclosing relays, ACR reclosing relays and MDP digital Time-overcurrent relays. GE’s advanced digital and multi-function microprocessor relays provide the latest in protection, control, automation, metering and communications, all within a single device. • Multilin 350 Feeder Protection System – intuitive circuit protection, feeder breaker control capabilities including auto-reclose, and detailed diagnostic capabilities offered in a draw-out or non-drawout construction

Motor Protection Solutions

P4A, 139 or 239 Motor Protection to 339 GE’s Multilin P4A, 139 and 239 Motor Protection relays offered protection of three phase AC motors. GE’s latest family of relays offer unparalleled protection, control, automation, diagnostics and communications capabilities in a compact drawout or non-drawout design. • Multilin 339 Motor Protection System – Intuitive, comprehensive motor management for medium voltage AC motors in industrial applications

Go online for the full listing of Multilin Protection & Control product upgrades GEDigitalEnergy.com/Multilin/upgrades

GEA-12907(E) English 150122

Accessories Accessories Overview Learn more about GE accessories typically found in protection panels, control houses and switchgear, including Test Equipment, Terminal Blocks and Indicator Lights.

Product Listing

Accessories – Product Listing Accessories

Switches

Terminal Blocks



SB-1 Control and Transfer Switches



116B407 Pullout Fuse Blocks



SB-9 Master Control Switches



Terminal Blocks for Connecting Leads



SB-10 Control and Transfer Switches



EB 25/26/27 Terminal Block



SBM Control and Transfer Switches



EB 1/2 Terminal Block



SERIES 95 Heavy Duty Rotary Switches



FT and RT Test Switch

Test Equipment

Indicator Lights



515 Blocking and Test Module



ET-16 Incandescent Indicating Lights



PK-2 Test Block and Plugs



ET-16 LED Light Emitting Diodes



XCA Test Probes and Plugs



XLA Test Plugs



PMTB-14 IEC 14-pole Test Blocks & Plugs



SMTB-4 IEC 4-pole Test Blocks & Plugs

RTT

Go online for the full listing of Multilin Protection & Control accessories GEDigitalEnergy.com/PC-Accessories

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Desktop Test Set

Ethernet Switches Ethernet Switches Overview Over the past decade, Ethernet has become a popular networking technology because of its low cost, high bandwidth, and versatile support for multiple applications. This section examines some of the factors and requirements that should be considered when designing an Ethernet network for Industrial or Utility applications

MutiLink Family Brochure The MultiLink family is a line of industrial and substation hardened Ethernet Switches that provide secure, reliable communications for critical infrastructure devices. Designed to meet the unique requirements of the protection and control industry, the MultiLink family of products will help ensure your communications network is available, fast and secure.

Ethernet Networking Principles

Ethernet Networking Principles Ethernet Switches

Industrial and Utility Networking Modern Utility and Industrial sites have evolved into complex operations that perform many functions and require a wide variety of devices and controls to work properly and safely. To automate these environments, these devices need to work in close concert. Today, organizations are moving from coordinating these devices using low-speed serial connections, to implementing high-performance networks built from Optical, Wireless, and Ethernet technologies. These modern networks enable quick, reliable communications that allow critical devices to be managed, analyzed, or controlled from a single location. Taking the next step from automating a single site, organizations have begun to interconnect their various facilities to create larger, high-speed networks that allow control and monitoring from any location attached to the network. Many different technologies can be used to network together different sites. Over the past decade, Ethernet has become a popular networking technology because of its low cost , high bandwidth, and versatile support for multiple applications such as voice, video, and data. Ethernet Networks provide the following benefits: • Any-to-any connectivity: Ethernet networks support both point-to-point and multipoint connections between devices. This means that once a device is connected to the network, it can be set up to communicate with any other devices on the network to allow management and control of any device from any location. • Shared Access Network: With support for multiple types of applications and protocols, Ethernet networks provide the ability to run many different applications using a single infrastructure. • Economical use of bandwidth: Ethernet is designed to dynamically use bandwidth for whatever application needs it most, so that when an application is not using bandwidth, that bandwidth can be used by other applications that do need it. Voice

SCADA

Video

On-site Access

• Network security and management: Because Ethernet is the “default standard” for industrial and IT networking, it provides network security with support for the latest secure authentication standards, such as 802.1x and TACACS+, as well as rich network management and analysis support using Simple Network Management Protocol (SNMP), Remote Monitoring (RMON), and Port Mirroring. • Traffic prioritization and separation: to ensure critical traffic and applications are given preference over non-critical ones, Ethernet is designed to support traffic prioritization and Quality-of-Service (QoS) standards, such as 802.1p. Ethernet also allows traffic optimization using Virtual LANs (VLANs) to separate traffic from different sets of devices in order to reduce network congestion and increase performance. Low Priority Data Collection Low Priority

High Priority Management

Top Priority

Top Priority Control

Industrial Ethernet Industrial Automation environments, such as industrial locations or utility sites, often have special requirements or restrictions that need to be considered when designing a network. Typical considerations include: • Environmental Factors: unlike a home or office environment, industrial and utility networking often happens in uncontrolled or harsh environments. Resistance to extremes of hot and cold, and in some cases, to corrosive atmospheres, must be considered when choosing equipment for these networks. As well, electromagnetic interference (EMF) from nearby machinery or other equipment must not interfere with network devices and cables. • Standards Compliance: for many projects, compliance to industryspecific standards may apply. From regulatory requirements such RoHS (Restriction of Hazardous Substances), industry specification to IEC 61850 and NERC CIP for utilities, to UL/CUL and ISA99 for industrial protection, industrial standards support may be a requirement for Ethernet equipment. • Reliability & Recovery: due to the critical nature of industrial and utility control schemes, devices have to be continually accessible via redundant paths, and if a fault does occur, the network needs to be able to recover and seamlessly resume connectivity.

Ethernet Network

Network Fault recovery using Multilink SMART RSTP Protection and Control Relays • Support for multiple media types: Ethernet technology has specifications for multiple media types, so that users can take advantage of inexpensive and readily available copper cabling where suitable, but can also take advantage of the long-distances and resistance to electrical interference available from optical cabling.

Less than 5 milliseconds per hop 670

High Priority

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Ethernet Networking Principles

• Security and Auditing: with increasing requirements from regulatory bodies as well as corporate IT policies, Industrial Ethernet applications need to ensure they offer a robust and usable set of security functions, as well as the ability to validate security and provide tracking of activities on the network.

MultiLink switches are designed and tested in the same environment as all GE Multilin relays and protection devices. In addition to physical considerations such as temperature, humidity, EMF, and chemical corrosion, MultiLink switches are built with intelligent recovery options to quickly and seamlessly retain network integrity after any type of disruption. This ensures a solution that keeps your critical infrastructure available and online all the time. • Certification: MultiLink switches are compliant with all major International Standards for networking communications including: UL Listed/CE Agency Approved, IEC 61850-3, IEE 1613, NEBS Level 3, ETSI Certified, NEMA TS2, MIL-STD-167. MultiLink switches also provide options for RoHS-compliant hardware. • Harsh Chemical Environment Option: All MultiLink switches can be optionally configured to include a conformal coating that ensures product function and viability in corrosive or other environments that can damage typical electronic equipment. • Redundant Power Supplies: MultiLink’s ML2400 Managed Switch provides options for full power redundancy with support for two power supplies. These power supplies can be of the same type, or of mixed voltage types to ensure even greater reliability through diverse power sources.

• Legacy Devices: not all devices that need to be networked have standard Ethernet interfaces. In many cases, older legacy equipment with basic I/O or serial interfaces may need to be integrated into the network. These can often be added to the network using protocol converters, or switches with serial port servers.

• Continuous end-device connectivity with Link-Loss Alert: When used in conjunction with GE Multilin’s Universal Relay (UR) or the F650 families of relays, MultiLink switches can compensate for situations where only the relay’s transmitter fiber cable is broken. Upon detection of the broken Transmit fiber, the ML2400 will cease sending a link pulse to the relay’s Receive fiber cable, thereby allowing the relay to switch to its secondary port. The Link Loss Alert feature is available on both the 10Mbit and 100Mbit fiber optic ports, thus allowing for recovery of a single broken fiber connected to any GE Multilin relay.

GE MultiLink Switch Advantages GE’s MultiLink family of switches are built and designed with industrial and utility use in mind. From physical hardening and network resilience, to support for industrial protocols and legacy device types, to compliance with regulatory standards and support for the latest in network management and security functions, MultiLink provides a simple, flexible solution that can meet the needs of almost any critical project. Link Loss Alert allows recovery from a broken fiber connection in both 10Mbit and 100Mbit applications

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Ethernet Switches

• Traffic Management: because of the critical nature of industrial and utility applications, Ethernet networks for these environments need to have measures in place to ensure that wherever possible, network traffic between devices and applications that do not need to know about each other is kept to a minimum. In addition, because these networks are generally used for more than one purpose, data for critical applications needs to be ensured of performance and priority at all times

Physically Hardened, Network-Reliable

Ethernet Networking Principles

Ethernet Switches

• Fast Fault Recovery with RSTP and Smart RSTP: MultiLink switches provide the industry standard in performance for meshed or multi-vendor switched networks by providing support for the latest version of the IEEE 802.1w protocol for Rapid Spanning Tree. Using RSTP, MultiLink switches will quickly eliminate loops or redundant paths in network architectures and reconfigure the network to these redundant paths in the event of a fault occurring in the primary path. For even faster performance, users can build their network on a ring of GE MultiLink switches and utilize MultiLink’s exclusive Smart RSTP feature to create networks with fault recovery times of just milliseconds per hop.

• 802.1x with RADIUS & TACACS+ support for authentication: 802.1x can be used on MultiLink switches to provide additional security against unauthorized devices connecting to the switch. When activated, only authorized user who authenticated against the switch port can access the network. On Multilink switches, 802.1x can be configured to work in conjunction with an authentication server, such as TACACS+ or RADIUS. • Secure and Encrypted Management with SNMPv3: For secure management and control, MultiLink switches come equipped with support for Simple Network Management Protocol. SMNPv3 includes encryption for a high level of security not found in the previous versions that utilize both encryption and authentication of all management functions, as well as compliance with SNMPv1 and SNMPv2. • SMTP Email Alerts: All MultiLink managed switches can be configured to send Email notification that will provide warnings of unauthorized network access attempts or other critical events to System Administration personnel, which can be used to help enable real-time visibility and administrator responsiveness to network activity. • Complete Event Logging for all switch changes: To help enable forensic and regulatory auditing and reporting, MultiLink’s Event Log will store and timestamp all configuration changes and network problems detected by the switch. This data can be used to analyze network problems and provide traceability to network configuration changes.

Managed Networks for Intelligent Traffic Planning Example of Network Fault recovery testing using MultiLink SMART RSTP in a Ring Network Architecture.

Network Security for Critical Cyber Protection In today’s environments, any industry where communications networks run mission critical applications has an increasingly urgent need for cyber security as an integrated part of their networking strategy. The electric utility, transportation, military, and industrial markets have special needs not found in traditional IT applications. MultiLink switches are designed with security features and functions tailored to these industries, providing robust, usable network security as well as helping enable compliance with regulatory standards for many regions and industries. • Secure Management via SSL support: MultiLink switches ensure secure configuration and management by providing SSL encryption anytime users connect to the switch using Web Management Interface. SSL is the same technology used by financial institutions to ensure all transactions are secure and free from eavesdropping or interception. • Remote Access Security: Remote Access Security ensures that only specified users have access to the Switch’s management functions. Once configured, commands sent to the Switch through the Web Interface, Telnet connection, or via SNMP device, will only be accepted from specified MAC addresses. • Multi-level Password Control: Multi-level Passwords enhance security by providing different levels of privilege and command for different users or groups of users.

Multilink switches include a full suite of managed Ethernet features to provide visibility into network performance, and diagnostic tools to enable troubleshooting as well as proactive network planning. These tools help ensure continuous optimized function of the network and its critical applications. • SNMPv3: With full support for SNMPv3, MultiLink switches are ready to operate in harmony with any standards-compliant network devices or Network Management Systems (NMS) that may exist in your infrastructure • 802.1q: In order to help keep network traffic between devices and applications that do not need to know about each other minimized and optimize network performance and security, MultiLink switch provide support for Virtual Local Area Networks (VLANs) with compliance to IEEE 802.1q. VLANs allow separation of a larger physical network into smaller Virtual networks restrict network traffic to only VLAN on which it resides, preventing excess traffic from crowding the network, improving bandwidth allocation and optimizing network efficiency. • QoS: In order to ensure high network performance for critical applications and data, MultiLink switches offer Quality of Service (QoS) in compliance to IEEE 802.1p. By defining certain switch ports, or certain traffic types, with different priority levels, 802.1p prioritizes network flows so that critical data is allowed to jump ahead of normal network traffic passing through the switch at the same time. Network traffic priority classification can be made by Port, by Tag or by IP Type of Service (ToS).

• Port Security: Port Security prevents unauthorized access to the network by validating network traffic entering each port to a list of acceptable MAC addresses. If an unauthorized device is connected to any port on the switch, the device will be refused connection by the Port Security feature. The list of accepted devices can be entered by a system manager, or learned and controlled by the MultiLink Switch itself.

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Ethernet Networking Principles

• RMON: For additional management and monitoring, MultiLink managed switches comply with the Remote Monitoring (RMON) specification. RMON provides statistics and data exchange to remote sites for the purpose of network planning and network fault diagnosis.

Ethernet Switches

• IPv6 Support: With support for IPv6, MultiLink switches are ready to be used with extremely large networks and to integrate with next-generation network addressing schemes and protocols. • Alarm Contact: MultiLink switches provide 2 Alarm contacts that can be used for identifying problems with the network or networking devices. The hardware alarm contact will change state upon the loss of control power or upon detecting of a critical problem with hardware within the switch. The software alarm contact can be configured to change state upon the detection of several user configurable events including, loss of one or more communication ports, detection of a broadcast storm, or illegal network access attempts. Viewpoint Monitoring provides monitoring of the status of all network ports, indication of network problems and alarming of unauthorized network access attempts. • IGMP Snooping: By using the Internet Group Management Protocol (IGMP) Snooping feature, MultiLink users can prune their networks from unnecessary multicast activity. IGMP Snooping reduces the amount of multicast traffic crowding the network by restricting these messages only to the ports that need to receive this data.

