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AGILE DIGITAL SUBSTATIONS The complete guide

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Overview

of Digital Substation Solutions

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Agile Digital Substations

Alstom’s agile digital substation offers unprecedented performance using intelligent primary systems and tailored automation solutions

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Index

Overview of digital substation solutions

The complete digital substation solution........ 8 The benefits................................................. 11 IEC 61850................................................... 13 The architecture of digital substations......... 16 Digital instrument transformers................... 20 Primary converters...................................... 23 Control and monitoring................................ 26 Service & technical training......................... 30 Summary.................................................... 32 Digital substation solutions – Q&A............... 33

GIS solutions

GIS overview............................................... 41 Our mission statement................................ 42 GIS fact sheet index..................................... 43 Digital solutions for GIS............................... 44 Digital instrument transformers................... 47 Data sheets: COSI-RECT............................................. 49 COSI-CEVT............................................. 53 COSI RogoFlex........................................ 57 COSI-PC12............................................. 61 MU Agile XMU800.................................. 65 MU Agile XMU820.................................. 69 BWatch3................................................ 73 Online PDWatch..................................... 79 RPH3..................................................... 83 GIS Service solutions................................... 87 GIS conclusions........................................... 90

AIS solutions

AIS overview............................................... 93 Our mission statement................................ 94 AIS fact sheet index..................................... 95 AIS digital substation overview.................... 96 Data sheets: COSI-CT.................................................. 99

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COSI-CT F3........................................... 105 COSI-PC13........................................... 111 MU Agile XMU820................................ 115 CBWatch-2........................................... 119 DWatch................................................ 125 RPH3................................................... 133 AIS Service solutions................................. 137 AIS conclusions......................................... 139

SAS solutions

SAS overview............................................ 142 SAS global footprint................................... 144 Introducing DS Agile.................................. 145 The complete digital substation solution.... 146 DS Agile key benefits................................. 147 DS Agile components................................. 153 Data sheets: DCS OI................................................. 155 DS Agile Gateway................................. 159 DS Agile WACU.................................... 163 DS Agile bay controllers........................ 165 DS Agile Switchgear Control Unit......... 171 MU Agile AMU...................................... 173 Introducing Protection Relays............... 179 MiCOM Alstom P40.............................. 181 MiCOM Alstom P847............................ 197 P40 Agile.............................................. 203 P60 Agile.............................................. 211 DAPserver™......................................... 219 MiCOM S1 Agile................................... 223 DS Agile H series.................................. 227 SAS conclusions........................................ 229

Online condition monitoring

MS3000.................................................... 233

Reference projects

Jambua, India............................................ 240 Saumade, France...................................... 241 Nadezhda, Russia...................................... 242 Energinet, Denmark.................................. 243

Introduction

Agile Digital Substations

After more than 15 years of advanced research and projects around the world, Alstom Grid’s digital substations now deliver the great potential of this technology: interoperability, ease of configuration, maximised reliability and availability, real-time performance, Smart Grid communications capabilities and reduced cost of ownership. Integration from conventional through to nonconventional substations is ensured, thanks to IEC 61850 compliance. Alstom Grid’s engineering teams can interface with any system, whatever its age or generation. We provide stage-by-stage extensions, whilst keeping the remaining circuits safely in service. Alstom Grid has developed simple tools that enable operators to manage their substations easily and safely while identifying problems quickly. We provide a fully documented solution with clear instructions on interconnecting, testing and commissioning. Moreover, extension and retrofit solutions in the future will not require the original manufacturer to be involved, as everything is designed for interoperability.

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The complete digital substation solution B

C

IEC 61850 Ethernet network

DS Agile substation bay controller

C Hardwire link

A M Condition

monitoring unit

Process bus IEC 61850

B

A D M Condition

monitoring unit

M Analog

merging unit

M Numerical

A

L

merging unit

M Switchgear controlling unit

Fibre optic link

A

Condition monitoring unit

M

Smart primary equipment

M

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Merging units integration

Agile Digital Substations

D

E

DS Agile switches

F

DS Agile A300 substation gateway

G

Remote access and telecommunication

Grid control room

Cyber security G

F

F

H

I

E

I

F Central access server

K D

B Station bus IEC 61850

J F

H I J L

Precision time protocol

K

System Configuration Editor (SCE)

DS Agile Operator Interface (OI)

DS Agile A400 WACU / SACU

MiCOM protection and other IED integration

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Alstom Grid agile digital substations – key advantages Based on the IEC 61850 unifying communication standard for complete information, future modernisation and the integration of new systems. Digital Control Systems may connect with the primary bays via a process bus built on redundant Ethernet architectures. Merging and control units collect and translate measurements, indications and commands (I/O) from the primary equipment into sampled values and GOOSE messages and vice-versa Digital instrument transformers and HMI (Human Machine Interface)-integrated condition monitoring systems for the primary equipment can be added, providing superior substation situational awareness locally and remotely.

Optimise your operational costs Asset managers now have a critical tool that, with less wiring and fewer commissioning tests, optimises preventive maintenance and can extend the lifetime of the entire substation, including third party plant items. Alstom Grid’s digital solutions: ■■ Maximise the reliability of your substation ■■ Operate assets more efficiently and safely close to the limits of the system ■■ Optimise maintenance, repair and retrofit of equipment with minimal outages

Complete and adaptable solutions Alstom Grid’s digital solutions solutions are available for: Retrofit and extension schemes, as they reinforce conventional tools and systems ■■ New substations ■■ The particular solution and architecture can be adjusted to meet your operational needs according to how critical your asset and substation is to the network. ■■ Extensions and modifications are easier, as the substation functions via software, not hardware. ■■

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Agile Digital Substations

Alstom Grid’s digital substation – the benefits Increased reliability and availability The extensive self-diagnostic capabilities of digital devices ensure the maximum availability of the substation, as well as its full suite of functionalities: any degradation in the performance of an asset is pinpointed in real-time. The inherent redundancy built into the system can be employed to self-heal and permits troubleshooting without the need for primary system outage.

Optimised operation of assets The intelligence within digital substation schemes allows close monitoring of the load capacity of plant equipment, based on their design ratings. This dynamic load analysis means that lines, cables, transformers and other grid equipment can operate closer to their limits.

Improved safety Removal of wired cross-site CT (Current Transformer) circuits reduces the risk of fatal injury due to inadvertent opening of the circuit by personnel ■■ Absence of oil in transformers reduces explosion risks ■■ Advanced self-monitoring of substation assets ensures that they are operating within safe limits ■■

Reduced maintenance costs The digital substation closely monitors all substation assets in terms of operational conditions, effective load capacity and asset health indicators. Intelligent systems analyse the data and provide recommendations on maintenance and repair actions. This allows a shift to predictive maintenance, avoiding unplanned outages and emergency repair costs.

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Investment optimisation The capital cost of investment projects is reduced on many fronts: ■■ savings on the time needed to engineer and install substations ■■ reduced real-estate needs ■■ copper cabling is cut by up to 80% through the use of optical fibre ■■ asset optimisation tools allow faster targeting of weak areas which need to be reinforced, allowing for reduced operational costs

Easier renovation and extension of existing substations Interoperable solutions and the use of fibre optics instead of copper wires reduce the duration and costs of unavailability of substations during the refurbishment phase of secondary equipment. This also applies to extension works.

Standardisation and interoperability Being IEC 61850 compliant, Alstom Grid digital solutions and substations are designed to be interoperable with other vendors’ equipment, with a strong degree of standardisation at the interface level of secondary equipment systems.

Improved communication capabilities Data exchange between intelligent devices, intra and inter- substation, is optimised through Ethernet communications. Smart local and wide area control units allow data exchanges between voltage levels within substations and between substations. Direct inter-substation communication without the need to transit via a control centre reduces the response times, enabling fast, real-time applications.

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Agile Digital Substations

IEC 61850: the key technology enabler Modern sensors and other Intelligent Electronic Devices (IEDs) must be connected to communicate within the substation and over the greater grid system. In the past, there were many different protocols requiring much effort to make them communicate with each other. Insufficient standardization, fear of degraded reliability and lack of return on investment slowed down the emergence of the fully digital substation. But today, the IEC 61850 standard makes it possible to facilitate interoperability between different equipment and suppliers. Introduced in 2004, the IEC 61850 standard is increasingly accepted across the world, as its main objective is to ensure interoperability between equipment coming from various suppliers. IEC 61850 continues to evolve and encompass the needs identified by the industry’s user group (UCA UG),

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ensuring that it caters to all substation needs. IEC 61850 is rapidly being enriched as new application areas are continually added, most notably IEC 61850-8-1 and IEC 61850-9-2. This permits the full digitising of signals in a substation so that large amounts of data can be managed and communicated for the real-time management of a modern power grid – a smarter grid.

IEC 61850 IEC 61850 is the international standard for Ethernet-based communication in substations. It is more than just a protocol, it is a comprehensive standard designed for utilities, to deliver functionalities that are not supported in legacy communication protocols. IEC 61850 defines a domain specific data model (data and services) supporting all functions required in substations. These unique characteristics can significantly reduce costs associated with designing, installing, commissioning and operating power systems. IEC 61850 is designed for interoperability and longevity, removing the dependence on one supplier and one generation of IEDs.

IEC 61850-8-1 IEC 61850-8-1 is the relevant standard for the station bus. It defines the means to generate and present reports which may be subscribed to by other devices and HMIs (Human Machine Interfaces) as well as the way to communicate peer-to-peer. The latter is achieved by the exchange of GOOSE messages between devices on the LAN (Local Area Network).

IEC 61850-9-2 IEC 61850-9-2 is the part of the standard that brings non- conventional instrument transformer technology into play, breaking the constraints of conventional CTs and VTs. It is particularly important for the process bus, as it describes how analogue signals such as phase currents and voltages can be exchanged as sampled values.

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Agile Digital Substations

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The digital substation architecture can be divided into three levels

Remote access

WAN

The station control area

Advanced

Communication within substation and control system, coordination with the substation operational functions and the station-level support functions.

Gateway

Switches

The protection and control level

Protection and control of substation equipment includes IEDs traditionally called “secondary equipment” (protections, measurement devices, bay controllers, recorders...)

Bay controllers

Switches

The primary equipment process level

Capture of voltage and current signals, consolidation, processing, and transmission of data via optical fibres: intelligent primary devices (electronic power and instrument transformers, circuit-breakers, disconnectors) and optic fibre have replaced traditional CT/VT systems and conventional cable wiring.

Figure 1 Generic overview of a digital substation 16

Analogue and digital merging units

Protection relays

Agile Digital Substations

The architecture of Alstom Grid digital substations Grid control rooms

d substation situation awareness HMI

Alstom Grid’s digital substations incorporate the newest DS Agile digital control system that provides the complete architecture, connecting all the components, together and with the operator interface, through an IEC 61850 Ethernet network. DS Agile digital substation solutions are highly scalable in terms of equipment, functions, architecture and services.

STATION Bus

Phasor data concentration

Wide area control

Process Bus

Conditioning monitoring units

Primary equipment with embedded digital sensors

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A typical Alstom Grid digital substation solution incorporates many components, all designed for optimal inter-operability, data retrieval, protection and control capability and remote settings. Its architecture is organised on three levels:

1. The process level A digital substation is based on a communicating architecture, where real-time operational measurements and other data are polled from the primary system by sensors embedded within the primary system. This data is communicated to devices that must act on those measurements (pressure or temperatures in GIS switchgear, current and voltage measurements) via a “process bus”. Most important is that smart devices and systems within the substation, (protection relays, recorders, phasor measurement units, bay controllers, wide area controllers) can immediately process this data. By subscribing as clients to this data flow over an Ethernet process bus, the information from the ‘eyes and ears’ of the power system is distributed and communicated much more efficiently to the bay level than in conventional hardwired schemes. The process bus is also the link by which the primary equipment information from out in the yard travels back to the substation control room. In a fully digital architecture, control commands are also routed to the primary devices via the process bus. The process bus, therefore, enables time-critical services.

2. The protection and control level Between the process bus and the station bus are devices identified as ‘secondary equipment’. In the digital substation, these devices are IEDs (intelligent electronic devices), interacting with: the field via the process bus; with other peer devices in the bay; with other bays, and with the digital control system via the station bus. They are designed to provide the Smart Grid applications demanded by utilities via real-time and secure equipment. They provide interoperable solutions, stability applications, wide area protection & control plans, and more globally, substation situation awareness. 18

Agile Digital Substations

Key components are: the protection relays, bay controllers, switches and Ethernet network, measurement and recording devices, substation proxy, the operator user interface within the substation control room, time synchronization units, security applications and the panels where all this equipment is commissioned and energised. IEC 61850 communications enable complete integration between devices. It ensures optimal use of the information for the continuity and reliability of electrical grid operations in secured access situations.

3. The station control area The digital substation station bus is much more than a traditional SCADA bus, as it permits multiple clients to exchange data, supports peer-to-peer device communication and links to gateways for inter-substation wide-area communication. The IEDs perform their time critical functions such as protection, point-on-wave switching supervision and other tasks via direct interaction with the process bus. Additionally, other clients in the substation may require information-sharing of some or all of this data. For example, protection and control schemes may be distributed amongst multiple IEDs. There is also the need to distribute the information to local or remotely-stationed control operators so they can visualise the operational status of the substation in real-time. This requires substation HMIs, proxy server links to remote HMIs and control servers. One or more workstations can apply the instructions assigned by regional dispatchers, or can be used as an engineering workstation for IED configuration, or for local concentration and archiving of power system data. Online condition monitoring may have specific workstations for alerts and to manage the database history of each primary device. Using industry norms and enabling technologies to their fullest, Alstom Grid’s global experts now bring the digital substation to the market. Whether for incremental refurbishment, or complete green-field installations, Alstom has the equipment, the system delivery capability and project management expertise to be operational first time and on-time. The component parts of this offer are detailed in further sections. 19

Agile Digital Substations

Digital instrument transformers Decades of extensive research by Alstom Grid has delivered proven non-conventional instrument transformers, designed to be accurate, intelligent, safe, cost-effective – and very importantly – core-less. The root of many of the limitations of conventional instrument transformers is their reliance on an iron core. The core is a source of inaccuracy, due to the need to magnetise it, but not to overflux it. In the case of conventional CTs, achieving the low- level accuracy and dynamic range to satisfy both measurement and protection duties is a challenge. Conventional VTs may experience ferroresonance phenomena resulting in thermal overstressing. Instead of an iron core, the translation from primary to secondary measurement uses optical, Rogowski or capacitive technology, with the optimal choice for AIS (air-insulated substation) and GIS (Gas-Insulated Substation) equipment driven by the size of the respective digital device, which allows size optimisation for the switchgear. A wide array of sensors monitor conditions in real-time thanks to multiple applications: diagnostic analysis, asset management and condition-based maintenance. Alstom Grid COSI (COmpact Sensor Intelligence) solutions: Device

Description

Optical Sensor

Faraday optical technology devices: COSI-CT: Composite optical CT COSI-CT F3: Flexible, portable optical current sensor

Rogowski Sensor CT

COSI-RECT: Rogowski coil for current measurement COSI-Rogoflex: Flexible Rogowski current sensor

Capacitive Sensor VT

COSI-VT: AIS voltage transformers

COSI-CT-F3 20

AIS GIS AC •

•

•

•

•

COSI-CEVT: GIS voltage transformers

COSI-RECT

•

• •

COSI-CEVT

•

DC •

Agile Digital Substations

The facts

Optical sensors use the Faraday effect. A fibre optic loop sensor carrying a polarised light beam encircles the power conductor. This light will experience an angular deflection due to the magnetic field, generated by the primary current flow. The sensor’s intelligence is to accurately determine the primary current based on the real-time optical measurement. ■■ Rogowski sensors dispense with the conventional CT core and instead implement windings as tracks on a multi-layer printed circuit board. Four quadrants of the board are clamped together to form a toroid around the primary conductor. The sensor output becomes a lowlevel voltage measurement, which can be accurately correlated to the primary current. ■■ Capacitive dividers dispense with the conventional VT core. Capacitors are built from slimline film stacks for AIS sensors or printed circuit board electrodes laid on the interior of the enclosure for GIS sensors. ■■

Customer benefits

Enhanced safety: no risk of explosion, no wired CT secondary circuit running crosssite ■■ Measurement precision coupled with protection dynamic range ■■ No saturation, ferroresonance or unwanted transients ■■ Long-term accuracy ■■ Outstanding seismic resilience ■■ Unparalleled reliability and availability with full self-diagnostics ■■ Lightweight, compact and flexible ■■ Minimal inventory, near-zero maintenance ■■ Harmonic monitoring ■■ Online condition monitoring ■■

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Agile Digital Substations

Primary converters Converters

Alstom Grid digital substations optimise the amount of electronics residing in potentially harsh outdoor environments. The primary converters convert analog signals from the primary equipment into digital signals. Primary converters can be installed either directly in primary plant hardware or in cubicles. Digital controllers (switch control units) are the fast, real-time interface to switchgear, mounted close to the plant that they command. They replace the hardwiring of inputs and outputs with an Ethernet interface to the yard.

Merging units

Merging units perform all the digital data processing necessary to produce a precise, time-aligned output data stream of sampled values according to the IEC 61850-9-2 standard. This processing includes tasks such as sampling, analog to digital conversion, scaling, precise real-time referencing and message formatting. The design may vary with the applied technology of the instrument transformers (eg: optical, Rogowski, voltage dividers, or conventional wound instrument transformers), the switchgear type, mounting space available and also with the preferred substation communication architecture. 23

Device

Description

DS Agile SCU

Switchgear controller unit: Processes the I/O signals from/to the primary switchgear as IEC 61850-8-1 GOOSE messages

MU Agile AMU

Standalone compact merging unit: Digitising of conventional 1A/5A and 100/120V analog secondary circuits

MU Agile XMU800

Modular digital merging unit: Interfaces with multiple primary converters in the field

MU Agile XMU820

Modular merging unit: Interfaces with digital and conventional instrument transformers

MU Agile NXMU

Modular merging unit: Interfaces with COSI optical CTs and conventional VTs

Customer benefits

Interfaces with all types of power system current and voltage sensors, whether digital instrument transformers (DIT) or conventional CT/VT ■■ Ensures accuracy of protection applications up to highest fault currents and X/R ratios ■■ Ensures measurement accuracy ■■

Primary converter

MU Agile

MiCOM IEDs

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Agile Digital Substations

Digital protection relays

MiCOM Alstom is a complete range of IEDs designed for digital substation architectures. The full range of transmission protection is included, from the simplest back-up device, to subcycle tripping main protection schemes. In a fully-digital architecture, the relays receive currents and voltages as IEC 61850-9-2 sampled values and issue trip or alarm signals using IEC 61850-8-1 GOOSE. The flexibility of MiCOM allows you to adopt new technology tailored to match your pace of change – from initial station bus digital MiCOM P40 Agile integration, up to full station and process bus schemes. The following table indicates the typical relays selected, and their main functions: Device

Principal Application

MiCOM Alstom P446

Subcycle distance protection with integral teleprotection and one or two breaker reclosing

MiCOM Alstom P546

Line differential for 2 or 3 terminal lines with subcycle distance and one or two breaker reclosing

MiCOM Alstom P645

Transformer differential for up to 5 ends with advanced loss-of-life thermal monitoring

MiCOM Alstom P746 & P743

Digital busbar protection for centralised smaller schemes up to large decentralised bus configurations

MiCOM Alstom P841

Transmission line terminal IED for backup, reclose and breaker fail management

MiCOM Alstom C264P

One-box solution feeder protection with control and bay mimic diagram

Customer benefits

Proven algorithms of conventional applications remain unchanged, no need for reapproval Time-critical performance is maintained irrespective of the architecture, number of functions enabled, or extent of logic programmed ■■ Safer test and maintenance operations for technicians – no wired CT secondary circuit exists ■■ Accurate measurement capabilities – as accurate as the incoming -9-2 data itself ■■ Station bus communication redundancy available: PRP (Parallel Redundancy Protocol) and RSTP (Rapid Spanning Tree Protocol) ■■ ■■

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Also available, the MiCOM P847 phasor measurement unit offers industry-leading accuracy and dynamic response to frequency excursions. The MiCOM P594 provides the precision clock source reference for merging units and phasor measurement units in the substation. MiCOM Alstom IEDs extend their supervision facilities to address and check the plausibility of the incoming sampled values from the process bus. This addresses the fact that the traditional task of current and voltage sampling is now external to the device, and is connected via Ethernet. The supervision compensates for any latency or mismatch in the network, provides ride-through intelligent compensation in the event of several missing samples or jitter, and blocks/alarms if the quality of incoming data compromises the secure and reliable operation of the IED.

Control and Monitoring Alstom Grid’s DS Agile range is the latest generation of substation Digital Control Systems (DCS). It relies on fast Ethernet networks with IEC 61850 communication standards and offers topology-orientated automation combined with electrical security to minimise outages. DS Agile can be tailored either to single substations or to a harmonised system across multiple substations. Devices

Applications

DS Agile bay controllers (C-series)

Alstom’s IEC 61850-compliant bay controllers, like the C264, provide embedded or programmable fast automation (automatic voltage regulation, synchro-check, autorecloser, busbar transfer, etc.), backup feeder protection, data concentrator, events and waveform recorder, hot standby redundancy etc.

DS Agile OI

Real-time, user-friendly Operator Interface (OI) for complete substation automation

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Agile Digital Substations

Redundant architectures DS Agile architectures can be set up as a self-healing ring (HSR protocol) or dual-homing star (PRP protocol); both of which are fully redundant, eliminating outages. Fibre optical networks link all the system’s components together and with the operator interface (HMI), via a full range of Ethernet switches that provide full reliability and interoperability. Devices

Applications

DS Agile switches (H-series)

GOOSE switches External (rack) or internal Interoperable standard protocols (PRP/HSR) Gigabit switches IEEE 1588 transparent clock

Substation/grid control room communications The digital substation benefits from a wide-area network interface, receiving and responding to the data from its extensive array of sensors and IEDs. It can be integrated as part of the grid operator’s wide area control systems and defence plans, as the data from Phasor Measurement Units (PMUs) is concentrated and relayed from the substation to the control centre Customer benefits and analysed by online stability solutions to track current ■■ Reduced unscheduled oscillations and anticipate incidents. outages and repair times Alstom’s digital substation sensors and control systems ■■ Reduced routine work seamlessly with its software platforms for grid maintenance costs operator control rooms, allowing a real-time data exchange ■ ■ Increased equipment both at the substation operational data level and at the life expectancy asset management data level. This substation / control ■■ Frees-up skilled room communication introduces Smart Grid capabilities personnel for remote to the network, bringing complete synergy between field diagnostics and equipment operations and network management systems. operation centres The networks can be local to the substation or they 27

can interconnect several dispersed substations, and all are linked to the grid control room through gateway solutions. Inter-substation or intervoltage level automation exchanges GOOSE messages for: ■■ Logic selectivity ■■ Auto-reclose and fault location ■■ Automatic setting of the relays

Devices

Applications

DS Agile A300 Gateway

Powerful and ruggedised gateway solution that offers multiple communication protocols (including full IEC 61850 compliance) with hot-standby redundancy and simple commissioning

DS Agile A400 Substation inter-voltage (SACU) and SACU & WACU inter-substation (WACU) level exchange through IEC 61131 automation IEC 61850-compliant hot-standby redundancy

Cyber security The digital substation brings increased cyber security capabilities, as intrusion protection and protection against virus attacks are integrated in switches and IEDs. Cyber security provides protection against unauthorised access to equipment and unauthorised transfer, modification or destruction of data – whether deliberate or accidental. Particularly when wide area networks extend beyond the traditional substation fence, cyber-security measures are essential. Security procedures, controls, firewalls and rolebased access are all examples of such measures. A number of standards apply in this area, typically: NERC CIP, IEEE 1686, IEC 62351, ISO/IEC 27002, ETSI and CEN CENELEC.

C264 bay controller

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DS Agile switches

Agile Digital Substations

Online condition monitoring and asset management Online condition monitoring functions are essential for power transformers, circuit-breakers, disconnectors and gas-insulated switchgear. Physical parameters are continuously monitored and real- time measurements are combined and compared to models in order to generate specific recommendations for operations and maintenance, as well as alarms when necessary. Expert software providing additional advance warnings, automatic diagnostics and maintenance suggestions will boost the efficiency of asset management. An interface with an asset management system yields additional features such as remaining lifetime or dynamic rating capabilities. This architecture gives operational and maintenance teams an overview of the condition of all substations in real-time, so they can make appropriate strategic asset management decisions. Device

Principal applications

PTWatch MS3000

Power transformer condition monitoring: expert system for data management throughout the life span of the power transformer, with scalable range of sensors and modules for online continuous monitoring of all major components of the transformer (active parts, bushings, tap-changer and cooling system)

BWatch

GIS bay condition monitoring: interactive diagnostics, acquisition of pressure and temperature, threshold management, leakage, density and liquefaction calculation, internal arc location, enclosure overheating detection

PDWatch Partial discharge condition monitoring for GIS GISWatch Integrated bay & partial discharge condition monitoring for GIS CBWatch

Circuit-breaker condition monitoring: moving part timings and travelling curves, main contact wear, drive energy and auxiliary parts are continuously monitored

DWatch

Disconnector condition monitoring

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Services & technical training for Agile Digital Substations Alstom Grid service is committed to provide the support from retrofit solution engineering to the full lifecycle of the substation by leveraging the expertise of a worldwide leader in primary product manufacturing, condition data interpretation and product ageing models.

Expertise and consulting services

In addition to the real-time data information and alerts interpretation consulting services, reviews can be complemented with on-site condition assessment of the full system – equipment, sensors, data communication and IED processing units. This assessment provides the information needed for asset management strategies such as maintenance, repairs and residual life assessment, while maximising the asset reliability performances and minimising operational risks. Services can be provided either on an on-call basis, or a long term contract tailored to your needs.

Technical training

Dedicated technical training develops the knowledge and skills required to operate and maintain digital substations for peak performance. Gaining theoretical and hands-on experience at one of our training centres, Alstom Grid Technical Institute, ensures teams’ efficiency in their daily work. Our training offer on digital substation applications encompasses several topics such as cyber security, graphical programmable scheme logic, Ethernet ready solutions and online condition monitoring for circuit-breakers, CTs & VTs or DC supplies. Furthermore, this training is complemented by training on power equipment operation and maintenance, network management solutions and electrical safety.

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Agile Digital Substations

Digital retrofitting of substations

Alstom Grid’s engineering teams can interface with any system, whatever its age or generation. Simple tools, specifically developed, enable operators to manage their substation easily and safely while identifying problems quickly. Alstom Grid provides a fully documented solution with clear instructions on interconnecting, testing and commissioning. Moreover, as everything is designed for interoperability, a unique service provider will be able to maintain the equipment and manage the digital retrofitting of the substation in the future.

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Agile Digital Substations

Summary Alstom’s agile digital substation offers unprecedented performance using intelligent primary systems and tailored automation solutions. Digital components can be effectively and easily integrated into existing substations, networks and grids, allowing users to gradually move from conventional to digital solutions. This ability to integrate Alstom digital substation components allows for operator training, system testing and incremental investment while ensuring future compatibility.

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Agile Digital Substations | Q&A

Digital substation solutions – Q&A

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Let’s share some of the questions we have heard asked about digital substations so far, and the answers we provided.. “I am not sure about the reliability and accuracy of process bus solutions”

Regarding reliability and system architecture: Sometimes users express concern about the architecture of the digital solutions because it is different. With analogue solutions the information chain was: sensor then cable then relay. Now the route is different with sensors, fibre optics, station bus and process bus. Even though the architecture may seem more complex to non-specialists, the solution is extremely reliable, because it has auto-test and health-check capabilities that analogue solutions do not have. Regarding accuracy: The information is digitised from the source, so the information conveyed is very accurate. Indeed, accuracy is much improved, especially with digital instrument transformers, as there is no CT/VT iron core to magnetise or introduce measurement error.

“These systems transfer too much unnecessary/ unimportant information” “The information which is delivered is too complicated to analyse”

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Digital solutions are able to capture and transfer a lot of information, not only simple 0/1 values. Of course, more information means users have to interpret it and to define for each parameter the alarm thresholds. Alstom offers many functions to make the best out of digital systems. a. Expert support is available at all stages to design and parameter, analyse etc. b. Alstom solutions offer user-friendly interfaces with simple colour coded indicators: green = ok, orange = warning, red = not ok. c. Alstom solutions enable users to select the information displayed according to the user’s profile, as operation staff, maintenance staff or asset managers do not need to monitor the same things. Alstom makes it possible to give the right information to the right person. For example, the systems can generate data sets for managers once a day, while they can display the information in real time for operation people.

Agile Digital Substations | Q&A

“Only experts can use the information received from these systems”

d. Alstom solutions can concentrate and filter information before it is sent to upper levels of the system hierarchy. This avoids placing unnecessary bandwidth constraints on the communications network.

“What about the life time of electronic components?”

Electronic components obsolescence is a point of interest for network operators although such technologies are now used in many industrial applications, and well-proven in Digital Control Sytems and numerical protection relays.

“What will happen if we need to replace components?”

Solutions are designed incorporating the necessary ‘functional sustainability’ which implies that all new developments will replace/be compatible with older generations. Changing a component in 20 years, while keeping the same functionality, is made easier with Alstom. As regards the life time of digital components, the MTBF of many components is actually several decades. Temperature is the most impactful parameter when talking about the life time of digital components and the industry improves continuously. Alstom choses electronic components that have been selected to withstand higher temperatures and therefore feature longer service life. Furthermore Alstom solutions withstand extensive thermal testing during their design and development. Last but not least: with analogue solutions, if a component does not work, you might not know it unless you perform visual tests. Digital solutions incorporate automatic health check and if a component is out of order, it will give a signal, ensuring the reliability of the whole solution. And what may happen in 15 or 20 years if a component might need to be replaced? Alstom ranges are managed so as to replace the components and solutions gradually as they become obsolete, maintaining the same functionality. Service specialists are dedicated to supporting customers after the warranty period and to supply with the right component or solution.