MultiLink switches provide 2 alarm contacts that can be used to identify problems with devices or the network

• Port Mirroring: To help analyze and optimize network links and traffic, MultiLink users can enable the Port Mirroring feature. This feature allows all of the traffic on any given port to be duplicated on a selected second port, so it can be monitored and analyzed to help troubleshooting the network and ensure the whole system behaves as required

• Integrates with Viewpoint Monitoring: MultiLink switches are integrated into GE’s Viewpoint Monitoring software that allows for monitoring of all network and switch data in a local HMI. With Viewpoint Monitoring, users can monitor the status of all network ports, generate alarms for network problems, and diagnose the overall health of their entire communications network.

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Ethernet Networking Principles

Complete Event Logging for all Switch Changes

Simple Configuration and System Integration

To help enable forensic and regulatory auditing and reporting, MultiLink’s Event Log will store and timestamp all configuration changes and network problems detected by the switch. This data can be used to analyze network problems and provide traceability to network configuration changes.

• IP Out-of-the-Box: For ease of initial configuration, MultiLink managed switches are programmed to automatically have an IP address preassigned when the switch is powered on for the first time. In addition, MultiLink also comes configured as a DHCP client for those who want to immediately connect it to the network and configure it from there.

Ethernet Switches

• Secure Web Management: Multilink managed switches include a graphical Web Management interface for configuration and monitoring. The Web Manager allows configuring and monitoring of switches from any authorized device in your network with just a few simple clicks. • Multiple Configurations/Interface Options: For maximum flexibility and interconnectivity with devices, MultiLink switches are designed with a modular platform to allow flexible configuration of multiple media types on each Switch. MultiLink switches can be configured with front- or rear-mounted ports, and supports RJ-45 copper as well fiber optic ports with ST, SC, LC, and/or MTRJ connectors. All MultiLink port types provide options from 10Mbps to Gigabit speed. • Support for Industrial Protocols: Because they are designed with industrial and utility applications in mind, MutiLink switches are equipped with default support for Modbus devices by compliance to the Modbus TCP specification. MultiLink networks can be further extended to almost any other serial device using the MultiNet family of serial-to-Ethernet protocol converters.

Monitor traffic statistics such as usage and traffic type using intuitive bar graph representations

Use the Event Log to analyse network problems and provide traceability to network configuration changes

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MultiLink™ Hardened Ethernet Switches Ethernet Communications for Industrial Automation, Power Utility & Traffic Control Markets The MultiLink family is a superior line of Hardened Ethernet Switches that has the flexibility and features to fit all of your Industrial, Substation, and Transportation Networking needs. The MultiLink line of Managed and Unmanaged switches are designed for the unique needs of the protection and control industry and are unsurpassed in the areas of Network Security, Industrial Robustness and Network Reliability. The EnerVista Suite of Software products that support the MultiLink switches will simplify the configuration and diagnosing of your MultiLink switches and allow the data and alarms from your MultiLinks to be integrated into your monitoring and control systems.

Key Benefits • Physically hardened and environmentally ruggedized for reliability in harsh environments • Harsh chemical environment option available for circumstances that are corrosive or otherwise damaging to electronic equipment • Enables cyber protection and network integrity with advanced security features • Forensic auditing of activities and changes using event logging

Managed Networks • Supports SNMPv3, with full backwards compatibility for v1 & v2 • Traffic segregation and prioritization control via IEEE® 802.1p & IEEE 802.1Q • Hardware and software alarm contacts for detection of critical network or switch events • Fully integrates with Viewpoint Monitoring software

Ease of Use • Support for industrial protocols • IP out-of-the-box for easy installation • Simple but powerful web management interface for all configuration functions

Secure • Secure management via SSL

• Flexible options for Ethernet port and media types allow integration into any project requirement

• Port security prevents unauthorized devices gaining access to the network

• Supports intelligent traffic planning and integration with network management systems using a complete set of Ethernet switch management functions

• Multi-level passwords with levels of privilege and command for different users or groups

• Support for high speed recovery of redundant LANs for mission-critical applications Simple, powerful, and easy configuration using web management software

• Complete event logging for forensic and regulatory auditing and reporting

• Fully supported and viewable using EnerVista™ Viewpoint Monitoring

Applications • Safely and reliably extends Ethernet networks to harsh production environments for utility and industrial applications • Allows critical devices to be managed, analyzed, or controlled from a single location • Enables high speed, redundant connections to GE Universal Relays

Industrially Hardened • UL® listed/CE agency approved • IEC® 61850 & IEEE 1613 for operation in electric substation environments • Redundant and mixed power supply options for increased reliability • Harsh chemical environment options ensures product function and viability • RoHS (Reduction of Hazardous Substances) compliant

MultiLink™ Hardened ethernet switches

Ethernet Switches Designed for the Unique Needs of Critical Infrastructures

Ethernet Switches

Designed for the Needs of Protective Relaying The MultiLink Ethernet Switches have been designed for the specific requirements of devices used in utility and industrial environments, such as protective relays. MultiLink Ethernet Switches support many unique features that allow for full redundancy under network fault conditions.

Link Loss Alert The MultiLink Ethernet Switch family’s Link Loss Alert feature allows for protective relays to recover from situations where only one of the fiber cables connected to the relay is damaged. The Link Loss Alert feature works with both 10Mbit and 100Mbit fiber ports of GE’s Multilin™ Universal Relay, and allows for seamless switching to the relay’s secondary port under all network fault conditions.

Modbus Protocol Support Identifying network communication problems and retrieving network statistics from the MultiLink Ethernet Switches can now be achieved in SCADA or DCS systems through the use of the supported Modbus TCP/IP protocol. Modbus is a protocol supported by most Human Machine Interfaces and PLC’s and can therefore be integrated into existing systems without having to invest in additional SNMP or other Network Management Software.

Enhanced High Speed Recovery of Redundant Ring Networks The unique requirements of the Protection and Control Industry require Ethernet networks to be more reliable and to recover from network problems faster than is generally accepted in other commercially available equipment. The MultiLink Ethernet Switch's SMART RSTP feature allows for recovery from faults in ring network architectures in less than 5 milliseconds per switch in the network – 10 times faster than generally available in standard Ethernet switches.

Link Loss Alert allows recovery from a broken fiber connection in both 10Mbit and 100Mbit applications.

Network Fault Recovery Using MultiLink Ethernet Switches Network Traffic Generator

Fault Between Switches

Recovery Time Per Switch (Hop)

SW1-SW2

1.90 ms

SW2-SW3

2.12 ms

SW3-SW4

2.11 ms

SW4-SW5

2.29 ms

SW5-SW6

1.95 ms

SW6-SW7

2.06 ms

SW7-SW8

2.18 ms

SW8-SW9

1.82 ms

SW9-SW10

2.27 ms

SW10-SW1

0.00 ms

Network recovery times.

Example of network fault recovery testing using MultiLink SMART RSTP in a ring network architecture.

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MultiLink™ Hardened ethernet switches

Robust Ethernet Switches for Providing Secure and Reliable Networks Ideal for Harsh Environments

• Operating temperature -40°C to +85°C without fans • Type tested to IEC 61850-3, IEEE 1613 Class 2, NEBS level 3 substation requirements

The MultiLink Ethernet Switches support most 802.1 network management features and are configurable using the Command Line Interface (CLI) and through our web management interface. Management functionality includes: • SNMPv3 for secure configuration of network switches • Full support of the CLI commands • Web management interface for user-friendly configuration and monitoring

• IP40 Rated

• RSTP (802.1w) industry standard method for providing recovery of redundant networks

• Dual power supply option with the ability to mix the input sources used (i.e. 48 VDC and 125 VDC)

• SMART RSTP (ring only mode) for enhanced fast recovery (<5ms/hop) of ring architecture networks

Enhanced Security

• RMON for monitoring of network status and statistics

The MultiLink family of Ethernet Switches have implemented the most advanced techniques available for providing security in network communications including:

• VLAN (802.1Q) providing the ability of segregating the network into smaller virtual networks (up to 256) • QoS- (802.1Q) for prioritization of network traffic

• SNMP v1/v2/v3 supplying secure access to network devices through authentication, and encryption

• Port mirroring, assisting network troubleshooting

• Imbedded RADIUS and TACACS+ security for remote access and password verification

• SNTP for synchronizing the switch’s internal clock

• SSL web encryption preventing eavesdropping, tampering or message forgery • Port security through the disabling of packets from unauthorized MAC addresses

Ethernet Switches

GE's MultiLink Ethernet Switches have been tested and certified to meet the same rigorous environmental standards as all of our protection relays and meters.

Full Network Management Capabilities

• IGMP snooping, enabling reductions in multicast traffic • SMTP providing email notification when problems in the network have occurred • Event logs creating a historical record of events occurring on the network • IPv6 support, allowing for more addressable devices in a network

• Logging of events and sending email notification of unauthorized access attempts

EnerVista Viewpoint Monitoring and Integrator Supported The MultiLink Ethernet Switches are fully supported by the EnerVista Viewpoint Monitoring and Integrator software packages, allowing integration of LAN status, network alarm problems, and security alerts into your monitoring and control system.

EnerVista Viewpoint Monitoring provides monitoring of the status of all network ports, indication of network problems and alarming of unauthorized network access attempts.

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MultiLink™ Hardened ethernet switches

EnerVista Web Interface Provides User-Friendly Configuration and Network Monitoring Easy-to-Use Web Configuration and Reporting Software

Ethernet Switches

The EnerVista Web configuration software allows programming of all settings in the MultiLink Ethernet Switches using a simple web browser. Accessible by typing the pre-configured IP address of your switch into the address bar of a web browser, the user-friendly graphical interface allows for easy navigation, monitoring and configuration through simple point and click operations.

Communication Status & Port Navigation • Instant graphical indication of the status of all communication ports • Identify the configuration of all communication parameters • The ability to click on any of the shown Ethernet terminals to jump immediately to the settings screen for that port

Intuitive Menu-Driven Configuration • Navigate through configuration screens using an easy to understand categorized menu tree • Configure all settings using menu-driven pull-down fields • Program alarm triggers by selecting from a list of all possible conditions • Eliminate the need to memorize any CLI commands

Powerful Troubleshooting Statistics • Monitor traffic statistics using intuitive bar graph representations • Identify the amount and type of traffic sent and received through each port of the switch • Simplify troubleshooting by identifying the number of CRC errors, collisions, and dropped packets occurring on each port • Clear and restart the capturing of port statistics to allow for the troubleshooting of specific network problems

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MultiLink™ Hardened ethernet switches

Managed Switches The MultiLink ML3000 Series, ML2400, ML1600, ML1200, ML810 and ML800 Managed Ethernet Switches provide extremely reliable networks with very fast reconfiguration times for recovering from faults occurring in the network. The complete set of network management functions available provides the configurability and monitoring capability needed for most applications, while the high level of security features available ensures your network is protected from tampering or illegal access. Ethernet Switches

ML3000 Series

ML810

ML3000 Series supports (model dependent): Up to 32 ports 10/100 Mbit copper RJ45 Up to 16 ports 10 or 100 Mbit fiber Up to 8 ports GigE fiber or copper Up to 18 fiber ports depending on configuration 1588v2 timing Redundant power supplies Field replaceable power supply models available

ML810 supports: 8 ports 10/100 Mbit copper RJ45 4 ports LC, ST, SC or MTRJ fiber 2 ports 1 Gbit fiber or copper RJ45

Unmanaged Compact Switch

PORT TYPE

TYPICAL DISTANCE

POWER BUDGET

10/100 Mbit RJ45 Copper

100 m

N/A

10 Mbit Multimode ST Fiber Optic

2 km

17 dB

100 Mbit Multimode ST Fiber Optic

2 km

14 dB

100 Mbit Multimode SC Fiber Optic

2 km

14 dB

100 Mbit Singlemode SC Fiber Optic

20 km

17.5 dB

100 Mbit Singlemode SC Fiber Optic

40 km

17.5 dB

100 Mbit Multimode LC Fiber Optic

2 km

14 dB

100 Mbit Singlemode LC Fiber Optic

15 km

17.5 dB

100 Mbit Multimode MTRJ Fiber Optic

2 km

14 dB

1 Gbit RJ45 Copper

100 m

N/A

1 Gbit Multimode SC Fiber Optic

2 km

12.5 dB

1 Gbit Singlemode 1310nm SC Fiber Optic

10 km

10.5 dB

1 Gbit Singlemode 1310nm SC Fiber Optic

25 km

17.5 dB

1 Gbit Singlemode 1550nm SC Fiber Optic

40 km

17.5 dB

ML600 supports:

1 Gbit Singlemode 1550nm SC Fiber Optic

70 km

20.5 dB

6 ports 10/100 Mbit copper RJ45 2 ports 100 Mbit ST, or SC fiber High voltage AC power supply

100 Mbit Multimode MTRJ Fiber Optic

2 km

15.8 dB

The ML600 Unmanaged Ethernet Switch provides the ability to connect remote sites or stations that contain few Ethernet devices to your local network in a cost effective manner. The ML600 can be configured with several different port configurations allowing for use with many different device types and can be connected to other Ethernet switches, forming a ring architecture that provides redundancy throughout your critical networks.