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“Implementing digital solutions will be difficult” “We do not have the skills in-house to implement such systems”

I mplementing a substation with digital control and monitoring will actually be easier than implementing a substation with analogue systems. The main reason is that the whole cabling adventure is a thing of the past! Cabling in a HV substation is reduced by approx. 80%. For the design and implementation of the digital systems themselves, Alstom experts provide support and all the solutions are scalable, meaning that they can be implemented one stage at a time. For example, conventional current and voltage sensors can be linked via fibre optics to digital merging units and protection relays, so as to reduce the cabling, while keeping the conventional substation equipment. Note that much of the digital system engineering is in software, which means that the maximum can be engineered and proven before the FAT (factory acceptance test). The site works are drastically reduced, meaning that the more senior specialists need not travel to each project site. Alstom delivers training to all involved staff: ■■ ■■ ■■ ■■

Architecture and design of solution Maintenance Operation Asset management

The younger generation of network engineers are educated and very familiar with these technologies. As the future is digital, the training and knowledge gained is career enhancing, so utilities can remain attractive to talented young engineers!

“The information given by the system requires highly skilled people to interpret it” 36

 lstom solutions range from the most basic information delivery to A expert systems. We are able to discriminate the right information for the right person according to his/her position and profile. Expert systems also include some analysis and clever data display, so as to make the reading and interpretation easier. Training is available for all positions from operational staff to asset management executives.

Agile Digital Substations | Q&A

“Is it right that the safety of my staff can be enhanced?”

Digital devices run on Safety Extra Low Voltage (SELV), meaning that staff are at no risk while working with them.

“What are the references?” or “which utilities have already implemented such systems?”

In 2013, Alstom has installed a base of:

The elimination of oil in instrument transformers (removal of explosion risk), and the removal of cross-site current transformer circuits (risk of lethal injury if open-circuited whilst live) are the two principal examples of staff safety being improved.

Protection : over 400 000 digital relays Control : more than 3000 control systems ■■ Monitoring : more than 1300 GIS bays There are specific case studies in the ‘Reference Projects’ section of this handbook. ■■ ■■

37

Agile Digital Substations | Q&A

A quick visual guide to answering questions and overcoming objections System concerns Reliability and accuracy

Permanent health check capabilities + info digitised at its source

Too much information Too complicated

+ User-friendly HMI + tailored datasets + expert support

Life time of components

Functional sustainability + robustness of the design and component selection

New solution

Numerous references, pilot projects and real installations

Implementation concerns Difficulty to implement

Easy to implement + scalable solutions

38

Need for experience/skills for results analysis

How to replace a component

Alstom provides training + such skillsets more available in the engineering community today

Functional sustainability + dedicated service specialists

GIS Solutions

39

40

GIS Solutions

Digital solutions for GIS With more than 40 years of operational experience in power substation provision, Alstom Grid is a leader in the GIS market. Our leadership is largely thanks to meeting the most demanding operational criteria through the sustainable process of improvement of our solutions. We offer a complete GIS range from 72.5 to 800 kV to interconnect and protect electrical networks. We have manufactured and commissioned more than 20,000 GIS bays from 72.5 up to 800 kV and 150 km of GIL circuits worldwide over the last 45 years. We focus on smarter solutions, integrating devices for predictive maintenance including online bay monitoring (BWatch3), Partial Discharge measurement (PDWatch) and point-on-wave controlled switching (RPH3) We are shrinking the technology footprint to maximise space efficiency and flexibility. For example, our F35 170 kV has a footprint 30% smaller than its predecessors.

41

Our mission statement Alstom Grid’s GIS product line provides power networks and industrial customers with state-of-the-art Gas-insulated substations from 72.5 kV to 800 kV. We offer: Most compact GIS range ■■ Optimised products at all voltage levels ■■ Fully eco-designed products ■■ First class spring-mechanisms ■■ Connectivity for Smart Grids with integration of automation and monitoring systems ■■

42

GIS Solutions

GIS Solutions Fact sheets Digital Instrument Transformers - DIT COSI-sensors COSI-CEVT sensor ■■ COSI-RECT sensor ■■ COSI-Rogoflex sensor ■■

Primary converters ■■ COSI-PC12 Merging units ■■ MU Agile XMU800 ■■ MU Agile XMU820

Monitoring and control SF6 and GIS monitoring ■■ BWatch3 Partial discharges monitoring ■■ PDWatch Point-on-wave switching ■■ RPH3

43

Digital solutions for gas-insulated substations The new generation of GIS digital substation solutions bring unprecedented levels of reliability, security and performance through real-time monitoring, automation and interoperability. They integrate high performance primary equipment including Alstom’s COSI (COmpact Sensor Intelligence) and advanced substation automation solutions. Information acquisition, processing and output is treated in real-time through a digital architecture with multiple layers of automation units.

GIS Bay 44

GIS Solutions

45

Bay introduction Combined disconnector / earthing switch

Spring drive

Circuitbreaker Local control cubicle

Combined voltage & current sensors

Busbar disconnector / earthing switch

Cable feeder

Full digital control cubicle Reduced cabling 46

GIS Solutions | DIT

Digital instrument transformers Our range of digital instrument transformers provide measurement using optical, Rogowski or capacitive technology, which have been optimised for operation with GIS equipment, integrating into the relevant switchgear to provide accurate realtime measurement of key operational parameters.

47 47

GIS Solutions | DIT

COSI sensors

Current sensor

Voltage sensor

Current & voltage measurement Current sensor

Voltage sensor Protection relays

Primary Converter (Signal-conversion of analog/digital)

Bay controller

9.2 508 1 6 IEC Merging unit (Conversion to IEC 61850-9-2) IEEE 1588 synchronisation 48

IEEE 1588

GIS Solutions | COSI-RECT sensor

Fact sheet – Gas insulated substations

COSI-RECT

Rogowski electronic current transformer for GIS High voltage designs now increasingly incorporate Smart devices - making Smart substations part of the real world. In the digital chain for current measurement, the COSI-RECT uses the latest sensor technologies for DIT applications.

Customer benefits One single sensor design suitable for protection, metering and qualimetry ■■ Sensor enclosures are smaller than conventional ones space gains for substations ■■ High degree of electromagnetic immunity ■■

4949

Integrated voltage sensor

Integrated current sensor

Measure

Primary converter

Convert

RECT: High-tech sensor

Less maintenance

Sensors are the basic elements of current measurement. In order to get the best results for final measurement or protection applications, the sensor must be highly accurate and should be protected against the electromagnetic perturbations (EMC) found in GIS substations.

Thanks to the coating on the PCBs and the highly accurate processing, the sensors are designed to work whether conditions are optimal or not.

Sensors are designed based on an Alstom patent, using a double-sided PCB (printed circuit board) as sensor material. This provides an excellent stability in the measurements, even when temperature and currents have slight variations.

Compatible with all GIS types Several sensor designs have been introduced to cover all types of high voltage equipment. RECT sensors are available for all GIS equipment. Their small size allows for smaller enclosures and consequently smaller GIS substations.

An external memory (EEPROM) is associated to the sensor allowing all calibration values to be stored as soon as the sensors are mounted. Thus, when a sensor is connected to the PC12 primary converter, the electronics automatically adjust the compensation gains related to calibration values found in the EEPROM.

Maximum protection against EMC Based on an Alstom patent, sensors are on a double-sided PCB with interlaced copper tracks, providing high immunity against EMC and external magnetic fields. The PCB is shielded to have a perfect immunity against nearby magnetic fields.

50

GIS Solutions | COSI-RECT sensor

important note: This product may not be sold on its own. It must always be integrated in a global DIT engineering solution.

Merging unit

Merge IEC 61850

Protection relay

Protect

Single-phase GIS design

Three-phase GIS design

COSI-RECT 550 kV

51

GIS Solutions | COSI-RECT sensor

Ratings (sensor associated with PC12) Module type

Technical features ■■

PC12-3I 3 x RECT*

Rated voltage

kV

-

Rated current

kA

Up to 150

Accuracy 50/60Hz

%

<0.05

Delay time

μs

<500

Sample Values Output rate (IEC 61869-9) ■■ Protection channel ■■ Metering channel ■■ Qualimetry channel

KSPS KSPS KSPS

4.8 /4 /5.76 4.8 /4 /5.76 14.4 /12.8 /15.36

FFT Analysis Harmonics (qualimetry channel only)

Harmonic rank

100

Frequency domain (sensor imput)

Hz

0-10K

A/D converters

Qty

2 + 3 refs

Auxiliary Channels

Type

4/20 mA, RTD150

MTBF (acc. To MIL-HDBK-217F)

khrs

>350

Weight

kg

1.2

*RECT: Rogowski Electronic Current Transformer.

52

■■

■■

■■

■■

■■

Rated supply voltage 48 Vdc (proprietary input) connected to PC1 power supply (48 - 350 Vdc / 100 240 Vac) Power cons. < 10 W @ 20°C Ambient temperature -40°C up to 80°C Protective index IP64 compliant Case material Magnetic Stainless Steel EMC Protection IEC 61000-4 1,3,4,5,6,8,12,13,16 Class 3 to 5, 18 55022 Class A Standard (instrument transformers) IEC 61850-9-2 IEC 61869 -1, -6, -7, -8, -9

GIS Solutions | COSI-CEVT sensor

Fact sheet – Gas insulated substations

COSI-CEVT

Capacitive Electronic Voltage Transformers for GIS High voltage designs now increasingly incorporate Smart devices - making Smart substations part of the real world. In the digital chain for voltage measurement, the COSI-CEVT uses the latest sensor technologies in voltage measurement for DIT applications.

Customer benefits One single sensor design suitable for protection, metering and qualimetry ■■ Sensor enclosures are smaller than conventional ones space gains for substations ■■ High degree of electromagnetic immunity ■■

53

Integrated voltage sensor

Primary converter

Measure

Convert

CEVT: High-tech sensor

Less maintenance

Sensors are the basic elements of voltage measurement. In order to achieve the best accuracy for final measurement or protection applications, sensors must be as accurate as possible and protected against electromagnetic perturbations (EMC) that exist in GIS substations.

Thanks to the particular coating on the PCBs and highly accurate processing, the sensors are designed to work whether conditions are optimal or not.

Sensors are designed following an ALSTOM patent which uses a doublesided PCB (printed circuit board) as the sensor material. This provides excellent stability in the measurements, even if temperature, pressure and voltages have variations.

Compatible with all GIS types Several sensor designs have been introduced to cover all types of high voltage equipment. CEVT sensors are available for ALSTOM GIS substations. Their small size allows them to fit into smaller enclosures, which means smaller substations.

54

An external memory (EEPROM) is associated to the sensor allowing all calibration values to be stored while the sensors are mounted. Thus, when a sensor is connected to a PC12 primary converter, the electronics automatically adjust the compensation gains related to calibration values found in the EEPROM. The components are therefore easily and quickly replaced

High immunity against EMC Based on an Alstom patent, the sensors are created on a double-sided PCB (printed circuit board), providing high immunity against EMC and fast transient currents and voltages. The current analog signal for measurement also provides perfect immunity against nearby magnetic fields.

GIS Solutions | COSI-CEVT sensor

important note: This product may not be sold on its own. It must always be integrated in a global DIT engineering solution.

Merging unit

Merge IEC 61850

Protection relay

Protect

Single-phase GIS design

Three-phase GIS design (135 kV)

COSI-CEVT 420 kV

55

GIS Solutions | COSI-CEVT sensor

Ratings (sensor associated with PC12) Module type

Technical features ■■

PC12-3U 3 x CEVT*

Rated voltage

kV

Up to 1100

Rated current

A

-

Accuracy 50/60Hz

%

<0.05

Delay time

μs

<500

Sampled Values Output rate: ■■ Protection channel ■■ Metering channel ■■ Qualimetry channel

KSPS KSPS KSPS

4.8 /4 /5.76 4.8 /4 /5.76 14.4 /12.8 /15.36

FFT Analysis Harmonics (qualimetry channel only)

Harmonic rank

100

Frequency domain (sensor imput)

Hz

0-10K

A/D converters

Qty

2 + 3 refs

Auxiliary Channels

Type

4/20 mA, RDT100

MTBF (acc. To MIL-HDBK-217F)

khrs

>350

Weight

kg

1.2

*CEVT: Capacitive Electronic Voltage Transformer.

56

■■

■■

■■

■■

■■

Rated supply voltage 48 Vdc (proprietary input) connected to PC1 power supply (48 - 350 Vdc / 100 240 Vac) Power cons. ~ 5 W @ 20°C Ambient temperature -40°C up to 80°C Protective index IP64 compliant Case material Magnetic Stainless Steel EMC Protection IEC 61000-4 1,3,4,5,6,8,12,13,16 Class 3 to 5, 18 55022 Class A Standard IEC 61850-9-2LE IEC 61869 -1, -6, -7, -8, -9

GIS Solutions | COSI-RogoFlex sensor

Fact sheet – Gas insulated substations

COSI-RogoFlex

RogoFlex® electronic current transformer for GIS High voltage designs now increasingly incorporate Smart devices - making Smart substations part of the real world. In the digital chain for current measurement, the COSI-RogoFlex® uses the latest sensor technologies in current measurement for DIT applications.

Customer benefits Very flexible design, allowing installation in a huge variety of locations in the substation ■■ Sensor enclosures are smaller than conventional ones space gains for substations ■■ Higher electromagnetic immunity ■■

57

Integrated voltage sensor

Integrated current sensor

Measure RogoFlex® : Flexible current sensor Sensors are the basic elements of current measurement. In order to obtain the highest accuracy for protection applications, the sensor should measure the current with the best linearity and repeatability. It should also be protected against the electromagnetic perturbations (EMC) found in GIS substations. Sensors are designed based on an Alstom patent, using flexible polymer pipes as wiring supports with a shielded double winding.

Compatible with all GIS types Thanks to their design, RogoFlex® sensors are flexible and the length of the ‘ring’ can be calculated for each application, depending on conductor diameter.

58

Primary converter

Convert These sensors are available for the entire GIS range from 72.5 kV to 1200 kV or higher. Thanks to their flexibility, RogoFlex® sensors can be installed in retrofit in existing substations without designing specific enclosures and with no need to remove HV parts. The sensors can be opened if needed (e.g. inspection). The open/close mechanism is rugged and locks the external tube.

Less maintenance An external memory (EEPROM) is associated to the sensor, allowing all calibration values to be stored when the sensors are mounted. Thus, when a sensor is connected to the PC12 primary converter, the electronics automatically adjust the compensation gains related to calibration values found in the EEPROM.

GIS Solutions | COSI-RogoFlex sensor

important note: This product may not be sold on its own. It must always be integrated in a global DIT engineering solution.

Merging unit

Merge IEC 61850

Protection relay

Protect

High immunity against EMC

Closed RogoFlex sensor

Based on an Alstom patent, the double wiring inside the sensor provides immunity to EMC. Moreover, there is a metallic shield around the windings. The signal cable uses twisted pairs and a specific shield.

COSI-RogoFlex sensor installed on a bushing

Fixing point for RogoFlex sensors

Fixing point for RogoFlex sensors

59

GIS Solutions | COSI-RogoFlex sensor

Ratings (sensor associated with PC12)

Technical features ■■

Rated current

kA

Up to 200

Accuracy error 50/60Hz

%

<1

Repeatability error

%

<1

Linearity error

IEC Class %

0.2

Resistivity (for D = 336 mm)

Ω

~10

Sensitivity*

mV/kA

48

FFT Analysis Harmonics (qualimetry channel only)

Harmonic rank

100

Frequency domain (sensor imput)

Hz

0-10K

MTBF (acc. To MIL-HDBK-217F)

khrs

>350

Weight*

kg

1.2

■■

■■

■■

*Standard values; further data is available on request

60

■■

Ambient temperature -40°C up to 80°C Protective index IP64 compliant Case material Magnetic Stainless Steel Polymer EMC Protection IEC 61000-4 1,3,4,5,6,8,12,13,16 Class 3 to 5, 18 55022 Class A Standard (instrument transformers) IEC 61850-9-2LE IEC 61869 -1, -6, -7, -8, -9

GIS Solutions | COSI-PC12

Fact sheet – Gas insulated substations

COSI-PC12

Primary digital converter for GIS applications High voltage designs now increasingly incorporate Smart devices - making Smart substations part of the real world. In the digital chain for current and voltage measurement, the PC12 converter uses the latest technologies to convert analog signals into digital data to be transmitted to the merging unit and ultimately to the protection relays and control room.

Customer benefits High performance and rugged design Easy to maintain & test: off-the-shelf replacement ■■ 3-phase compact design for voltage levels up to 1,100 kV ■■ Reliable substation protection ■■ ■■

61

Integrated voltage sensor

Integrated current sensor

Measure PC12: A high-tech converter The digitising of signal outputs from DITs is crucial and requires state of the art electronics using high-speed and high-accuracy components. The PC12 is a smart converter providing high performance and reliability. It is based on a digital conversion unit and a digital core (FPGA: programmable gate array) for signal treatment, management and communication. An analog condition circuit, digital filters and integrator provide low noise, high linearity and high bandwith to the converter. Compliant with all GIS layouts and with a rugged and compact design, the PC12 can be easily integrated with all HV products in voltage ranges up to 1,100 kV. The 3-phase design means only one converter is required for a 3-phase measurement point. The design is particularly adapted to harsh environments where Electromagnetic Compatibility

62

Primary converter

Convert (EMC) can be a problem, as is the case with GIS substations in most layouts.

Easy to maintain Thanks to its modular concept, the replacement of a PC12 module is as simple as an off-the-shelf replacement. Calibration values for sensors are included in the sensors themselves and pre-stored in an EEPROM memory unit before leaving the factory. If a PC12 needs to be replaced, as soon as the new sensor is plugged in, the calibration values are automatically swapped to PC12 internal memory.

Several communications rates High-speed electronics allow the simultaneous transmission of protection, metering and qualimetry sample value outputs according to the IEC 61850-9.2 / 61869-9 standards. The design meets Smart Grid requirements up to harmonic 100 on the qualimetry channel.

GIS Solutions | COSI-PC12

important note: This product may not be sold on its own. It must always be integrated in a global DIT engineering solution.

Merging unit

Merge IEC 61850

Protection relay

Protect

COSI-PC12

COSI-PC12

1. Power connector 2. Led indicators (alarm & power Ok) 3. Optical fibre connector 4. Sensor connectors (from 1 to 3) 5. Auxiliary connector 6. Test connector (for commissioning)

63

GIS Solutions | COSI-PC12

Ratings

Technical features

Module type

PC12-3U 3 x CEVT*

PC12-3I 3 x REVT*

Rated voltage

kV

Up to 1100

-

Rated current

kA

-

Up to 200

Accuracy 50/60Hz

%

<0.05

<0.05

Delay time

μs

<500

<500

Sample Values Output rate: ■■ Protection channel ■■ Metering channel ■■ Qualimetry channel

■■

■■

KSPS KSPS KSPS

4.8 /4 /5.76 4.8 /4 /5.76 14.4 /12.8 /15.36

FFT Analysis Harmonics (qualimetry channel only)

Harmonic rank

100

100

Frequency domain (sensor imput)

Hz

0-10K

0-10K

A/D converters

Qty

2

2

Internal references

Qty

3 (1 at 0.02%)

Auxiliary Channels

Type

4/20 mA, RTD100

4/20 mA, RTD100

MTBF (acc. To MIL-HDBK-217F)

khrs

175

175

Weight

kg

1.2

1.2

■■

■■

*CEVT: Capacitive Electronic Voltage Transformer *RECT: Rogowski Electronic Current Transformer.

64

■■

■■

Rated supply voltage 48 Vdc (proprietary input) connected to PC1 power supply (48 - 350 Vdc / 100 240 Vac) Power cons. ~ 5 W @ 20°C Ambient temperature -40°C up to 80°C Protective index IP64 compliant Case material Stainless Steel EMC Protection IEC 61000-4 1,3,4,5,6,8,12,13,16 Class 3 to 5, 18 55022 Class A Standard (instrument transformers) IEC 61850-9-2LE IEC 61869 -1, -6, -7, -8, -9

GIS Solutions | MU-Agile XMU800

Fact sheet – Gas insulated substations

MU Agile XMU800

Merging unit High voltage designs now increasingly incorporate smart devices – making smart substations part of the real world. In the digital chain for current and voltage measurement, the MU-Agile 800 merges data and signals to make them IEC 61850 compliant.

Customer benefits High performance and rugged design Self monitored and easy to set up via webserver ■■ Many input/output ports provide compatibility with most known GIS layouts ■■ Remote supervision of primary sensors and converters ■■ ■■

65

Integrated voltage sensor

Integrated current sensor

Measure

Primary converter

Convert

XMU800: Smart, powerful device

Compliant with GIS architectures

As soon as the analog signals have been digitised via the COSI-PC12, the data is sent digitally to the MU-Agile XMU800. Several COSI-PC12s can send their measurements to one merging unit.

The MU-Agile XMU800 design is compact, with all the communications ports at the back of the box. A mechanical form factor was chosen for simple integration into a 19-inch bay. The large number of I/O ports allows the MU-Agile XMU800 to fulfill most GIS substation architectures (one busbar, two busbars, one and half circuitbreakers) thanks to the 13 Ethernet ports: 10 as LC optical connectors, 3 as RJ45.

The MU-Agile XMU800 merges all signals and synchronises them using 1 PPS (Pulse Per Second) input or the PTP IEEE 1588 protocol. Then, the data is packed into one or several 61850.9-2 frames and sent to protection relays, data loggers, smart terminals, etc. The device has a powerful FPGA core (parallel microprocessor), creating a real time matrix for interconnections between HV sensors and secondary Intelligence Electronic Devices (IEDs).

Highly communicative device Thanks to its powerful core, the device is able to communicate via 61850.9-2 (& 9-2 LE) and the future IEC 61869-9, sending Sample Values (SV) to a 9-2 network simultaneously over several ports. It is also possible to connect another digital network (such as a 61850.8-1 network) to check the health of the unit or, for example, the RMS value on each PC12 channel.

66

GIS Solutions | MU-Agile XMU800

important note: This product may not be sold on its own. It must always be integrated in a global DIT engineering solution.

Merging unit

Merge IEC 61850

Protection relay

Protect MU-Agile XMU800

User-friendly interface A webserver integrated into the device allows users, depending on access rights, to check the health of the unit, to change some parameters and to display measured values on a webpage. This can be done via any computer equipped with an internet browser.

MU-Agile XMU 800

Available ports: Optional ports (e.g. 600044-8) ■■ 1 PPS input (a PPS output is also available for daisy chaining for IEEE 1588 synchronisation) ■■ Ethernet input ports ■■ Power supply and alarm contact ■■ HMI Ethernet connection ■■

67

GIS Solutions | MU-Agile XMU800

Ratings

Technical features

Unit Type

MU-Agile XMU800

Ethernet ports: - Input (PCBUS type) - Output (61850.9-2 type) - HMI/8.1 connections

Qty Qty Qty

6 7: 4LC, 3RJ45 1 front (HMI) + 1 rear (8.1 compliant)

PPS synchro. ports

Qty

1 In + 1 Out

Optional ports (Compliant 44-8)

Qty

8 (4 In + 4 Out)

Auxiliary contacts

Type

Alarm NO & NC Type

MTBF (acc. To MIL-HDBK-217F)

KHrs

150

Weight

Kg

2.7

Dimensions (mm): - Height: - Width: - Depth:

mm mm mm

90 480 240 / 340 with optical fibre

68

■■

■■

■■

■■

■■

Rated supply voltage Option 1: 100 to 350 Vdc + 100 to 240 Vac Option 2: 20 to 72 Vdc Power cons. max. 18 W @ 25°C Ambient temperature -40°C up to 70°C Protective index IP20 compliant Case material Aluminium anodised (EMC) EMC Protection IEC 61000-4 1,3,4,5,6,8,12,13,16 Class 3 to 5, 18 55022 Class A

GIS Solutions | MU-Agile XMU820

Fact sheet – Gas insulated substations

MU-Agile XMU820

Analog & Digital Merging Unit High voltage designs now increasingly incorporate Smart devices and Smart substations are now part of the real world. DIT sensors, for both current and voltage, are one of the most important components of this new generation of GIS. The XMU820 (Analog & Digital Merging Unit) is the ‘switchboard’ of DIT systems, facillitating communications using the 61869 and 61850 protocols.

Customer benefits High performance and rugged design Self monitored and easy to set up via webserver ■■ Both digital & analog CT & VT use is possible on the same unit ■■ Remote supervision of digital primary sensors and converters ■■ ■■

69

Integrated voltage sensor

Integrated current sensor

Measure

Primary converter

Convert

XMU820: Smart, powerful device

Compliant with GIS architectures

As soon as the analogue signals have been digitised via the PC12, the data is sent digitally to the XMU820 merging unit. (Several PC12s can send their measurements to one or more merging units).

The XMU820 design is compact, with all the communications ports at the back of the XMU box.

The XMU820 merges all those digital signals and is also able to include analog signals coming from conventional VT & CTs and synchronises them using the 1 PPS (Pulse Per Second) input or IEEE1588 protocol. Then, the data is packed into one or several 61850.9-2 frames and sent to protection relays, data loggers, Smart terminals, etc. The device is powered by a powerful FPGA, creating a real time matrix for interconnections between HV Sensors (conventional and/or DIT) to secondary IEDs.

70

A mechanical form factor was chosen for simple integration into a 19-inch wide bay. The large number of I/O ports allows the XMU820 to fulfill most GIS substation architectures (one busbar, two busbars, one and half circuit-breakers) thanks to the 13 Ethernet ports and 14 analog input terminals which can be used as PC12 and/or CT,VT inputs. All communication ports are designed with standard LC- type optical connectors or RJ45 plugs.

Highly communicative device Thanks to its powerful core, the device is able to communicate via 61850.9-2 (& 9-2 LE) sending Sample Values (SV) to a 9-2 network simultaneously over several ports.

GIS Solutions | MU-Agile XMU820

important note: This product may not be sold on its own. It must always be integrated in a global DIT engineering solution.

Merging unit

Merge IEC 61850

Protection relay

Protect MU-Agile XMU820

It is also possible to connect another digital network (such as a 61850.8-1 network) to check the health of the unit or, for example, the RMS value on each PC12 channel.

User-friendly interface A webserver integrated into the device allows users (depending on access rights) to check the health of the unit, to change some parameters and to display measured values on a webpage. This can be done by connecting any computer equipped with an internet browser.

MU-Agile XMU 820

1. Ethernet input ports 2. Optional ports (e.g. 600044-8) 3. 1 PPS input (a 1 PPS output is also available for daisy chaining) 4. Power supply 5. HMI ethernet connections 6. Ethernet output ports 7. Conventional VT input Terminals (1A and/or 5A type) 8. Conventional CT input Terminals

71

GIS Solutions | MU-Agile XMU820

Ratings

Technical features

Unit Type Ethernet ports: - Input (PCBUS Type) Qty - Output (61850.9-2 Type) Qty or input or mirror - HMI/8.1 connections Qty

MU Agile XMU820

■■

6 7

■■

1 HMI/Station Bus 61850.81 compliant RJ45 or LC

■■

■■

Conventional TC inputs

Qty/ type

4 x 1A + 4 x 5A

Conventional CT inputs

Qty/ type

6 x 100/√3 V AC up to 600V AC

PPS synchro. Ports

Qty

1 In + 1 Out

Optional ports (Compliant 44-8)

Qty

8 (4 In + 4 Out)

Auxiliary Contacts

Type

Alarm NO & NC Type

MTBF (acc. To MILHDBK-217GF)

KHrs

150

Weight

Kg

7

Dimensions (mm): - Length: - Width:

mm mm

- Depth:

mm

480 240 (340 with rear connectors) 135 (3U)

72

■■

Rated supply voltage 48 to 300V DC - 90 to 220V AC Power cons. - 14 to 22 W @ 20°C Ambient temperature -40°C up to 60°C Protective index IP40 compliant Case material Stainless Steel EMC Protection 610004-1,3,4,5,6,8,12,13,16 Class A 55022 Class A

GIS Solutions | BWatch3

Fact sheet – Gas insulated substations

BWatch3 system

Expert GIS and SF6 monitoring

The BWatch3 system is our expert solution for GIS monitoring.Thanks to modern condition monitoring systems, transmission substations can now be monitored remotely and in real time, providing better reliability and availability in the Smart Grid era.

Customer benefits Asset management: schedule maintenance Greater safety for personnel and switchgear ■■ Environmentally-friendly ■■ Quality assurance: life span extension ■■ Ergonomic and simple HMI ■■ Permanent monitoring and auto-test ■■ ■■

73

Local control cubicle Sensors Control monitoring unit

Customer challenge Transmission systems and related equipment must be designed for reliability. Energy managers require cost effective applications and solutions to avoid unscheduled downtimes, major failures and the subsequent penalties.

Alstom Grid’s solution The most effective solution to avoid potential GIS failure is through condition based asset management with advanced detection. The BWatch3 system is therefore designed for accurate and anticipated SF6 monitoring. The BWatch3 monitoring system is a digital, open and modular system, easy to adapt to all switchgear types, cost effective and reliable. Optional functions are also available, such as internal fault localisation and circuit-breaker condition monitoring.

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Main features - Gas density monitoring Gas density monitoring with immediate and anticipated density threshold alarms, fast leakage alarms, centralised displays of compartment status, alarm management, protected circuit-breaker security tripping and interlocking.

- Data management Archival recording and displays of measurements and events in the central monitoring unit for switchgear condition evaluation and assistance for diagnosis before maintenance and repairs. Evolutive system capacities for additional functions requiring monitoring.

- Gas temperature monitoring Liquefaction and overheat alarms management thanks to the temperature sensor embedded in each transducer. The friendly mobile HMI displays all current measurements and alarms and allows maintenance and commissioning.

GIS Solutions | BWatch3

References Internet links Electrical wire Ethernet fibre optic

More than 150 gas-insulated substations around the world are equipped with Bwatch3 representing more than 1,200 bays and 20,000 gas sensors.