ML600

Port Selector Guide

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MultiLink™ Hardened ethernet switches 17.5" (44.4 cm)

ML3000 Series

12.1" (30.7 cm)

Supports up to 16, 10 or 100Mbit, ST, SC, LC or MTRJ Fiber Ports 1.74" (4.4 cm)

Ethernet Switches

Supports up to 8 Ports Gigabit Copper or Fiber and 1588v2 Timing

Supports up to 36 Ports Copper RJ45

Ordering

ML3000

Mounting

Power Supply

Gigabit

*

F B

GigE 1 2 * *

** HX HH LX LL P1 P2 HL

A B C D E F G H J K L M N P Q R X

100Mbps

A B C D E F G H J K L M N P Q R X

Coating

ML3100

Mounting Power Supply

Gigabit

100Mbps

Environment

680

*

F B

** HX HH LX LL P1 P2 HL

3 *

4 *

5 *

A B C D E F G H J K L M N P Q R S T U W Y Z X

A B C D E F G H J K L M N P Q R S T U W Y Z X

A B C D E F G H J K L M N P Q R S T U W Y Z X

GigE 1 2 3 4 * * * *

A A A B B B C C C D D D E E E F F F G G G X X X

A B C D E F G X

10 or 100Mbps 6 7 8 * * *

A B C D E F G H J K L M N P Q R S T U W Y Z X

5 *

100Mbps 6 7 8 * * *

A C D E F G H J K L M N P Q R S T U W Y Z X

A C D E F G H J K L M N P Q R S T U W Y Z X

A C D E F G H J K L M N P Q R S T U W Y Z X

A C D E F G H J K L M N P Q R S T U W Y Z X

A B C D E F G H J K L M N P Q R S T U W Y Z X

A B C D E F G H J K L M N P Q R S T U W Y Z X

9 *

10 *

A B C D E F G H J K L M N P Q R S T U W Y Z X

A B C D E F G H J K L M N P Q R S T U W Y Z X

*

X H

ML3000 Chassis with Fixed Power Supplies

Front Mounted Ports Rear Mounted Ports Single Integrated 90 to 250V AC/DC Power Supply Dual Integrated 90 to 250V AC/DC Power Supplies Single Integrated 22 to 60 VDC Power Supply Dual Integrated 22 to 60 VDC Power Supplies Single Integrated 22 to 60 VDC Power Supply with PoE Support Dual Integrated 22 to 60 VDC Power Supply with PoE Support Combination of a 90 to 250V AC/DC and a 22 to 60 VDC Power Supply 2 x 1000 Mbits RJ45 Fixed Ports 2 x 1000 Mbit SFP, LC Connector, Multimode Fiber, 550m 2 x 1000 Mbit SFP, LC Connector, Singlemode Fiber, 2km 2 x 1000 Mbit SFP, LC Connector, Singlemode Fiber, 10km 2 x 1000 Mbit SFP, LC Connector, Singlemode Fiber, 25km 2 x 1000 Mbit SFP, LC Connector, Singlemode Fiber, 40km 2 x 1000 Mbit SFP, LC Connector, Singlemode Fiber, 70km 2 x 1000 Mbit SFP Ports (No Transceivers) Empty Cage 2x 1000 Mbit RJ-45 Fixed Ports with 1588 Timing 2x 1000 Mbit SFP, LC Connector, Multimode Fiber, 550m with 1588 Timing 2x 1000 Mbit SFP, LC Connector, Singlemode Fiber, 2km with 1588 Timing 2x 1000 Mbit SFP, LC Connector, Singlemode Fiber, 10km with 1588 Timing 2x 1000 Mbit SFP, LC Connector, Singlemode Fiber, 25km with 1588 Timing 2x 1000 Mbit SFP, LC Connector, Singlemode Fiber, 40km with 1588 Timing 2x 1000 Mbit SFP, LC Connector, Singlemode Fiber, 70km with 1588 Timing 2x 1000 Mbit SFP ports (no transceivers) empty cage with 1588 Timing None 4 x 10/100 Mbit - RJ45 Copper 4 x 10/100 Mbit - RJ45 Copper with PoE* 4 x 10/100 Mbit - RJ45 Copper with PoE+* 2 x 10Mbit - ST 2 x 100Mbit - ST Multimode Fiber 2 x 100Mbit - SC Multimode Fiber 4 x 100Mbit - LC Multimode Fiber 4 x 100Mbit - MTRJ Multimode Fiber 2 x 100Mbit - SC Singlemode Fiber 20km 4 x 100Mbit - LC Singlemode Fiber 20km 2 x 100Mbit - SC Singlemode Fiber 40km 4 x 100Mbit - LC Singlemode Fiber 40km 4 x 100Mbit SFP Ports (No Transceivers) Empty Cage 4x 10/100 Mbit - RJ45 Copper with 1588 Timing 2x 100Mbit - ST Multimode Fiber with 1588 Timing 2x 100Mbit - SC Multimode Fiber with 1588 Timing 4x 100Mbit - LC Multimode Fiber with 1588 Timing 4x 100Mbit - MTRJ Multimode Fiber with 1588 Timing 4x 100Mbit - LC Singlemode Fiber 20km with 1588 Timing 2x 100Mbit - ST Singlemode Fiber 20km with 1588 Timing 2x 100Mbit - SC Singlemode Fiber 20km with 1588 Timing 4x 100Mbit - LC Singlemode Fiber 40km with 1588 Timing None None Harsh Chemical Environment Conformal Coating

* ML3100 Chassis with Integrated Power Supplies

Front Mounted Ports Rear Mounted Ports Single Integrated 90 to 250V AC/DC Power Supply Dual Integrated 90 to 250V AC/DC Power Supplies Single Integrated 22 to 60 VDC Power Supply Dual Integrated 22 to 60 VDC Power Supplies Single Integrated 22 to 60 VDC Power Supply with PoE Support Dual Integrated 22 to 60 VDC Power Supply with PoE Support Combination of a 90 to 250V AC/DC and a 22 to 60 VDC Power Supply 2 x 1000 RJ45 or SFP Combo Ports, Ports are Auto-Detect, No SFT Transceivers, with 1588 Timing 2 x 1000 RJ45 or SFP Combo Ports, Populated with 2 x SFP Multimode Fiber, 550m , with 1588 Timing 2 x 1000 RJ45 or SFP Combo Ports, Populated with 2 x SFP Singlemode Fiber, 2km, with 1588 Timing 2 x 1000 RJ45 or SFP Combo Ports, Populated with 2 x SFP Singlemode Fiber, 10km, with 1588 Timing 2 x 1000 RJ45 or SFP Combo Ports, Populated with 2 x SFP Singlemode Fiber, 25km, with 1588 Timing 2 x 1000 RJ45 or SFP Combo Ports, Populated with 2 x SFP Singlemode Fiber, 40km, with 1588 Timing 2 x 1000 RJ45 or SFP Combo Ports, Populated with 2 x SFP Singlemode Fiber, 70km, with 1588 Timing None 4 x 10/100Mbit - RJ45 Copper 4 x 10/100Mbit - RJ45 Copper with PoE+* 2 x 10Mbit - ST 2 x 100Mbit - ST Multimode Fiber 2 x 100Mbit - SC Multimode Fiber * The power source of the ML3000 must be in 4 x 100Mbit - LC Multimode Fiber the range of 45-57 VDC for PoE and 52-56 4 x 100Mbit - MTRJ Multimode Fiber VDC for PoE+. The power source of the 2 x 100Mbit - SC Singlemode Fiber 20km ML3100 must be in the range of 52-56 VDC 4 x 100Mbit - LC Singlemode Fiber 20km 2 x 100Mbit - SC Singlemode Fiber 40km for PoE+. PoE and PoE+ modules are only 4 x 100Mbit - LC Singlemode Fiber 40km supported on units ordered with P1 or P2 4 x 100Mbit SFP Ports (No Transceivers) Empty Cage power supply options. 4 x 10/100Mbit - RJ45 Copper with 1588 Timing  2 x 100Mbit - ST Multimode Fiber with 1588 Timing 2 x 100Mbit - SC Multimode Fiber with 1588 Timing Optional field replaceable power supplies are 4 x 100Mbit - LC Multimode Fiber with 1588 Timing available with models ML3001 and ML3101. 4 x 100Mbit - MTRJ Multimode Fiber with 1588 Timing Please see online store for the latest module 4 x 100Mbit - LC Singlemode Fiber 20km with 1588 Timing availability. 2 x 100Mbit - ST Singlemode Fiber 20km with 1588 Timing 2 x 100Mbit - SC Singlemode Fiber 20km with 1588 Timing 4 x 100Mbit - LC Singlemode Fiber 40km with 1588 Timing None X None H Harsh Chemical Environment Conformal Coating

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MultiLink™ Hardened ethernet switches

ML810 8” (20.3cm)

6” (15.2cm)

Ethernet Switches

1.75” (4.4cm)

Supports up to 2 Gbit Fiber or Copper Ports

Supports up to 4 100Mbit ST, SC, MTRJ, or LC Fiber Ports

Up to 10 Copper Ports supported

Ordering ML810 Power Supply

Mount SlotA SlotB

SlotC

Coating

-

** 250S 125S 48VS 48PS 24VS 12VS 125D 48VD 48PD 24VD 12VD HIAC

- ** -

P D

**

C1 C2

-

**

H1 H2 H3 H4 H5 H6 H7 XX

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**

C1 C2 C3 C4 C5 C6 C7 C8 CB CD CF CH CI CK E1 E2 E3 E4 E5 E6 E7 E8 EA EB EC ED EH EJ EK EL EM X

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**

Base Unit

X H

ML810 250VDC Chassis ML810 125VDC Chassis ML810 48VDC Chassis ML810 48VDC Chassis with PoE enabled ML810 24VDC Chassis ML810 12VDC Chassis ML810 125VDC Chassis - Dual Input PSU ML810 48VDC Chassis - Dual Input PSU ML810 48VDC Chassis with PoE enabled - Dual Input PSU ML810 24VDC Chassis - Dual Input PSU ML810 12VDC Chassis - Dual Input PSU ML810 100 - 240 VAC Panel Mount Kit DIN Mount Kit 4x 10/100 RJ45 4x 10/100 RJ45 PoE-enabled ports (only with ML810-48PD models) 2x 1000Mb LC mm Fiber, SFP connector type 2x 1000Mb LC mm Fiber 2km, SFP connector type 2x 1000Mb LC sm Fiber 10km, SFP connector type 2x 1000Mb LC sm Fiber 25km, SFP connector type 2x 1000Mb LC sm Fiber 40km, SFP connector type 2x 1000Mb LC sm Fiber 70km, SFP connector type 2x 10/100/1000TX RJ45, fixed copper None 4x 10/100 RJ45 4x 10/100 RJ45 PoE-enabled ports (only with ML810-48PD models) 2x 10/100 RJ45 + 2x 100Mbit MTRJ mm Fiber 2x 10/100 RJ45 + 2x 100Mbit LC mm Fiber 2x 10/100 RJ45 + 2x 100Mbit LC sm Fiber 20km 2x 10/100 RJ45 + 2x 100Mbit SC mm Fiber 2x 10/100 RJ45 + 2x 100Mbit SC sm 20km Fiber 2x 10/100 RJ45 + 2x 100Mbit ST mm Fiber 3x 10/100 RJ45 + 1x 100Mbit MTRJ mm Fiber 3x 10/100RJ45 + 1x 100Mbit LC mm Fiber 3x 10/100RJ45 + 1x 100Mbit LC sm 20km Fiber 3x 10/100RJ45 + 1x 100Mbit LC sm 40km Fiber 2x 10/100 RJ45 + 2x 100Mbit LC sm Fiber 40km 2x 10/100 RJ45 + 2x 100Mbit SC sm Fiber 40km 4x 100Mbit ST mm Fiber 4x 100Mbit SC mm Fiber 4x 100Mbit MTRJ mm Fiber 4x 100Mbit LC mm Fiber 4x 100Mbit SC sm 20km Fiber 4x 100Mbit LC sm 20km Fiber 4x 100Mbit SC sm 40km Fiber 4x 100Mbit LC sm 40km Fiber 1x 100Mbit MTRJ mm Fiber 1x 100Mbit LC mm Fiber 1x 100Mbit LC sm 20km Fiber 1x 100Mbit LC sm 40km Fiber 3x 100Mbit LC mm + 1x 100Mbit sm 20km Fiber 2x 100Mbit LC mm + 2x 100Mbit sm 20km Fiber 2x 10/100 RJ45 + 1x 100Mbit LC mm + 1x 100Mbit sm 20km Fiber 2x 10FL + 2x 100FX ST (2km) 4x 10FL None none Harsh Chemical Environmental Option

Additional modules and configurations available. Please see the Online Store for the latest module availability.

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681

ML600 3.0" (7.6 cm)

1.7" (4.3 cm)

3.6" (9.2 cm)

6 - 10/100 Mbit Copper RJ45 Ports Supports up to 6 - 10/100 Mbit Copper RJ45 Ports

Supports up to 2 - 100 Mbit ST, or SC Fiber Ports

4 - 10/100 Mbit Copper RJ45 Ports 2 - 100 Mbit ST, or SC Fiber Ports Additional modules and configurations available. Please see the Online Store for the latest module availability.

Ordering ML600

Power Supply

Modules

Conformal Coating Option

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**

AC 48 24

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**

-

XX B1 B2 B3 B4

**

X H Z Y

Base Unit

External 100 - 240 VAC Adaptor 30 - 60 VDC Power Supply 10 - 36 VDC Power Supply None 6 x 10/100 Mbit - RJ45 Copper 2 x 100 Mbit - ST mm Fiber + 4 x 10/100 Mbit - RJ45 Copper 2 x 100 Mbit - SC mm Fiber + 4 x 10/100 Mbit - RJ45 Copper 2 x 100 Mbit - SC sm Fiber + 4 x 10/100 Mbit - RJ45 Copper Standard Environment Harsh Chemical Environment Conformal Coating ROHS Compliant ROHS Compliant with Harsh Chemical Environment Conformal Coating

Accessories for MultiLink Switches   •  Industrial Power System Communications Learning CD

TRCD-ICOM-C-S-1

  •  MultiNet Serial to Ethernet Converter

MultiNet-FE

 • EnerVista Integrator

EVI-1000

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Media & Protocol Converters Media & Protocol Converters Overview Purpose-built for extremely harsh environments such as power utility substations with offering that meet IEEE1613 and IEC 61850-3 specifications for EMI/ESD protection, GE media and protocol converters are ready for almost any location challenge. From industrially-hardened managed routers to multi-port serial servers and to protocol converters, GE’s suite of communications modules allow connection of substation protection and control equipment to a variety of networks.

Product Listing

Media & Protocol Converters – Product Listing Media & Protocol Converters

Multinet1000

Router and Multi-Port Serial Server The MultiNet 1000 Managed Router is an industrial-hardened, multipurpose networking appliance that combines a serial port server, a managed switch, and a full-featured WAN & Ethernet Router into a single device. With support for IP routing, a full suite of managed switch features, and support for up to hundreds of serial devices, the MN1000 provides the flexibility to interconnect almost any network or device type, while offering reliability and rich cybersecurity features in an easy-to-use appliance.

Multinet4

Multi-Port Serial Server & Managed Switch MultiNet4 provides devices with serial ModBus to ModBus TCP/IP communications capability on an Ethernet network, allowing connection of up to 128 devices to LAN and WAN network systems via fiber or wire media.

Multinet

Serial-to-Ethernet Converter MultiNet is a communications module that provides GE Multilin serial ModBus IEDs with ModBus TCP/IP communications over Ethernet, allowing connection to fiber optic LAN and WAN network systems.

MC-E Series

MC-E10, MC-E100, MC-E1000 Ethernet Copper-to-Fiber Converters The MultiLink MC-E10, MC-E100, and MC-E1000 are a family of environmentally-hardened Ethernet Fiber media converters that include an integrated 2-port copper switch for device access. With options for a wide variety of AC and DC power supplies, as well as the ability to configure the fibre port type and speed, MultiLink Converters provide a flexible, robust, plug-and-play solution for extending your Ethernet network.