Ergonomic HMI

Expert remote support

Options - Advanced communications features and remote access

Digital gas sensors

GIS current and stored monitoring data are available to any authorised external PC user using high-speed ethernet links via internet, intranet or telephone links.

- CB monitoring Electrical wear calculation and recording Operations counter by current ranges ■■ Travel curves recording with comparison to reference curves. ■■ ■■

Mobile HMI

- Internal fault location ■■ ■■

Allows quick faulty compartment location Helps secure substation automatic reconfiguration through interlock, even in the CB compartment (faulty and normal operation discrepancy).

Bwatch3 sensor

75

Ratings

Units

Values

Warranted measurement scale (Full Scale)

abs Bars

0-11

1 minute overpressure withstand

abs Bars

20

Measurement resolution

FS%

<= 0.01

Long term stability

FS%

0.1

Accuracy

FS%

<=0.1

Repeativity at 25 °C

FS%

< 0.05

Endurance (0…100 % FS at 25°C)

No. of cycles

1,000,000

°C

0.1

°

90

1. Gas sensors Pressure

Temperature ToB Bridge temperature resolution 2. Travel sensors Range Independant linearity (at 20°C)

<±0.25%

3. Acquisition and process unit Gas compartments Gas sensors bus length

Up to 30 (3x10) m

Up to 800

Digital ouputs

Up to 128

Digital inputs

Up to 64

Analog inputs

Up to 16

Density sets

Up to 8

Pressure acquisition cycle time

ms

300

Temperature acquisition cycle time

min

1

Density calculation cycle time

s

2

Leakage advanced alarm forecast time

days

90

Gas sensors communication speed

bytes/s

115,000

LVCC touch panel communication speed

bytes/s

19,200

Distributed Control System communication speed

bytes/s

9,600

4. Central Monitoring Unit Gateway

Up to 4

Bays by gateway

Up to 12

Event records

Infinite

Density records

Infinite

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GIS Solutions | BWatch3

System composition 1. Digital gas sensors with separated pressure and temperature measurements, daisy chained in field bus on each bay. Sensors for HV current and and CB operation curve available as options. 2. Programmable logic controller implemented in the low voltage control cubicle of each bay, with I/O and communications modules. 3. Central unit, which is dedicated to display measurements and alarms, to record events and trends and to communicate the data to users. CB operation curve available as options. 4. A LVCC touch panel HMI, which is an independent unit, manages the display of current monitored values and alarms that it is able to read directly from the APU’s* memory. (*Aquisition and Process Unit)

Technical Features EMC Protection

IEC 61004-2,3,4,5,6,8,10,12 Class 3 to 5

55022 Class A

Standard

Gateway

APU

Gas sensors

Travel sensors

Low temperature

IEC 60068-2-1

-40°C

-40°C

-40°C

-20°C

Dry heat

IEC 60068-2-2

55°C

55°C

110°C

80°C

Protection index

IEC 60068-2-30

IP20

IP20

IP68

IP65

Climatic withstand

Mechanical withstand Shocks

IEC 60068-2-27

15 g

25 g

25 g

40 g

Vibration

IEC 60068-2-6

1 g / 10 - 150 Hz

1 g / 10 - 150 Hz

1 g / 10 - 150 Hz

10 g / 10 - 150 Hz

77

GIS Solutions | BWatch3

78

GIS Solutions | PDWatch

Fact sheet – Gas insulated substations

Online PDWatch

Online partial discharge monitoring for GIS

The UHF PDWatch online monitoring system records and displays the UHF signals generated by partial discharges in a GIS. Thanks to modern condition monitoring systems, transmission substations can now be monitored remotely and in real time, providing better reliability and availability in the Smart Grid era.

Customer benefits Predict potential faults ■■ External noise discrimination ■■ Superior reliability and auto-test ■■ Ergonomic and simple HMI ■■ Expert support available ■■

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Sensors

PD Panel

System composition

External noise discrimination

1. A set of UHF modules, which are dedicated to signals acquisition and pre-treatment.

In order to avoid spurious alarms, signals generated by real partial discharges must be distinguishable from external noises: the detection of UHF signals is based on calculations of spectrum key features, such as average and variance.

2. A central unit dedicated to recording the signals, generating alarms and displaying data to users.

Predict potential faults The system is permanently fitted into the substation and can be queried remotely. Thanks to this system, developing dielectric faults can be detected and eliminated before complete breakdown occurs. Used with suitable couplers, this system can detect all critical defects such as particles, coronas, free potentials and insulator voids at the sensitivity specified by CIGRE TF 15/33.05.03. The link between the UHF modules is ensured by a 100 Mbit/s ethernet network with self-healing features, providing greater reliability.

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The key features are calculated by placing specific masks on the spectrum to exclude the known externally disturbed frequency bands. This possibility is not currently offered by broadband systems using thresholds on analog signals. A clever algorithm validates an event generated by a threshold on the mean and variance of the spectrum by making an analysis of signals on internal and external noise sensors.

GIS Solutions | PDWatch

Internet links Electrical wire Ethernet fibre optic

Ergonomic HMI UHF coupler for external noise discrimination

Expert remote support

Short and long term analysis A trend curve shows the evolution of the UHF signals level inside the GIS over the short and long term. It is very useful for risk assessment because the UHF signals level is not fully linked to the partial discharge level (due to factors such as the kind of defect or the distance to coupler,…). This evolution of UHF activity is crucial to the determination of the defect’s severity.

PDWatch sensor

A single HMI with monitoring The HMI shows the Single Line Diagram with gas compartments and PD couplers. It is thus common to both PD monitoring and SF6 density monitoring, avoiding the need for multiple HMIs. This tool also brings important time savings thanks to automatic test report generation.

PD-Box

Auto-test function The status of the complete system is continuously checked, including the couplers: the HMI displays an indication if a UHF module is out of order, if a UHF coupler is disconnected or if a synchronisation signal is absent.

Acquisition Box

81

GIS Solutions | PDWatch

Ratings

Technical features

UHF modules

■■

6 inputs for PD couplers (N type sockets) ■■ ■■

Amplitude resolution: 256 amplitude levels Overall signal range: - 100 dBm to - 10 dBm

Spectrum analysis ■■ ■■

UHF spectrum bandwidth: 300 to 1200 MHz UHF spectrum resolution: 2.5 MHz

Time analysis ■■ ■■

Time resolution: 20 μs at 50 Hz / 16.7 μs at 60Hz Band-pass filtering on central frequency during acquisitions

Coupler test through UHF cable 3 possibilities of synchronisation signal: main supply, voltage transformer, capacitive coupler Versatile layout: Integration in GIS control cubicles or in stand-alone boxes Network ■■ ■■

Ethernet 100 Mbits/s between PC and measuring units IEC 61850-8-A compliant

Operational limits Temperature: -250C to 550C Protection: IP54 or IP66 ■■ EMC compliant (electronics completely protected) ■■ ■■

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Mains supply ■■ 48 Vdc – 15% to 250 Vdc ■■ 110/240 Vac +/- 20% ■■ Power consumption: 20 W per UHF module ■■ Central unit: PD-Panel: ■■ Industrial PC: ■■ Fanless, without moving parts ■■ Touch screen 17” ■■ Processor: Core II duo, 1.5 GHz ■■ Memory: 2 GB, DDR ■■ Hard disk capacity: 80 GB Flash (SDD) ■■ Long duration storage with external HDD ■■ OS: XP Embedded ■■ MODEM ■■ For digital lines ■■ For G3 links (on request) ■■ Possible integration with SF6 monitoring BWatch3

GIS Solutions | RPH3

Fact sheet – Gas insulated substations

RPH3

Point on Wave switching Optimising the closing and opening of a circuitbreaker is of the utmost importance because random switching can result in high transient overvoltages and/or high inrush currents. These transients generate stresses on all substation and network equipment, leading to accelerated aging - or the worst case scenario - flashover of the HV apparatus.

Customer benefits Eliminate switching transients Reduce stress, overvoltages and inrush currents on electrical networks ■■ Increase lifetime of HV equipment ■■ Enhance power system security ■■ Support operations and maintenance ■■ IEC 61850-9-2 compliant ■■ ■■

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Sensors CB drive (Spring or Hydraulic)

Controlled switching of high voltage circuit-breakers The RPH3 is an advanced microprocessor-based synchronising relay suitable for Independent pole operated circuit-breakers. More commonly referred to as a Point-on-Wave controller, it protects high voltage network components from transients generated during switching operations. Thanks to the RPH3’s sophisticated algorithms, the operation of the circuit-breaker is configured to reduce stress in all conditions and network configurations. Random switching operations on high voltage networks cause electrical transients that stress equipment and degrade power quality. The way to deal with switching transient phenomena is to act efficiently on their root-causes. Eliminate random switching and replace these practices with a controlled switching strategy - or “point-on-wave” switching. Point-on-wave controlled switching consists of

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Synchronous switching relay

issuing switching commands to the circuit-breaker at the optimal point on the reference voltage waveform. Thanks to its electronics and software, the RPH3 point-on-wave controller effectively sends a switching command to the circuit-breaker to operate at the correct instant, thus eliminating or substantially reducing transients.

Perfect matching with the circuit-breaker under control Success of controlled switching operations depends on the ability of the RPH3 controller relay to assess beforehand the reference synchronising voltage, as well as the characteristics and the consistency of circuit-breaker operations under all operating and ambient conditions. To optimise the performance of the RPH3 in its controlled switching operations, the relay can be programmed according to network and circuitbreaker operational characteristics. Thanks to the permanent monitoring of the circuitbreaker’s parameters and the sophisticated adaptive

GIS Solutions | RPH3

Internet links Electrical wire Ethernet fibre optic

Ergonomic HMI

Expert remote support RPH3

control routines, the RPH3 enables a reliable and accurate control over the behaviour of the device, thus permitting optimal switching sequences.

Advanced communications features and user friendly interfaces With its integrated memory and communications ports, the RPH3 records switching parameters and communicates the results of controlled switching operations. An embedded web server for the machine interface allows: Real-time information on the RPH3 device & application status ■■ Configuration of parameters needed for controlled switching applications ■■ Retrieval of switching archives and data from RPH3 devices ■■

DIT for current measurement

The web server program operates by accepting HTTP requests from the client via a standard web browser. The ‘RPH3 Manager’ dedicated software allows the analysis of archive records stored in the RPH3 relay in service and can perform data evaluations of controlled switching operations. GIS 550 kV circuit-breaker

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GIS Solutions | RPH3

Functionalities

Technical features

Switching applications

■■

Capacitor banks

■■

Reduce overvoltages and eliminate inrush current ■■ Switch in at zero voltage

Shunt reactors

■■

Power transformers

■■

Reduce overvoltages and prevent current chopping and re-ignition ■■ Switch out with medium arcing time ■■

Transmission lines (uncompensated and shunt reactor compensated)

Eliminate inrush current Switch in under conditions where residual flux is minimal

Limit overvoltages while energising or re-closing ■■ Switch in at zero voltage across circuitbreaker poles ■■

Advanced features ■■ ■■

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Digital interface via ethernet 100 Mbit/s Open for 61850-9.2 protocol

Temperature : -25°C to +55°C EMC compliant (electronics completely protected) ■■ Mains supply ■■ 48 Vdc – 15% to 250 Vdc ■■ 110/240 Vac +/- 20%/5060 Hz ■■ Power consumption: < 20 W ■■ Solid state control of breaker coils ■■ 48 V= / 250 V= ■■ 10 A – 300 ms / 15 A – 200 ms ■■ Alarm relays operating range: 230 V= / 5 A ■■ Reference synchronising voltage: 15 – 330 V~ (20-60 Hz) ■■ Switching time resolution: 0.1 ms ■■ Control voltage (auxiliary) ■■

GIS Solutions | Service

GIS Service solutions

87

Improve equipment availability through SF6 monitoring SF6 leakages are the first root causes of the minor failures in GIS, due to sealing technologies of the interfaces and ageing of the material. Maintenance and monitoring functions are the key solutions for keeping the substations in good operating conditions. In addition, looking forward to protecting the environment from the global warming, many regulations are increasing the level of requirements pertaining to SF6 leakages in high-voltage equipment.

Digital GIS substation From a standardised technical solution to a tailored application on existing assets, our Service engineering departments can propose retrofit solutions to install the BWatch system to all existing substations, either Alstom or third-party branded. The sensor installation, cabling and low-voltage cubicle upgrades can be performed during scheduled maintenance or overhaul.

Expertise and consulting Our experts are available for customer data interpretation and analysis. Several options for data collection and transmission are available, from remote online access to manual file exchange. This consultancy can be provided on an on-call basis and on a contractual frequency basis. All the BWatch data are applicable to the Asset Health Index (AHI) of our asset management solution, supporting customer asset management policies.

88

GIS Solutions | Service

Monitoring dielectric condition Partial discharges are the key indicators of highvoltage equipment dielectric condition. The assessment of the GIS dielectric condition is one of the major conditions to reach the level of Reliability Centred Maintenance (RCM), combining the advantages of time based maintenance and those of condition monitoring.

Retrofitting GIS Substations with new sensors The use of several types of sensors allows our experts to define the optimum comprehensive retrofit solution for most installed GIS substations. The sensor installation, cabling and low-voltage cubicles upgrades and signal calibration can be performed during scheduled maintenance or overhaul. The UHF method used along with all PDWatch features and options, allow maximum leveraging the GIS condition and improve lifetime expectancy of the existing assets.

89

GIS Solutions

GIS conclusions Alstom Grid’s digital substation solutions offer a range of market leading benefits for GIS operations. These include: ■■ GIS product range from 72.5 to 800 kV ■■  Integration with our complete range of state-of-the-art digital hardware, software and communications products ■■  Increased reliability and availability delivered through extensive self-diagnostic abilities ■■  Improved safety, through innovations and self monitoring ■■  Investment optimisation delivered through reduce space requirements, service and maintenance scheduling, and asset optimisation ■■ Global footprint, local service.

90

AIS Solutions

91

92

AIS Solutions

Digital solutions for AIS With more than 100 years of experiences in High voltages switchgear, Alstom is the leader on the Air Insulated substation market. Our leadership is largely thanks to our complete product portfolio from 72.5 kV up to 1200 kV. A leader in the field of High Voltage equipment, Alstom has delivered and commissioned more than 10,000 of each key element of a substation (Circuit-breaker, Disconnectors and Instrument Transformers) worldwide. Thanks to recent progress in electronics, in information technology and in new communication protocol standards, Alstom has developed and put into service a new generation of Air Insulated equipment such as Instrument Transformers, which allow real time information input from modern sensors and complete interoperability. Digital substations are able to meet a whole new set of expectations.

93

Our mission statement Alstom Grid provides essential equipment from 72.5 kV up to 1200 kV, to secure and optimise transmission of the electricity from generation to consumption with a full range of Circuit-breakers, Disconnect Switches and Instrument Transformers. We offer: Full product portfolio up to 1200 kV ■■ High performance range ■■ First class spring mechanism ■■ Solution to ensure the operational reliability of self-monitoring equipment ■■

94

AIS Solutions

AIS Solutions Fact sheets Digital Instrument Transformers - DIT COSI-sensors ■■ COSI-CT ■■ COSI-CT F3 Primary converter ■■ COSI-PC13 Merging unit ■■ MU Agile XMU820

Monitoring and control SF6 and AIS monitoring ■■ CBWatch-2 Partial discharges monitoring ■■ DWatch Point-on-wave switching ■■ RPH3

95

AIS digital substation overview Alstom, the worldwide market leader in Air Insulated Switchgear, offers all the advantages of the new generation of AIS digital substation solutions. Alstom offers you a state-of-the-art Air Insulated product portfolio, combined with advanced substation automation solutions.

96

AIS Solutions

97

AIS Solutions

Digital instrument transformers The new generation of AIS digital substation solutions bring unprecedented levels of reliability, security and performance through real-time monitoring, automation and interoperability. Integrating high performance primary equipment including Alstom’s COSI (COmpact Sensor Intelligence) and advanced substation automation solutions. Information acquisition, processing and output is treated in real-time through a digital architecture with multiple layers of automation units.

Monitoring and controls Our range of digital instrument transformers provide measurement using optical, Rogowski or capacitive technology, which have been optimised for operation with AIS equipment, integrating into the relevant switchgear to provide accurate real-time measurement of key operational parameters.

98

AIS Solutions | COSI-CT

Fact sheet – DIGITAL INSTRUMENT TRANSFORMERS

COSI-CT

Optical Current Transformer Our comprehensive COSI range (COmpact Sensor Intelligence) includes innovative digital instrument transformers for AC and DC applications. The COSI-CT optical current sensor brings a new level of accuracy to sensing over the range between 1 A rms and 63 kA rms.

Customer benefits Improved measurement performance Significant system cost reduction ■■ Environmentally friendly ■■ World-wide standard for Interconnection ■■ Reliability, availability, safety ■■ Light weight ■■ One device only – not multiple CTs ■■ ■■

99

Performance features Accuracy exceeds ANSI/IEEE Class 0.15S/IEC Class 0.2S for metering and IEC Class 5P/ IEEE 10% for protection ■■ Wide dynamic range ■■ Bandwidth from DC to 100th harmonic ■■ No magnetic core saturation ■■ Excellent phase accuracy ■■ Digital Interface and analog output ■■ DC / AC without calibration ■■

The reduced size and weight are attractive benefits compared to conventional oil-filled equipment, allowing placement in compact substations or in retrofit applications where space may be limited. A lightweight dry-type insulator and window head design allow pedestal mounting or suspension from a rigid bus. Its broad dynamic range makes this CT particularly suited for both high-precision metering and protection applications at the same time. The accurate measurement of DC and AC to the 100th harmonic and the measurment of phase angle is a must for new Smart Grid applications. The standard digital interface will ensure smooth integration of COSICT in the digital substation application.

100

Intrinsically safe, environmental friendly No oil, gas or SF6 No hazardous open secondaries ■■ No violent failure ■■ ■■

AIS Solutions | COSI-CT

Smart Solutions for Smart Grid Fast fault response Extreme fast and accurate response ■■ COSI-CT actually measures the dynamic current ■■ No distortion due to core saturation, no need for TPY TPZ specs, yet no danger for secondary equipment ■■

40 000 20 000 0

Basic Faraday effect In Faraday Effect current sensors; the current flowing through a conductor induces a magnetic field that affects the propagation of light traveling through an optical fibre encircling the conductor. A linear state of polarization rotates in the presence of a magnetic field because the field produces a circular birefringence in the glass. Birefringence refers to an optical material with two indices of refraction.

Current (A)

-20 000 -40 000 -60 000 -80 000 -100 000 -200 000

1200

1600 Time (arb.)

CT

Ref

2000

2400

Metering and protection accuracy The COSI-CT design permits measurements to be made with the highest possible accuracy and stability. To address stringent revenue metering applications, its performance exceeds IEC Class 0.02S and IEEE Class 0.3 accuracy (optional 0.15%) with a dynamic range that extends from 1 A to 5000 A. The COSI-CT has ultra-accurate and stable phase measurement, which is critical for intertie metering. For protection applications, the COSI-CT exceeds IEC Class 5P accuracy ratings and IEEE 10% accuracy ratings.

101

Wide dynamic range

Choice of connection option

Accuracy specification is maintained over a broad dynamic range - from 0.2% to 150% of rated current (extended metering range sensor) and up to 171 kA (protection range sensor). Broad dynamic range allows elimination of separate high and low range CTs.

New window head design allows a variety of connection options including standard NEMA pads, up to 300 mm rigid bus, or flexible cable pass through, allowing optimal selection for ease of installation and reliability.

Wide bandwidth Accurate waveform reproduction up to 6 kHz allows full power quality analysis of harmonics and transients with no sensor-imposed limitations.

Dry type insulator seismic stable Field-proven lightweight composite insulator reduces transportation costs, substation support structure requirements, and installation equipment demands. The lightweight design also allows location in seismically active areas.

Green design The COSI-CT insulator contains no oil, SF6 or other gas. There is no internal mechanism for violent failure to endanger personnel or adjacent equipment. There are no environmental concerns or gas to recycle. With an optical design there are also no open secondary concerns.

Low maintenance The COSI-CT has no active components at line potential, eliminating the need for costly outages to maintain the electronics. Since there is no insulating oil or paper there are no complex maintenance procedures. The polymeric insulating column employs silicone rubber sheds that do not require liveline washing.

Smart Grid ready with digital interface The standard digital interface will ensure smooth integration of COSI-CT into digital substation applications the accurate measurement of harmonics and phase angle is a must for new Smart Grid applications.

102

AIS Solutions | COSI-CT

Specifications COLUMN MECHANICAL & ELECTRICAL Ratings CT Type

72.5

123

145

245

362

420

550

800

72.5

121

145

245

362

420

550

800

350

550

650

1050

1300

1550

1800

2100

57 1400

115 2900

115 2900

193 4900

285 7240

562 14280

562 14280

562 14280

54.7 1389.4

54.7 1389.4

77.91 1978.9

107.44 2729

127.13 3229.1

204.71 5199.6

204.71 5199.6

204.71 5199.6

kg

75 34

88 40

88 40

111 50

124 56

177 80

177 80

177 80

lbs N

675 3000

675 3000

675 3000

900 4000

Suspension application only

Maximum system Voltage (Um) kV Impulse test voltage (BIL)) kV Minimum creepage distance in mm Height

in mm

Weight Static Withstand

lbs

Suspension application only

Ratings and dimensions for IEC pollution Class 2. Other ratings are available.

Environmental Operating Temperature Range

- 40° C to 55° C (- 40° F to 131° F) Outdoor Service Conditions

Opto-Electronic Module

- 5° C to 40° C (23° F to 104° F) Indoor Service Conditions

Seismic Capability

0.5 g

Mechanical Standard Pollution Withstand

IEC Level II, other ratings available

Insulation

Solid composite insulator

Electronics Dimensions

19’’ x 18’’ x 8.75’’ (482 mm x 457 mm x 222 mm) (includes high energy metering interface)

103

AIS Solutions | COSI-CT

Specifications continued... Electronics Packaged in 2 modules:

Low Energy Analog Interfaces1

< 0.2% error at rated current for 4V output, < 0.5% error at rated current for 200 mV output

Dynamic Range

< 2% error at 108 kApeak (using protection sensor)

Sensor Electronics Bandwidth

0.5 Hz to 6 kHz DC available

High Energy Analog Interfaces

1 Arms [2 ohm burden] or 5 Arms [B0.1 (2.5 VA) burden] nominal at power 0.9 for metering

Dynamic Range

< 0.2% error from 1 A to 4000 A (using extended metering range sensor)

Bandwidth

10 Hz to 6 kHz for 1 A metering output

Input Power Requirements

70 Vdc to 150 Vdc

1

Current Amplifier/Power Supply

4 Vrms metering 200 mVrms protection

Typical power 60 W Electronic Turns Ratio

Electronic Turns Ratio

Alarms Contacts

Data invalid / Maintenance required

ElectrICAL PERFORMANCE Type I3: Type II3:

Metering Accuracy

IEC Class 0.2S, IEEE Class 0.3, 0.15S

Protection Accuracy

IEC Class 5P, IEEE 10%

Extended Range Std Metering Accuracy

0.2% (0.2% to 150% of rated current)2

Extended Range High Metering Accuracy

0.15% (0.2% to 150% of rated current)2

Continuous Current

4800 A Max (4800 A, RF = 1; or 3000 A, RF = 1.33; or 2500 RF = 1.5)

Rated Current

User specified for up to 4000 A

Short-time Thermal Current

63 kArms for 1 s

Type II3:

1 Scales linearly with primary voltage and current. / 2 Accuracy window moves with selected ratio. / 3 Other ratings available, consult Alstom Grid.

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AIS Solutions | COSI-CT F3

Fact sheet – DIGITAL INSTRUMENT TRANSFORMERS

COSI-CT F3

Flexible Optical Current Transformer Our comprehensive COSI range (COmpact Sensor Intelligence) includes innovative digital instrument transformers for AC and DC applications. The COSICT F3 optical current sensor is the most flexible, portable optical current transformer sensor available and the easiest to install.

Customer benefits Flexible Form Factor Easy installation and configuration ■■ Improved measurement performances ■■ On-site calibration tool ■■ World-wide standard for interconnection ■■ ■■

105

Three product types are available, Type A, Type B, and Closed Loop, each optimised for different applications and specifications. Each F3 has a wrap-around sensing head around high-voltage bushings, generator buses, and other conductors in ways not possible with conventional Current Transformers. The sensing loop is an all-dielectric cable, which connects to the standard electronics, giving the user the same high performance capability and output options as the high-voltage optical CT. It is an ideal solution for retrofit applications and installations in difficult spaces, on a temporary or permanent basis.

Type A F3 Current Transformer The type A F3 CT is a fibre optic current sensor consisting of an electronics module, a fibreglass sensor box, and a flexible PVC conduit wrap-around sensing cable. The sensing fibre resides in the PVC conduit, which attaches directly to the sensor box. Standard telecommunications optical fibre cabling and wire cabling connect the electronics module to the sensor box. Because the sensor box has a wire connection to the electronics, it should not be installed in a high-voltage environment. However, it may be installed in a low-voltage environment, allowing the sensing cable to be wrapped around a high-voltage bushing.

106

AIS Solutions | COSI-CT F3

Flexible Form Factor The type A F3 CT has metering grade accuracy to 0.15%, and it can measure both AC and DC currents with this accuracy from 1 A to 160 kA, depending on the number of sensing cable wraps used to measure the current.

COSI-CT F3 installed on AIS bushing

Undersea cable metering & protection

Type B F3 Current Transformer DC valve hall wall bushing

The cable length between the electronics module and the sensor box can be up to one kilometer. The sensing cable has a standard length of 20 m, but other lengths may be specified at the time of order. The output of type A F3 CT can be analog with 1 A or 5 A for metering application or digital for metering and protection applications. ■■

The type B F3 CT is a fibre optic current sensor consisting of an electronics module, a fibreglass sensor box, and a flexible PVC conduit wrap-around sensing cable. The sensing fibre resides in the PVC conduit, which attaches directly to the sensor box. Standard telecommunications optical fibre cabling connects the electronics module to the sensor box. In the type B sensor, no wire connection is required at the sensor box, allowing it to be installed in a high-voltage environment. The type B F3 CT is a protection grade sensor with accuracy to 1%. It measures AC currents over a bandwidth of 10 Hz to 3 kHz and can cover a range from 1 A to 160 kA, depending on the number of sensing cablewraps used to measure the current.

Applications include metering and protection, wrap-around bushing for metering or protection, DC valve hall measurements for metering and protection, and very large aperture applications. Sensor box

107

Measuring current at an overhead to underground line transition

Closed Loop F3 CT The Closed Loop F3 CT is a fibre optic current sensor consisting of an electronics module, a fibreglass sensor box, and a flexible PVC conduit wrap-around sensing cable. The sensing fibre resides in the PVC conduit which attaches directly to the sensor box. Standard telecommunications optical fibre cabling and wire cabling connect the electronics module to the sensor box. However, it may be installed in a lowvoltage environment allowing the sensing cable to be wrapped around a high-voltage bushing.

Underground Power Line Protection

The cable length between the electronics module and the sensor box can be up to 10 km. The sensing cable has a standard length of 20 m, but other lengths may be specified at the time of order. The output of the type B F3 CT can be an analog voltage (11.3 V full scale), a current (1 A or 5 A formats), or digital (IEC61850). ■■

Applications include protection, wrap-around bushing for protection, temporary field service measurements, and underground cable monitoring.

The underground cable monitoring application uses sensors at both ends of the underground line to measure the differential current. When the underground cable is in good condition, there is little to no difference between the two measured currents. But, when the cable between the two sensors has faulted, there is a substantial differential current. Because the type B F3 CT sensor box can be placed up to 10 km away from its associated electronics, this line differential currentprotection scheme can be implemented at remote sites where there is no substation or power available (such as an overhead to underground line transition).

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0.1% class Closed Loop F3 metering CT for DC valve hall

The Closed Loop F3 CT uses a current feedback to null the impact of the sensed current on the sensing cable. As a result, the Closed Loop F3 CT achieves accuracies Cl 0.1. Both AC and DC currents are measured from 1 A up to >500 kA. The distance between the electronics module and the sensor box is limited to 100 m. The sensing cable has a standard length of 20 m, but other lengths may be specified at the time of order. The output of the Closed Loop F3 CT can be an analog voltage (11.3 V full scale), a 1 A current, or digital (IEC 61850-9.2).

AIS Solutions | COSI-CT F3

■■

Applications include protection, wrap-around bushing for protection, temporary field service measurements, and underground cable monitoring.

Current Transformer specifications ■■

■■

Single phase, three phase, and six phase system configurations available

■■

Sensor enclosure; fibreglass box; -Type A and Type B: Dimensions: 355 x 304 x 145 mm Weight: 9 Kg IP66 -Closed Loop F3: Dimensions: 406 x 355 x 145 mm Weight: 20 Kg IP66

F3 CT

■■ ■■

20-meter length wrap-around sensing fibre standard, other lengths available on request Programmable output scaling Output format options: analog voltage (IEC 60044-8 200 mV and 4 V formats), current (1 A or 5 A metering format), digital (IEC 61850-9.2)

Type A

Type B

Closed Loop

Class 1

x

Class 15s

x

x

Class 2s

x

x

Class 3

x

x

Class 1

x

Class 5

x

AC

x (up to 20 kHz)

DC

x

AC/DC

x

Sensor box HV isolated Max distance between electronics and sensor

x (10 Hz to 3 kHz)

x (up to 20 kHz) x x

x 1 km

10 km (no repeater)

Fibre cable required

x

x

Copper cables required

x

100 km x x

109

AIS Solutions | COSI-CT F3

APPLICATIONS Bushing

Type A

Type B

Closed Loop

x

x

x

Currents > 160 kA

x

AIS

x

x

Calibration

x

Field service

x

x

Metering

x

Protection

x

x

Cable monitoring

x

x

x x x

Rated current range vs. number of fibre wraps # of fibre wraps

Minimum rated current*

Max rated current*

1

2000 A

80 kA

2

1000 A

40 kA

5

400 A

16 kA

10

200 A

8 kA

20

100 A

4 kA

*F3 maintains accuracy class from 1% to 200% of rated current.

110

AIS Solutions | COSI-PC13

Fact sheet – AIR insulated substations

COSI-PC13

Primary digital converter for AIS applications High voltage designs now increasingly incorporate Smart devices - making Smart substations part of the real world. In the digital chain for current and voltage measurement, the PC13 converter uses the latest technologies to convert analog signals into digital data to be transmitted to the merging unit and ultimately to the protection relays and control room.

Customer benefits High performance and rugged design Easy to maintain & test: off-the-shelf replacement ■■ 3-phase compact design for voltage levels up to 1,200 kV ■■ Reliable substation protection ■■ ■■

111

Primary converter

Measure PC13: A high-tech converter The digitising of signal outputs from DITs is crucial and requires state of the art electronics using high-speed and high-accuracy components. The PC13 is a smart converter providing high performance and reliability. It is based on a digital conversion unit and a digital core (FPGA: programmable gate array) for signal treatment, management and communication. An analog condition circuit, digital filters and integrator provide low noise, high linearity and high bandwith to the converter. Compliant with all AIS layouts and with a rugged and compact design, the PC13 can be easily integrated with all HV products in voltage ranges up to 1,100 kV. The 3-phase design means only one converter is required for a 3-phase measurement point. The design is particularly adapted to harsh environments where Electromagnetic Compatibility

112

Convert (EMC) can be a problem, as is the case with AIS substations in most layouts.

Easy to maintain Thanks to its modular concept, the replacement of a PC13 module is as simple as an off-the-shelf replacement. Calibration values for sensors are included in the sensors themselves and pre-stored in an EEPROM memory unit before leaving the factory. If a PC13 needs to be replaced, as soon as the new sensor is plugged in, the calibration values are automatically swapped to PC13 internal memory.

Several communications rates High-speed electronics allow the simultaneous transmission of protection, metering and qualimetry sample value outputs according to the IEC 61850-9.2 / 61869-9 standards. The design meets Smart Grid requirements up to harmonic 100 on the qualimetry channel.

AIS Solutions | COSI-PC13

important note: This product may not be sold on its own. It must always be integrated in a global DIT engineering solution.

Merging unit

Merge IEC 61850

Protection relay

Protect

COSI-PC13

113

AIS Solutions | COSI-PC13

Ratings

Technical features

Module type

PC13-3U 3 x CEVT*

PC13-3I 3 x RECT*

Rated voltage

kV

Up to 1100

-

Rated current

kV

-

Up to 200

Accuracy 50/60Hz

%

<0.05

<0.05

Delay time

μs

<500

<500

Sample Values Output rate: ■■ Protection channel ■■ Metering channel ■■ Qualimetry channel

■■

■■

kHz kHz kHz

4.8 /4 /5.76 4.8 /4 /5.76 14.4 /12.8 /15.36

■■

■■

FFT Analysis Harmonics (qualimetry channel only)

Harmonic rank

100

100

Frequency domain (sensor imput)

Hz

0-10,000

0-10,000

A/D converters

Qty

2

2

Internal references

Qty

3 (1 at 0.02%)

Auxiliary Channels

Type

4/20 mA, PT100

4/20 mA, PT100

MTBF (acc. To MIL-HDBK-217F)

khrs

175

175

Weight

kg

1.2

1.2

*CEVT: Capacitive Electronic Voltage Transformer *RECT: Rogowski Electronic Current Transformer.

114

■■

■■

Rated supply voltage 48 Vdc (proprietary input) connected to PC1 power supply (48 - 350 Vdc / 100 240 Vac) Power cons. ~ 5 W @ 20°C Ambient temperature -40°C up to 80°C Protective index IP64 compliant Case material Stainless Steel EMC Protection IEC 610041,3,4,5,6,8,12,13,16 Class 3 to 5 55022 Class A Standard IEC 61850-9-2LE IEC 61869 -1, -6, -7, -8, -9

AIS Solutions | MU-Agile XMU820

Fact sheet – AIR insulated substations

MU-Agile XMU820

Analog & Digital Merging Unit High voltage designs now increasingly incorporate Smart devices and Smart substations are now part of the real world. DIT sensors, for both current and voltage, are one of the most important components of this new generation of AIS. The XMU820 (Analog & Digital Merging Unit) is the ‘switchboard’ of DIT systems, facillitating communications using the 61869 and 61850 protocols.

Customer benefits High performance and rugged design Self monitored and easy to set up via webserver ■■ Both digital & analog CT & VT use is possible on the same unit ■■ Remote supervision of digital primary sensors and converters ■■ ■■

115

Primary converter

Measure

Convert

XMU820: Smart, powerful device

Compliant with AIS architectures

As soon as the analogue signals have been digitalised via the PC13, the data is sent digitally to the XMU820 merging unit. (Several PC13s can send their measurements to one or more merging units).

The XMU820 design is compact, with all the communications ports at the back of the XMU box.

The XMU820 merges all those digital signals and is also able to include analog signals coming from conventional VT & CTs and synchronises them using the 1 PPS (Pulse Per Second) input or IEEE1588 protocol. Then, the data is packed into one or several 61850.9-2 frames and sent to protection relays, data loggers, Smart terminals, etc. The device is powered by a powerful FPGA, creating a real time matrix for interconnections between HV Sensors (conventional and/or DIT) to secondary IEDs.

116

A mechanical form factor was chosen for simple integration into a 19-inch bay. The large number of I/O ports allows the XMU820 to fulfill most AIS substation architectures (one busbar, two busbars, one and half circuit-breakers) thanks to the 13 Ethernet ports and 14 analog input terminals which can be used as PC13 and/or CT,VT inputs. All communication ports are designed with standard LC- type optical connectors or RJ45 plugs.

Highly communicative device Thanks to its powerful core, the device is able to communicate via 61850.9-2 (& 9-2 LE) sending Sample Values (SV) to a 9-2 network simultaneously over several ports.

AIS Solutions | MU-Agile XMU820

important note: This product may not be sold on its own. It must always be integrated in a global DIT engineering solution.

Merging unit

Merge IEC 61850

Protection relay

Protect

MU-Agile XMU820

It is also possible to connect another digital network (such as a 61850.8-1 network) to check the health of the unit or, for example, the RMS value on each PC13 channel.

User-friendly GUI (Graphic User Interface) A webserver integrated into the device allows you (depending on rights and privileges) to check the health of the unit, to change some parameters and to display measured values on a webpage. This can be done by connecting any computer equipped with an internet browser.

MU-Agile XMU 820

1. Ethernet input ports 2. Optional ports (e.g. 600044-8) 3. 1 PPS input (a 1 PPS output is also available for daisy chaining) 4. Power supply 5. HMI ethernet connections 6. Ethernet output ports 7. Conventional CT input Terminals (1A and/or 5A type) 8. Conventional VT input Terminals

117

AIS Solutions | MU-Agile XMU820

Ratings

Technical features

Unit Type Ethernet ports: - Input (PCBUS Type) Qty - Output (61850.9-2 Type) Qty or input or mirror - HMI/8.1 connections Qty

Conventional TC inputs

MU-Agile XMU820

■■

6 7

■■

1 HMI/Station Bus 61850.8-1 compliant RJ45 or LC

Qty/ type

4 x 1A + 4 x 5A

Conventional VT inputs

Qty/ type

6 x 100/√3 V AC up to 600V AC

PPS synchro. Ports

Qty

1 In + 1 Out

Optional ports (Compliant 44-8)

Qty

8 (4 In + 4 Out)

Auxiliary Contacts

Type

Alarm NO & NC Type

MTBF (acc. To MILHDBK-217GF)

KHrs

150

Weight

Kg

7

Dimensions (mm): - Length: - Width:

mm mm

- Depth:

mm

480 240 (340 with rear connectors) 135 (3U)

118

■■

■■

■■

Rated supply voltage 48 to 300V DC - 90 to 220V AC Power cons. - 14 to 22 W @ 20°C Ambient temperature -40°C up to 60°C Protective index IP40 compliant Case material Stainless Steel EMC Protection 610004-1,3,4,5,6,8,12,13,16 Class 3 to 5 55022 Class A

AIS Solutions | CBWatch-2

Fact sheet – AIS SOLUTIONS

CBWatch-2

Modular circuitbreaker monitoring system Substation equipment life management is of key importance - and one of the best ways to accurately supervise your network is through an efficient monitoring system. Alstom has developed the CBWatch-2 monitoring system which can be your proactive link to cost-effective circuit-breaker management.

Customer benefits Optimised, proactive circuit-breaker maintenance through constant surveillance ■■ Increased circuit-breaker availability ■■ Diagnostic assistance in case of failure ■■ Optional web interface display ■■

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The CBWatch-2 monitoring system offers you the possibilities to manage a proactive, more cost effective maintenance programme by constantly monitoring your circuit-breakers’ condition and the trends in your operational parameters. These advance warning notifications are the best insurance to avoiding network failure and guarantee a longer life to your equipment. The CBWatch-2 installs directly on the circuitbreaker and maintains a constant, monitored link with your local or remote database via the CBWatchTool software package. The monitoring system records information coming from the sensors installed on the breaker and analyses this information, comparing it with standard operational parameters programmed into the system.

SF6 or gas mixture The installation of the CBWatch-2 monitoring system makes it possible to constantly watch the gas pressure and temperature, calculating the SF6 or gas mixture density using the Beattie-Bridgeman algorithm. It detects and inhibits false alarms in the event of liquefaction. The system measures SF6 leakage rates giving you advance warning before sending alarms or reaching lockout threshold levels. The system also maintains historical records.

Mechanical operation CBWatch-2 monitors close and open operating times, allows the use of conventional auxilary switches or primary contact travel sensors, monitors primary contacts separation speed, buffering and over travel, detects mechanical performance deterioration (friction, corrosion, breakage, spring fatigue and buffer defects) and it monitors auxilary switch timing.

120

AIS Solutions | CBWatch-2

Spring or hydraulic operating mechanism

Swiching

CBWatch-2 can also monitor the hydraulic or spring-operated mechanisms. For spring-operated mechanisms, the system monitors recharging motor operating times and can detect motor limit switch defects. For hydraulic operating systems, it monitors pump motor operating times, detects internal and external leakage, nitrogen loss from the accumulator and threshold pressure.

During switching, the CBWatch-2 monitors the current during breaking, arc duration, and estimates primary contact wear.

Auxiliary and control circuits The CBWatch-2 system monitors operating coil continuity, your auxiliary supply voltage and heater integrity.

Available versions CBWatch-2 exists for circuitbreakers with one operating mechanism for all three pole or for one operating mechanism for each of the three poles. CBWatch-2 also exists for generator circuit-breakers (please consult us for the available functions).

CBWatch-2 installed in the central control cubicle.

121

Installation

Power supply

Dimensions: 310mm x 280mm x 95mm 121/4”x11”x3 3/4” ■■ Installation in operating mechanism, local control cubicle or separate enclosure

> 48-125 Vdc; 48 - 120 Vac > 150-250 Vdc; 150 - 240 Vac > Tolerance: -30 % to +15 % > Power consumption: 30 VA maximum

■■

Environment Ambient temperature: -40oC to +55oC (Option: -50oC with heater) ■■ Electromagnetic compatibility according to the following standards: -IEC 255-5 -IEC 1000-4-4 -ANSI C37-90-1 -IEC 1000-4-12 -IEC 255-22-3 ■■

122

Dependability ■■

High reliability and high availability due to continuous self monitoring of electronic module and sensors: auto diagnostic

Local interface LCD display and keypad (optional) ■■ 1 self monitoring status relay ■■ 4 configurable output relays ■■ 1 self monitoring status LED ■■ 4 local LED indicators ■■ RS232 local communication port ■■

Network interface ■■

Isolated RS485 communication port with MODBUS protocol

AIS Solutions | CBWatch-2

Sensors required for different functions SF6 or gas mixtures: Pressure and temperature sensors ■■ Operations: Coil signal sensors Auxiliary contacts Primary contact travel sensors ■■ Primary current: Auxiliary current transformers ■■ Spring mechanism: Spring motor limit switch contacts ■■ Hydraulic mechanism: Pump start contacts Hydraulic pressure sensor ■■ Auxiliary and control circuits: Temperature sensors Coil supervision relays ■■

CBW2TOOL software CBWatch-2 has communication interfaces that connect to a personal computer loaded with the CBW2Tool Human-Machine Interface Software. This software gives access to CBWatch-2 settings, event recordings, measurements and alarms.

Connection and configuration Connection to a CBWatch-2 can be made via a RS232 or a RS485 serial link, via MODEM or an Ethernet gateway. The software configures and edits the data via a user-friendly interface.

Access to the measurements and to the alarms The software provides a visual display of the state of the on-going alarms and measurements on the connected CBWatch-2.

Access to the recordings of events The data archived in the CBWatch-2 connected to the PC can be downloaded and saved in the EXCEL format, then recalled, visualised, and printed out. The archived events can be studied and/or recalled on your PC on demand.

Example of a CBWatch-2 installation on a circuit-breaker with one operating mechanism per pole.

CBWatch-2 interface software

Examples of some of the industrial sensors used.

123

AIS Solutions | CBWatch-2

124

AIS Solutions | DWatch

Fact sheet – AIR INSULATED SWITCHGEAR

DWatch

The Smart operating mechanism DWatch integrates a hardware and software solution to enable the smart automation and monitoring of disconnector operations, through continuous control of a variety of modes across the entire range of disconnectors

Customer benefits Continuous monitoring of the circuit to maximise efficiency ■■ Early detection of excessive torque ■■ Flexible configuration based on disconnector types ■■ Improved reliability, better lifetime management and optimised maintenance. ■■

125

The D-Watch Application The D-Watch device is designed to drive the Disconnector operation through the automation of the operating mechanism with an electronic board ■■ The D-Watch permits users to monitor and control mechanism and most of the disconnector’s mechanical parts ■■ D-Watch is a reliable electronic module that manages the control unit for very flexible operation ■■

Operating mechanism overview 0.22 to 0.5 kW AC or DC supply voltage ■■ Stainless steel box ■■ Irreversible reduction gear ■■ Lubricated for life ■■ Maintenance free ■■ Easy wiring ■■ Emergency crank ■■ IP55 ■■ Padlockable front door ■■ ■■

126

D-Watch Features The new operating mechanism equipped with the D-Watch device features: ■■ Stainless steel box ■■ Irreversible gearbox ■■ Robust design to cope with adverse environmental conditions ■■ Can be adjusted for any motor-driven motor supply voltage ■■ Less cabling and wiring ■■ Reduced maintenance cost by predictive maintenance (“when necessary”) ■■ Variable speed during the operations ■■ Disconnector operation time is independent for voltage supply ■■ Time operation not function of voltage supply ■■ Modularity on the configuration to suit any type of installation ■■ Digital communication plug

AIS Solutions | DWatch

D-Watch Installation The electronic device is installed inside Alstom Grid’s motor operating mechanism.

D-Watch Smart Product Speed control Data logger of several parameters ■■ All integrated in the standard operating mechanism ■■ Standard drive for all disconnectors ■■ Plug & play (ready to use) ■■ ■■

127

D-Watch benefits This solution allows the system to manage a multitude of information.

Digital Mechanism Two way communication Adaptive Several sensors available Less copper wires with fibre optics Self-monitoring Self-diagnostic Generalised and deeper control Vast range of options available for customers Standardised device fully adaptable

Software Interface

128

AIS Solutions | DWatch

Monitoring benefits The D-Watch device offers the following benefits to the user: ■■ Archive curve to have historical data for maintenance purposes ■■ Evaluate the state of kinematic chain and live part position during the operation ■■ Control circuit monitored ■■ Quickly identify location of failure thanks to digital internal control ■■ Control the real end open-close position of disconnector ■■ Operation times recorded for each operation ■■ Record load curves during commissioning activities and for maintenance purposes ■■ Detect an excessive torque to operate the disconnector ■■ Offer a flexible configuration based on the different disconnector type

D-Watch device Alstom Grid has designed a very flexible electronic module that allows its entire range of disconnectors to be controlled. Through continuous monitoring with variable speed, the D-Watch device allows various operation modes to be set considering different disconnector kinematics, architecture, live part design and special environmental conditions: e.g. operations under ice, etc. D-Watch can be used with any disconnector in service

Monitoring specification D-Watch device monitors/controls following parameters as a function of position and time: 1. Voltage 2. Current 3. Operating time 4. Synchronisation of operation 5. Disconnector in motion/not in motion 6. N° of operation cycles 7. Max current reached 8. Minimum voltage reached 9. Motor torque Data is recorded in non-volatile memory and transferred via PC communication. Ethernet connection for remote diagnostic and integration to the Digital substation using the IEC 61850 protocol.

129

I/O functions and integration in substation networks – Features of Communication ■■

RS-232-USB connection for commissioning measurement/set-up − Maintenance DMC • Firmware update • Debug warning alarm • Download operation data − On-site diagnostic − On site adjustment − PC operation

Integration examples With PC With C264 BCU ■■

Webserver for Remote diagnostic − Viewing status of disconnector − Debug warning alarm − Download operation data − Notification via e-mail

130

■■

■■

IEC 60870-5-104 integration through fibre optics − Integration with substation network with possibility to integrate data in control network IEC 61850-8-1 integration through fibre optics − Integration with a SMART –GRID protocol − Exchange data with other devices in the substation

AIS Solutions | DWatch

Schematic block with communication features in Modbus RS-485 Fibre optics

Technical features ■■

■■

■■

■■

■■

I/O: communication with substation through serial or Ethernet 1,2,..n: speed/torque profile memorized in the electronic board ■■ E: PWM driver ■■ M: DC motor ■■ R: reduction gear ■■ DS: disconnector ■■ Temp: temperature ■■ ■■

■■

Rated supply voltage (power or/and auxiliary) 70 V to 250 V DC - 50 to 400 V AC Motor 0.22 kW to 0.5 kW Ambient temperature -60°C up to 50°C Protective index IP55 compliant Case material Stainless Steel  MC Protection according to E IEC62271-1 (6.9.1, 6.9.2, 6.9.3,..) Class A Dimensions Length: 545mm Height: 600mm Depth: 460mm Weight: 65Kg

131

AIS Solutions | DWatch

132

AIS Solutions | RPH3

Fact sheet – AIR insulated substations

RPH3

Point on Wave switching Optimising the closing and opening of a circuitbreaker is of the utmost importance because random switching can result in high transient overvoltages and/or high inrush currents. These transients generate stresses on all substation and network equipment, leading to accelerated aging - or the worst case scenario - flashover of the HV apparatus.

Customer benefits Eliminate switching transients Reduce stress, overvoltages and inrush currents on electrical networks ■■ Increase lifetime of HV equipment ■■ Enhance power system security ■■ Support operations and maintenance ■■ IEC 61850-9-2 compliant ■■ ■■

133

Sensors CB drive (Spring or Hydraulic)

Controlled switching of high voltage circuit-breakers The RPH3 is an advanced microprocessor-based synchronising relay suitable for Independent pole operated circuit-breakers. More commonly referred to as a Point-on-Wave controller, it protects high voltage network components from transients generated during switching operations. Thanks to the RPH3’s sophisticated algorithms, the operation of the circuit-breaker is configured to reduce stress in all conditions and network configurations. Random switching operations on high voltage networks cause electrical transients that stress equipment and degrade power quality. The way to deal with switching transient phenomena is to act efficiently on their root-causes. Eliminate random switching and replace these practices with a controlled switching strategy - or “point-on-wave” switching. Point-on-wave controlled switching consists of

134

Synchronous switching relay

issuing switching commands to the circuit-breaker at the optimal point on the reference voltage waveform. Thanks to its electronics and software, the RPH3 point-on-wave controller effectively sends a switching command to the circuit-breaker to operate at the correct instant, thus eliminating or substantially reducing transients.

Perfect matching with the circuit-breaker under control Success of controlled switching operations depends on the ability of the RPH3 controller relay to assess beforehand the reference synchronising voltage, as well as the characteristics and the consistency of circuit-breaker operations under all operating and ambient conditions. To optimise the performance of the RPH3 in its controlled switching operations, the relay can be programmed according to network and circuitbreaker operational characteristics. Thanks to the permanent monitoring of the circuitbreaker’s parameters and the sophisticated adaptive

AIS Solutions | RPH3

Internet links Electrical wire Ethernet fibre optic

Ergonomic HMI

Expert remote support

control routines, the RPH3 enables a reliable and accurate control over the behaviour of the device, thus permitting optimal switching sequences.

Advanced communications features and user friendly interfaces With its integrated memory and communications ports, the RPH3 records switching parameters and communicates the results of controlled switching operations. An embedded web server for the machine interface allows: Real-time information on the RPH3 device & application status ■■ Configuration of parameters needed for controlled switching applications ■■ Retrieval of switching archives and data from RPH3 devices ■■

RPH3

The web server program operates by accepting HTTP requests from the client via a standard web browser. The ‘RPH3 Manager’ dedicated software allows the analysis of archive records stored in the RPH3 relay in service and can perform data evaluations of controlled switching operations. AIS 420 kV circuit-breaker

135

AIS Solutions | RPH3

Functionalities

Technical features

Switching applications

■■

Capacitor banks

■■

Reduce overvoltages and eliminate inrush current ■■ Switch in at zero voltage

Shunt reactors

■■

Power transformers

■■

Reduce overvoltages and prevent current chopping and re-ignition ■■ Switch out with medium arcing time ■■

Transmission lines (uncompensated and shunt reactor compensated)

Eliminate inrush current Switch in under conditions where residual flux is minimal

Limit overvoltages while energising or re-closing ■■ Switch in at zero voltage across circuitbreaker poles ■■

Advanced features ■■ ■■

136

Digital interface via ethernet 100 Mbit/s Open for 61850-9.2 protocol

Temperature : -25°C to +55°C EMC compliant (electronics completely protected) ■■ Mains supply ■■ 48 Vdc – 15% to 250 Vdc ■■ 110/240 Vac +/- 20%/5060 Hz ■■ Power consumption: < 20 W ■■ Solid state control of breaker coils ■■ 48 V= / 250 V= ■■ 10 A – 300 ms / 15 A – 200 ms ■■ Alarm relays operating range: 230 V= / 5 A ■■ Reference syncronising voltage: 15 – 330 V~ (20-60 Hz) ■■ Switching time resolution: 0.1 ms ■■ Control voltage (auxiliary) ■■

AIS Solutions | Service

AIS Service solutions

137

AIS Solutions | Service

Condition based maintenance Time based maintenance is still the most frequently maintenance strategy in use, although it has been shown not to be the most efficient when looking at cost and equipment failure prevention compromise. With a clear objective of shifting to condition base maintenance and reliability centred maintenance (RCM) strategy, the need for monitoring ageing physical parameters in real-time has increased. Maintenance and monitoring solutions are key for keeping the substation’s primary equipment in optimal operating condition.

Digital AIS substation From a standardised technical solution to a tailored application on existing assets, our Service engineering departments can propose retrofit solutions to apply DWatch and CBWatch to most existing disconnectors and circuit-breakers in substations regardless of OEM. The sensor installation, cabling and IED upgrades can be performed during scheduled maintenance or overhaul.

Expertise and consulting Our experts are available for customer data interpretation and analysis. Several possibilities for data collection and transmission are available, from remote online access to manual file exchange, this consultancy can be provided on an on-call basis and on a contractual frequency basis. BWatch and CBWatch data are applicable to Asset Health Index (AHI) of our asset management solutions, supporting customer asset management policies.

138

AIS Solutions

AIS conclusions Alstom’s digital substation solutions offer a range of market leading benefits for AIS operations. These include: ■■ ■■ ■■ ■■

■■ ■■

■■

Entire Air Insulated Switchgear product portfolio A range from 72.5 up to 1200 kV Worldwide footprint, with local services High level of reliability and availability, with real time performance and extensive selfdiagnostics Standardisation and solutions designed to be interoperable Investment optimisation through reduced real estate needs, with copper cabling cut by up to 80% Move to predictive maintenance thanks to intelligent asset management systems

139

AIS Solutions

140

SAS Solutions

141

142

Substation Automation Solutions

Substation Automation Solutions Alstom Grid is the technology leader in substation automation solutions. Alstom Grid benefits from a leading position in the substation automation market: The number one in the Near and Middle East, India, Western Europe and Africa, its worldwide market-share amounts to more than 10%. With a complete substation automation range, offering full IEC 61850 compliance, the products are ready for Smart Grid applications. Alstom Grid Substation Automation Solutions (SAS) is amongst the leading suppliers to provide high-performance, mission-critical solutions that protect, control and monitor electrical substations. Our leadership is based on a strength of over 1600 experts, with fully-local project, delivery and application support capabilities, to offer integrated solutions for utilities and industrial customers worldwide.

143

SAS global footprint The new era of intelligent Smart Grids requires more sophisticated substation automation systems which allow energy operators to provide a secure, dependable and cost effective power supply to meet increasing customer demands for higher standards of power automation. Alstom Grid SAS provides intelligent systems and smart services to protect and control all equipment and assets, for secure and optimum transmission and distribution of electricity. We offer a complete control, protection and monitoring range in all segments, from medium voltage to over 1000kV, including: ■■ Fully-engineered digital control systems (DCS) ■■ Numerical protection relays ■■  Merging units, switchgear controllers, Ethernet switches and gateways for use in digital substations ■■ Automation turnkey projects ■■ Recording, measurement and phasor measurement solutions ■■ Conventional control/relay panels ■■ Refurbishment, training and post-delivery support services

144

Substation Automation Solutions

Introducing DS Agile DS Agile is the latest in turnkey automation solutions for digital substations. It combines cutting-edge hardware, software, communications and the highest technology engineering to IEC 61850 standards. DS Agile is a fully scalable solution, in terms of functionality, architecture and services, that can be tailored either to single substations or to a harmonised system across multiple substations.

145

The complete digital substation solution

D C

B

IEC 61850 Ethernet network ●● International standard protocol ●● Allows interoperability between IEDs from different vendors

DS Agile substation bay controller Substation control, communication, monitoring, protection and automation functions ●● Modular, IEC 61850-compliant solution ●● Open platform for real-time automation schemes ●● Both legacy and cutting-edge communication protocols ●● LCD graphical display for local control, monitoring and maintenance ●● Suitable for retrofitting and modernising existing installations

DS Agile switch For various Ethe ring, multi-ring, ●● Interoperable ●● Gigabit switch ●● Full complian constraints (I ●● Internal PC an ●● External racka

C Hardwire link

A M Condition

monitoring unit

Process bus IEC 61850

B

A D M Condition

monitoring unit

A

M Analog

merging unit

M Numerical

L

merging unit

L M Switchgear controlling unit

Fibre optic link

A

Smart primary equipment ●● Non-conventional voltage and current transformers Condition M ●● for gas-insulated switchgear (GIS) monitoring unit ●● for air-insulated switchgear (AIS) ●● Primary devices with embedded sensors for condition monitoring ●● Power electronics-based equipment: HVDC systems, FACTS

146

M

Merging units inte ●● AMU (Analogue) ●● NMU (Numerica ●● SCU (Switchgear transformer tap●● CMU (Condition

Substation Automation Solutions

G

hes ernet redundant architectures: , star, double-star e protocols (PRP/HSR) hes nce with electrical installation IEC 61850-3) and bay controller switches kable switches

E

F

DS Agile A300 substation gateway ●● Protocols: IEC 61850, IEC 60870-5-104, IEC 60870-5-101, DNP 3.0, ModBus ●● Hot standby redundancy ●● Integrated Ethernet switch

Remote access and telecommunication ●● Remote desktop ●● Cyber-secure web access to substation ●● e-terragridcom telecommunication solutions for MV & HV networks

F

Grid control room ●● Network management systems (EMS/DMS) ●● Market management systems (MMS) ●● Asset management solutions ●● Wide area solutions (WAMPAC)

G

F

H

I

E

I

F Central access server

K D

I

B Station bus IEC 61850

J F

Precision time protocol ●● Synchronisation of IEDs and merging units ●● GPS clock server 1 PPS, IEEE 1588

K

egration ) - for conventional instrument transformers al) - for digital instrument transformers (DIT) r controller) - for circuit-breakers, disconnectors and -changers switching and control monitoring) - for monitoring of primary devices

Cyber security ●● Intrusion protection ●● Integrated in switches and IEDs

MiCOM protection and other IED integration ●● MiCOM protection relays for application from MV through to EHV ●● Measuring and recording devices ●● Phasor measurement units ●● Interoperable third-party relays integration through IEC 61850, IEC 60870-5-103, IEC 60870-5-101, DNP 3.0 and ModBus protocols

J

DS Agile A400 WACU / SACU Wide Area Control Units (WACU) for inter-substation and inter-voltage exchange ●● IEC 61131 PLC automation ●● IEC 61850 -compliant ●● Hot stand-by redundancy

DS Agile Operator Interface (OI) ●● Single-line dynamic diagram viewer and bay viewer ●● Alarm viewer ●● Select-before-operate configurable function ●● Data monitoring, logging, archiving and curve trends ●● Phasor data concentrator ●● Condition monitoring HMIs ●● Secure access control by user profile ●● Protection and automation engineering toolsuite MiCOM S1 Agile

H

System Configuration Editor (SCE) ●● Allows integral data creation for system coherency ●● ISaGRAPH editor IEC 61131 standard ●● PSL editor for fast automation ●● Graphical editor ●● Reference templates library

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DS Agile key benefits DS Agile is a complete substation automation solution whose typical architecture consists of a local IEC 61850 Ethernet network (LAN) that links all components, together and with the operator interface (HMI). The network can be local to the substation or can interconnect several dispersed substations. Redundant architectures can be set up as self-healing ring or dualhoming star; eliminating outages. All LAN configurations are linked to the grid control room.