F485

Isolated RS232 to RS485 to Fiber Optic Converter The F485 is a self-contained device for converting between RS232, RS485 and fiber optic signals. The F485 is electrically isolated to improve communications in noisy environments.

USB2Serial

USB to Serial Cable Converter This cable is the solution for users who want to communicate with GE Multilin IEDs via PCs that have USB communication ports. Using this cable is quick and easy.

Go online for a full listing of all Multilin Media & Protocol Converter products GEDigitalEnergy.com/Converters

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Lentronics Fiber Optics Solutions Purpose-built for Secure and Dependable Communications Today’s complex, converged services networks need powerful, flexible and reliable communication solutions. GE Lentronics is a leading supplier of hardened multi-service telecommunications platforms, providing secure application performance over optical cable and other media from the network core to the edge. Lentronics Multiplexers and Switch/Routers are designed for reliable operation in extremely harsh environments making them perfectly suited for critical communications and asset protection. Their adherence to industrial communications safety and security standards mitigates the risks facing all types of organizations, to better protect critical assets, people, equipment and data.

Utility Hardened Designed and purpose-built for use in electric utility, pipeline, heavy industrial and transportation applications, the Lentronics family of fiber optic solutions are tested to harsh specifications. These include tolerance to extreme temperatures and electrical surges, as well as radio frequency and electromagnetic interference.

Flexible Because of their unique modular architecture, Lentronics Multiplexers and Switch/Routers integrate easily into existing networks, providing support for legacy requirements, as well as the latest telecommunication innovations. Lentronics solutions create a secure, segregated transport environment for mission critical applications and traditional business requirements. From Ethernet modules to serial, voice, data and specialty teleprotection interfaces, Lentronics fiber optic solutions offer a wide variety of telecommunication service choices to optimize the usefulness of your network.

Reliable & Scalable With their add/drop capability for new application connections and changes in network topology, coupled with the ability to provide Sx9 availability, Lentronics solutions seamlessly address network modifications with a minimum of downtime. Combined with a full suite of operations, management and administration tools, Lentronics Communications solutions can easily integrate with existing network management systems, providing real-time visibility and control.

Secure With robust, multi-level division of traffic, Lentronics Communications solutions provide simple, dependable security across network applications. In addition to separating traffic types into distinct transport “pipes”, they can also ensure segregation of critical data and applications from other network traffic using traffic classification and LAN division techniques. Combined with the ability to handle the latest in encrypted traffic types and event logging for security forensics, Lentronics fiber optic solutions offer a complete suite of security options to ensure the safety of your data and applications.

Comprehensive Suite Of Optical Networking Solutions & Management Tools

JunglePAX MPLS Switch/Router Platform MPLS-TP at 1G/10G JunglePAX is a converged High-Capacity Packet Transport and Access platform designed with purpose for network operations requiring mission-critical and time-sensitive communications within harsh utility environments. JunglePAX supports an optimized version of MPLS-TP for Teleprotection that also provides determinism for Operational and IT applications with security and dependability.



JungleMUX SONET Multiplexers OC-1/OC-3/OC-12/OC48 SONET Multiplexers delivers robust, secure wide area telecommunications over on optical cable infrastructure adhering to Telcordia SONET standards, supporting a wide array of applications in a reliable, secure manner.



TN1U SDH Multiplexers STM-1/STM-4/STM-16 SDH Multiplexers deliver robust, secure wide area telecommunications over on optical cable infrastructure adhering to ITU-T SDH standards, supporting a wide array of applications in a reliable, secure manner.



TN1Ue SDH Multiplexers STM-1/STM-4/STM-16 SDH Multiplexers delivers robust, secure wide area telecommunications over on optical cable infrastructure adhering to ITU-T SDH standards, supporting a wide array of applications in a reliable, secure manner. The enclosed shelf design provides additional security in sensitive electromagnetic interference (EMI) environments.



Lentronics T1MX and E1MX/E1MXe Multiplexers Electrical & Optical T1/E1 Lentronics T1 and E1 Multiplexers provide Voice. Data, Telemetry, Ethernet and Teleprotection client services over leased line, microwave radio, as well as dedicated copper or optical cable media. An integrated digital cross connect offers powerful traffic grooming options. Electrical and Optical ports are available, with Linear and E1 Ring support.



VistaNET Network Management System As a flexible NMS for all Lentronics Multiplexers, VistaNET can be provisioned as a standalone or a client­server LAN/WAN solution, permitting centralized or distributed network management. A complement of Security, Traffic Management and SNMP support is offered to further enhance the overall network management experience.

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MDS Industrial Strength Wireless Solutions Secure And Reliable Wireless Designed For Harsh Environments To enable today’s modern power grids and complex, converged services networks, utilities, industrial, and commercial customers are looking for flexible and reliable communication solutions. With a comprehensive suite of end-to-end wireless solutions, GE is a leading supplier of secure, long range, and high capacity wireless devices designed and tested to harsh environmental specifications. From wellhead monitoring to utility substation automation, our wireless networks carry serial and IP/Ethernet traffic, as well as analog and digital I/O signals connected directly to field devices and sensors, and supports an extensive range of industrial communications protocols.

Data Acquisition

LAN Extension

Backhaul

Our devices offer reliable long range communications for asset monitoring that provides signal regeneration of discrete I/O, precise timing for controller data transmission, and support for multiple protocols.

Our wireless solutions that extend your network into the field to provide full networking support for IP-based PLCs/RTUs, video surveillance, and field force automation applications.

When an alternative to fiber or copper is required, our devices offer secure, high capacity wireless backhaul solutions to carry up to 800 Mbps of data, voice, and video back to your operations center.

MDS Industrial Strength Wireless Solutions

Data Acquisition SD Series

Secure, Long Range IP/Ethernet The MDS SD Series provide high performance, long distance IP/Ethernet and serial communications over licensed radio bands from 150 to 960 MHz between remote devices such PLCs, RTUs or meters and host monitoring and control systems. The SD Series is backward compatible with previous MDS generations allowing for a smooth and controlled migration for existing systems.

NETio

Analog and Digital I/O Signal Communications The unlicensed MDS NETio family provides flexible I/O signal communication solutions on two levels. Protocol addressable I/O allows direct communication with remote I/O accommodating IP/Ethernet and serial protocols, without the need for a PLC or RTU. I/O extension allows regeneration signals between remote I/O points and monitoring/control devices, providing location-specific distance and point count requirements.

WiYZ

Intelligent Data Acquisition and Signal Communications

MDS

The MDS WiYZ implements standards-based mesh networking and allows both Ethernet and serial data collection for use in asset management, supply chain management, inventory control, and metering. With self-powered I/O and sensor data acquisition, the flexible WiYZ allows for cost effective deployment of both simple data acquisition and enterprise wide area networking.

MPRS Series

Master Stations The MDS Master Stations, built upon our modular communications platform, are used with SD Series and x710 series remote radios. The MDS Master Stations support full duplex communication in a protected 1+1 warm standby transceiver configuration to provide reliability for continuous use, high duty cycle applications associated with licensed narrowband Base Station and Repeater applications.

TransNET

Long Range, High Speed Serial Communications Today’s SCADA and Telemetry systems must transmit large amounts of data at ever increasing speeds. The MDS TransNET uses frequency hopping technology to provide a flexible wireless serial solution. Featuring a sleep mode that is well suited to solar-powered applications, store and forward capabilities, and unparalleled robustness, the TransNET sets new standards for reliable, long range wireless serial data transmission.

entraNET

Extended Range IP/Ethernet and Serial Networking The MDS entraNET is an exceptionally long range, unlicensed device offering robust performance in extreme environmental conditions. Sleep modes keep power consumption low for battery and solar applications. Both Ethernet and serial devices can communicate in peer-to-peer mode and connect to an IP network—all with multiple layers of cyber-security. The end result is reduced cost of deployment and a low cost of ownership for systems that bring mission-critical, revenue-generating data from assets dispersed over great distances.

Selector Guide SD Frequency 900 MHz Unlicensed 2.4 GHz Unlicensed 100 – 200 MHz Licensed 400 MHz Licensed 900 MHz Licensed Cell WiFi Range

NETio

WiYZ

entraNET

TransNET

• •

•

• •

• •

• •

• •

50 miles

30 miles

1 mile, cell

30 miles

30 miles

19.2 kbps

115 kbps

9.6 kbps

106 kbps

115 kbps

• •

• • •

• •

• •

•

• •

• • •

• •

•

•

•

•

•

Speed Data Interfaces – Access Point Ethernet Serial I/O Data Interfaces - Remote Ethernet Serial I/O Network Type Point-to-Multipoint Mesh

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• • •

MDS Industrial Strength Wireless Solutions

LAN Extension Orbit Platform

MCR Series - Converged Communications for Hybrid Networks The MDS Orbit Platform integrates a range of technologies, from cellular to private, and licensed to unlicensed, supporting customers’ needs for secure private, public and hybrid communications networks. The MDS Orbit platform provides a comprehensive security framework to support device, user and network security requirements. The MDS Orbit Platform is available with 900 MHz, 3G, 4G and WiFi communications options, along with multiple interface options in a compact, robust package.

Mercury Series

Industrial WiMAX Networking The MDS Mercury Series is a highly secure, industrial-grade standard WiMAX communications platform for mission critical, industrial applications. The Mercury product line provides a global licensed and unlicensed solution designed to facilitate high throughput wireless networking requirements. The MDS Mercury Series supports Ethernet, serial, USB and WiFi connectivity, and offers extended range and aggregate throughput of up to 30 Mbps.

iNET-II

Secure IP/Ethernet

Backhaul Intrepid Series

High Capacity Point-to-Point Solutions

(Intrepid Ultra, Ultra P, New OIT (mni))

The MDS IntrepidTM family of products is offered in a variety of protected and non-protected configurations, and supports a variety of frequencies with speeds up to 800 Mbps (two carrier offering). The Intrepid family is differentiated by its wide array of interfaces, including SONET/OC3, multiple E1s/T1s, Ethernet, Gigabit Ethernet, and Fast Ethernet. The Intrepid is available in MDS’s traditional industrial class, and for some models, has expanded to include Enterprise class solutions for projects where environmental specifications are less stringent. Note US manufactured versions available for global sale.

LAN Extension Features

iNET

Mercury

Orbit MCR

Frequency

Wireless Technology

Range

900MHz Unlicensed 900 MHz WIMAX 1800 MHz Licensed WIMAX 3650 MHz Non-Exclusive WIMAX 5800 MHz Licensed WIMAX 3G Global GSM4G LTE 2.4 GHz Wi-FIi

•

• •

Speed Data Interfaces - Access Point Data Interfaces - Remote Simultaneous / Redundant Uplinks Network Topologies Cyber Security QoS and Determinism Networking Functionality

Ethernet Serial Ethernet Serial Point to Point Point to Multipoint Store and Forward Proprietary Mesh Bridging Static Routing Serial Server (Modbus/DNP3)

Backhaul Features Frequency

Range

400 MHz Licensed 900 MHz Licensed 1400 MHz Licensed 2.4 GHz Unlicensed 5.8 GHz Unlicensed 6 – 38 GHz Unlicensed

Speed Data Interfaces

Network Topologies

Ethernet Serial T1/E1 E3/DS3 Point to Point Point to Multipoint

•

• •

20 miles

• 15 miles

1 Mbps

30 Mbps

• • • • 900 MHz only • •

• • • • WIMAX only • •

Basic •

Intermediate • •

•

•

• • • >30 miles (900MHz) 1.25 Mbps (900MHz) 50/25 Mbps (4G LTE) • • • • 900 Mhz + Cellular • • • • Advanced • • • •

Intrepid Intrepid Ultra

Intrepid HC MX Intrepid HC OIP

75 Miles 25Mbps Full Duplex Intrepid 100Mbps Full Duplex Intrepid Ultra • •

50 miles Up to 340Mbps MX Up to 350Mbps OIP • • (MX only) • (MX only)

25 miles Up to 200Mbps Base Station Up to 50 Mbps Remotes •

• •

•

• •

• • •

GEDigitalEnergy.com

•

INTREPID P2MP • •

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MDS

The MDS iNET-II is the industry leader for unlicensed industrial networking with its combined megabit speed, exceptional range and industry-leading cyber security. The iNET-II supports IP/Ethernet and serial communication to permit the smooth migration of legacy serial devices to IP networks. The iNET-II meets the needs of SCADA system designers and IT professionals, with a cyber-security suite including VLAN tagging, Radius Authentication, and AES 128-bit encryption, all at the lowest cost of ownership..

Commercial Services The MDS Wireless Services Group (WSG) offers a wide range of services to assist our customers with their wireless communications and networking requirements. We have the expertise and experience to complete large end-to-end projects. Our advanced network design capabilities and engineering services assists customers with their wireless communications challenges.

Wireless System Development

Training: In-class and On-site

Our team of highly-qualified engineers manage the design, installation, integration, commissioning, and training for complete end-to-end projects across the globe. The experience we have gained in over 30 countries allows us to ensure optimal wireless system performance in the most diverse environments for both greenfield and upgrade/retrofit installations.

We provide customers with the high-quality training and certifications required to be safe, efficient and successful. Our courses cover topics such as the fundamentals of wireless communications and product training. We also offer on-site training at customer facilities and instructor-led Virtual Classroom training. Customers can learn at their own pace with our online web-based training.

Engineering Services Our engineers have extensive domestic and international experience with commercial, industrial, and government systems, offering a full range of engineering services: • Site Surveys • Network Design

Racks & Custom Enclosures Our equipment integration designs are developed with detailed attention to equipment placement and accessibility. Offerings include both standard and custom packages for wireless device integration with networking accessories. Standards-based procedures for both equipment integration and testing ensure that wireless systems are robust and future-proof.

• Equipment Installation • Path Analysis and Propagation Studies

Accessories To ensure our customers get the maximum performance from their wireless devices, we provide a complete line of reliable and cost-effective accessories that are fully tested to perform at optimal levels, and maintain product warranties. We simplify wireless system design by providing a convenient single source for ordering.

Antennas

RF Essentials Kits

MDS provides a full range of antennas to fit every specification and budget. Whether the application demands withstanding high winds, protection against extreme temperatures, or water resistance, MDS antennas are designed to have a long, trouble-free life.