Industry standardisation Alstom DS Agile offers topology-orientated automation protecting, controlling and monitoring installations to ensure continuity and reliability of electrical networks. Based on IEC 61850 communication standards, DS Agile enables complete integration between devices and therefore ensures optimum use of information.

Reliability and security DS Agile provides ultimate reliability through the application of fully redundant architectures. This is reinforced by unmatched cyber security, at all levels throughout the digital substation.

Wide-area automation DS Agile is much more than a control and protection system for substations. Rapid data exchange and communications between all control and protection IEDs is enabled, not only across the substation and substation gateway, but also through Wide-Area Control Units (WACU) that can process real-time automation, taking into account the topology of multiple substations. The new WACU solution developed by Alstom makes inter-substation automation and protection possible, helping protect assets and optimise power flows.

Project delivery and support Alstom has experienced teams located worldwide, with a proven track record in project management, engineering, application support, maintenance and training. Our experts can provide assistance in any or all of these areas, allowing users to make the best use of DS Agile. 148

Substation Automation Solutions | DS Agile

DS Agile Interface (HMI)

A-series Gateway

SCADA

IEC 61850 ethernet network C26x Bay Controllers

Serial communication with IEDs

MiCOM P40 IED

Digital I/Os, instrument transformers, etc.

DS Agile functions Data concentration and processing

One of the main functions of the DS Agile is to concentrate and process data: the information can come from a variety of sources, both analog and digital. For example, when re-using legacy equipment, analog data can be acquired directly from current and voltage transformers and digital data can be acquired over serial communications links or via hardwired links. DS Agile manages many types of data from the substation’s primary and secondary equipment such as: tapchanger and switchgear positions, control signals, measurement values, disturbance records, settings, etc. Each item of qualified data is uniquely referenced in the system configuration tool in order to ensure full consistency of the information, as well as allowing it to be re-used in other parts of the system.

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Automation

Monitoring and analysis

Among DS Agile standard features are functions for locally or remotely monitoring and analysing collected data. Extremely compact monitoring can be achieved via the embedded LCD in the C26x bay controller, displaying single line diagrams, alarms, measurement values and sequence of event lists. Alternatively, more sophisticated monitoring is possible via one or more flat screens, providing additional benefits such as busbar colouring for easier maintenance, advanced alarm screens and accurate fault localisation within the system. Other features include advanced reporting, dual language display and disturbance record analysis.

Control

Controls can be initiated by the operator (locally or remotely) and multiple checks are performed before the issue of a control signal in order to make it fully secure. For instance, interlocking is achieved by logical equations or as the result of a dynamic topological analysis coupled with expert rules. Interlocks are managed as close to the process as possible in order to provide the best security of operation. Interlocking conditions are graphically displayed on the operator’s screen in order to immediately identify the locking conditions (if any), allowing the operator to make the appropriate changes before issuing the order. 150

An operator can configure specific control sequences or automation schemes, across one or more sites (e.g. automatic reclosing, System Integrity Protection Schemes (SIPS), load shredding). Such applications can be based on local or remote data. Similarly, the outputs can perform local or remote actions. Programmable logic can be implemented using either ProgrammableScheme Logic (PSL) or the Programmable-Logic Controller (PLC). PSL is for fast automation applications and it is available in the C26x bay controller. It is event-driven, so there is no cycle time. The optional PLC tool is fully compliant with IEC 61131-3 and it can be used for complex or sequential automation applications, not only at bay level (in the C26x) but also at inter-substation (or intersystem) level, by means of the programmable WideArea Control Units (WACU).

Substation Automation Solutions | DS Agile

DS Agile architecture Homogenous

DS Agile offers a unified architectural framework for building multiple solutions tailored to the real needs of almost any application. It allows for progressive upgrading of the system design according to the evolving requirements in terms of functions, size, performance etc.

Extendable

A DS Agile solution can be contained within a standard panel or be geographically distributed, depending on the application. The DS Agile architecture is structured in a series of hierarchical levels. Each level maintains a given performance in terms of transmission time, dependability and automation independently of the other levels. It therefore ensures that the system can be extended consistently and securely.

Standardised

The combination of modern, multi-functional and highly programmable IEDs together with fast communications greatly improves the capabilities for producing a “standard bay”. A standard bay is a product made of standard hardware, software and engineering libraries (automation, graphical representations, wiring interface and IED composition). It can then be customised to the exact requirements of the project through changes to the database.

Reliable

System availability is a function of the reliability of each individual component and the architecture in which they are combined. DS Agile accommodates a variety of redundancy options, ranging from the switch redundant power supply to the complete redundancy of each component, including configuration database redundancy. A DS Agile solution can be engineered from a few integrated components or have its functions split into several components, thus offering a balance between functional availability, cost and compactness. In addition to the self-checks carried out by each component, DS Agile offers a variety of system test modes such as ‘device maintenance management’ and ‘data forcing’ to further increase the overall availability.

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Communications protocols

Physical communications between components are based on both Ethernet and serial RS links in order to cope with different applications such as the re-use of existing devices and the integration of third-party equipment. State-of-the-art communications technology based on client-server and peer-to-peer links such as IEC 61850 is DS Agile’s standard. It relies on fast Ethernet networks and offers new perspectives in terms of distributed functions, performance and flexibility, enabling innovative automation schemes and the flexible addition of new application clients. In addition to Ethernet’s IEC 61850, DS Agile supports the most typical serial protocols (T103, DNP3 and MODBUS), in order to interface with existing devices, and it can be fully integrated within a remote control scheme. When using MiCOM Alstom devices, the same link can be used to retrieve settings or disturbance records. Communications with remote control centres is achieved using IEC 60870-5-101, IEC 60870-5-104 or DNP3 protocols. DS Agile also supports a series of older protocol generations. State-of-the-art communications technology based on client-server and peer-to-peer links such as IEC 61850 is DS Agile’s standard. It relies on fast ethernet networks and offers new perspectives in terms of distributed functions, performance and flexibility, enabling innovative automation schemes and the flexible addition of new application clients.

Simple architecture

The DS Agile base architecture interconnects a Remote Terminal Unit (RTU) or a PC with a series of Intelligent Electronic Devices (IEDs) such as protection relays or measurement IEDs. This architecture is typically used within a simple distribution substation, a wind farm or a transmission substation bay (a feeder, for example).

Complete architectures

A DS Agile complete architecture is made up of an ethernet network linking components from the base architecture with an operator interface (HMI), gateway and IEDs. The ethernet network might be local to a substation, typically for a transmission application, or it may interconnect dispersal sites commonly found in industrial or infrastructure applications through wide-area control units. The client-server communications exchange avoids any central point between local and remote control (as found in the simple architecture) and allows for tailored redundancy of the client and/or server. 152

Substation Automation Solutions | DS Agile

The full architecture is also typically implemented as a way to make an existing installation evolve progressively via new technologies. The older system thus becomes a slave to an IEC 61850 converter and new devices can successively be plugged into this network.

DS Agile components A typical DS Agile Digital Control System (DCS) will incorporate different Intelligent Electronic Devices (IED, such as protection relays, measurement devices and monitoring equipment), bay controllers, Ethernet switches and gateways. All key components are designed for optimal interoperability, data retrieval, control capability and remote settings.

DS Agile substation server with DCS OI operator interface (HMI) The DS Agile system database is hosted in at least one Human-Machine Interface (HMI) server, but it may support two servers with hot-standby redundancy. The HMI itself can be hosted either in the main server workstation or in a dedicated one and supports up to 10 HMI Clients. The DCS OI software platform provides real-time access to all substation automation data and enables secure and intuitive control operation functions.

DS Agile bay controllers IEC 61850-compliant substation bay controllers that provide fast automation, embedded or programmable (automatic voltage regulation, synchrocheck, autorecloser, busbar transfer), IED interface for legacy protocol conversion, data concentrator, events and waveform recorder, hot standby redundancy and are adaptable for individual requirements. Alstom’s bay controllers, like the MiCOM C264, are proven solutions with more than 30,000 units installed worldwide.

MU Agile merging units and DS Agile switchgear control units Alstom provides a full range of flexible merging units, allowing measurement conversion and switchgear control. Both AMU and SCU are based on proven architectures, such as those of MiCOM P40 Agile relays and MiCOM C264 bay controllers, respectively. 153

Substation Automation Solutions

DS Agile switches The DS Agile H-series Ethernet switches combine interoperable redundancy protocols (such as PRP) and fibre-optic connections for ultimate reliability of the substation communication networks. They maintain the flexibility to connect to standard Ethernet networks for substation upgrades or refurbishments.

DS Agile communication devices Alstom’s A-series provide powerful and ruggedised gateway and wide-area automation solutions for interfacing bay level devices, station level devices or upper level systems. They combine full IEC 61850 compliance with hot standby redundancy and simple commissioning.

MiCOM Protection range The MiCOM Alstom and agile protection ranges provide a complete family of technologically advanced protection relays for the modern digital substation. Typical protection applications include busbar, transformer and line differential, distance, feeder, generator, motor and phasor measurement.

Condition monitoring IEDs

A complete range of state-of-the-art systems for online condition monitoring of the primary substation equipment can be fully integrated within the DS Agile system, through IEC 61850, to provide valuable online condition data, plus expert tools for safer operation, preventive maintenance and lifetime management of your assets.

Measuring and recording IEDs Alstom supplies advanced IEDs for highly accurate, real-time fault recording and analysis, power quality measurements and trend recording. They are the ideal IED for analysing network faults, protection IED reactions, dynamic network stability and long term trends.

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Substation Automation Solutions | DCS OI

Fact sheet – SUBSTATION AUTOMATION SOLUTIONS

DCS OI

Operator interface (HMI) platform for substation automation While substations are usually unmanned during normal conditions, efficient information access is a key requirement in emergency situations. Design, installation, life extension and maintenance instances of an electrical substation’s digital control system (DCS) demand a straightforward, user-friendly interface. Intuitive access to the most relevant information and fully secure operations are necessary to ease operator tasks. To help you meet these challenges, we offer the Alstom DCS OI operator interface platform dedicated to our substation automation systems, DS Agile v5.0 and upwards, and PACiS (up to v4.6). Customer benefits Native integration of substation requirements Intuitive, secure and efficient interface ■■ Scalable platform tailored to each project ■■ HMI server hot redundancy ■■ Consistent suite of operator tools ■■ Compatible with all versions of Alstom Grid’s DCS ■■ ■■

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Native integration of substation requirements Alstom DCS OI relies on a standard graphical user interface, enabling local or web visualisation of single line displays. The HMI’s true added value consists of a series of fully tested modules that match electrical application needs such as: real-time communication protocol interface, select before operate sequences, automation capabilities and no data loss guarantee.

Intuitive and fully secure interface Alstom’s DCS OI scans of two dimensional substation representations or remote visualisations of real time video significantly improve the operator’s understanding of the situation. Embedded buttons enable functions such as synchro-check or interlocking condition displays to greatly increase the safety of operation and maintenance actions. Multiple language management allows dynamic switching between task-oriented dialects (operation vs. maintenance), or between national languages.

Scalable platform tailored to your project The configuration of Alstom’s DCS OI is tailored according to the needs of each project. This includes the number and type of screens and engineering facilities. From a performance perspective, the HMI can be expanded seamlessly from a single box to a series of interconnected PCs - with partial or complete redundancy. The interface is open to the integration of any additional software and may display any type of HMI, including real-time images issued from video cameras, providing a remote and secure view of the application.

Open and efficient interfaces The DCS OI provides an open interface to multiple intelligent electrical devices (IEDs) and Master SCADA through the latest Ethernet protocol IEC 61850. Disturbance files (COMTRADE 97/2001) and setting data are retrieved on the same link without disturbing real-time performance, using pass-through technology. Additional supported standards for data access include web access, SQLTM interface, COMTRADE archives or Crystal ReportTM.

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Substation Automation Solutions | DCS OI

Consistent suite of operator tools HMI software tools cover the complete lifecycle of the electrical application including: system engineering, IED engineering, substation automation, network analysis, system maintenance and IED maintenance - all integrated with a consistent look and feel. The DCS OI can provide access to (as a complement to local HMIs) any remote connection to present real-time information and any archived data for maintenance and supervision. Remote access is available through PSTN, DSL, satellite link as a dedicated application or Web server.

OI hot redundancy The DCS OI server redundancy is managed through a set of 2 HMI servers (named cluster). The OI client can be connected to one of the 2 servers. Reconfiguration is automatically managed when the preferred server is reconnected. Each datapoint change is consolidated between the 2 servers (real-time data & historical data are the same on both servers).

KEY FEATURES Intuitive and secure monitoring and control via Windows® 2000, Windows 7 or XP modules Real-time communication with following protocols: UCA2, IEC 61850, OPC, IEC 60870-5-103, IEC 60870-5-101, DNP3, ModBus... Powerful archiving and reporting facilities (SQL, COMTRADE, etc.) Universal real-time IEC 61131-3 automation capabilities Unique system management tool for efficient database version management Complete system engineering tools for XML database design Hardware compliant with EMC and environmental electrical constraints 10 s internal resolution and instance

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Substation Automation Solutions | DCS OI

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Substation Automation Solutions | DS Agile Gateway

Fact sheet – SUBSTATION AUTOMATION SOLUTIONS

DS Agile Gateway

Rugged, solid-state, communications solution DS Agile’s A300 communications protocol gateway is an advanced solution for interfacing substation networks with digital control systems and network management systems.

Customer benefits Fully compliant with IEC 61850 Simple commissioning and maintenance ■■ Hot standby redundancy ■■ Available with additional cyber security tools ■■ ■■

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Combining full IEC 61850 compliance, hot standby redundancy and simple commissioning, the A300 is a powerful solution for interfacing bay level devices (protection, control or measurement devices), station level devices (digital control system client/servers) and upper level systems (network management systems or digital control systems). The DS Agile Gateway is ruggedised and solid-state - designed to work within stringent substation environmental conditions (EMC compliance as per IEC 61850-3 etc.).

Full compliance with IEC 61850 Alstom Grid’s A300 provides a dedicated interface to any other IEC 61850 enabled device, either with a single or dual-redundant communications architecture. The DS Agile Gateway is also is also fully compliant with the different editions of IEC 61850, which ensures backward compatibility and interoperability ideal for substation refurbishment or upgrades.

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Simple commissioning and maintenance The A300 gateway has flexible communications interfaces enabling multiple, separate redundant substation ethernet architectures. This helps to guard against the repercussions of network failure and facilitates a clear separation of network functions, simplifying commissioning and maintenance activities.

Hot stand-by redundancy DS Agile A300 is equipped with two native independent ethernet ports which can support Alstom’s H-series dual-redundant ethernet switches and/or multiple LAN/ WAN connections. Two A300 gateways can also be physically connected in a redundant hotstandby configuration for high communications data integrity.

Substation Automation Solutions | DS Agile Gateway

Communications protocols Alstom’s A300 gateway is compatible with the most popular communications standards at IED, DCS and NMS levels: IEC 61850 Client and Server, DNP3.0 serial and IP, MODBUS serial and TCP/IP, Profibus DP, HNZ 66, IEC 60870-5-101 & 101 NUC, IEC 60870-5104 & 104 NUC, OPC, etc

Tools and cyber security Supervision of the trip circuit, whether the breaker is closed or open (preclosing supervision), can be implemented using opto-coupled inputs and the programmable scheme logic.

Technical specifications Dimensions: (W x D x H) 181 x 238 x 177 mm Mounting kits (optional): wall/ panel/ stand ■■ Weight: 5 kg ■■ Power consumption typical: typical 25 W ■■ Power supply: 24 Vdc; 36 - 60 Vdc; 90 - 350 Vdc; 100 240 Vac/ 50-60 Hz ■■ ■■

Communications LAN: 2 x 10/100Base-T RJ-45 ports Ethernet switches (optional): 2 x MiCOM H152 or H162 redundant ethernet boards ■■ Serial Ports: 2 × RS-232, 2 x RS-232/422/485 ■■ USB ports: 4 x USB Rev. 2.0 compliant ■■ ■■

Environmental conditions Humidity: IEC 60068-2-3, 95% @ 40°C (non-condensing) ■■ Operating temperature: IEC 60068-2-1&2, -20°C to 55°C ■■ Storage temperature: IEC 60068-2-1&2, - 40°C to 60°C ■■ Shock protection: IEC 60068 2-27 ■■ Vibration protection: IEC 60068 2-64 ■■ Electromagnetic compatibility: EN55022, EN55011, EN61000 ■■

System hardware Processor: CPU Intel Atom D510 1.66GHz Memory: 2GB DDRII SDRAM built-in ■■ Operating system: Microsoft WINDOWS XP ■■ Battery backup RAM: 512 KB ■■ Expansion slots: 4 x PCI V 2.2 ■■ Indicator LEDs: power input 1, power input 2, power fault, IDE, diagnosis, 4 COM ports Tx/Rx ■■ Video: VGA DB15 VGA connector, 1600 x 1200 @ 85 Hz ■■ Storage: internal solid state drive ■■ ■■

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Substation Automation Solutions | DS Agile WACU

Fact sheet – SUBSTATION AUTOMATION SOLUTIONS

DS Agile WACU

Based on the DS Agile gateway, the new DS Agile WACU A400 allows inter-voltage and inter-substation control exchange through IEC 61131 PLC automation. This wide-area automation capability becomes highly valuable whenever the implementation of multi-substation control is needed (e.g., among the multiple substations across railway lines or between the generation subsystem and the transmission interconnection substation in a power plant).

Customer benefits Wide Area Control Units (WACU) for inter-substation and inter-voltage exchange ■■ IEC 61131 PLC automation ■■ IEC 61850-compliant ■■ Hot stand-by redundancy ■■

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Substation Automation Solutions | DS Agile WACU

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Substation Automation Solutions | DS Agile bay controllers

Fact sheet – SUBSTATION AUTOMATION SOLUTIONS

DS Agile bay controllers

IEC 61850-compliant
substation bay controllers
that provide fast automation, embedded or programmable (automatic voltage regulation, synchrocheck, autorecloser, busbar transfer), IED interface for legacy protocol conversion, data concentrator, events and waveform recorder, hot standby redundancy and are adaptable for individual requirements. Alstom’s bay controllers, like the MiCOM C264, are proven solutions with more than 30,000 units installed worldwide.

Customer benefits Substation control, communication, monitoring, protection and automation functions. ■■ Modular, IEC 61850-compliant solution ■■ Open platform for real-time automation schemes ■■ Both legacy and cutting-edge communication protocols ■■ LCD graphical display for local control, monitoring and maintenance ■■ Suitable for retrofitting and modernising existing installations

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Alstom’s C264 Bay Control Unit (BCU) is a sophisticated solution supporting many applications and functions for substation control, communication, monitoring, protection and automation. Flexibility, reliability and ease of use are among the top features required in a substation computer; the MiCOM C264 has these features. A combination of dual redundant fibre optic Ethernet, modular I/O, an expandable design and an extensive library of functions make the C264 the ideal solution for a wide array of applications in substation digital control systems. In addition to the traditional data management (inputs and outputs) the DS Agile BCU can be used as a: ■■ Remote Terminal Unit (RTU) ■■ Bay computer ■■ Feeder manager (protection & control) ■■ Substation automation processor ■■ Sequence of Events Recorder (SER) ■■ Automatic Voltage Regulator (AVR) ■■ Measurement centre ■■ Load shedding controller ■■ Protocol converter ■■ Substation gateway Seamless modernisation of existing installations The C264 provides seamless integration with existing substation assets, thanks to its flexible interfaces and native expandability. Its powerful processing, communication and configuration facilities make it the ideal tool for upgrading substation supervision, automation and maintenance. Innovative real-time automation schemes MiCOM C264 enables innovative automation schemes thanks to extremely fast (event driven) Programmable Scheme Logic (PSL) and robust Programmable Logic Control (PLC). Optimised engineering The multifunctional capabilities of the C264 optimise system engineering as fewer devices result in less wiring, training and maintenance.

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Sample logical equations

Substation Automation Solutions | DS Agile bay controllers

Applications Bay/substation interlocking Alstom’s C264 provides two methods of interlocking: ■■ A logical equation based method ■■ A topology based method, using predefined rules and substation topology Interlocks are managed as close to the process as possible in order to provide the best security of operation. Interlocking conditions are graphically displayed in order to immediately identify the interlocking conditions (if any) and make the appropriate changes before issuing the command. Trip circuit supervision The purpose of this function is to supervise the continuity of the trip circuit of a circuit-breaker. Two options are available: two wires or four wires. The two-wire option verifies the trip circuit continuity when the circuitbreaker is closed. The four-wire option permits verification of the continuity whether the CB is open or closed. In the case of single phase circuitbreakers the C264 can supervise the continuity of the trip circuit separately for each phase. Automatic Voltage Regulation (AVR) The Automatic Voltage Regulation (AVR) function is used to automatically maintain the correct secondary side voltage of a tap changing transformer.

AVR in the MiCOM C264 is a compact voltage regulation solution for IEC61850 systems in electrical substations. It is able to manage one transformer or up to four transformers in parallel. C264 AVR provides: ■■ Active and reactive compounding in order to maintain the voltage at a remote location ■■ Homing in order to adjust a transformer to the voltage of the busbar to which it will be connected ■■ For transformers in parallel: Minimising circulating current method, master/follower mode ■■ Optimised transformer ratio Auto-recloser The MiCOM C264 can manage one autorecloser per bay (up to 12 bays per unit). The integrated auto-reclosers can operate in 1 phase and/or 3 phase mode. Up to four autoreclosing cycles are available and the time delay for each is independently configurable. Auto reclosers can be initiated either internally in the bay unit or via external protection devices using digital inputs. Synchro-check The synchro-check function can be used in conjunction with automatic or manual reclosure. The function (limited to one bay) determines the difference between the amplitude, phase angles and frequencies of two voltage vectors and uses this information to determine whether or not to

close the breaker. Locking and coupling modes are available and a deadline and dead bus logic are also included. IED gateway and data concentrator One of the main features of the C264 is to concentrate and process data. This information can come from a variety of sources, both analogue and digital. For example, when re-using existing equipment, analogue data can be acquired directly from current and voltage transformers and digital data can be acquired over serial communication links or via hardwired links. The DS Agile BCU manages many types of data: tap positions, controls, measurements, disturbance records, settings, etc. Each item of qualified data is uniquely referenced in order to ensure full consistency of the information, as well as allowing it to be reused in other parts of the system.

MiCOM C264 front view (40TE variant)

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Features Communication protocols Alstom’s MiCOM C264 is fully compatible with many communication standards such as UCA2/IEC 61850, IEC 608705-104, DNP3, IEC 60870-5101/103, and MODBUS. Redundancy At substation level and / or bay level an optional redundant C264 can be used to avoid the loss of critical functions. Digital inputs The MiCOM C264 offers five types of digital inputs: ■■ Single point ■■ Double point ■■ Multiple point ■■ System input for internal C264 information ■■ Logical combination of digital inputs All inputs are acquired and timestamped with an accuracy of 1 ms. Digital input processing In addition to de-bouncing many customisable filtering functions can be used to process digital inputs, including: ■■ Toggle filtering ■■ Persistence filtering ■■ Motion filtering ■■ Undefined state filtering

Additionally a digital input can be manually suppressed, substituted, forced invalid and detected as faulty. Digital inputs can then be transmitted on the substation LAN using the desired protocol. Binary counters Two types of binary counter are available; single counters for single data points and double counters for double data points. Counters can be transmitted periodically or on request. In the event of a supply interruption the counters can resume from their previously stored values. Digital outputs Digital outputs can be used to apply a switching voltage to an external device. These outputs can be controlled in one of three ways: Select Before Operate once (SBO once) ■■ Select Before Operate many (SBO many) ■■ Direct execution The SBO once mode is used for controls via set points or ancillary devices, as well as synchronised or non-synchronised circuit-breakers, transformers, disconnectors and earthing switches. The SBO many (selection, execution, and de-selection) control sequence is used for the control of transformers. ■■

Encoded digital data The C264 BCU can interpret a group of digital inputs as an encoded digital value. Binary, Binary Coded Decimal (BCD), gray code, decimal and 1 among N types of encoding can all be processed. These values can represent data such as process measurements and tap positions. Analogue inputs Analogue measurements can be acquired from either an analogue input board, a transducerless measurement board (for current and voltage transformers) or via a communication network. Analogue outputs Analogue outputs can be used to interface with auxiliary devices (measurement viewers, generators, motors, etc). The Analogue outputs are powered from an external supply (48VDC) and can maintain their value even if the C264 is powered down.

MiCOM C264 rear view (40TE variant)

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Substation Automation Solutions | DS Agile bay controllers

Measured and derived values Directly measured values of voltage and current can be measured using the transducerless measurement board. Many different values can be calculated from the measured values including: RMS currents and voltages Network frequency and phase angle ■■ Active, reactive and apparent powers - total and per phase ■■ Power factor ■■ Sequence components ■■ Derivatives: df/dt, dV/dt, etc ■■ ■■

Waveform recording The MiCOM C264 provides two types of waveform recording, Fast Waveform Record (FWR), which stores samples at the maximum sampling frequency and Slow Waveform Record (SWR), which stores RMS measurements over a longer period. Both modes can run simultaneously. Recording can be triggered by, the change of state of binary digital inputs/outputs, measurement threshold violations and a request from an operator. Waveform records are stored using COMTRADE 2001 binary format. Power quality Alstom’s C264 can measure the percentage Total Harmonic Distortion (THD) (up to and including 15th harmonic) and the Total Demand Distortion (TDD) on voltage and currents.

Self monitoring Comprehensive self-monitoring procedures, including power-on and continuous testing, ensure that internal hardware or software errors are detected and do not cause malfunctions. If a fault is detected an alarm will be issued and/or the watchdog contacts will change state depending on the fault severity. Maintenance web server The maintenance web server can be used to visualise maintenance data (Hardware/Software, Communication, I/O values) and to download the up-to-date event log. It is directly accessible with a standard Internet Browser. Programmable logic An operator can configure specific control sequences or automation schemes (e.g. automatic switching, System Integrity Protection Schemes (SIPS), load shedding). Such applications can be based on local or remote data. Similarly the outputs can perform local or remote actions. Programmable logic can be implemented in the C264 using either Programmable Scheme Logic (PSL) or the Programmable Logic Controller (PLC). PSL is for fast automation applications (<5ms). It is event driven and so there is no cycle time. The optional PLC tool is fully compliant with IEC 61131-3. It can be used for complex or sequential automation applications.

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Substation Automation Solutions | DS Agile bay controllers

Local interface for control, operation and display The control of switching devices is possible using a keypad and a graphical backlit LCD. Operations can be performed in a simple and intuitive way via up to 12 switchable displays for bay control. Additionally there are dedicated panels for monitoring (i.e. measurements, events list, alarms, etc.), display and maintenance. If required the operator panel can be mounted separately from the C264 (up to five meters away). Access barriers can be used to guard against inadvertent or unauthorised operations. Event logging Up to 2,000 events can be stored in nonvolatile memory. The events are time stamped and stored in chronological order.

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Substation Automation Solutions | DS Agile switchgear control unit

Fact sheet – SUBSTATION AUTOMATION SOLUTIONS

DS Agile Switchgear Control Unit (SCU)

Switchgear control units are the fast, real-time interface to switchgear, mounted close to the plant which they command. They replace the hardwiring of inputs and outputs with an Ethernet interface to the yard. They combine full IEC 61850 compliance with hot standby redundancy and simple commissioning.

Customer benefits For Ethernet redundant double-star architectures: Interoperable protocol (PRP) ■■ Gigabit switches ■■ Multiple Gigabit ports and IEEE 1588 supported ■■ Full compliance with electrical installation constraints (IEC 61850-3) ■■ Hardwired binary I/O in the yard scaleable up to 48 binary inputs and 20 outputs ■■ Fast 1ms GOOSE response time, with high speed, high break contacts available for time-critical trip commands ■■

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Substation Automation Solutions | DS Agile switchgear control unit

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Substation Automation Solutions | MU Agile AMU

Fact sheet – SUBSTATION AUTOMATION SOLUTIONS

MU Agile AMU

Analogue merging unit The Alstom MU Agile AMU provides a high quality, cost effective, IEC 61850-9-2LE sampled value interface to conventional current and voltage transformers.

Customer benefits Measures accurate, time synchronised power system data Communicates sampled values according to IEC61850-9-2LE ■■ Uses the same transformers for current and voltage measurement as in the MiCOM Alstom P40 product family ■■ Compact, cost effective solution ■■ Withdrawable ■■ ■■

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Digital technologies have brought many benefits in the strategic field of transmission networks and specifically substations. Digital technology at station bus level is today widely spread and has also extended to process buses at the primary equipment level. The Alstom MU Agile Analogue Merging Unit goes one step further towards a complete digital substation; facilitating the connection of conventional current and voltage transformers to modern substation automation solutions through IEC 61850-9-2LE. With a space-saving case accommodating four current and four voltage transformers taken from the proven MiCOM P40 product range, the MU Agile AMU affords a low-risk transition from conventionally connected substation automation to a fully digital substation.

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Substation Automation Solutions | MU Agile AMU

Configuration and status monitoring The MU Agile AMU can be quickly and easily configured using the intuitive MiCOM S1 Agile PC tool suite via the front USB port. A visual indication of the IEDs status via 4 tri-colour LEDs is available on the front panel. These are used to indicate the health of the IED, the time synchronisation status, whether it is out of service, and whether it has raised an alarm.

Hardware The MU Agile AMU hardware offers: Support for 4 x CTs and 4 x VTs Space-saving 4U height and 30TE (6”) case size ■■ A front USB port and a rear fibre optic Ethernet port ■■ Power-up diagnostics and continuous selfmonitoring ■■ Time synchronization via fibre optic 1-PPS ■■ N/O (form A) and N/C (form B) watchdog contacts ■■ Withdrawability ■■ ■■

MU Agile AMU standard hardware

All CT connections have integral shorting, when the IED is withdrawn from the case. This affords additional safety to personnel who may be working near live apparatus.

175

Sequence of event recording All events are time tagged to a resolution of 1 ms. Up to 2048 time-tagged event records are stored in the flash memory, and can be extracted using the USB port.

Communications Two communication ports are standard: a rear port providing for process bus communications and a front port for substation staff. The front USB port facilitates the programming of settings, and the extraction and viewing of events. The rear fibre optic LC Ethernet connection offers the ability to transmit IEC 61850-9-2 sampled values and to receive SNTP time synchronisation messages.

Time synchronisation The high-precision referencing of sampled values to GPS real time uses the one pulse per second (1 pps) fibre input, typically provided by the MiCOM Alstom P594.

Alstom Grid agile digital substations Alstom Grid agile digital substations are based on IEC 61850, the unifying communication standard for complete information sharing and interoperability. They allow for future modernisation and the integration of new systems. Digital Control Systems are connected with the primary bays through a process bus built on redundant Ethernet. Merging and control units collate and convert measurements, indications and commands (I/O) into sampled values and GOOSE messages, and vice-versa. At an advanced level, digital instrument transformers and condition monitoring systems integrated with the substation HMI (Human Machine Interface) can be added, providing superior substation situation awareness, locally and remotely.

Cyber-Security The sophistication of protection schemes, coupled with the advancement of technology, increasingly leads to devices and substations being interconnected with open networks, such as the internet or corporate-wide networks. This introduces a potential security risk making the grid vulnerable to cyber-attack, which could in turn lead to electrical outages. To secure communication within such environments, the MU Agile AMU offers NERC-compliant cyber security. MU Agile AMU withdrawability

176

Substation Automation Solutions | MU Agile AMU

IEC 61850-9-2LE process bus IEC 61850-9-2LE facilitates the integration of non conventional instrument transformers into modern substation automation equipment. It also allows conventional current and voltage transformers to be interfaced to the same equipment via merging units. It describes how analogue signals such as phase currents and voltages can be exchanged as sampled values.

Benefits of IEC 61850-9-2LE Asset optimisation Reduced maintenance cost ■■ Optimisation of new investments ■■ Reliability and availability ■■ Standardisation and Interoperability ■■ Ease of refurbishment ■■ Safety ■■ Environmental responsibility ■■ ■■

Environmental Responsibility The MU Agile AMU allows for the substitution of many copper cables with just a few optical fibres. In a full digital substation wiring can be reduced by up to 80%. The IEDs are manufactured in a lead-free soldering process using lead-free components. This eco-responsibility is demonstrated in the Product Environment Profile (PEP). The PEP shows claims for raw material depletion, energy depletion, water depletion, global warming potential, ozone depletion, photochemical ozone creation, air acidification, and hazardous waste production. The IED does not require any resident battery.

Quality Built-In Quality Built-In methodology is applied throughout the development and manufacturing of the IEDs. Part stress analysis in R&D, rigorous component supplier selection, and a shipping carton compliant with ISTA protection requirements all are examples of best-practice to maximise long-life reliability. All circuit boards have harsh environmental coating, to resist moisture, salt, corrosive atmosphere and industrial ambient pollution – as standard. Circuit board production uses in-circuit tests, boundary scanning, built-in self-test, automated optical inspection, and X-ray scanning to achieve maximum test coverage.

177

Substation Automation Solutions | MU Agile AMU

178

Substation Automation Solutions | Protection Relays

Introducing Protection Relays No matter how well designed, faults will always occur on a power system, and these faults may represent a risk to life and/or property. The destructive power of a fault arc carrying a high current is very large; it can burn through copper conductors or weld together core laminations in a transformer or machine in a very short time – some tens or hundreds of milliseconds. Even away from the fault arc itself, heavy fault currents can cause damage to plant if they continue for more than a few seconds. Uncleared faults would also pose a risk to system stability, resulting in unwanted disconnection of generation or interruption of supplies to consumers. The provision of adequate protection to detect and disconnect elements of the power system in the event of faults is therefore an integral part of power system design. Only by doing this can the objectives of the power system be met and the investment protected.

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Substation Automation Solutions | Protection Relays

180

Substation Automation Solutions | MiCOM Alstom P40

Fact sheet – SUBSTATION AUTOMATION SOLUTIONS

MiCOM Alstom P40 Protection platform devices

The MiCOM Alstom P40 range offers a suite of relay functionality and hardware options to best suit the protection requirements, while allowing the customer to choose the most cost-effective solution for their application. Customer benefits Unparallelled speed, security and selectivity Comprehensive models, hardware options, protection and control functions ■■ Graphical programmable scheme logic (PSL) eases protection scheme creation, and avoids the need for external logic controllers ■■ Ease of integration into DCS, SCADA and engineering workstations ■■ Comprehensive communication options including IEC 61850 and redundant Ethernet ports ■■ IEC61850-9-2 process bus applications: deploy in digital substation architectures ■■ MiCOM S1 Agile software manages your IEDs ■■ ■■

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The 40 series platform, incorporating a full complement of utility, generation and industrial-focussed models is the principal building block of Alstom Grid’s offer, hosting the wide variety of protection, control, measurement, monitoring and communication functions demanded.

Typical device in small case size variant

The versatile hardware allows deployment with confidence and the PC tool, S1 Agile, makes for easy configuration, application and management of the installed base. A fresh and intuitive user interface makes the 40 series ideal for any environment and suits all skillsets of headquarters and field personnel. Numerous integrated communication protocols allow easy interfacing to substation control or SCADA systems. From simple wired serial buses, to Ethernet station and process bus architectures with IEC 61850 - MiCOM Alstom protection has the solution. The MiCOM Alstom P40 range offers comprehensive solutions for all power system protection applications, including:

Generation ■■

Integrated generator protection

Industrial Motor management Feeder management ■■ Interconnection protection

■■ ■■

Rail Trackside AC Grids Catenary distance protection ■■ Transformer management ■■ Transformer-rectifier units ■■ ■■

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Transmission and distribution Distance protection Line differential ■■ Transformer management ■■ Busbar protection ■■ Feeder management ■■ Voltage and frequency protection ■■ Loadshedding ■■ Breaker fail and reclosing ■■ Line phase comparison ■■ Phasor Measurement Units (PMU) ■■ ■■

Substation Automation Solutions | MiCOM Alstom P40

Scope The P40 range fulfills the requirements at all voltage levels from MV to EHV/ UHV for industrial, distribution, generation, transmission and railway systems.

Common features 1 A/5 A dual rated CTs for simplified inventories Event and disturbance recording for post-fault analysis ■■ Rear ports with choice of protocols, and front port for local setting ■■ Full Programmable Scheme logic for customer-specific automation ■■ Scalable input / output hardware depending on requirements ■■ Operating voltage user programmable for opto inputs ■■ Hardware accessories available for easy mounting in racks or panels ■■ ■■

Applications Feeder protection A full range, with directional and non-directional applications of overcurrent and earth fault at its heart: ■■ P14x - Feeder management relay suitable for MV systems and HV system backup, with autoreclose, and check synchronism within the model option selection ■■ P341 - Grid interconnection protection, at the point of coupling systems with embedded generation. Line protection A full range extending up to the most demanding sub-cycle technology for EHV and UHV transmission: ■■ P44* - Full scheme distance protection relays for HV, EHV and UHV systems ■■ P54* - Line Differential protection relays for direct fibre

and multiplexed communication options as well as phase comparison protection for use with power line carrier ■■ P84* - Transmission line terminal devices for backup, reclose and breaker fail with single, dual, breaker and a half and mesh circuit-breaker toplogies. Substation plant protection Applicable at all voltage levels, to safeguard the most costly system assets: ■■ P64* - Transformer management and protection, for between two and five-ended schemes ■■ P74* - Numerical busbar protection (biased principle) suitable for application on MV, HV and EHV busbars ■■ P14* - Numerical highimpedance busbar and REF protection schemes, deployed with varistors.

Rotating machine protection Specialist devices for protection, control and monitoring of all machine types and ratings: ■■ P24* - Rotating machine management relay for application on a wide range of synchronous and induction machines ■■ P34* - Generator protection for small to sophisticated generator systems, and interconnection protection. System monitoring and stability devices Fast-acting devices to take local decisions and input to wide area schemes: ■■ P14* - Voltage and frequency protection for load shedding, load restoration and generator abnormal detection ■■ P84* - System stability devices, including a P847 Phasor Measurement Unit (PMU) for all grid applications.

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Protection and control features Protection elements All algorithm and hardware know-how is the culmination of decades of advances in Alstom’s centres of excellence. The platform has vast experience in test and in-service operational environments, proving the technical integrity. The comprehensive and advanced library of protection and control functions in each device allow it to meet the exact application requirements. Multiple protection functions, logic and control functions may be enabled, without deterioration in performance – the platform is fully deterministic.

Independent protection settings groups

The 40 series can offer up to four independent settings groups. These can be activated locally, remotely or via a dedicated input and are used to allow for different system operating conditions and where adaptive relaying is applied.

Programmable scheme logic

Powerful logic available in the 40 series relays allows the user to customise the protection and control functions of the relay. It is also used to program the functionality of the opto-isolated inputs, relay outputs, LED and user alarms. The programmable scheme logic can be used to implement additional supervision features, such as trip circuit supervision or implement complex logic such as frequency restoration schemes. Schemes have been developed capable of supervising the trip coil and circuit with the circuit-breaker open or closed. The Px40 gate logic includes OR, AND, NOT and MAJORITY gate functions, with the ability to invert the inputs and outputs, and provide feedback. A number of general purpose logic timers are also available as well as those timers used to condition the relay contacts. The system is optimised (event driven) to ensure that the protection outputs are not delayed by the PSL operation. The programmable scheme logic is configured using the graphical S1 Agile PC software, as shown in Figure 1.

Figure 1 Programmable logic for P40

184

Substation Automation Solutions| MiCOM Alstom P40

Measurements, recording and post fault analysis Measurement & post fault analysis The relays are capable of measuring and storing a wide range of system quantities such as current, voltage, frequency, power, distance to fault etc. depending on the relay functionality. These measured values can be displayed on the front LCD display or transferred locally or remotely per user requirements. All event, fault and disturbance records are time tagged to a resolution of 1ms using the internal real time clock and are stored in non-volatile memory. Where relays are communicating with a SCADA system, the protocol’s telegrams can be used for external time synchronisation or alternatively an optional IRIG-B port is available for accurate time synchronisation on all P40 relays. Relays can also use an opto input to synchronise the internal clock. Event records These are generated for status changes to logic inputs and outputs, modifications to one or more setting parameters and alarm signals. All events are time-tagged and stored in chronological order in cyclic memory. These are readily

available for viewing on the LCD, or by extraction via the communication ports. Fault records Up to 15 records are supported for every fault (5 on some models), with the following information captured: ■■ A fault number ■■ The date and time ■■ The active setting group ■■ The function that issued the trip ■■ The magnitude of the current/ voltage that gave rise to the trip command Distance to fault calculation is provided on most feeder and line protection models. Disturbance records The internal disturbance recorder will record the sampled values of all analogue input variables such as phase currents and voltages where applicable during a fault. Oscillographic analysis can be performed using the S1 Agile PC tool which will provide the means to quickly analyse analogue and digital signals on the same time scale for convenience. (Figure 2 on next page) Disturbance records can be extracted from the relay via the communication ports and saved in the COMTRADE format.

as an option on relays providing easy access to settings, records and measurements for protection engineers. A main rear communications port is also available for interface to a SCADA system. A number of protocols are available as an option for this purpose, with different media such as wired serial, fibre serial, RJ45 Ethernet, and fibre Ethernet. Local communication The front EIA(RS)232 communication port has been designed for use with the S1 Agile software and is primarily for configuring the relay settings and programmable scheme logic. It is also used to locally extract event, fault and disturbance record information and can be used as a commissioning tool by viewing all relay measurements simultaneously. Communication The rear communication port is based on EIA(RS)485 voltage levels and is designed for permanent multidrop connection to network control and data acquisition systems. Optional fibre optic and ethernet communications ports are also supported on the 40 platform, the latter available with redundancy.

Relay communications As standard, a front communication port is available for local access to the relay. An auxiliary rear communication port is available

185

The following protocols are available: ■■ Courier/K-Bus ■■ Modbus ■■ IEC 60870-5-103 ■■ DNP 3.0 ■■ IEC 61850 This flexibility allows the MiCOM Alstom P40 range of relays to be integrated into a SCADA system as well as to provide engineering data for remote access by utility engineers. Redundant Ethernet communication MiCOM Alstom P40 series includes several redundant Ethernet options for IEC 61850 or DNP3/IP: ■■ Parallel Redundancy Protocol (PRP) according to IEC 62439-3 ■■ Rapid Spanning Tree Protocol (RSTP) ■■ Alstom Self Healing Ring ■■ Alstom Dual Homing PRP has the advantage of taking zero time to recover from a failure, as parallel alternative paths are continually operative. All settings are configurable with the use of MiCOM S1 Agile. User interfaces The ability to customise the menu text and alarm descriptions are supported on P*40. The front panel user interfaces, as per the example shown in Figure 3 comprise: (1) A back-lit liquid crystal display (2) Four fixed function LEDs

186

Figure 2 Oscillography analysis using S1 Agile software for optimum results

(3) Up to 18 user programmable LEDs (4) Menu navigation and data entry keys (5) “READ” and “CLEAR” keys for viewing and reset of alarms (6) An upper cover identifying the product name, which may be raised to view full product model number, serial number and rating information

(7) A lower cover concealing the front EIA(RS)232 port and download/monitor port (8) Facility for fitting a security seal (9) Up to ten programmable function keys with tricolour LEDs – for control and test applications and easy annunciation (not visible in the 40TE example shown)

Figure 3 P40 series user interface

Substation Automation Solutions | MiCOM Alstom P40

Self monitoring Comprehensive self-monitoring procedures within the device ensure that internal hardware and software errors are detected, thus ensuring a high degree of reliability. Automatic tests are performed during start-up and cyclic selfmonitoring tests are performed during operation. Any deviations are stored in non-volatile memory and the result of the fault diagnosis determines whether a blocking of the device will occur or whether only an alarm is issued. Trip circuit supervision Supervision of the trip circuit, whether the breaker is closed or open (preclosing supervision), can be implemented using opto-coupled inputs and the programmable scheme logic.

functionality within the product. Communication ports and model/ serial number information are concealed by upper and lower covers. Physical protection of the front panel user interface and prevention of casual access is provided by an optional transparent front cover, which can be fitted or omitted according to choice, since the front panel was designed for IP52 protection against dust and water.

The 40TE case width is often narrow enough to allow a retrofit of legacy vertically-mounted relays. Wiring External connections are made via ring type terminals, for the peace of mind of secure ring lug and screw-through fastening. Ring terminals accommodate one or two lugs per terminal.

The cases are suitable for either rack or panel mounting as shown in Figure 4. Taking into account the differing case widths, relays can be combined with or without the use of standard blanking plates to form a complete 19” mounting. This saves space and allows for a neat installation, especially in conjunction with MiCOM ALSTOM P*90 series interfaces, P991 and MMLG test blocks, and MIDOS auxiliary relays – all of which share the same 4U mounting dimensions.

Mechanical description Cases The Px40 series relays are housed in a specially designed case providing a high density of

Figure 4 Typical case dimensions Case dimensions Px40

A

40TE 60TE

B

C

D

E

240 (inc wiring)

270 (inc wiring)

157.5 max

206 177

309.6

80TE

413.2

80TErack

483

Note: Maximum sizes for guidance only, for specific product information please check the relevant product documentation. (All dimensions in mm)

187

Technical data Measuring inputs – analogue All CT inputs are dual-rated at 1A and 5A to simplify ordering and strategic spares inventories. The heavy duty terminal block features integral current transformer shorting to prevent dangerous voltages being present should the block be removed; a maintenance error could otherwise lead to a potentially unsafe/lethal scenario. Measuring inputs – process bus IEC 61850-9.2 Many models in the range are available with an IEC 61850-9.2 process bus interface to replace traditional analogue inputs. This facilitates interoperability with non-conventional instrument transformers and merging units, with the measuring signals marshalled via Ethernet. IEC 61850-9-2 process bus interface An optional process bus interface is available in MiCOM P40. It allows the relay to received current and voltage sampled data from non-conventional instrument transformers such as optical devices and Rogowski devices. In other digital substation architectures, the -9-2 data is generated by merging units in the yard, which digitize conventional 1A/5A and 100/120V secondaries, for safer and more economical cross-site communication to IEDs by fibre optic. Alstom’s -9-2

188

implementation has been designed to be especially resilient and reliable in the presence of “noise”, such as latency, jitter or missing/ suspect data. Power supplies Three ranges of power supply options are available at the

ordering stage to balance ease of deployment with energy efficiency. Digital inputs (Optos) The digital status input pickup thresholds are programmable, so specifying the inputs is just a question of counting how many are needed.

General Series Data

Px40

Frequency 50/60Hz

x

Dual rated 1A/5A

x

CT Thermal Ratings Continuous: 4 Inom for 10s: 30 Inom for 1s: 100 Inom

x

Opto Inputs

max 48

Output Contacts

max 46

Carry: continuous

10 A

Make and Carry

30 A for 3s

LED Indication (freely programmable)

12 (8) - plus those with function keys

Function Keys/Hot keys

10 functions/2 hotkeys (available on some models)

Settings Groups

4 (2)

Fault Records

15 (5)

Event Records

up to 1024

Disturbance Records

75 s max

Programmable Logic

Fully programmable

IRIG B

Option

LCD Display

Alphanumeric

Front Port (RS 232)

Yes

Rear Port

Yes, 2nd rear port option

Courier

K-Bus/ EIA(RS) 485 or fibre (some models only)

Modbus

EIA(RS) 485 or fibre (some models only)

IEC 60870-5-103

EIA(RS) 485 or fibre (some models only)

DNP3.0

EIA(RS) 485 or fibre (some models only)

IEC 61850

Available on most models

Terminals

Ring

Substation Automation Solutions | MiCOM Alstom P40

Extended temperature range operation In addition to the standard -25oC to +55oC operating temperatures claim as per IEC 60255-6, the P40 range has proven withstand capability at extremes of temperature as per IEC 600682. These onerous tests were passed at -40oC and +85oC for 96 continuous hours in each case.

Application tips P141 - for cable feeders and overhead line circuits without reclosing ■■ P142 - for radial overhead line circuits employing reclosing ■■ P143 - used where reclosing is used with check synchronism, or in applications where the larger case width is required to accommodate a larger binary I/O count ■■ P145 - used where F-keys assist engineering of the scheme ■■

Nominal Voltage Vx Px40

DC

AC

24-48

19-65

-

48-125

37-150

24-110

110-250

87-300

80-265

Overcurrent and feeder management relays Device CT inputs

Px40

24/27, 30/34, 48/54, 110/125 and 220/250 (software selectable)

P142

P143

P145

5

5

5

VT inputs

3

3

3/4

3/4

Opto inputs (max)1

8

16

32

32 32

Output contacts (max)1

7

15

30

Function keys/Hotkeys

2

2

2

12

Interlocking logic

x

x

x

x

Protection Autoreclose

79

-

x

x

x

Check synchronising

25

-

-

x

x

3 Phase overcurrent

50/51P

x

x

x

x

Ground fault

50/51N

x

x

x

x

Phase directional

67P

x

x

x

x

Ground fault directional

67N

x

x

x

x

Sensitive directional Earth fault

67N

x

x

x

x

Wattmetric Earth Fault

67W

x

x

x

x

Neutral Admittance

YN

x

x

x

x

Restricted Earth fault

64

x

x

x

x

Voltage dependent overcurrent

51V

x

x

x

x

Negative sequence overcurrent

46

x

x

x

x

Thermal overload

49

x

x

x

x

Undercurrent

37

x

x

x

x

Over/Under Voltage

27/59

x

x

x

x

Residual overvoltage

59N

x

x

x

x

Negative sequence overvoltage

47

x

x

x

x

Over/Under Frequency

810/U

x

x

x

x

Rate of Change of Frequency

87R

x

x

x

x

Lock-out

86

x

x

x

x

Directional power

32

x

x

x

x

Circuit-breaker failure

50BF

x

x

x

x

Broken conductor

46BC

x

x

x

x

Voltage Transformer Supervision

VTS

x

x

x

x

Current Transformer Supervision

CTS

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

Cold load pick-up Inrush Blocking

Auxiliary Voltage Vmin/Vmax thresholds

P141 5

Switch On To Fault

SOTF

Circuit-breaker monitoring Trip Circuit Supervision InterMiCOM

TCS

1: Please note that some relays may have a limit on max. I/0 when used as a combination

189

Motor and generator management relays P241

P242

P243

P341

P342

P343

P344

P345

P346

CT inputs

Device

4

4

7

4

5

8

8

9

8

VT inputs

3

3

3

4

4

4

5

6

4

Opto inputs (max)1

8

16

16

16

24

32

32

32

32

Output contacts (max)1

7

16

16

15

24

32

32

32

32

RTDs(option)

10

10

10

-

10

10

10

10

10

Analogue I/O(option)

4/4

4/4

4/4

4/4

4/4

4/4

4/4

4/4

4/4

Function Keys/Hotkeys

x

x

x

x

x

x

x

x

x

Interlocking logic

x

x

x

x

x

x

x

x

x

x

x

Protection Motor Protection Short circuit

50/51

Motor differential

87M

x

Locked rotor

50S/51LR/51S

x

x

x

-

-

-

-

-

-

Reverse power

32R

x

x

x

-

-

-

-

-

-

Reacceleration/LV ride-through/ Autorestart

27LV

x

x

x

-

-

-

-

-

-

Startup monitoring/Excessive long start

66/48/51

x

x

x

-

-

-

-

-

-

Negative sequence overvoltage

47

x

x

x

-

-

-

-

-

-

Out of step

55

x

x

x

-

-

-

-

-

-

Loss of load

37

x

x

x

-

-

-

-

-

-

Undercurrent

37P/37N

x

x

x

-

-

-

-

-

-

Unbalance/Lock-out

30/46/86

x

x

x

-

-

-

-

-

-

Speed switch inputs

14

x

x

x

-

-

-

-

-

-

Anti backspin

27ABS

x

x

x

Generator/Transformer differential

87G/T

-

-

-

-

-

x

x

x

x

Check synchronising

25

-

-

-

-

x

x

x

x

x

Interturn/split phase

50DT

-

-

-

-

-

x

x

x

x

Underimpedance

21

-

-

-

-

x

x

x

x

x

Pole slipping

78

-

-

-

-

-

x

x

x

-

Directional power

32

-

-

-

x

x

x

x

x

x

Loss of field

40

x

x

x

-

x

x

x

x

x

Restricted earthfault

64

-

-

-

x

x

x

x

x

x

100% stator earth fault(3rd harmonic)

27TN/59TN

-

-

-

-

-

x

x

x

-

100% stator earth fault(Low Freq. Injection)

64S

-

-

-

-

-

-

-

x

-

Overfluxing

24

-

-

-

-

x

x

x

x

x

Unintentional energisation at standstill

50/27

-

-

-

-

x

x

x

x

-

Voltage dependent O/C

51V

-

-

-

-

x

x

x

x

x

Rotor earth fault

64R

-

-

-

-

x

x

x

x

x

x

Generator Protection

190

Substation Automation Solutions | MiCOM Alstom P40

Motor and generator management relays continued Device

P241

P242

P243

P341

P342

P343

P344

P345

P346

Phase overcurrent

50/51P

x

x

x

x

x

x

x

x

x

Phase directional

67P

-

-

-

x

x

x

x

x

x

Ground fault

50N/51N

x

x

x

x

x

x

x

x

x

Sensitive directional earth fault

67N

x

x

x

x

x

x

x

x

x

Wattmetric earth fault

64N/32N

x

x

x

x

x

x

x

x

x

Negative sequence overcurrent

460C

x

x

x

-

x

x

x

x

x

Negative sequence thermal

46T

-

-

-

-

x

x

x

x

x

Thermal overload

38/49

x

x

x

x

x

x

x

x

x

Under/Over voltage

27/59

x

x

x

x

x

x

x

x

x

Residual overvoltage

59N

x

x

x

x

x

x

x

x

x

Negative sequence overvoltage

47

x

x

x

x

x

x

x

x

x

Under frequency

81U

x

x

x

x

x

x

x

x

x

Over frequency

81O

-

-

-

x

x

x

x

x

x

Turbine abnormal frequency

81AB

-

-

-

-

x

x

x

x

x

Voltage vector shift

dV

-

-

-

x

-

-

-

-

-

Rate of change of frequency

81R

-

-

-

x

x

x

x

x

x

Circuit-breaker fail and monitoring

50BF

x

x

x

x

x

x

x

x

x

Loss of life/Thru fault monitor

LoL/Thru

-

-

-

x

x

x

x

x

x

Dynamic line rating

49DLR

-

-

-

x

-

-

-

-

-

Trip circuit supervision

TCS

x

x

x

x

x

x

x

x

x

Protection Ancillary Functions

1: Please note that some relays may have a limit on max. I/0 when used as a combination

Application tips P241 - for small/medium motors where the scheme requires only a small binary I/Ocount ■■ P242 - used in applications where the larger case width is required to accommodate a larger binary I/O count ■■ P243 – for motor applications requiring differential protection ■■ P341 - used at a grid main interface to a local network having embedded generation ■■ P342 – for smaller generators not requiring per phase differential protection ■■ P343 – the standard choice for large generator protection ■■ P345 – for large generators, where the customer requires 100% stator earth fault by low frequency injection ■■ P346 – for smaller generators requiring differential protection ■■

191

Application tips

Distance and phasor measurement Device CT inputs

P441 P442

P443 P444 P445

P446 P847

4

4

8

4

4

4

3/12

VT inputs

4

4

4

4

4

5

3

Opto inputs (max)1

8

16

32

24

16

24

24

Output contacts (max)1

14

21

32

46

16

32

24

Function Keys/Hotkeys

x

x

x

x

x

x

x

Protection Distance protection

21/21N

x

x

x

x

x

x

-

- Phase Mho/Quad

21P

-/x

-/x

x/x

-/x

x/-

x/x

-

- Ground Mho/Quad

21G

- Autoreclose

79

- Power swing blocking

78

3 pole 1/3 pole

-/x

-/x

x/x

-/x

x/x

x/x

-

x

-

-

-

x

-

-

-

x

x

x

-

2

-

x

x

x

x

x

x

-

- Out-of-step tripping

68

-

-

x

-

-

x

-

- Check synchronising

25

x

x

x

x

x

2

-

- Switch on to Fault

50/27

- Mutual compensation Phasor Measurement

PMU

x

x

x

x

x

x

-

x

x

x

x

-

x

-

-

-

-

-

-

-

x

P441 and P445 – for smaller device size and optimum functionality for subtransmission and distribution ■■ P442 and P444 – distance relay for transmission applications ■■ P443 – distance relay with subcycle tripping for fastest fault clearance ■■ P446 – for subcycle tripping applications with dual circuitbreaker topologies (eg. breaker and a half) ■■ P847 – for phasor measurement applications ■■

Ancillary functions Phase overcurrent

50/51P

x

x

x

x

x

x

x

Phase directional

50BF

x

x

x

x

x

x

x

Delta directional Comparsion

ΔI/ΔV

-

-

x

-

-

x

-

Ground fault

50/51N

x

x

x

x

x

x

x

Ground fault directional

67N

Negative sequence overcurrent 46

x

x

x

x

x

x

x

x

x

x

x

x

x

x

Directional negative sequence

46/67

x

x

x

x

x

x

x

Thermal overload

49

x

x

x

x

x

x

x

Under/Over voltage

27/59

x

x

x

x

x

x

x

Redsidual over voltage

59N

x

x

x

x

x

x

x

Under/Over frequency

81U/O

-

x

x

x

x

x

x

Rate of change of frequency

81R

-

-

x

-

x

x

x

Circuit-breaker Failure

50BF

x

x

x

x

x

2

x

Broken Conductor

46BC

x

x

x

x

x

x

x

Stub Bus Protection

50ST

x

x

x

x

x

x

x

Voltage/Current Transformer Supervision

VTS/CTS

x

x

x

x

x

x

x

Capacitive Voltage Transformer Supervision

CVTS

x

x

-

x

-

-

-

Channel Aided Scheme Logic

85

x

x

x

x

x

x

-

Trip Circuit Supervision

TCS

x

x

x

x

x

x

x

InterMiCOM

46BC

-

x

x

x

x

x

-

192

1: Please note that some relays may have a limit on max. I/O when used as a combination. 2: Denotes functionality for two circuit-breakers per line

Substation Automation Solutions | MiCOM Alstom P40

Line differential, transformer and busbar protection relays Device CT inputs

P541 P542 P543 P544 P545 P546 P547 P642 P643 P645

P741 P742 P743 P746

P747

4

4

18

4

5

8

5

8

4

8

12

18

4

4

18

VT inputs (max)

-

-

4

5

4

5

4

1

4

4

-

-

-

3

3

Opto inputs (max)1

8

16

16

16

32

24

8

12

24

24

8

16

24

40

48

Output contacts (max)1

7

14

14

14

32

32

8

12

24

24

8

8

21

32

32

Analogue I/O (option) 1

-

-

-

-

-

-

-

4/4

4/4

4/4

-

-

-

-

-

RTDs (option) 1

-

-

-

-

-

-

-

10

10

10

-

-

-

-

-

Function Keys/Hotkeys

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

Interlocking Logic

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

-

-

-

-

-

-

-

-

-

Protection Line differential - 2 terminal

87P

- Neutral differential

87N

- 2/3 terminal - FO signalling

-

-

x

x

x

x

-

-

-

-

-

-

-

-

-

x

x

x

x

x

x

-

-

-

-

-

-

-

-

-

x

x

x

x

x

x

-

-

-

-

-

-

-

-

-

- SDH/Sonet networks

78

-

-

x

x

x

x

-

-

-

-

-

-

-

-

-

- In-zone transformer

68

x

x

x

-

x

-

-

-

-

-

-

-

-

-

-

x

x

x

-

x

-

-

-

-

-

-

-

-

-

-

- 2nd harmonic restraint

x

x

x

-

x

-

-

-

-

-

-

-

-

-

-

2 breaker configuration

- Vector compensation

50/27

-

-

-

x

-

x

-

-

-

-

-

-

-

-

-

- Direct/permissive intertripping

x

x

x

x

x

x

-

-

-

-

-

-

-

-

-

Phase comparison

87PC

-

-

-

-

-

-

x

-

-

-

-

-

-

-

-

- PLC signalling

0

-

-

-

-

-

-

x

-

-

-

-

-

-

-

-

Transformer Differential

87T

-

-

-

-

-

-

-

x

x

x

-

-

-

-

-

- Windings/Bias inputs

0

-

-

-

-

-

-

-

2

3

5

-

-

-

-

-

Restricted Earth fault

87G/64 -

-

-

-

-

-

-

2

3

3

-

-

-

-

-

- Overfluxing/5th harmonic

0

-

-

-

-

-

-

-

x

x

x

-

-

-

-

-

- Overexcitation

24

-

-

-

-

-

-

-

x

2

2

-

-

-

-

-

- 2nd harmonic restraint

0

-

-

-

-

-

-

-

x

x

x

-

-

-

-

-

Busbar Protection

87BB

-

-

-

-

-

-

-

-

-

-

x

x

x

x

x

- Central unit feeders

0

-

-

-

-

-

-

-

-

-

-

2B

-

-

6/18

18

- Peripheral units

0

-

-

-

-

-

-

-

-

-

-

-

x

x

-

-

- Phase-segregated differential zones

87P

-

-

-

-

-

-

-

-

-

-

8

-

-

2

4

- Sensitive Earth fault differential zones

87N

-

-

-

-

-

-

-

-

-

-

6

-

-

-

-

- Check zone

87CZ

-

-

-

-

-

-

-

-

-

-

8

-

-

x

x

- CT supervision

CTS

x

x

x

x

x

x

x

x

x

x

x

x

- CT saturation immunisation

0

-

-

-

-

-

-

-

-

-

-

-

x

x

x

x

- Fibre optic signalling

0

-

-

-

-

-

-

-

-

-

-

x

x

x

-

-

Continued on next page...