The MDS RF Essential Kits provide an easy-to-order wireless package. These kits include everything needed in typical applications, including wireless devices, antennas, cables, connectors, grounding, lightening arrestors, and power supplies.

Lightning Arrestors

Ethernet Switches

Preparation is the best course of action when protecting wireless devices against lightning strikes. Our lightning arrestors can handle the immense amount of current released during lightning strikes, drawing the current away to protect valuable wireless assets.

MultiLink Ethernet switches are extremely cost effective solutions for high speed networking. These Ethernet switches are designed for harsh environments, and are equipped with Link Loss Alert for use in redundant architectures.

Power Supplies

Multiplexers

Power supplies not only allow customers to increase the efficiency of their wireless system, but they can also help protect against power system overloads. MDS power supplies come with universal adapters and are available in a wide range to fit all MDS wireless devices.

Our line of SONET, T1 and SDH access multiplexers provide voice, data, teleprotection, Ethernet WAN, and video application solutions. GE’s Lentronics multiplexers operate in rugged environments ensuring reliability for mission critical traffic.

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M&D Monitoring & Diagnostics of Power Transformers Detect impending transformer issues to avoid unplanned outages For over 35 years, GE has been designing and developing advanced transformer monitoring solutions that enable continuous monitoring of power transformers, providing utilities and industrial organizations with accurate diagnostics and detection of impending issues. Through early detection these organizations are able to maximize critical asset and power system uptime. As a world leader of technology that predicts transformer failures, GE’s monitoring and diagnostics equipment empowers customers with real-time information that leads to better decision making. With proactive and increased asset information, our customers can improve reliability, reduce maintenance expenses, proactively manage performance and delay or reduce capital expenditures.

Dissolved Gas Analysis (DGA) Accepted as the most effective method to assess transformer health, our DGA extraction and analysis tools identify rates of increase of transformer gasses over time to provide advanced indication of a developing fault condition.

On Load Tap Changer Monitoring (OLTC) For comprehensive transformer monitoring beyond the transformer’s main tank, we have developed solutions for OLTC monitoring. With advanced technologies including bushing monitoring, partial discharge detection, hot spot temperature measurement, load and temperature sensing, and cooling control, GE provides maximum coverage of potential fault causes for these critical power system assets.

Monitoring your Fleet of Transformers Unlocking the full value of condition based monitoring, GE provides solutions to enable remote monitoring capabilities with intuitive, easy-to-use software. GE’s Perception™ Fleet Software suite provides data centralization to visualize, trend, interpret, and assess the risk of potential transformer failure individually and across a power network.

Monitoring & Diagnostics

Monitoring for Small and Medium Sized Transformers Intellix GLA 100 Small, intuitive and easy to install fault gas level alarm that provides a low cost warning solution to extend DGA monitoring to the smaller transformers in your fleet.

Hydran 201Ti Basic transformer fault gas monitor with data communications and alarm capabilities. Optional separate repeater (201Ci).

Hydran M2 M&D

Compact fault gas and moisture monitor with alarms and wide range of communications options to transfer data. Additional sensors can be connected and local transformer mathematical models calculated to transform it into a mini system.

Monitoring & Diagnostics for Precise On-Line Monitoring Using Multiple Fault DGA Kelman TRANSFIX The TRANSFIX is a 9-gas plus moisture on-line transformer DGA monitoring unit. Using specially developed advanced photo-acoustic detection technology, the TRANSFIX measures all significant fault gases as well as moisture in oil.

Kelman MULTITRANS On-line multi-gas DGA monitoring for 2 or 3 nearby individual transformer tanks. Ideal for three single phase transformers in a bank, offering the same capabilities as the Kelman TRANSFIX.

Kelman TAPTRANS On-line multi-gas DGA monitoring of transformers with OLTCs. Providing accurate and reliable DGA Measurements of the main transformer tank, the diverter, and selector tanks of the OLTC, all with no cross-contamination between tanks.

Kelman MINITRANS Cost-effective discrete DGA device monitoring 3 significant fault gases plus moisture, offering load sensor, outputs, extensive communication options and configurable alarms.

Kelman TRANSPORT X Compact and portable multi-gas DGA system that performs laboratory quality Dissolved Gas Analysis on manually taken transformer oil samples and renders a diagnostic result on-site in 30 minutes.

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Monitoring & Diagnostics

Enhanced Transformer Monitoring Solutions for Better Knowledge and Protection

Intellix MO150 The Intellix MO150 focuses on moisture and temperature data to provide insulation ageing analysis as well as enabling safe overloading of transformers and monitoring of the cooling system. The MO150 comes with its own single gas DGA monitor.



Kelman TRANSFIX Plus A combination of the Kelman TRANSFIX 9-gas plus moisture on-line DGA monitor and the Intellix MO150 insulation monitoring system combined into a single unit. It provides the benefits of both units but, housed in a single compact enclosure, saving space.

M&D



Intellix BMT 300 On-line system that continuously monitors the condition of the bushings and the presence of partial discharge (PD) activity in the transformer main tank. With alarms, personnel are alerted to fault conditions at an early stage providing health information on the bushings and the transformer.

GEDigitalEnergy.com

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Perception™ Fleet Transformer Fleet Risk Management Software System Easy to install and configure, Perception Fleet delivers instantaneous results upon installation. Continuing its legacy in providing innovative solutions, Perception Fleet is GE’s Online Transformer Fleet Management Software System that provides a revolutionary and holistic approach to transformer fleet assessments for utilities and industrial customers around the globe. GE’s Perception Fleet is a smart, simplified and standards-based software system that moves customers from a manual, one-on-one transformer assessment process to an automated and online fleet management assessment. By regularly acquiring data and continuously and automatically evaluating the condition of assets and establishing their risk of failure, Perception Fleet is able to continuously rank assets within a fleet and highlight assets requiring attention as a priority.

The device summary dashboard automatically self-configures to show, the most important data from all available online monitoring devices in a simple and concise design.

Its built-in wallboard and dashboards enable users to visualize the status of even large transformer fleets at a glance. Its web browser interface makes this information available to the asset manager anywhere on any internet ready device. Perception Fleet also provides a broad range and comprehensive suite of DGA diagnostics tools for rapid analysis as well as access to the raw data and trend charts for the transformer expert to be able to delve into. Perception Fleet is simple to use and setup. Its risk calculations algorithms are already built in using recognized IEC® and IEEE® standards (IEEE C57.104, IEC 60599, IEC 60422) as well as CIGRÉ® and EPRI® best Practices. Yet should you wish to customise or create new algorithms to support unique transformer insight . an Integrated Workflow Designer application is available. Lastly, the software is fully interoperable thanks to its data exchange facility with no predefined formats required.

At the top the ranking history graph displays the transformers ranking position over a 30 day period. A condition statement for each point is displayed on the dashboard when a point is selected on the graph. The condition statement provides details on the risk and rank evaluation. At the bottom the risk history graph displays the transformer risk variation over a period of 30 days.

RISK INDEX: 5

RISK INDEX: 4

TRANS-DIST-04

Perception Fleet’s built-in algorithms incorporate the data from the monitoring devices and produce a Risk Index from 1 to 5.

GEA-12911(E) English 150121

Instrument Transformers ITI Overview GE’s ITI products are designed to enable the protection of equipment and minimize the loss of product flow to the consumer. Utilizing high quality materials and innovative designs, ITI products provide reliable sensing for power systems.

Product Listing Product listing for Instrument Transformers offered by GE.

Product Listing

ITI Product List Utility Instrument Transformers

OEM Instrument Transformers

Low Voltage CTs (600V)

IEEE 600V VTs



Encompass CTs





RevenueSense CTs

IEEE 600V Bushing CTs



Indoor single and three phase VTs



Cast Resin Indoor/Outdoor CTs - 10kV BIL



Taped & Varnished Indoor CTs - 10kV BIL



Board Mounted Indoor CTs – 10kV BIL

Indoor Window Type CTs Indoor Bar Type CTs Indoor/Outdoor CTs

Low Voltage VTs (600V)

IEEE 5-35kV Indoor CTs





Indoor/Outdoor VTs

Medium Voltage CTs and VTs (5-69kV)

SUPERBUTE Outdoor CTs and VTs (5-69kV)



HCEP Outdoor CTs and VTs (15-35kV)

CTW Series Indoor CTs – up to 200kV BIL

IEEE 5-35kV Indoor PTs

PT Series Indoor – up to 200kV BIL

IEC 720V-36kV CTs

Polyurethane Indoor CTs and VTs (5-35kV)



Overhead Primary Meter Assemblies

OEM Instrument Transformers IEEE 600V CTs

Commercial Grade Indoor CTs

Window Type Indoor CTs – 720V, 50 to 3000A primary



JKW Series Outdoor CTs – 12 to 36kV, 5 to 1200A primary

IEC 720V-36kV VTs

Indoor VTs – 720V, fused & unfused



JVW Series Outdoor VTs – 12 to 36kV, 95-170kV BIL

Instrument Grade Indoor CTs



Rectangular Type Indoor CTs



Three Phase Window Type Indoor CTs



Split Core Indoor CTs



Wound Primary/Auxiliary Indoor CTs



Ground Fault Sensors

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For a full listing of GE’s Power Sensing products, visit gedigitalenergy.com/ITI

GEDigitalEnergy.com

Distributor & Representative Sales Offices

GE Digital Energy Global Sales Channels GE Digital Energy - Multilin Online Store ....................................................................................................................................................... 697 GE Digital Energy Offices ............................................................................................................................................................................................................... 698 Distributors & Sales Representatives

GE Locations

North America Canada ....................................................................................................................................................................................................................................................................... 699 USA ................................................................................................................................................................................................................................................................................ 699 Latin America .......................................................................................................................................................................................................................................................................... 702 Europe .......................................................................................................................................................................................................................................................................................... 703 Middle East & Africa ............................................................................................................................................................................................................................................................ 704 Asia ................................................................................................................................................................................................................................................................................................. 705 Australia/New Zealand/India ....................................................................................................................................................................................................................................... 706

GE Digital Energy - Multilin Online Store www.GEDigitalEnergy.com/OnlineStore Flexible Product Configuration The Digital Energy Online Store allows you to choose from over 300 Digital Energy products, available for order 24 hours a day, 7 days a week. Easy to use configurators provide visibility to all product options, allowing you to configure products for your specific application requirements.

Quotes and Orders based on Preferred Pricing Visit the Digital Energy online store to set up an account and take advantage of preferred pricing. With an account, create accurate quotes with your actual pricing and product lead times. Conveniently select from a list of pre-qualified product accessories, recommended for use with our products.

Hassle-Free Ordering and Tracking Save partially completed orders before submitting, so you can start an order one day, and submit it the next. Track the status of your purchase from the date you place the order, to the time it arrives at your door, and view your past online purchases in the order history.

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Distributor & Representative Sales Offices

GE Digital Energy Global Offices Protection & Control - Multilin GLOBAL OFFICE

EUROPEAN OFFICE

LATIN AMERICA OFFICE

Avenida Pinoa 10-48170 Zamudio (Vizcaya), Spain

Avenida Maria Coelho Aguiar, 215 Bloco C, 6o. andar Jd. São Luiz - São Paulo - SP CEP: 05804-900 - Brazil

GLOBAL OFFICE

EUROPEAN OFFICE

LATIN AMERICA OFFICE

1907 Calumet St. Clearwater, FL 33765, USA

Avenida Pinoa 10-48170 Zamudio (Vizcaya), Spain

Avenida Maria Coelho Aguiar, 215 Bloco C, 6o. andar Jd. São Luiz - São Paulo - SP CEP: 05804-900 - Brazil

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TECHNICAL SUPPORT

T 905-927-7070 (Press 2) T 1-800-474-0964 (Press 2)

GE Locations

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TECHNICAL SUPPORT

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T +55 11 3614 1700 F +55 11 3614 1799 W gedigitalenergy.com/contact.htm

Communications - MDS | Lentronics GLOBAL OFFICE T T F W

1-800-474-0964 (Toll Free in North America) 585-242-9600 585-242-9620 gedigitalenergy.com/contact.htm

Wireless Center of Excellence 175 Science Parkway Rochester, New York 14620 USA

EUROPEAN OFFICE

T +34 94 485 88 00 F +34 94 485 88 45 W gedigitalenergy.com/contact.htm Avenida Pinoa 10-48170 Zamudio (Vizcaya) Spain

Monitoring & Diagnostics - Kelman l Hydran l Intellix l Perception GLOBAL OFFICE

EUROPEAN OFFICE

LATIN AMERICA OFFICE

Lissue Industrial Estate East Lissue Road Lisburn BT28 2LU United Kingdom

Avenida Pinoa 10-48170 Zamudio (Vizcaya), Spain

Avenida Maria Coelho Aguiar, 215 Bloco C, 6o. andar Jd. São Luiz - São Paulo - SP CEP: 05804-900 - Brazil

T 1-800-474-0964 (Toll Free in North America) T +44 2892 622 915 W gedigitalenergy.com/contact.htm

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T +34 94 485 88 00 F +34 94 485 88 45 W gedigitalenergy.com/contact.htm

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Distributor & Representative Sales Offices

Sales Representatives North America Canada ALBERTA

NEW BRUNSWICK

NUNAVUT

QUEBEC

Altelec Engineering Services Inc. #203-2816 21st Street N.E. Calgary, AB T2E 6Z2 T (403) 216-2150 F (403) 216-2159 E [email protected]

Charlton & Connolly Inc. 11 Thornhill Drive, Suite 205 Dartmouth, NS B2W 3X8 T (902) 468-4388 F (902) 468-9006 E [email protected]

Altelec Engineering Services Inc. #203-2816 21st Street N.E. Calgary, AB T2E 6Z2 T (403) 216-2150 F (403) 216-2159 E [email protected]

Altelec Engineering Services Inc. 10342 - 176 Street Edmonton, AB T5S 1L3 T (780) 455-2020 F (780) 454-0185 E [email protected]

NEWFOUNDLAND & LABRADOR

ONTARIO

Charlton & Connolly Inc. 11 Thornhill Drive, Suite 205 Dartmouth, NS B2W 3X8 T (902) 468-4388 F (902) 468-9006 E [email protected]

Chess Controls, Inc. 11 Mary Street, Unit C Sudbury, Ontario P3C1B4 T 705-682-2828 E [email protected]

Ventes Techniques Trelec 324 Route Racette St-Augustin-de-Desmaures, QC G3A 1R2 T (418) 878-8919 (Quebec City Office) (877) 307-5525 (toll-free) (514) 743-3888 (Montreal Office) F (418) 878-8920 E [email protected]

BRITISH COLUMBIA

MANITOBA Altelec Engineering Services Inc. #203-2816 21st Street N.E. Calgary, AB T2E 6Z2 T (403) 216-2150 F (403) 216-2159 E [email protected]

NORTH WEST TERRITORIES Altelec Engineering Services Inc. 10342 - 176 Street Edmonton, AB T5S 1L3 T (780) 455-2020 F (780) 454-0185 E [email protected]

NOVA SCOTIA Charlton & Connolly Inc. 11 Thornhill Drive, Suite 205 Dartmouth, NS B2W 3X8 T (902) 468-4388 F (902) 468-9006 E [email protected]

Chess Controls 5716 Coopers Avenue, Unit 11 Mississauga, Ontario L4Z2E8 T 1-800-461-4076 E [email protected]

Altelec Engineering Services Inc. #203-2816 21st Street N.E. Calgary, AB T2E 6Z2 T (403) 216-2150 F (403) 216-2159 E [email protected] GE Locations

Wilmount Engineering Products, Ltd. 2895 Keets Drive Coquitlam, BC V3C 6J2 T (604) 944-1166 F (604) 944-9001 E [email protected]

SASKATCHEWAN

PRINCE EDWARD ISLAND Charlton & Connolly Inc. 11 Thornhill Drive, Suite 205 Dartmouth, NS B2W 3X8 T (902) 468-4388 F (902) 468-9006 E [email protected]

Sales Representatives North America United States of America ALABAMA

ARKANSAS

Levine Lectronics & Lectric 200 Powers Ferry Road Marietta, GA 30067 T (770) 565-1556 F (770) 973-9264 E [email protected] [email protected]

Doby Associates Inc. 4915 Hillcrest Ave Little Rock, AR 72205 T (501) 282-6824 F (601) 981-7919 E [email protected]

ALASKA Engineered Equipment Co. of Alaska 12501 Old Seward Hwy, Suite A Anchorage, AK 99515 T (907) 345-3474 F (907) 345-9525 E [email protected]

ARIZONA Control Solutions LLC 9012 W. Mauna Loa Lane Peoria, AZ 85381 T (623) 266-1846 F (623) 266-1762 E [email protected] [email protected]

CALIFORNIA Industrial Electrical Machinery (IEM) 21818 S Wilmington Ave #409 Carson, CA 90810 145 T (310) 549-5673 F (310) 549-2309 E [email protected]

COLORADO IEM Rocky Mountains 8071 S. Williams Cir. Centeninel, Colorado, USA T (310) 549-5673 E [email protected]

McClure-Hill 6175 N. Ponderosa Way Parker, Colorado 80134-5528 USA T (720) 524-4055 E [email protected]

CONNECTICUT Bluefin Energy Solutions Inc. 11 S Angell St. Ste 348 Providence, Rhode Island 02906-5206 T +(888) 489-5551 E [email protected]

DELAWARE Ewing Two Inc 429 W Vernon Ave Linwood, nj 08221-1320 United states T (609) 601-1666 E [email protected]

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FLORIDA GF Electro Mechanical 7603 Oakmoor Drive Tampa, FL 33634 T (813) 962-3671 F (813) 960-2673 E [email protected]

GEORGIA Levine Lectronics & Lectric 200 Powers Ferry Road Marietta, GA 30067 T (770) 565-1556 F (770) 973-9264 E [email protected] [email protected]

699

Distributor & Representative Sales Offices

Sales Representatives North America United States of America (Cont’d) IDAHO

KENTUCKY

Control Technology Co., Inc. 760 Lake Elmo Billings, MT 59105 T (406) 259-4597 F (406) 259-4599 E [email protected]

Patrick Enterprises 63 Dixie Drive N., Unit B Vandalia, OH 45377 T (937) 454-0000 F (937) 454-0050 E [email protected])

Riter Engineering Company 8175 South Chestnut Street Mail P.O. Box #25005 Salt Lake City, UT 84104 T (801) 973-9063 F (801) 973-8333 E [email protected]

LOUISIANA

GE Locations

ILLINOIS Electrorep Energy Products 1904 Grist Mill Drive Springfield, Illinois 62711 T 217-341-1008 F 314-991-3852 E [email protected] Lehman Company & Associates 28369 Davis Parkway, Suite 401 Warrenville, IL 60555 T (630) 942-1900 F (630) 942-1955 E [email protected] [email protected] [email protected] [email protected] [email protected]

INDIANA Lehman Company 799 Roosevelt Road, Building 2, Suite 208 Glen Ellyn, IL 60137 T (630) 942-1900 F (630) 942-1955 E [email protected] Patrick Enterprises 63 Dixie Drive N., Unit B Vandalia, OH 45377 T (937) 454-0000 F (937) 454-0050 E [email protected]

IOWA PowerCon Co. 449 Kingbard Blvd. Waterloo, IA 50701 T (319) 610-0132 F (402) 835-0112 E [email protected]

Automation Control Co. Inc. 11914 Cloverland Court Baton Rouge, LA 70809 T (225) 752-0337 F (225) 756-8348 E [email protected] [email protected] [email protected] [email protected] [email protected] [email protected] [email protected] [email protected] [email protected] [email protected]

700

MINNESOTA

NEW MEXICO

Protection & Control Solutions 5400 Opportunity Ct Hopkins, Minnesota 55343-9044 USA T (952) 767-4500 E [email protected]

Control Solutions L.L.C. 9012 W. Mauna Loa Lane Peoria, AZ 85381 T (623) 266-1846 F (623) 266-1762 E [email protected] E [email protected]

Doby Associates Inc. 1437 Old Square Road, Suite 204 Jackson, MS 39211 T (601) 981-1138 F (601) 981-7919 E [email protected] [email protected] [email protected]

MISSOURI

Automation Control Co. Inc. 2321 Suwanee Drive Marrero, LA 70072 T (504) 309-9235 F (504) 309-9236 E [email protected]

MAINE

Bluefin Energy Solutions Inc. 11 S Angell St. Ste 348 Providence, Rhode Island 02906-5206 T +(888) 489-5551 E [email protected]

MARYLAND Ewing Two Inc 429 W Vernon Ave Linwood, nj 08221-1320 United states T (609) 601-1666 E [email protected] Bluefin Energy Solutions Inc. 11 S Angell St. Ste 348 Providence, Rhode Island 02906-5206 T +(888) 489-5551 E [email protected]

Advance Power Products & Solutions Inc. 123 Town Square Place Num. 224 Jersey City, New Jersey 07310 T (201) 963-8269 E [email protected]

NEW YORK Advance Power Products & Solutions Inc. 123 Town Square Place Num. 224 Jersey City, New Jersey 07310 T (201) 963-8269 E [email protected]

NORTH CAROLINA

Electrorep Energy Products 2121 Schuetz Road St. Louis, MO 63146 T (314) 991-2600 F (314) 991-3852 E [email protected]

Polytech Electrical Sales 425-D South Sharon Amity Road Charlotte, NC 28211 T (704) 367-1240 F (704) 367-5760 E [email protected] [email protected]

MONTANA

NORTH DAKOTA

Control Technology Co., Inc. 760 Lake Elmo Billings, MT 59105 T (406) 259-4597 F (406) 259-4599 E [email protected]

NEBRASKA PEAR Inc. 3701 W 49th St. Suite 108 Sioux Falls, North Dakota 57106-4241 T (605) 361-4383 E [email protected]

NEVADA

MASSACHUSETTS

HEK Inc. 6083 Lafayette Ann Arbor, MI 48103 T (734) 995-0900 F (734) 995-0960 E [email protected]

NEW JERSEY

MISSISSIPPI

Automation Control Co. Inc. 214 Constitution Drive Lafayette, LA 70503 T (337) 988-6595 F (225) 756-8348 E [email protected]

MICHIGAN

Midwest Electrical Sales 220 Robert Street Watertown, WI 53098 T (920) 262-1668 F (920) 262-1903 E [email protected]

Control Solutions LLC 9012 W. Mauna Loa Lane Peoria, AZ 85381 T (623) 266-1846 F (623) 266-1762 E [email protected] [email protected] Riter Engineering Company 875 South Chestnut Street P.O. Box #25005 [84125] Salt Lake City, UT 84104 T (801) 973-9063 F (801) 973-8333 E [email protected]

NEW HAMPSHIRE Bluefin Energy Solutions Inc. 11 S Angell St. Ste 348 Providence, Rhode Island 02906-5206 T +(888) 489-5551 E [email protected]

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PEAR Inc. 3701 W 49th St. Suite 108 Sioux Falls, North Dakota 57106-4241 T (605) 361-4383 E [email protected]

OHIO Patrick Enterprises 63 Dixie Drive N., Unit B Vandalia, OH 45377 T (937) 454-0000 F (937) 454-0050 E [email protected] HEK Inc. 6083 Lafayette Ann Arbor, MI 48103 T (734) 995-0900 F (734) 995-0960 E [email protected]

OKLAHOMA KenCor Inc.

102 North Elm Place, Suite I Broken Arrow, OK 74012 T (918) 258-4101 F (918) 516-0600 E [email protected]

OREGON Control Technology Co., Inc. 760 Lake Elmo Billings, MT 59105 T (406) 259-4597 F (406) 259-4599 E [email protected]

Distributor & Representative Sales Offices

Sales Representatives North America United States of America (Cont’d) PENNSYLVANIA Ewing Two Inc 429 W Vernon Ave Linwood, nj 08221-1320 United states T (609) 601-1666 E [email protected]

RHODE ISLAND Bluefin Energy Solutions Inc. 11 S Angell St. Ste 348 Providence, Rhode Island 02906-5206 T +(888) 489-5551 E [email protected]

SOUTH CAROLINA

SOUTH DAKOTA PEAR Inc. 3701 W 49th St. Suite 108 Sioux Falls, North Dakota 57106-4241 T (605) 361-4383 E [email protected]

TENNESSEE Doby Associates, Inc. 1001 Willow Oak Lane, #102 Jackson, TN 38305 T (901) 497-4659 F (601) 981-7919 E [email protected]

VIRGINIA

WISCONSIN

Polytech Electrical Sales 911 Saddle Dr Salem, VA 24153 T (540) 589-5681 F (540) 389-2409 E [email protected]

Midwest Electrical Sales 220 Robert Street Watertown, WI 53098 T (920) 262-1668 F (920) 262-1903 E [email protected]

WASHINGTON

WYOMING

TEXAS

Control Technology Co., Inc. 760 Lake Elmo Billings, MT 59105 T (406) 259-4597 F (406) 259-4599 E [email protected]

Control Technology 800 Werner Court, Ste 130A Casper, WY 82601 T (307) 235-4809 F (307) 235-0603 E [email protected]

WASHINGTON D.C.

IEM Rocky Mountains 8071 S. Williams Cir. Centeninel, Colorado, USA T (310) 549-5673 E [email protected]

Double E Engineering Sales 5700 Northwest Central Drive, Suite 240 Houston, TX 77092 T (713) 290-1151 F (713) 290-1167 E [email protected]

UTAH Riter Engineering Company 875 South Chestnut Street Salt Lake City, UT 84104 T (801) 973-9063 F (801) 973-8333 E [email protected]

Ewing Two Inc 429 W Vernon Ave Linwood, nj 08221-1320 United states T (609) 601-1666 E [email protected]

WEST VIRGINIA

VERMONT Bluefin Energy Solutions Inc. 11 S Angell St. Ste 348 Providence, Rhode Island 02906-5206 T +(888) 489-5551 E [email protected]

Patrick Enterprises 63 Dixie Drive N., Unit B Vandalia, OH 45377 T (937) 454-0000 F (937) 454-0050 E [email protected]

GE Locations

Polytech Electrical Sales 425-D South Sharon Amity Road Charlotte, NC 28211 T (704) 367-1240 F (704) 367-5760 E [email protected] [email protected]

EMR Associates Inc. 1101 Kermit Drive, Suite 501 Nashville, TN 37217 T (615) 292-1977 F (615) 292-1560 E [email protected] [email protected] [email protected] [email protected]

Riter Engineering Company 875 South Chestnut Street Salt Lake City, UT 84104 T (801) 973-9063 F (801) 973-8333 E [email protected]

EMR Associates 9080 Barbee Lane, Suite 100 Knoxville, TN 37923 T (865) 769-1998 F (865) 769-2227 E [email protected] [email protected] [email protected] [email protected]

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Distributor & Representative Sales Offices

Sales Representatives

GE Locations

Latin America ARGENTINA

CHILE

Artec Ingenieria S.A. King 386 - (C1199AAB) Buenos Aires, Argentina T +(54) 11-4106-6500 F +(54) 11-4106-6549 E [email protected]

CRT Chile S.A. San Pio X 2460 Oficina 1310 Providencia Santiago, Chile T +56 2 2232 7720 E [email protected]

BRAZIL

COSTA RICA

Ag Representacoes Ltda Rua Fernandes Tourinho, 999 – Sala 101 Lourdes Belo Horizonte 30112-000 Minas Gerais, Brazil T +55 31 8814 7566 E [email protected]

GB Tecnologia Pavas, del Rest. Isla Verde 400 NY 250 San Jose, Puerto Rico T +506-229-02249 F +506-229-08347 E [email protected]

CAVG Representacoes E Instalacoes Eletricas Ltda Quadra Ql 07- Bloco B Lotes 11/17 Sala 202 - Parte 03 Brasilia, Brazil T +(628) 299-1770 E [email protected] Concert Technologies S/A Rua Antonio De Albuquerque - 757 Belo Horizonte, Brazil T +55 31 9345 0667 KGM Comercio E Representacoes Ltda Chico Science 68S/N Olinda, Pernanmbuco, Brazil 53320-1 T +(081) 3429 0656 E [email protected] NDVIX Representacoes E Servicos Ltda RUA OURO PRETO 159, PRAIA GRANDE, FUNDÃO, ESPIRITO SANTO, CEP 29.187-000 T +55 27 3315 1115 E [email protected] Protection Assessoria Comerical Ltda Av. 13 De Maio 33SL 704 Rio de Janeiro, Brazil 20031-920 T +55 21 2240 6713 E [email protected] Ronan Patrus Adm. De Negocios Ltda Rua Sebastiao Fabiano Dias 210 Loja 10 Belo Horizinte, Brazil 30320-690 T +55 31 3286 5469 Uniao Automacaos & Energia Ltd Rua Senador Theotonio Vilela No. 190 Salas 603/604 Bahia, Brazil 40279-435 T +55 71 3355-0399 E [email protected]