193

Line differential, transformer and busbar protection relays (...continued) Device

P541

P542

P543 P544 P545 P546 P547 P642 P643 P645 P741 P742 P743 P746

P747

Ancillary Functions Phase Overcurrent

50/51P

x

x

x

x

x

x

x

x

x

x

-

x

x

x

x

Phase Directional

67P

-

-

x

x

x

x

x

-

x

x

-

-

-

-

x

Ground Fault

50/51N x

x

x

x

x

x

x

x

x

x

-

x

x

x

Ground Fault Directional

67N

-

x

x

x

x

x

-

x

x

-

-

-

-

-

CT Supervision/ Differential CTS

CTS

-

-

x

x

x

x

x

x

x

x

x

x

x

x

x

Sensitive Directional Earth Fault

67N

-

-

x

x

x

x

x

-

-

-

-

-

-

-

-

Wattmetric Earth Fault

64W

x

x

x

-

x

-

-

-

-

-

-

-

-

-

-

Distance Protection

21

-

-

x

x

x

x

x

-

-

-

-

-

-

-

-

Power Swing Blocking

78

-

-

x

x

x

x

x

-

-

-

-

-

-

-

-

Check Sync

25

-

-

x

-

x

-

x

-

-

-

-

-

-

-

-

Negative Sequence Overcurrent

46

-

-

x

x

x

x

x

x

x

x

-

-

-

-

-

Thermal Overload

49

x

x

x

x

x

x

x

x

x

x

-

-

-

-

-

Loss of life and Through Fault

LOL

-

-

-

-

-

-

-

x

x

x

-

-

-

-

-

Under/Over Frequency

81U/O

-

-

x

x

x

x

x

x

x

x

-

-

-

-

-

Circuit-breaker Failure

50BF

x

x

x

2

x

2

x

2

3

5

x

x

x

6/18

18

Autoreclose

79

-

3 pole

1/3 pole

-

1/3 pole

-

-

-

-

-

-

-

-

-

-

Over/Under Voltage

27/59

-

-

x

x

x

x

-

-

x

x

-

-

-

-

x

Trip Circuit Supervision

TCS

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

1: Please note that some relays may have a limit on max. I/O when used as a combination. 2: Denotes functionality for two circuit-breakers per line

Application tips P145 – the typical high impedance busbar protection choice ■■ P541 – for cable and line differential in an economical device size for distribution ■■ P543 – the standard choice line differential for subtransmission and transmission applications ■■ P545 - used in applications where the larger case width is required to accommodate a larger binary I/O count ■■ P547 – for phase comparison line unit protection operating via power line carrier ■■ P642 – for two winding transformer differential with one set of CTs per side ■■

194

P643 – for three sets of phase CTs in a transformer differential scheme, or where 3-phase voltagebased functionality is required ■■ P645 – for transformers requiring four or five CT bias input sets to the scheme ■■ P741 – central unit in a busbar scheme typically with three or more discrete zones ■■ P742 – the typical busbar protection peripheral unit used per feeder bay ■■ P746 – for simple busbar topologies with one or two discrete protection zones ■■ P747 - centralised busbar protection for up to 18 feeders and four zones ■■

Substation Automation Solutions | MiCOM Alstom P40

Autoreclose relays P841

P842

CT inputs

Device

4/9

-

VT inputs

4/5

4

Opto inputs (max)

32

48

Output contacts (max)

32

32

Protection Breaker Failure Protection

50BF

x/2

-

- 2-stage

c

x

-

x

x

- Pole discrepancy

Typical application advice: P841 – for autoreclose, check synchronism, breaker fail and backup protection of transmission and subtransmission circuits ■■ P842 – UK-specific mesh corner reclosing device ■■

Product selector Up-to-date guidance on the best protection product can be explored within our product selector, available from: http://www.alstom.com/ grid/products-and-services/ Substation-automation-system/ protection-relays/MiCOMAlstom-product-selector/

Autoreclose

79

x/2

- Mesh corner/Single switch

78

-

x

- Check sync

25

x/2

x

-

x

- Ferroresonance suppression Voltage and Frequency Protection

50/27

- Undervoltage

27

x

-

- Overvoltage

59

x

-

- Residual overvoltage

59N

x

-

- Under/Over frequency

81U/O

x

-

- Rate of Change of Frequency (df/dt+t)

81R

x

-

- Frequency Supervised Rate of Change of Frequency (f+df/dt)

81RF

x

-

- Frequency Supervised Average Rate of Change of Frequency f+Δ f/ Δt)

81RAV

x

-

- Trip Circuit Supervision

TCS

x

x

1: Please note that some relays may have a limit on max. I/O when used as a combination. 2: Denotes functionality for two circuit-breakers per line

Device track record P14x series introduced in 1999. Worldwide application, with over 95 000 units delivered. P24x series introduced in 1999. Worldwide application, with over 14 000 units delivered. P34x series introduced in 1999. Worldwide application, with over 13 000 units delivered. P44x series introduced in 1999. Worldwide application, with over 35 000 units delivered. P54x series introduced in 1999. Worldwide application, with over 26 000 units delivered. P64x series introduced in 2009. Worldwide application, with over 4600 units delivered. P74x series introduced in 2002. Worldwide application, with over 2100 schemes delivered.

195

Substation Automation Solutions | MiCOM Alstom P40

196

Substation Automation Solutions | P847 PMU

Fact sheet – SUBSTATION AUTOMATION SOLUTIONS

MiCOM Alstom P847

Phasor measurement unit MiCOM Alstom Phasor Measurement Units (PMU) provide high quality, synchronised measurements of key power system quantities.

Customer benefits Measures accurate, time synchronised power system data Communicates synchrophasors according to IEEE C37.118 ■■ Available with ancillary protection, control and recording functions ■■ Galvanic, fibre optic and redundant communication options ■■ ■■

197

Stability and thermal limits, voltage collapse and loop flows are constraints that electrical power system planners and operators continually have to deal with. With today’s stretched systems, often having minimal reserve, cascading events, such as the loss of generator units or transmission lines, can easily lead to severe power swings, voltage collapses, possible loss of synchronism and underfrequency load shedding. Real-time knowledge of system conditions and changes is at the heart of the battle to maintain security of supply. The MiCOM Alstom P847 is a product that can help in this battle by providing highly accurate, time-synchronised phasor measurements (synchrophasors) from anywhere in the system. Use the Phasor Measurement Unit (PMU) as part of a wide area monitoring and control system to assess key metrics in, or between, critical areas in the power system. High-speed transfer of key system parameters, complemented by cutting-edge visualisation tools at the control centre, enhances the system management capability.

Physical communications Galvanic or fibre optic Ethernet communication ports are provided for streaming synchrophasor data. Redundant Ethernet is available, optionally managed by the market’s fastest recovery time protocols: ‘self-healing’ ring and ‘dual homing’ star, allowing bumpless redundancy. IEC 62439 PRP and RSTP are also available, offering multi-vendor interoperability.

198

■■

■■

■■

■■

Anticipate impending system failures such as angular instability by monitoring bus angles between key generating areas Predict impending voltage instability problems by monitoring high VAR flows in the network associated with fast declines in regional voltage magnitudes Invoke system wide defence plans to ensure system stability is maintained. Improve control to prevent the risks of unnecessary islanding, damage to costly transmission equipment, unnecessary load shedding, and blackouts.

IEEE C37.118 synchrophasor communications The MiCOM P847 supports synchrophasor data transmission according to IEEE C37.118 via UDP/ IP and TCP/IP. Synchrophasors to be transmitted via IEEE C37.118 can be selected from the available set, by simply enabling or disabling them in the PMU configuration column of the menu.

Substation Automation Solutions | P847 PMU

Software tools

Event records

Software tools are available for the configuration, monitoring and analysis of multiple P847 PMUs. All PMU settings can be configured using MiCOM S1 Agile locally or remotely.

Up to 512 time-tagged event records are stored in battery backed memory.

Dynamic performance

The oscillography can record up to 12 analogue channels and 32 digital channels at a resolution of 48 samples per cycle. Disturbance records can be extracted from the relay via the remote communications and saved in the COMTRADE format.

Under dynamic system conditions the PMU needs to track system parameters very accurately and this is ensured with an advanced frequency tracking algorithm able to perform accurately even under off-nominal frequency and abnormal voltage and current conditions.

Programmable Scheme Logic (PSL) Powerful graphical logic allows the user to create customised logic schemes using logic gates, latches and timers. Inputs to the PSL can include digital inputs and programmable function keys; outputs can include programmable LEDs, user alarms and IEEE C37.118 digital data.

User Interface The front panel user interface consists of an LCD display, navigation keypad, 10 programmable function keys, fixed function LEDs and 10 programmable function LEDs.

Disturbance records

Language support The user interface and menu text are available in English, French, German and Spanish as standard. The ability to customise the menu text and alarm descriptions is also supported.

Quality Built-in (QBi) Alstom Grid’s QBi initiative has deployed a number of improvements to maximise field quality. Harsh environmental coating is applied to all circuit boards to shield them from moisture and atmospheric contamination. Transit packaging has been redesigned to ISTA standard, and the third generation of CPU processing boosts not only performance, but also reliability.

Password protection Password protection may be independently applied to the front user interface, front communications port and rear communications port. Two levels of password protection are available providing access to the controls and settings respectively.

Side view of MiCOM Alstom P847 B/C PMU

199

Related products Phasor Terminal Phasor Measurement Units (PMUs), such as the MiCOM P847, output synchronised phasor data over an Ethernet network at rates of up to 60 frames per second. This results in large amounts of data being produced that can be challenging to handle in real time when commissioning or troubleshooting an individual PMU or even a small Wide Area Monitoring System (WAMS). Phasor Terminal solves this problem; it is a software tool that provides clear visualisation and archiving of real time IEEE C37.118-2005 data. Multiple PMUs can be quickly and easily configured, connected and graphically compared using an intuitive drag-and-drop interface.

Phasor Terminal, Synchrophasor visualisation and archiving tool

Substation Phasor Data Concentrator (sPDC) In support of the MiCOM P847 PMU, a Substation Phasor Data Concentrator is available to aggregate and time-align high speed synchronised data from multiple P847s into a single data stream. The PhasorPoint sPDC offers the following functionality: Receives multiple PMU streams Phasor stream rate conversion ■■ Phasor stream time alignment ■■ Multi-rate stream outputs ■■ User defined content for stream outputs (managing data provided to third-parties) ■■ Local rolling buffer storage ■■ Data recovery for upstream archive (PhasorPoint Central PDC based systems only) ■■ Cyber-security ■■ ■■

PhasorPoint substation phasor data concentrator

200

Substation Automation Solutions | P847 PMU

Applications Synchronised phasor measurements can be transmitted by the MiCOM Alstom P847 to a PhasorPoint Phasor Data Concentrator (PDC) or other upstream application using a high speed communications link. The applications that can be deployed to utilise synchrophasor data include wide area monitoring, visualisation and alarming, post-event analysis, islanding detection and oscillatory stability management. Islanding, Resynchronisation and Blackstart (IRB) The MiCOM Alstom P847 can be applied to make synchronised measurements of key variables such as voltages, currents and phase angles at strategic busses and corridors in the transmission system. These measurements can be used by the PhasorPoint Islanding, Resynchronisation and Blackstart (IRB) application to aid the operator before, during and after an islanding event.

PhasorPoint Islanding, Resynchronisation and Blackstart (IRB)

Oscillatory Stability Management (OSM) Synchrophasor data from the MiCOM Alstom P847 can be used by the PhasorPoint Oscillatory Stability Management (OSM) application to allow power system operators to visualise and analyse real time power system dynamics. By studying the oscillatory modes of a power system this application can be used to detect and manage power system oscillations which can be a sign of system instability.

PhasorPoint Oscillatory Stability Management (OSM)

Main features Product variants Three models of the MiCOM P847 Phasor Measurement Unit are available: A, B, and C. Model A features a three-phase VT input and a three-phase CT input and provides phasor measurements of the three-phase voltages, the three-phase currents and the derived sequence components. Basic protection functions including under and over, frequency, voltage and current, and circuit-breaker monitoring are included in the P847 A. As well as the three VT inputs, Models B and C feature twelve CT inputs. The CT inputs can be configured as 4 sets of three-phase measurements or 12 independent phasor measurements. No protection functions are available in Models B & C. The functions available in each model are outlined in full in the table overleaf:

201

Substation Automation Solutions | P847 PMU

MAIN FEATURES ANSI

FEATURES

P847 A

P847 B

P847 C

PMU

Synchronised phasor measurements

-

-

-

Voltage channels

3

3

3

Current channels

3

12

12

Optocoupled logic inputs

8

16

24

Conventional output contacts

8

1A and 5A CT inputs

-

-

-

Direct access menu “Hotkeys”

-

-

-

-

-

24

Multiple password access levels

-

81U/O/R

Under/Over and rate of change of frequency

-

50/51/67

Phase overcurrent stages

-

50N/51N/67N

Earth/Ground overcurrent stages

-

51N/67N/SEF

Sensitive Earth Fault (SEF)

-

67/46

Negative sequence overcurrent

-

46BC

Broken conductor

-

49

Thermal overload

-

50BF

High speed breaker fail

-

VTS

Voltage transformer supervision

-

Fault locator

-

Event records

-

-

-

Disturbance recorder

-

-

-

Circuit-breaker condition monitor

-

Graphical Programmable Scheme Logic

-

-

-

GPS time synchronisation input

-

-

-

IEEE C37.118-2005 communications

-

-

-

-

-

SOE

PSL GPS

Redundant Ethernet (option)

202

Substation Automation Solutions | P40 Agile

Fact sheet – SUBSTATION AUTOMATION SOLUTIONS

P40 Agile

Feeder management IEDs The P14N non-directional feeder, P14D directional feeder and P94V voltage & frequency IEDs bring the design rigour and technology of transmission applications to the entire utility and industrial market. The footprints of both the device physical size and the lifecycle environmental impact have been minimised using state-of-the-art design, component, and process selection. Agile solutions from Alstom are ideal for new-build and retrofit alike.

Customer benefits Novel I Draw-out I Versatile Powerful logic, protection and communications ■■ Cost effective IEC 61850 and DNP3 Ethernet solution ■■ High impedance downed conductor element boosts the safety of the public and livestock ■■ Alstom’s user-centric access tool ‘S1 Agile’ used as the single PC tool for all MiCOM ■■ NERC compliant cyber security ■■ ■■

203

Agility, versatility MiCOM P40 Agile IEDs provide an integrated solution for the complete protection, control and monitoring of electrical power systems. Application for overhead lines, underground cables, busbars, breakers, transformers, reactors, distributed generation and motors is supported, right from distribution (as primary protection) to transmission voltage levels (as back-up). The IEDs are suitable for application in solidly-earthed, resistance earthed and Petersen coil systems alike.

The perfect balance: standardised and adaptable With a wide range of protection functions as standard, MiCOM P14N, P14D and P94V IEDs also offer additional pre-configured applications for smaller generators and a choice of functionality applicable to overhead lines. This allows the user to conveniently scale the application, which is then readily adapted via simple enable/disable feature selection in the configuration menu. The IEDs offer a universal wide-range power supply, universal 1A/5A CT inputs (software selectable), and universal binary inputs - the latter with programmable pickup thresholds. Harmonisation at just one ordering option is often possible, easing the task of creating standard cubicle designs and strategic spares holding. Model

Hardware Base

Intended application

P14NB

P14N

Non-directional feeder

P14NZ(1)

P14N

Non-directional feeder with HIF(2)

P14DB

P14D

Directional feeder

P14DG

P14D

Distributed generation

P14DL

P14D

Advanced directional feeder protection (with autoreclose and fault locator)

P14DZ(1)

P14D

Advanced directional feeder with HIF(2)

P94VB

P94V

Voltage and frequency

P94VP

P94V

Voltage and frequency with check synchronising

(2)

204

(1) Only with sensitive earth fault CT option HIF - high impedance (downed conductor) fault

Substation Automation Solutions | P40 Agile

P40 AGILE PROTECTION FUNCTIONAL OVERVIEW ANSI

FUNCTION

P14NB

50

Definite time overcurrent

6

50N

Neutral/Earth definite time overcurrent

4

P14NZ

P14DB

P14DG

6

6

6

6

6

4

4

4

4

4

Non-Directional

P14DL

P14DZ

51

IDMT overcurrent

3

3

3

3

3

3

51N

Neutral/Earth IDMT overcurrent

2

2

2

2

2

2

50/51SEF

Sensitive earth fault

4

4

4

4

4

4

51V

Voltage controlled overcurrent

*

*

*

*

*

*

*

50 SOTF

Switch on to fault

*

*

*

*

*

*

68

Inrush blocking

*

*

*

*

*

*

Cold load pick up

*

*

*

*

*

*

*

*

4

4

Load encroachment supervision (Load blinders) HIF

High impedance earth fault

46

Negative sequence overcurrent

*

46BC

Broken conductor

*

*

*

*

*

*

Programmable curves

4

4

4

4

4

4

4

4

P14VP

Voltage & frequency

Directional

Voltage restrained overcurrent

P14VB

* 4

4

67

Directional phase current

6

6

6

6

67N

Directional neutral current

4

4

4

4

Sensitive directional earth fault

4

4

4

4

Wattmetric earth fault

*

*

*

*

*

*

*

Blocking scheme

*

*

*

37

Undercurrent detection (low load)

*

*

*

32

Phase directional power (Forward / Reverse / Under / Over)

49

Thermal overload

*

*

*

*

*

*

50BF

CB failure

2

2

2

2

2

2

21FL

Fault locator

*

*

27

Undervoltage

3

3

3

3

3

3

59

Overvoltage

3

3

3

3

3

3

59N

Residual overvoltage

3

3

3

3

3

3

47

Negative sequence overvoltage

*

*

*

dv/dt

Rate of change of voltage

79

Autoreclose (number of shots)

4

*

*

*

2

2

2

*

*

4

4

4

4

* 4

205

P40 AGILE PROTECTION FUNCTIONAL OVERVIEW (...continued) ANSI

FUNCTION

25

Check synchronising

81O

Overfrequency

81U 81V

P14NB

P14NZ

P14DB

Non-Directional

P14DG

P14DL

P14DZ

P14VB

P14VP

Voltage & frequency

Directional *

*

*

9

9

9

9

9

9

Underfrequency

9

9

9

9

9

9

Undervoltage blocking of frequency protection

*

*

*

*

*

*

81df/dt 81Rf 81RAV

Rate of change of frequency, with optional frequency supervision and averaging

9

9

9

9

9

9

81R

Frequency restoration

9

9

64N

Restricted earth fault

*

*

87B

High impedance busbar

*

*

PSL

Programmable scheme logic

*

*

86

Latching output contacts (Lockout)

*

*

VTS CTS

*

9

*

*

*

*

*

*

*

*

*

*

*

*

*

*

VT supervision

*

*

*

*

CT supervision

*

*

*

*

*

*

*

*

*

*

4

4

DC supply supervision

*

*

CB condition monitoring

*

*

*

*

*

*

Setting groups

4

4

4

4

4

4

The numbers in the table denote the number of elements or stages available

Intuitive User Interfaces The front-panel interface (shown in Figure 1) allows direct IED interaction. A USB front port offers enhanced access by laptop computers. Integrated user function keys and tri-colour programmable LEDs provide a cost effective solution for control and annunciation. Numerous, optional, modern communication protocols, including IEC 61850, ensure interfacing to upper-level Supervisory, Control, Automation or Data Acquisition systems.

206

Figure 1 P40 Agile front panel interface

Substation Automation Solutions | P40 Agile

Environmental responsibility The IEDs are manufactured in a lead-free soldering process using lead-free components. Power dissipation is the lowest among comparable products, easing concern on station batteries. Even the product weight (including packaging) has been optimised to lessen the transit carbon footprint. All such actions boost the eco-responsibility demonstrated in the Product Environment Profile (PEP). The product does not require any resident battery. The PEP shows claims for raw material depletion, energy depletion, water depletion, global warming potential, ozone depletion, photochemical ozone creation, air acidification, and hazardous waste pollution.

Quality Buit-In Quality Built-In methodology is applied throughout the development and manufacturing of the IEDs. Parts stress analysis in R&D, rigorous component supplier selection, and a shipping carton compliant with ISTA protection requirements are all examples of best-practice to maximise long-life reliability. All circuit boards have harsh environmental coating, to resist moisture, salt, corrosive atmosphere and industrial ambient pollution - as standard. Circuit board production uses in-circuit tests, boundary scanning, built-in self test, automated optical inspection, and X-ray scanning to achieve maximum test coverage. Figure 2 depicts the software scalability of models, within the overall superset of the range functionality. The strong P40 family identity offers high customer familiarity, with minimal training requirements.

Cyber-security The sophistication of protection schemes, coupled with the advancements of technology, increasingly leads to devices and substations being interconnected with open networks, such as the internet or corporate-wide networks. This introduces a potential security risk making the grid vulnerable to cyber-attack, which could in turn lead to electrical outage. To secure communication within such environments, MiCOM P14N, P14D and P94V offer NERC-compliant cyber security.

Asset life extension In addition to new-build, P40 Agile IEDs can be used to refurbish legacy protection schemes. As MiCOM P14N and P14D are pin-to-pin compatible with KCGG14x and KCEG14x respectively, they can simply be plugged-in to the K relay cases for an easy upgrade. This draw-out and substitute strategy dramatically reduces the refurbishment time and cost. Figure 2 P40 Agile application scalability

207

Hardware All models offer: Space-saving 4U height and 20TE (4”) or 30TE (6”) case sizes ■■ A front USB port and a rear RS485 port ■■ Power-up diagnostics and continuous self-monitoring ■■ 8 opto-isolated binary inputs, and 8 output relays ■■ N/O (form A) and N/C (form B) watchdog contacts ■■

208

Figure 3 Example P40 Agile standard hardware (P14D)

Substation Automation Solutions | P40 Agile

HARDWARE OVERVIEW FUNCTIONS

P14NB

Trip circuit supervision

Option

P14NZ

P14DB

P14DG

Option

Option

Non-Directional

P14DZ

Option

P14VB

P14VP

Voltage & frequency

Directional

Option

Rear communications port

P14DL

Option

RS485, Fibre optic, or Ethernet

RS485

RS485

2nd Rear port hardware options

RS485

RS485

RS485

RS485

RS485

RS485

RS485

RS485

IRIG-B hardware options

Option

Option

Option

Option

Option

Option

Option

Option

Communication protocols

IEC-103, IEC 61850, Modbus, Courier, DNP3, or DNP3 Ethernet

Digital inputs min./max. hardware options

8/13

8/13

8/13

8/13

8/13

8/13

8

8

Output relays min./max. hardware options

8/12

8/12

8/12

8/12

8/12

8/12

8

8

3ph + N

3ph + N

3ph + N

3ph + N

3ph + N

3ph + N

4

4

4

4

4

4

CT (AC Current inputs: 1 and 5A software selectable 100/120V VT (AC voltage inputs)

IEC-103, Modbus, Courier, or DNP3

The numbers in the table denote the number of elements or stages available

Alstom Grid: Feeder device track record CDG - Forerunner of feeder developments undertaken by Alstom in Stafford since 1949 MCGG - World’s first mass-produced digital relay launched in 1984 and sold over 80,000 units. KCGG/KCEG - First fully-numerical overcurrent relay launched in 1992 and sold over 100,000 units. P14x MiCOM series introduced in 1999. Worldwide application, with over 95,000 units delivered. Addition of UCA2 protocol and Ethernet port in 2004

Addition of IEC 61850 protocol in 2004 P40 Agile tested in the ILAC-accredited automation product laboratories in Stafford

MiCOM P40 Agile: | Novel | Draw-out | Versatile 209

Substation Automation Solutions | P40 Agile

210

Substation Automation Solutions | P60 Agile

Fact sheet – SUBSTATION AUTOMATION SOLUTIONS

P60 Agile

Feeder protection P60 Agile enhances Alstom’s range of IEDs by providing a ‘One Box solution’ for protection, control and monitoring of electrical power systems.

Customer benefits Bay visibility: large HMI with configurable views One box solution: protection, control and measurements ■■ Integration into existing substation automation: choice of communication protocols ■■ High performance (1.5 ms) IEC 61850-8-1 GOOSE ■■ Low depth design for installation in switchgear LV compartment ■■ ■■

211

Compact | Multifunction | Versatile P60 Agile One Box solutions The P60 range is suitable as main or backup protection for a wide range of typical applications and covers all common power system earthing arrangements such as solid, resistive, or resonant earthing and isolated networks. The colour touch-screen HMI with provision for bay mimic display and integrated control / interlocking functions maximises the application range of the P60 family. The fully programmable nature of P60 Agile makes it an extremely versatile and cost effective solution for all switchgear applications with varied protection requirements. Alstom’s one box solution brings touch-screen technology into the substation. Switchgear control and single-line diagram presentation is achieved thanks to the full colour, graphical HMI. The P16x series comprises the P161, P162 and P163 feeder management IEDs. Each requires a shallow depth of only 90 mm behind the panel, for ease of mounting within any switchgear cabinet. High performance features include 1.5 ms GOOSE, graphical logic, colour bargraph displays, and optional motor protection. IEC 61850, Modbus, Profibus DP, CANBUS and IEC 60870-5-103 protocols are available for full system integration.

Human machine interface

The P60 Agile has a state-of-the-art HMI with intuitive and easy navigation across the full range of its features and functionality. The membrane keypad hosts up to 6 configurable function keys and eight programmable LEDs, in addition to a USB port for communication with the PC-based configuration software. The default HMI may be configured to display user preferences such as the single line diagram or load flow parameters such as voltages or currents instead of the Main Menu shown. The IED’s touchscreen along with hotkeys facilitate quick and convenient access to the whole menu system. Up to four user-defined pages are available in the home menu, with easy touch-screen navigation from one to the next. Main menu screen

212

Substation Automation Solutions | P60 Agile

Switchgear control The P60 Agile offers comprehensive switchgear control, aided by the dynamic single-line-diagram display, ON/OFF switching via the function keys and programmable bay and inter-bay interlocks. Up to five (5) switchgear elements may be switched by the P60 Agile bay control models. The single line diagram for the bay or a subset of the substation, along with relevant data such as measurements or alarms, may be generated by the user via the P60 configuration tool, aided by integrated graphical icons. Remote controls are facilitated by the relay’s SCADA communication interfaces.

Example single line diagram (SLD) display

The provision of such powerful control capacity within the relay (the “one box” concept) negates the need for external control, switches and annunciation on the panel. Equipment cost and panel engineering time is reduced. For ease of operability and security of the command, dedicated open and close push buttons are provided on the P60 Agile front panel.

Protection + Control + Measurement + Recording = One-box solution

Applications Feeder protection All models of P60 Agile provide full-featured overcurrent and earth fault protection, with six stages and a choice of definitetime or IDMT characteristics, including reset curves. Applications involving directional earth fault are covered by the P162, and the P163 provides full directional control of phase and earth fault elements in four independent stages. Harmonic stabilisation for inrush, voltage control and customisable directional characteristic boundaries all add to the versatility of the feeder protection

functions. Sensitive earth fault (SEF) applications are also covered by the P60 Agile with a choice of CTs for the neutral input. Core balance CTs may be connected for maximum sensitivity, also the neutral displacement voltage may be fed from a broken-delta VT where available. The integral multishot autoreclosing function supplements the application of feeder protection where transient faults on overhead lines are expected. Distributed generation protection The P163 relay features two-stage voltage vector

surge protection for islanding applications, with the enhanced security of supervision by load current change. Three stages of df/dt (rate of change of frequency) are also available in the P163, with the flexibility of configurable hysteresis and supervision by frequency thresholds and/or direction. The P163 also features under/ over voltage and under/over frequency protection with twelve (12) stages each and the possibility of assigning the measurement to any of the threephase VTs signals in the relay hardware on a per-stage basis, thereby securing the applications against the loss of a single VT input.