702

PANAMA

Guiehr S.A. Avenida Abel Bravo Urbanizacion Obarrio No. 22 Edificio Eurocentro Panama, Republica de Panama T (011) 507-269-7852, 507-3001400 F (011) 507-263-2156 E [email protected] [email protected]

PERU Ditec Proyectos S.A.C. Jose Gonzales 675 Miraflores Lima, Peru T (511) 627-4310 F (511) 627-4316 E [email protected]

DOMINICAN REPUBLIC

Soluciones Teleinformaticas Y Control S.A. Av. Paseo De La Republica 6287 Miraflores, 18 Lima, Peru T 51 (1) 446-9245 E [email protected]

Grupo Electrico Industrial Calle Jose Amado Soler No.12 Serralles, Santo Domingo Dominican Republic T +(1) (809) 620-0808 E [email protected]

PUERTO RICO Pro-Energy Corp Aee Monacillos Edificio La Torre Rio Piedrassistema Administracion de Energia Calle San Roberto Final Puerto Rico, 00926-000 T 7873657188

GUATEMALA Productos Electricos CentroAmericanos, SA Calzada Aguilar Batres 42-21 Zona 12 Guatenala City, Guatemala T (502) 2388-8686 E [email protected]

HONDURAS Compania De Ingenieria Y Tecnologia S De Rl Residencial Costas Del Sol 15 Calle, Avenida Del Sol, Sector Sur Este San Pedro Sula, Honduras T +(504) 2550-4434 E [email protected]

TRINIDAD, TOBAGO, BARBADOS RPM Marketers ltd. 35 Cross Crossing San Fernando, Trinidad, West Indies T +(868) 652-6606/8622 F +(868) 652-6925 E [email protected]

MEXICO Protecciones Electricas Y Control S.A. de C.V. Constiticion No. 283 Col. Centro, C.P. 91700 Verzcruz, Mexico T +(52) 229-938-1879, 939-3469 F +(52) 229-938-1854 Transmision Y Distribuccion SA de CV Tres Zapotes 39-2 Letran Valle Mexico City, D. F.Mexico T (52 55) 9116-9805 F (52 55) 5539-3446 E [email protected]

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URUGUAY Artec Ingenieria S.A. Andes 1293 – Of 701 (11100) Montevideo, Uruguay T +598-2-903-0785 F +598-2-903-0785 E [email protected]

VENEZUELA GEMSCO, C.A. Av. Don Diego Cisneros Centro Empresarial Los Ruices, Piso 1 Ofic. 114. Los Ruices Caracas, 1071. Venezuela T T (58) 212-935-7648 / 234-6089 / 935-0550 F (58) 212-234-8068 E [email protected]

Distributor & Representative Sales Offices

Distributors & Sales Representatives Europe AZERBAIJAN

ENGLAND AND WALES

PORTUGAL

SCOTLAND

Araz Energy Ltd. N.Narimanov Ave. 268-267, G8 14th Floor, (Yasamal) Baku, Azerbaijan T +994 12 4085363 F +994 12 5650163 E [email protected]

Global Substation Solutions 1 Merchant Court Monkton Business Park South Hebburn Tyne and Wear NE31 2EX United Kingdom T +44 (0) 191 495 5206 E [email protected]

R.M.E. - Representações de Material Eléctrico, Lda. Rua Salgueiro Maia, nº 79 / 85 Custóias - Matosinhos 4460-802 Portugal T +(351) 229-574-200 F +(351) 229-574-209 E [email protected]

GREECE

REPUBLIC OF IRELAND

Global Substation Solutions 1 Merchant Court Monkton Business Park South Hebburn Tyne and Wear NE31 2EX United Kingdom T +44 (0) 191 495 5206 E [email protected]

BELARUS Enerink Of. 4, 8 Novovilenskaya Str. Minsk, Russian Federation T +(375) 17-289-7835 E [email protected]

BOSNIA AND HERZEGOVINA Energoinvest 2 Hamdije Cemerlica Sarajevo, Bosnia and Herzegovina T +(387) 33-724-189 E [email protected]

BULGARIA T&D Engineering-EOOD Izgrev Distr. 865 Varna, Bulgeria 9010 T +(359) 0 52312 100 E [email protected]

CROATIA KONCAR 22 Fallerovo Setaliste Zagreb, Croatia T +(385) 1 366 5615 E [email protected]

CZECH REPUBLIC/SLOVAKIA ELPAK Psohlavcu 693/62 Praha, Czech Republic T +(420) 244 468 024 E [email protected] UNIREC spol. s r.o. (Ltd.) Weilova 2, budova B Praha 10, 10205 Czech Republic T +(420) 267-215-989 Ext. 21 F +(420) 267-215-572 E [email protected]

ITALY Engineering Technical Services SPA Via Per Novara 112 Cameri, Italy T +39 32 16 41 711 E [email protected] GIGA Tech Viale Risorgimento 174/A 21040 Gerenzano ( VA ), Italy T +39 029 64 89 130 E [email protected] SAET Via Alberto Moravia 8, Selvazzano Dentro Padova, Italy 35030 T +39 049 89 89 711 E [email protected]

LATVIA, LITHUANIA, ESTONIA Sigma Telas Energy UAB Kalvariju G. 125 Vilnius, Lithuania 08221 T +37052773592 E [email protected]

NORTHERN IRELAND Global Substation Solutions 1 Merchant Court Monkton Business Park South Hebburn Tyne and Wear NE31 2EX United Kingdom T +44 (0) 191 495 5206 E [email protected]

POLAND SIP Monika Joanna Kowalik UL. Jana Kochanowskiego 26/7 Warsazawa, Poland T +(48) 226335712 E [email protected]

Global Substation Solutions 1 Merchant Court Monkton Business Park South Hebburn Tyne and Wear NE31 2EX United Kingdom T +44 (0) 191 495 5206 E [email protected]

ROMANIA Dacom Impex S.R.L. 12 Ion Ursu Street 020632 Bucharest, Romania T +(40) 21-210-3226 +(40) 21-210-3227 +(40) 21-210-3228 F +(40) 21-210-3229 E [email protected] [email protected]

RUSSIAN FEDERATION CHEAZ 16 Str. 1, Dokukina UL Moscow, Russian Federation T + (8352) 62-20-99 E [email protected] CHETA Avtozapravochnyj proezd, 24 Chuvash Republic, Russian Federation T +007 8352 54 1713 T +007 8352 28 1520 F +007 8352 63 0625 E [email protected] Energetika, Mikroelektronika, Automatika OOO 2 Fedoseeva UL. Novosibirsk, Russian Federation T +380975192802 E [email protected]

SERBIA Global Substation Solutions The Sava Centar Milentija Popovica 9 11070 Belgrade, Serbia T +381-11-220-6347 F +381-11-220-6094 E [email protected]

SPAIN (CANARY ISLANDS)

GE Locations

TIMIOR МИНИНА , ПЕРЕУЛОК 26 MNHCK, Belarus 220014 T +(375) 17-226-28 42 E [email protected]

Powertec 255, Kifisia Avenue Athens, Greece, 14561 T +00 302 1062 33701 F +00 302 1062 33453 E [email protected]

AGS Proteccion Medida y Control S.L. C./ Los Martinez de Escobar, n° 3. Oficinas1 y 3 35007 - Las P almas G.C., Spain T (+34) 902 999 382

TURKEY EKOSINERJI Elektrik San. ve Tic. A.S. Instanbul Cad. E5 Uzeri No.15 Cayirova-Gebze, 41420 Izmit, Turkey T +(90) 262-656-47-67 F +(90) 262-656-47-70 E [email protected] [email protected]

UKRAINE EMV Energo AG, TOV Bed. 6 Korp. 1, Prospekt Moskovsky Kyiv, Ukraine T +380 975 19 2802 E [email protected] SoyuzenergoProjekt 45 Melnykova St. Kharkiv, Ukraine 61001 T +38 (057) 704 78 25 E [email protected]

Komplektenergo LLC. 3 Ivana Yakovleva Prospekt Cheboksary, Russian Federation T +78352220110 E [email protected]

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703

Distributor & Representative Sales Offices

Distributors & Sales Representatives Middle East & Africa ISRAEL

NIGERIA

SAUDI ARABIA

UNITED ARAB EMIRATES

General Engineers Ltd. Industrial Zone Grand Netter PO Box 3731 Kfar Netter, 4059300 Israel T +(972) 9-866-2845 F +(972) 9-885-3151 E [email protected]

GIL Automations DTN Complex Lateeef Jakande Ikeja Lagos T 0700-AUTOMATION E [email protected]

Abdel Hadi Abdullah Al-Qahtani & Sons Co. Al-Qahtani P.O. Box 20 Street 9; Al Adami Area Dammam, 31411 Saudi Arabia T (966) 3-826-1477 F (966) 3-826-9894 E [email protected] [email protected]

Emdad LLC P.O. Box 4118 Abu Dhabi, UAE T +(971) 26-349-999 F +(971) 26-318-181 E [email protected]

KUWAIT United Gulf Enterprises General Trading & Contracting Company WLL Al-Bana Building, Ahmed Al-Jaber St., 6th Fl. Sharq, Kuwait T +965 24613112 E [email protected]

GE Locations

LIBYA United Group Aljomhoria St. Tripoli, Libya 11435 T +218 213630381 E [email protected]

MOROCCO Natural Resources Junction International 3 Rue Ennahas Annahoui Casa Blanca, Morocco T +(212) 522-23-11-88 F +(212) 22-23-09-99 E [email protected]

704

PAKISTAN EPESOL Pvt Ltd 71B Garden Block, New Garden Town Lahore, Pakistan T +(92) 42 3588 4232 E [email protected]

QATAR Petrotec, Petroleum Technology Co. W.L.L. P.O. Box 16069 5th Floor, ToyotaTower, Airport Road Doha, Qatar T (974) 441-9603 F (974) 441-9604 E [email protected]

ETAC P.O Box 66479 - Riyadh 11576 Saudi Arabia T +966 11 2150701/ 2150702 Ext. 124 F +966 11 2150706 JAL International Co. Ltd. 2nd Industrial City Dammam, Saudi Arabia T 966 13 887 8888 E [email protected]

SOUTH AFRICA Powertech IST Energy (Pty) P.O. Box 95355 Waterkloof ZA, 0145 South Africa T +(27) (0)12-426-7200 F +(27) (0)12-365-1466 E [email protected] Powertech System Integrators (Pty) Ltd. Building 3 Summit Place Thys Street Menlyn, Pretoria South Africa 0181 T +27 12 426 7200 E [email protected]

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ETA-PCS Switchgear Manufacturing LLC Ascon House Salah Al Din Ayubi Street (Salahuddin Rd) Sharjah Rd, Almateena PO Box 5239 Dubai, United Arab Emirates T +(971) 43-284-004 E [email protected] SAS Power Industries FZC. Plot No. 8 Technology Park (RAK Free Trade Zone), Al Hamraras Al Khaimah Landmark: Near Intech Systems FZC PO Box 54505, United Arab Emirates T +(971) 72-447-278 E [email protected]

Distributor & Representative Sales Offices

Distributors & Sales Representatives Asia BANGLADESH

INDONESIA

MALAYSIA

SINGAPORE

Dana Engineers International Ltd. House 59 Rd 13 & 15 Block –D, Banani Dhaka 1213, Bangladesh T +(880) 2-9882225 F +(880) 2-8813108 E [email protected]

PT Guna Elektro Jln. Arjuna Utara 50 Jakarta, 11510 Indonesia T +(62) 21-565-5010, ext. 369 F +(62) 21-565-5030 E [email protected] [email protected]

Kejuruteraan Semangat Maju Sdn. Bhd. 9, Jalan USJ 10/ID, Subang Jaya 47620 Petaling Jaya Selangor, Darul Ehsan Malaysia T +(603) 5633-6882 F +(603) 5633-0794 E [email protected]

BHE Digital Energy PTE LTD 28D Penjuru Close #01-03 Singapore T +(65) 6262 3688 E [email protected]

CHINA YPP (China) Co., Ltd. – Wuhan Branch Room 2401, No.1 Hongyuan International Building No. 117 Xudong Road, Wuchang District Wuhan, 430077, China T +(86) 27-8673-0477 F +(86) 27-8683-4447 E [email protected]

Shanghai Jingyao Automaton & Control Co. 18 No. Box No. 2678 Shanghai Jiaotong University Qixin Minhang District, China T +(86) 21-6461-7448 E [email protected]

HONG KONG Lung Shing Internation Development Limited RM 1007 10/F Ho King Ctr Mowb2073 2 - 16 Fa Yuen St Kowloon, Hong Kong T +(852) 2740 0795 E [email protected] Wescon Limited Rm 402 4/F Tung Chai Bldg 88, 90 Wellington St. Central District, Hong Kong T +(852) 2397 7002 E [email protected]

Kappadaya SDN. BHD. 312 2nd Floor Bee San Building Jalan Chan Bee Kiew, Kuching Sarawak, Malaysia T +(60) 82331233 E [email protected]

Nippon Kouatsu Electric Co.,Ltd. 7F Sunrise Mita Bldg 3-16-12 Shiba Minatoku Tokyo 105-0014 Japan T +81-3-5439-9970 F +81-3-5484-1140 E [email protected] Tokyo Densetsu Service, Co., Ltd. 1-9-9 Shibadaimon, Nomurafudosan Shibadaimon Bldg. Tokyo, Japan 105-0012 T +(81)-3-6371-3137 E [email protected]

KOREA Oregon Systems Suite 1226, Doosan Weve Pavilion 58-1 Seoul, Republic of Korea T +(82)-2-735-2372 E [email protected] YPP Corporation YPP Bldg., 24, Gasan Digital 2-ro, Geumcheon-gu, Seoul, Korea T (82) 2 2104 8700 F (82) 2 2104 8711 E [email protected]

KSM Oil & Gas No. 9 Jalan USJ 10/1 D 47620 subang Jaya Selangor, Malaysia T +(60) 356336882 T +(603) 5633-6882 F +(603) 5633-0794 E [email protected] Matrix Power Network SDN BHD Lot 6 Jalan P/1A Section 13 Kawasan Perindustrian Bangi, P.O. Box 9 Selangor, Malaysia T +(60) 389264941 E [email protected]

PHILIPPINES Integrated Controls Corp (ICC) Unit 208 Skyway Twin Towers 351 Captain Henry Javier St. National Capital Region, Philippines T +(63) 26332213 E [email protected] KC Industrial Corporation 1520 Mayhaligue Street Corner T. Mapua Streets Manilla, Philippines T +(632) 781-0102 to 10, 781-0071 F +(632) 711-5115 E [email protected] [email protected] Nayon Kontrol Systems No. 8 Albany St. Barangay Silangan District III, Quezon City, Philippines T +(63) 29131347 E [email protected] [email protected]

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TAIWAN Innova Tech & Management Consultant Inc. 4F, 108, Min Chuan Rd. Taipei City, Taiwan T +(886)-2-2218-6959 E [email protected] PQClean Technology Ltd. 8F, 110 Keelung Rd., Sec. 2 Taipei City, Taiwan 10695 T +(886)-2-2735-0332 E [email protected] Umiak Technology Co. 7th Fl., No.7, Sec. 1 Roosevelt Rd., Zhongzheng Dist. Taipei, Taiwan 10092 T +(886)-2-2393-3283 E [email protected]

GE Locations

YPP (China) Co., Ltd. Room 801-802, Junling Plaza No. 500 Chengdu North Road Shanghai 200003, China T +(86) 21-6374-0746, 6374-0747 F +(86) 21-6374-0730 E [email protected]

JAPAN

THAILAND C.S.N Engineering Co., Ltd. 12, 14 SOI CHAKPHRA 28 TALINGCHAN, BANGKOK 10170, THAILAND T +(66)2 881-4528 E [email protected] Enova Automation Company Limited 134/469 Nonthaburi Rd. T. Thasaia. Muang Nonthaburi Nonthaburi, Thailand F +(662) 967-1379 E [email protected]

VIETNAM Hoang Trang Electric Co. 15A, Nguyen Trung Truc, Ward 5 Binh Thanh Dist. Ho Chi Minh City, Vietnam T +84-8-515-8100 F +84-8-515-8101 E [email protected]

705

Distributor & Representative Sales Offices

Distributors & Sales Representatives Australia, New Zealand & India AUSTRALIA

FIJI

INDIA

CSE Uniserve Pty. Ltd. 10 Columbia Way Parkview Business Centre Baulkham Hills, NSW 2153 Australia T +(61) 2-8853-4200 F +(61) 2-8853-4260 E [email protected] [email protected]

CSE - W Arthur Fisher Ltd. P.O Box 58955 Greenmount - 2141 Auckland, New Zealand T +(64) 9-2713810 F +(64) 9-2651362 E [email protected] [email protected] [email protected]

Graphene Automation Pvt Ltd 181 K, Kunnathusseril Bldg. Pulikkillam East Rd. Kerala, India T +91 48 440 16723 E [email protected]

GE Locations

CSE Uniserve Pty. Ltd. 56 Lavarack Ave., Unit 2 Eagle Farm, QLD 4009 Australia T +(61) 7-3861-7777 F +(61) 7-3861-7700 E [email protected] CSE Uniserve Pty. Ltd. Suite 5, 1st Floor Grand Central 26 Railway Road, Subiaco WA, 6008 Australia T +(61) 8-6380-0900 F +(61) 8-9381-9821 E [email protected] CSE Uniserve Pty. Ltd. 13 Royton Street East Burwood 3151 VIC, 3104 Australia T +(03) 92-45-1700 F +(61) 3-8805-7050 E [email protected] ZNX (2) PTY Ltd. 321 Ferntree Gully Rd., Locked Bag 7000 Mount Waverley, Australia 3149 T +(61) 3 8551 7349 E [email protected]

Kanekar Consulting Engineers Pvt. Ltd 201 Sagar Apartments Raghunath Mhatre Rd , Dahisar-W, Mumbai, Maharashtra, India Pin.: 400 068. T +91 2228944652 T +91 2228907848 E [email protected]

NEW ZEALAND CSE - W Arthur Fisher Ltd. P.O Box 58955 Greenmount - 2141 Auckland, New Zealand T +(64) 9-2713810 F +(64) 9-2651362 E [email protected] [email protected] [email protected]

Megawin Switchgear P.O Box 434 Perumalmalai Adivaram Tamil Nadu, 636004 India T +91 427 233 0498 F +91 427 233 0502 E [email protected]

PAPUA NEW GUINEA CSE Uniserve Pty. Ltd. 10 Columbia Way Parkview Business Centre Baulkham Hills, NSW 2153 Australia T +(61) 2-8853-4200 F +(61) 2-8853-4260 E [email protected] [email protected]

Odin Controls Pvt. Ltd. 1st Floor Medicherla Towers 47-10-3/6 Andhra Prades, India T +91 89122553370 E [email protected] ProtecSol 20, SAPTHAGIRI, 4th cross, Gururaja Layout, Behind Vidyapeetha, Banashankari 3rd Stage, Bangalore – 560 028 Karnataka, India T +91 9845477072 E [email protected] Venson Electric Private Ltd. No. 331 9th Cross, 4th Phase Bengaluru, Karnataka 560058 India T +91 8028360223 E [email protected]

706

GEDigitalEnergy.com

ANSI Standard Device Numbers & Common Acronyms Suffixes

Description

Suffixes

Description

_1

Positive-Sequence

TDO

Time-Delay Opening Contact

_2

Negative-Sequence

TDPU

Time Delayed Relay Coil Pickup

A

Alarm, Auxiliary Power

THD

Total Harmonic Distortion

AC

Alternating Current

TH

Transformer (High-Voltage Side)

AN

Anode

TL

Transformer (Low-Voltage Side)

B

Bus, Battery, or Blower

TM

Telemeter

BF

Breaker Failure

TT

Transformer (Tertiary-Voltage Side)

BK

Brake

U

Under or Unit

BL

Block (Valve)

X

Auxiliary

BP

Bypass

Z

Impedance

BT

Bus Tie

BU

Backup

C

Capacitor, Condenser, Compensator, Carrier Current, Case, or Compressor

CA

Cathode

CH

Check (Valve)

D

Discharge (Valve)

DC

Direct Current

DCB

Directional Comparison Blocking

DCUB DD DUTT

Directional Comparison Unblocking Disturbance Detector Direct Underreaching Transfer Trip

E

Exciter

F

Feeder, Field, Filament, Filter, or Fan

G

Ground or Generator

GC

Ground Check

H

Heater or Housing

L

Line or Logic

M

Motor or Metering

MOC

Mechanism Operated Contact

N

Neutral or Network

O

Over

P

Phase or Pump

PC

Pott: Permissive Overreaching Transfer Trip

PUTT

Putt: Permissive Underreaching Transfer Trip

R

Reactor, Rectifier, or Room

S

Synchronizing, Secondary, Strainer, Sump, or Suction (Valve)

T TD TDC TDDO

Description

AFD

Arc Flash Detector

CLK

Clock or Timing Source

CLP

Cold Load Pickup

DDR

Dynamic Disturbance Recorder

DFR

Digital Fault Recorder

ENV

Environmental Data

HIZ

High Impedance Fault Detector

HMI

Human Machine Interface

HST

Historian

MET

Substation Metering

PDC

Phasor Data Concentrator

PMU

Phasor Measurement Unit

PQM

Power Quality Monitor

RIO

Remote Input/Output Device

RTD

Resistance Temperature Detector

RTU

Remote Terminal Unit / Data Concentrator

SER

Sequence of Events Recorder

TCM

Trip Circuit Monitor

VTFF

Vt Fuse Fail

Phase Comparison

POTT

SOTF

Acronyms

Switch On To Fault Transformer or Thyratron Time Delay Time-Delay Closing Contact Time Delayed Relay Coil Drop-Out

GEDigitalEnergy.com

707

ANSI Standard Device Numbers & Common Acronyms Device No. Description 1

Master Element

33

Position Switch

2

Time Delay Starting or Closing Relay

34

Master Sequence Device

3

Checking or Interlocking Realy

35

Brush-Operating or Slip-ring Short Circuiting Device

4

Master Contactor

36

Polarity or Polarizing Voltage Device

5

Stopping Device

37

Undercurrent or Underpower Relay

6

Starting Circuit Breaker

37P

Underpower

7

Rate of Change Relay

38

Bearing Protective Device / Bearing Rtd

8

Control Power Disconnecting Device

39

Mechanical Condition Monitor

9

Reversing Device

40

Field Relay / Loss of Excitation

10

Unit Sequence Switch

41

Field Circuit Breaker

11

Multifunction Device

42

Running Circuit Breaker

12

Overspeed Device/Protection

43

Manual Transfer or Selector Device

13

Synchronous-Speed Device

44

Unit Sequence Starting Relay

14

Underspeed Device

45

Atmospheric Condition Monitor

15

Speed or Frequency Matching Device

46

16

Communication Networking Device

Reverse-Phase or Phase Balance Current Relay or Stator Current Unbalance

17

Shunting or Discharge Switch

47

Phase-Sequence or Phase Balance Voltage Relay

Accelerating or Decelerating Device

48

Incomplete Sequence Relay / Blocked Rotor

19

Motor Starter / Starting-to-Running Transition Contactor

49

Machine or Transformer Thermal Relay / Thermal Overload

20

Electrically-Operated Valve

18

21

Distance Relay

49RTD 50

Thermal Overload Instantaneous Overcurrent Relay

Ground Distance

50BF

Breaker Failure

21P

Phase Distance

50DD

Current Disturbance Detector

22

Equalizer Circuit Breaker

50G

Ground Instantaneous Overcurrent

Temperature Control Device

50N

Neutral Instantaneous Overcurrent

24

Volts-per-Hertz Relay / Overfluxing

50P

Phase Instantaneous Overcurrent

25

Synchronizing or Synchronism-Check Device

50_2

Negative Sequence Instantanous Overcurrent

Apparatus Thermal Device

50/27

Accidental Energization

27

Undervoltage Relay

50/74

Ct Trouble

27P

Phase Undervoltage

50/87

Instantaneous Differential

Third Hamornic Neutral Undervoltage

50EF

End Fault Protection

Auxiliary Undervoltage

50IG

Isolated Ground Instantaneous Overcurrent

27 AUX

Undervoltage Auxiliary Input

50LR

Acceleration Time

27/27X

Bus/Line Undervoltage

21G

23

26

27TN 27X

50NBF

Neutral Instantaneous Breaker Failure

Flame Detector

50SG

Sensitive Ground Instantaneous Overcurrent

29

Isolating Contactor

50SP

Split Phase Instantaneous Current

30

Annunciator Relay

51

Ac Time Overcurrent Relay

Separate Excitation Device

51

Overload

28

31 32

Directional Power Relay

51G

32L

Low Forward Power

51N

Neutral Time Overcurrent

Wattmetric Zero-Sequence Directional

51P

Phase Time Overcurrent

Directional Power

51V

Voltage Restrained Time Overcurrent

Reverse Power

51R

Locked / Stalled Rotor

32N 32P 32R

708

Device No. Description

GEDigitalEnergy.com

Ground Time Overcurrent

Device No. Description 51_2

Device No. Description

Negative Sequence Time Overcurrent

76

Dc Overcurrent Relay

52

Ac Circuit Breaker

77

Telemetering Device

53

Exciter or Dc Generator Relay

78

Phase Angle Measuring or Out-of-Step Protective Relay

54

Turning Gear Engaging Device

78V

Loss of Mains

55

Power Factor Relay

79

Ac Reclosing Relay / Auto Reclose

56

Field Application Relay

80

Liquid or Gas Flow Relay

57

Short-Circuiting or Grounding Device

81

Frequency Relay

58

Rectification Failure Relay

81O

Over Frequency

59

Overvoltage Relay

81R

Rate-of-Change Frequency

59B

Bank Phase Overvoltage

81U

Under Frequency

59P

Phase Overvoltage

82

Dc Reclosing Relay

59N

Neutral Overvolage

83

Automatic Selective Control or Transfer Relay

Neutral Voltage Unbalance

84

Operating Mechanism

59P

Phase Overvoltage

85

Carrier or Pilot-Wire Receiver Relay

59X

Auxiliary Overvoltage

86

Locking-Out Relay

59_2

Negative Sequence Overvoltage

87

Differential Protective Relay

60

Voltage or Current Balance Relay

87B

Buss Differential

59NU

60N

Neutral Current Unbalance

87G

Generator Differential

60P

Phase Current Unbalance

87GT

Generator/Transformer Differential

61

Density Switch or Sensor

87LG

Ground Line Current Differential

62

Time-Delay Stopping or Opening Relay

87S

Stator Differential

63

Pressure Switch Detector

87S

Percent Differential

64

Ground Protective Relay

87L

Segregated Line Current Differential

64F

Field Ground Protection

87M

Motor Differential

64S

Sub-harmonic Stator Ground Protection

87O

Overall Differential

100% Stator Ground

87PC

Phase Comparison

65

Governor

87RGF

Restricted Ground Fault

66

Notching or Jogging Device/Maximum Starting Rate/Starts Per Hour/Time Between Starts

87T

Transformer Differential

87V

Voltage Differenial

67

Ac Directional Overcurrent Relay

88

Auxiliary Motor or Motor Generator

67G

Ground Directional Overcurrent

89

Line Switch

67N

Neutral Directional Overcurrent

90

Regulating Device

67P

Phase Directional Overcurrent

91

Voltage Directional Relay

67SG

Sensitive Ground Directional Overcurrent

92

Voltage And Power Directional Relay

67_2

Negative Sequence Directional Overcurrent

93

Field-Changing Contactor

68

Blocking Relay / Power Swing Blocking

94

Tripping or Trip-Free Relay

69

Permissive Control Device

70

Rheostat

71

Liquid Switch

72

Dc Circuit Breaker

73

Load-Resistor Contactor

74

Alarm Relay

75

Position Changing Mechanism

64TN

50/74

Ct Supervision

27/50

Accidental Generator Energization

27TN/59N

GEDigitalEnergy.com

100% Stator Earth Fault

709

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GE Digital Energy

Protection & Control

reference guide

Worldwide Offices NORTH AMERICA / WORLDWIDE

EUROPE / MIDDLE EAST / AFRICA

650 Markland Street Markham, ON Canada L6C 0M1 Toll Free (NA Only): 1-877-547-8630 Tel: 905-927-7070

Avenida Pinoa 10-48170 Zamudio (Vizcaya), Spain Tel: +34 94 485 88 00

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GE Digital Energy reserves the right to make changes to specifications of products described in this reference guide at any time without notice and without obligation to notify any person of such changes.

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© 2015 GE Digital Energy

GEA-12909

VOLUME 23

PROTECTION & CONTROL reference guide

VOLUME

23

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