213

Dynamic grid support The P60 is designed with the need for availability of modern high voltage and medium voltage networks in mind. In the event of single or multiple short circuits in medium or high voltage networks, immediate mains decoupling of distributed generation may be allowed only under specific conditions defined by the operators. The P60 Agile includes custom functions for fault ridethrough with up to ten (10) permissible voltage dips and for reactive power direction protection, and has been KEMA certified in accordance with the requirements of the BDEW utilities’ standard, Germany.

Functional Overview Programmable Logic Control (PLC) The P60 Agile relays feature comprehensive programmable logic, with logic gates, flipflops, counters, timers and timed switches. Users can customise the logic associated with protection functions via the PLC, combining outputs from the function block, binary input signals and and inter-device signals (IEC 61850 GOOSE) in the PLC. Up to 500 logic gates can be programmed. Configuration of breaker or switchgear element control utilises similar logic capability,

214

with customisable triggering logic, interlocking and bypass features for each control action (eg: opening, closing, earthing) associated with the switchgear element. User-programmable alarm conditions can trigger on-screen customised text alarms. Each text field can be up to 40 characters, enabling alarms to be simple and explicit for maintenance/ operational personnel. Each alarm, and each entry in the event record can be colourhighlighted to correspond with the urgency, or customer classification desired. Four alternative settings groups are provided, such that P60 Agile may adapt to switched or emergency feeding scenarios. Front port setting and interrogation The USB front port provided on the P60 Agile relay is used for the configuration of settings, logic, and other downloadable data. An additional min-USB port is available at the side of the housing which provides the same functionality as the front USB port. Alternatively, setting and interrogation may be made from the menu system accessible on the front HMI. Password protection is provided, with the touch-screen providing a virtual keypad display for fast entry of the password.

Simplicity of logic programming provided by P60 Agile

Rear communications P60 Agile has 3 rear serial communications ports, operating at Baud rates up to 57.6 kbit/s. Port 1 is dedicated for MODBUS, Port 2 for IEC 60870-5-103 (optional) and Port 3 for Profibus DP (optional). IEC 61850 is available, with single port pointpoint connection, and RSTP redundant options. Accurate time synchronisation can be achieved using IRIG-B or SNTP. Fast IEC 61850 GOOSE 128 GOOSE inputs and 128 GOOSE outputs are available, offering best-in-class GOOSE performance (typically 1.5 ms response time, class P3). Overcurrent protection There are six stages of overcurrent protection provided in the P60 Agile family, with a choice of definite time, IEC Inverse or ANSI Inverse curves for time-coordinated tripping. The overcurrent protection features also include reset curves, blocking inputs and harmonic stabilisation to facilitate a variety

Substation Automation Solutions | P60 Agile

of protection schemes. The function may be directionalised in relay models with three-phase voltage inputs. Earth fault protection The earth fault protection functions in the P60 Agile include sensitive earth fault, wattmetric earth fault, neutral voltage displacement and neutral admittance protection in addition to the standard residual current based protection. All the functions have multiple stages and permit flexible scheme configuration with instantaneous (start) and timed event outputs. Voltage protection The P163 provides comprehensive overvoltage and undervoltage protection, with up to twelve stages and phasephase or phase-earth voltage as the measurand. The voltage measurement for each stage may be assigned to any of the three VT inputs in the relay for maximum flexibility.

Protection functions are conveniently referenced according to their IEEE/ANSI function number.

P60 AGILE PROTECTION FUNCTION OVERVIEW ANSI

FUNCTION

P161

P162

P163

51/51N

IDMT overcurrent/earth fault protection

*

*

*

51SEF

Sensitive earth fault

*

*

*

50/50N

Definite time overcurrent/earth fault protection

*

*

*

68

Inrush blocking

*

*

*

50BF

Breaker failure protection

*

*

*

67

Directional overcurrent protection

67N

Directional earthfault protection

*

* *

Neutral admittance

*

*

59N

Residual overvoltage

*

*

59

Overvoltage

*

27

Undervoltage

*

27T

Fault ride-through (BDEW)

*

27Q

Reactive power support (BDEW)

*

81O

Overfrequency

*

81U

Underfrequency

*

78

Vector surge

*

81R

Rate of change of Frequency (df/dt)

*

32

Power protection

79

Multishot autoreclose

25

Check synchronising

CTS

CT supervision

VTS

VT supervision

* *

*

* *

*

*

* *

74

Trip circuit monitoring

49

Thermal overload

*

*

*

32N

Wattmetric earth fault protection

*

*

*

46

Negative sequence overcurrent

*

*

*

51V

Voltage dependent overcurrent

*

*

CLP

Cold load pick-up

*

*

*

46BC

Broken conductor

*

*

*

64R

Restricted Earth Fault (REF)

*

*

*

*

215

Platform Overview The P60 Agile is designed for reliability with four powerful microprocessors and an integral cross-monitoring feature. The slim profile hardware (< 90 mm depth) makes it easy to fit into any switchgear compartment. The compact design together with the robust stainless steel housing provides rigidity, a wide operating temperature range, and maximum shock and bump capability for even the most demanding applications. The design pedigree draws from utility, industry, marine and genset installed base experience. ■■

■■

HMI Full colour touchscreen display

*

Programmable hotkeys

*

3 x status LEDs

*

8 x programmable LEDs

*

USB port

*

Communication MODBUS, RS 485/422

*

PROFIBUS DP, RS485

(O)

IEC 60870-5-103, RS485

(O)

IEC 61850 station bus

(O)

IEC 61850 station bus, RSTP redundancy

(O)

BINARY INPUTS / OUTPUTS Digital inputs, wide range

19

The innovative design of the P60 allows functions to be distributed between hardware and software implementation. For example, the eight freelyprogrammable physical LEDs can be supplemented with virtual LEDs on the LCD screen.

Relay outputs

12

Terminal blocks on the rear of the device are typically pin-type and encapsulated, for safety of personnel even when a cabinet door is even open.

ANALOGUE INPUTS Phase current inputs, 3 x 1 ph

*

Measurement class current inputs, 3 x 1 ph

(O)

Earth current input, 1 x 1 ph

(O)

Sensitive current input, 1 x 1 ph

(O)

Feeder voltage input, 1 x 3 ph

(M)

Busbar 1 voltage input, 1 x 3 ph

(M)

Busbar 2 voltage input, 1 x 3 ph

(M)

Neutral displacement voltage input, 1 x 1 ph

(M)

GENERAL Setting groups

4

Event logging

*

Alarm management

*

Disturbance recording

*

* Standard (O) Option (M) Model dependent

216

Substation Automation Solutions | P60 Agile

HARDWARE Dimension (H x W x D)

250 x 210 x 90 (mm)

Cut out

232 x 192 (mm)

Auxiliary supply

24 V DC, 80-300 V DC or 85-230 V AC

Climatic conditions

Operation -200C to + 700C Maximum -400C to + 700C

Housing

Front IP54 (IEC529) Rear IP20 (IEC529)

Measurements, recording, and post fault analysis Measurements Analogue measurement values are clearly displayed on the HMI screen. A subset of principle values may be placed alongside the single line diagram, with the full suite of measurements accessible within the menu. Real-time measurements are shown as accurate digital quantities, with a corresponding bar graph alongside. Each bar changes from green to orange and then red, annunciating normal loading, overloading and excessive loading in a way that is clearly visible by substation staff. Alternatively, voltage and current vector (polar) diagram displays may be consulted.

In addition to directly measured analogues, power, (including power factor) and energy measurements are provided for the P163. Energy measurement is accumulated in all four quadrants: kWh, kVArh, import and export. Frequency statistics track the present, maximum and minimum frequencies, in order to trend the stability of the network frequency. Operation logs count the number of operations of each switchgear device. For 3-position devices, the number of open and earthing operations are accumulated independently. High accuracy metering The P60 Agile platform offers measurement CT inputs optionally, for applications where high accuracy metering is called for. The measurement CT inputs are accurate to 0.2% for currents up to 3 in, and are intended for use in combination with an external metering class CT.

P60 Agile: full colour touch-screen technology within the substation Vector display capability of P60 Agile

217

Substation Automation Solutions | P60 Agile

Records The P60 Agile relay records up to 3000 sequence of events records in a FIFO buffer. Time-tagging is to a resolution of 1 ms. Disturbance recording stores the analogue waveforms and binary signal data to allow in-depth post-fault analysis. Typically ten disturbance records are stored. Alarm management The P60 features include extensive alarm management capability, keeping in view its role as the protection, control and measurement device for a bay. The HMI display has a configurable Alarms page, which is opened on occurance of any alarm. Alarm names may be configured by the user, along with a software LED which helps the user to recognise the alarm status - whether it is active, active and acknowledged or inactive and not acknowledged. The configuration tool allows the user to derive alarms as a combination of events available in the relay data model; up to 449 alarms may be defined, and allocated to alarm groups for efficiency.

ALSTOM GRID: FEEDER DEVICE TRACK RECORD CDG - Forerunner of feeder developments undertaken by Alstom since 1949 MCGG - World’s first mass-produced digital relay KCGG/KCEG - First fully-numerical overcurrent relay launched in 1992 and sold over 20 000 units P14x MiCOM series introduced in 1999. Worldwide application, with over 95 000 units delivered P40 Agile launched in 2012 P60 Agile brings one-box protection and control to the range

218

Substation Automation Solutions | DAPserver ™

Fact sheet – SUBSTATION AUTOMATION SOLUTIONS

DAPserver

TM

Digital Automation Platform The DAPserver™ is a versatile and scalable multi-function solution designed for electric power substations and industrial power systems. It is a reliable and efficient system that enables the integration of field devices, unification of substation data, interfaces with enterprise applications and secures delivery of substation information to utility users. DAPserver™ also provides a truly open migration platform for upgrading legacy RTU-based systems. It will keep the user informed on what is happening – or not happening – at every point on your network nodes and facilitate effective decision making and quick action to keep the power system operating smoothly.

Customer benefits Improves system availability and reliability Improves system security and risk management ■■ Enables effective decision making ■■ Consolidates substation data and information ■■ Provides role-based visualisation for technical and management staff ■■ Complements SCADA host with detailed information ■■ Eliminates hardwired annunciator panels ■■ Reduces dependency on expensive mimic control panels ■■ Improves staff safety in substation work ■■ Reduces unnecessary travel to sites ■■ Enables condition-based maintenance and asset management ■■ ■■

219

DAPserverTM – product features and functionality The DAPserver™ provides: Power PC substation hardened hardware platforms: ■■ DAPmini™, DAP-100, DP-300 ■■ Ruggedised substation hardware platforms: ■■ eg. DAP-AT (Advantech UNO) ■■ Embedded Linux Operating System ■■ Real-time and SQL database ■■ Fanless CPU and no rotational or moving machine parts ■■ A hardware watchdog and components for online diagnosis and self-restarting ■■ Built-in real-time database to support the distribution of data for multiple users through serial and/or TCP/IP network ■■ Provides network security and manages network application services (i.e. SSH/SSL/TLS, IPsec, SFTP, Firewall, and Routing functions) ■■ Comprehensive redundant architecture: ■■ Redundant server – failover switching between primary and backup server ■■ Redundant communication – failover switching between communication channels ■■ Redundant power supply – available on specific hardware platform ■■

HMI The DAPview embedded HMI provides users with measurements, indications, alarm management, trending, condition monitoring and control at substation site or from a remote location using a Web browser. It also allows users to view and control other remote sites from a local site. Programmable Logic Control The DAPlogic module provides soft logic programming application. It can perform programmable logic control in user-defined automation application on a event-driven or periodic basis. An optional software module for IEC 61131 is also supported.

220

Protocol Analyser The DAPstudio software utility provides a protocol analyser feature in which communication between remote devices and the server may be analysed. The DAPserver™ protocol analyser provides a command line interface through which messages can be sent to debug the communication channel. The protocol analyser displays and interprets filtered messages that contain timing and other relevant information. It also facilitates effective communication monitoring between devices. Device Library Device templates are full function definitions including the communication protocol and point mapping of IEDs. DAPStudio is delivered preloaded with a set of commonly used device templates. Users can create additional device templates or modify existing ones.

Substation Automation Solutions | DAPserver ™

How does DAPserverTM fit into utility operations? 1. Substation HMI (HMI) Graphical User Interface, Single Line Diagram, Annunication 2. Substation Security Gateway (SSG) Facilitates secure remote access to meet NERC CIP requirements 3. IEC 61850 Gateway (ICG) Facilitates mapping of 61850 data objects to protocols such as DNP and IEC 60870-5-104 4. Substation Data Gateway (SDG)/Substation Server (SS) Multi-function server including including data concentration, IED integration, protocol conversion, serial to IP conversion 5. DAPmini A substation server which is custom-designed for upgrading legacy D20/D200-type RTUs.

221

Substation Automation Solutions | DAPserver ™

The DAPserverTM product family Software Applications DAPcore™ - IED integration and protocol conversion software ■■ DAPview™ - substation HMI software with remote access capability ■■ DAPguard™ - cyber security software to secure remote access to legacy and new substation devices ■■ DAPgateway™ - IEC 61850 protocol conversion software for mapping IEC 61850 data objects to standard protocols ■■

Hardware Platforms ■■ DAPmini™ - plug-in module for D20 RTU upgrade ■■ DAP-100 - rugged substation server ■■ DAP-300 - multiple processor system The ASAT DAPserver™ product line is designed for electric power substation and industrial power systems. DAPserver™ has the FLEXIBILITY to build a RELIABLE, SCALABLE and VERSATILE system to meet your substation automation needs.

Retrofit Substation Legacy IED integration ■■ Serial-to-IP conversion ■■ Protocol conversion ■■ Integrated HMI function ■■ Substation cyber security ■■

New Substation ■■ Multi-vendor IED integration ■■ IEC 61850 IED integration ■■ User-friendly configuration tools ■■ Substation HMI ■■ Substation cyber security Asset Management ■■ IED and sensor integration ■■ Secure connectivity from substation devices to enterprise applications ■■ Online condition monitoring ■■ Turning data into actionable information

DAPmini ™

DAP-100

DAP-300

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How does the DAP substation server fit into your utility’s operation?

Substation Cyber Security ■■ NERC CIP features ■■ Authentication- User credential ■■ Authorisation - Multi-level access privileges ■■ Audit Trail - Security Event Log ■■ Secure tunnelling to IED ■■ Encrypted data communication

Substation Automation Solutions | Protection

Fact sheet – SUBSTATION AUTOMATION SOLUTIONS

MiCOM S1 Agile Graphical, universal, intuitive

MiCOM S1 Agile is the truly universal IED engineering toolsuite. No-longer are separate tools required for redundant Ethernet configuration, phasor measurement unit commissioning, busbar scheme operational dashboards, programmable curve profiles or automatic disturbance record extraction – all applications are embedded. Customer benefits Configuration file creation and management, following the substation topology ■■ Ethernet and IEC 61850 configuration, including SCL import and export ■■ Programmable logic, menu text and IDMT curve profiles ■■ Settings conversion to the new MiCOM P40 Agile IEDs ■■ Event and disturbance record extraction and viewing ■■ Embedded product selector ■■ Full successor to MiCOM S1 Studio ■■ Zero or minimal training to move from S1 Studio to S1 Agile ■■

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Redefining the engineering toolsuite for your IEDs MiCOM S1 Agile is the next step enhancement from MiCOM S1 Studio, encompassing all of its functionality plus new tools and features, to become the complete successor. It underlines Alstom’s R&D investment in usability: assembling all tools in a palette for simple entry, with intuitive navigation via fewer mouse-clicks. MiCOM S1 Agile supports all existing MiCOM ranges, K-Series and Modulex, including a utility for automatic conversion of setting files from previous generations of numerical relays like K-series and MiCOM P20 to the latest P40 Agile models. MiCOM S1 Agile will automatically import your datamodels and configured systems/projects from Studio and all files remain backward-compatible. S1 Agile offers a fresh new look - functions and components are presented as “tiles” rather than menu items for more intuitive use.

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Substation Automation Solutions | Protection

Environment Operating Systems: Windows XP, Vista or Windows 7 Languages: English, French, German, Spanish, Russian, Chinese. For more information on MiCOM S1 Agile: ■■ Navigate to the homepage: www.alstom.com/grid/ms1 ■■ Register for the software: www.alstom.com/grid/micomrequest

The selector application is continually refreshed with the latest releases, from the P40 Agile overcurrent/ voltage and feeder devices to the latest digital substation-ready MiCOM Alstom P40 relays. To get the selector stand-alone, navigate to Protection Relays on the SAS homepage: www.alstom.com/grid/sas

Embedded product selector The product selector eases your choice of the right IED for each application. In synergy with MiCOM S1 Agile, the user answers a few questions to choose the latest applicable full model number, which then allows the configuration and setting workflow to continue.

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Substation Automation Solutions | Protection

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Substation Automation Solutions | DS Agile H Switches

Fact sheet – SUBSTATION AUTOMATION SOLUTIONS

DS Agile H Series Secure and reliable Ethernet switches

The H series Ethernet switches use cuttingedge redundancy protocols to offer superior automation network availability and extremely fast reconfiguration in the event of link failure.

Customer benefits Superior network availability Very fast network reconfiguration Bumpless with Dual Homing Star and Parallel Redundancy Protocol (PRP). ■■ Easy to install and configure ■■ Monitoring capabilities ■■ ■■

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Substation Automation Solutions | DS Agile H Switches

Power transmission and distribution networks worldwide depend on reliable and highly available protection and control systems. These systems in turn depend on reliable and highly available communications networks for control, data collection, automation, monitoring and much more. Alstom Grid’s H series Ethernet switches use a combination of advanced redundancy protocols and fibre-optic connections to ensure the reliability, availability and dependability of substation communications networks. All this while maintaining the flexibility of being able to be connected to standard ethernet networks - ideal for substation refurbishments or upgrades. The H series switches use either the PRP, Dual Homing Star or Self Healing Ring protocols and are available in standalone, embedded and PCI card (for integration into a PC) variants. As part of Alstom Grid’s Digital Control Systems (DCS), the H series switches are fully compatible with our protection relays, bay computers and gateways.

KEY FEATURES ■■

■■

■■

■■

■■

Architecture DS Agile’s H series is a complete portfolio of ethernet switches for all substation automation applications covering: standalone DIN-rail switches, embedded switches in protection relays and bay computers and PCI internal switches for gateways and substation PC’s. Alstom Grid’s Ethernet network architectures reduce the cost of ownership, as embedded switches in Intelligent Electronic Devices (IEDs) reduce the number of external switches required. This has the advantage of reducing the overall power burden, reducing the maintenance requirements, reducing the required number of connections, improving communications availability and reducing unwanted downtime.

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Cutting edge redundancy protocols: PRP, Dual Homing Star and Self Healing Ring Flexible connectivity: Different port variants are available - copper or fibre (single mode or multi mode) with ST, SC or LC connectors Monitoring capabilities: Set an alarm to monitor link failure using either the inbuilt watchdog relay (contact) or via communications Increased reliability: Standalone switches have redundant power supplies Ruggedised: The H series switches are designed to work in harsh environments such as electrical substations

Substation Automation Solutions

SAS conclusions The new era of intelligent Smart Grids requires more sophisticated substation automation systems which allow energy operators to provide a secure, dependable and cost effective power supply to meet increasing customer demands for higher standards of power automation. As a world leader in substation automation solutions, Alstom is at the forefront of developing systems which help energy operators optimise the design, operation and maintenance of digital substations to meet the demands of an ever-changing environment, through realtime intelligent digital networks. This interoperable and IEC 61850-compliant solution allows operators to achieve a high level of availability and enhanced reliability of substation equipment. It also provides full integration with control room network monitoring and Smart Grid applications, such as network stability, wide-area protection plans and online condition monitoring. Through advanced, expert data processing, Alstom’s DS Agile and DAPserver digital substation solutions reduce cables, improve flexibility and increase reliability by preventing failures. The range continues to grow, with cybersecurity and substation situational awareness at the heart of the technology

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Substation Automation Solutions

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Online condition monitoring

Online condition monitoring

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Online condition monitoring

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Online condition monitoring | MS 3000

Fact sheet – Online condition monitoring

MS 3000

Online condition monitoring and expert system Transformers are critical to electrical power systems. Their reliability and availability is the key to profitable power generation and transmission and continuous supervision is essential to evaluate transformer performance and safe operating conditions.

Customer benefits Decision-making support Cost-effective solution ■■ Customised solution based on standardised modules ■■ User-friendly interface ■■ ■■

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Take advantage of our experience in transformer manufacturing. Decades of dedicated expert knowledge has made us a world leader in power transformer monitoring systems.

Our commitment to your success gives you a high degree of flexibility and reliability. While focussing on user-friendly operation, the MS 3000 also provides maximal support to accurately assess your transformer - and our solution serves new and existing transformers of all makes.

A practical solution for real needs The MS 3000 offers a complete solution as a one-stop concept: Data acquisition - fast and reliable ■■ Lifetime data management – high resolution when demanded; compressed where reasonable ■■ Data analysis and condition diagnostics – reflecting a high level of expert knowledge ■■ Interface – visible quality in your own language ■■ Information distribution – a communicative team-player with upper level systems ■■

The MS 3000 is Alstom Grid’s next generation of online condition monitoring systems. As the successor of the globally recognised MS 2000 system, it combines practical experience with innovative features and high technological standards. You get more with MS 3000: An expert system ■■ A DGA tool ■■ A report generator ■■ A simulator ■■ Sophisticated modelling ■■

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State-of-the-art communication with IEC 61850 standard MS 3000 provides the most efficient solution for communications with power automation systems using the new IEC 61850 standard. This is a key factor, reducing overall configuration costs and achieving improved inter-operability, flexibility and reliability in data exchange.

Online condition monitoring | MS 3000

A comprehensive and smart solution Our philosophy: a monitoring system should integrate all transformer main components with a correlation of the analysed acquired data - even for several transformers at the same time. Our expertise provides the basis for reliable interpretation of single or multi-transformer conditions. Our Expert System with its diagnostic functions supports and enables your engineers in making the right decisions at the right time for the proper operation and maintenance of your valuable equipment. The MS 3000 saves you time, so that you can concentrate on other tasks requiring more attention.

Expert system Algorithms for analysing the online acquired data are implemented in the software and reflect our extensive experience. This sophisticated tool highlights the capacities that a state-of-the-art monitoring system should have. The Expert System software provides you with recommendations and information concerning transformer operation and service/ maintenance.

Sophisticated modelling Thermal model Aging model ■■ Tap changer model ■■ Moisture model ■■ Bushing model ■■ Overload model ■■ Cooling model ■■ ■■

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A user-friendly solution MS 3000 software Our interactive, clearly structured interface is user-friendly and easy to operate. The straightforward messaging of alarms, warnings and diagnostics proposes both a quick key data overview and a deep look inside the transformer. The implemented web server in the MS 3000 IED provides multilingual web pages which can be accessed directly by ethernet, LAN or modem connection without any proprietary software. Various password protection levels give only specific users the permission to access the data or to configure the system. The visualisation software offers a user-friendly presentation of online and historical data as well as numerous combinations of graphs and zoom possibilities. Using quick links, recommendations for preventive actions can be obtained to optimise transformer operation or to initiate maintenance.

Report generator The configurable report generator automatically creates user-friendly protocols with status information about the transformer and its main components. This protocol can be generated on command or can be periodically created and sent to a defined email address.

Simulator The built-in simulator module allows the user to simulate external or transformer events and to study the transformer’s behaviour as well as the monitoring system’s. The simulator can also be used for training site personnel and engineers.

DGA-tool Choose your preferred method to analyse the acquired dissolved gas data according to MSS, Doernenburg, Rogers, extended Rogers, IEC 60599, Duval or KeyGas methods. Also a risk classification, including interaction recommendations, will be carried out according to IEEE C57.104-1991. This tool allows you to enter and historically store your transformer-related offline DGA (Dissolved Gas Analysis) data, including Furfurol determination.

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Online condition monitoring | MS 3000

The modular and flexible solution for new and existing transformers We have the answer for the complete transformer application range: from power generation to transmission - compatible with all transformers independent of the transformer manufacturer.

Standard kits Along with the MS 3000 standard kit, a new concept has been launched. Depending on transformer design and monitoring comprehension, different modules can be adapted to a basic kit. This standardised solution covers your needs in an efficient, cost-optimised package. Main characteristics Protection class*

IP 54

Operating temperature* -40°C - +55°C Power supply

Wide range

Signalisation

Transformer condition display

Data visualisation

Web Server on monitoring IED

Monitoring module

Without moving parts

Sampling rate

20 ms

Data resolution

1 ms

Data storage

Self-compressing historical data storage --> Lifetime storage for all connected transformers

Protocol*

IEC 60870-5-101/104 / Modbus / DNP 3 / IEC 61850

Architecture

Flexible – different topologies possible

Operating system

State-of-the-art real-time operating system

* others on request

MS 3000 Standard kits: measured and analysed quantities Active Part Apparent power and load factor Oil temperature Hot-spot temperature Gas-in-oil content Moisture-in-oil content Moisture of paper Bubbling temperature and safety margin Aging rate and lifetime consumption Breakdown voltage Actual losses Overload capacity Emergency overloading time Bushings Operating voltages Overvoltages Change of capacitance, online capacitance Capacitive displacement currents Load currents Over-and short-circuit currents Tap changer On-load tap changer position Number of switching operations Sum of switched load current Power consumption of motor drive Assessment of mechanical quality Contact wear Tap changer oil temperature Oil temperature difference OLTC-tank Cooling System Operating condition of fans and pumps Operating time of fans and pumps Cooling efficiency (Rth) Ambient temperature

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Online condition monitoring | MS 3000

Additional features and measurements Fibre optic hot-spot measurements ■■ Partial discharge ■■ Bushing power factor (tan delta) ■■ Transformer power factor (cos phi) ■■ Transformer efficiency ■■ Bottom oil temperature ■■ Monitoring module temperature ■■ Moisture of OLTC oil ■■ Gas quantity and rate in Buchholz relay ■■ Oil pressure and oil pressure differences ■■ Accelerations (tank wall, OLTC) ■■

Oil level Humidity of air inside conservator ■■ Air pressure ■■ Cooling power ■■ Intake and outlet cooling equipment temperatures ■■ Differences of intake and outlet temperatures ■■ AVR ■■ Control of cooling equipment ■■ Digital status information, etc. ■■ Others on request ■■ ■■

A tribute to quality One of our key objectives in developing the next generation was to achieve the highest possible reliability levels. To do this, we used the best available technology and components such as fanless IEDs (Intelligent Electronic Devices) that operate with a redundant flash memory for life time data acquisition and storage, in line with a proven bus technology for industrial applications. The new MS 3000 provides a very reliable solution thanks to consistent project management and continuous improvement. Multilingual documentation and interfaces are part of the constant quality process.

Type tested acc. to DIN/EN 55011, EN/IEC 61000, EN/IEC 60068, EN/IEC 61010 Electromagnetic disturbance tests Temperature and climate tests ■■ Electromagnetic immunity tests ■■ Safety tests ■■ KEMA IEC 61850 Certificate ■■ ■■

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Reference projects

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Reference Project

With multiple reference sites in different countries, Alstom Grid has been involved in the development of the various components of the digital substation for many years. We have gained precious experience in our IEC 61850 pilot projects that puts us in a strong position to meet the demands of utilities for instantaneous operability and backward compatibility of multi-vendor equipment.

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India

GETCO (India), Jambua AIS Substation 245 kV COSI-CT based on optical sensor technology (Faraday effect), connected to the merging unit and interfaced digitally with Alstom Grid distance protection by IEC 61850-9-2 process bus.

Reference Projects

Reference Project

With multiple reference sites in different countries, Alstom Grid has been involved in the development of the various components of the digital substation for many years. We have gained precious experience in our IEC 61850 pilot projects that puts us in a strong position to meet the demands of utilities for instantaneous operability and backward compatibility of multi-vendor equipment.

FRANCE

RTE (France), Saumade - 245 kV GIS substation with hybrid sensors, MU and distance protection DIT based on Rogowski coils and capacitors, connected to the merging unit and interfacing digitally with distance protection relays provided by Alstom Grid and a third party.

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Reference Project

With multiple reference sites in different countries, Alstom Grid has been involved in the development of the various components of the digital substation for many years. We have gained precious experience in our IEC 61850 pilot projects that puts us in a strong position to meet the demands of utilities for instantaneous operability and backward compatibility of multi-vendor equipment.

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RUSSia

Federal Grid Company of Unified Energy System (Russia), Nadezhda - 110 kV double-bus and 220 kV breaker and a half substation Supply of process bus protection relays and bay controllers, digital control systems, CCS panels, merging units and engineering.

Reference Projects

Reference Project The cables are over 20km in length, and the operational demands are such that autoreclosing is required for faults on the overhead lines, but not for faults within the underground cable sections. The differential protection is thus used for fast and precise detection of faults within the cables. The undersea cables run from stations on the Jutland mainland, on to Funen island and then onwards to Zealand. The equipment supply includes 72 optical CT units, 24 merging units and 24 line differential relays which subscribe to the sampled values in a process bus protection scheme. The principal reason for selecting to use non-conventional

DENMARK

Energinet, Denmark – Digital Current Measurement and Protection One current application is on Energinet’s transmission system, in a differential protection application. The protected circuits are hybrid lines, consisting of 400kV lines, and cabled portions laid sub-sea.

instrument transformers was due to their low mass and slimline construction. In the Energinet substations, the optical CTs are mounted on the same support structures as the cable bushings themselves. A single structure and foundation per phase carries the larger mass of the cable, plus the optical CT support on a cantilever frame.

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Grid-Sector-L4-DS_Sales_Handbook-2910-2013_05-EN © ALSTOM 2012. All rights reserved. Information contained in this document is indicative only. No representation or warranty is given or should be relied on that it is complete or correct or will apply to any particular project. This will depend on the technical and commercial circumstances. It is provided without liability and is subject to change without notice. Reproduction, use or disclosure to third parties, without express written authority, is strictly prohibited.

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