Generator Protection

Bapuji S Palki, INCRC/PowerTechnologies, 15-11-2009

Protection Application – An Overview Part 2A © ABB Group October 10, 2011 | Slide 1

© ABB Group October 10, 2011 | Slide 2

Layouts

Typical Parts of a Power Plant Substation

Busbar in Substation HV - Breaker Power plant Main Transformer

Auxiliary Transformer

Generator Breaker Excitation Transformer Excitation System

Turbine valve Turbine - Generator

Earthing System

G

Field Circuit Breaker

Generator Protection

Possible Faults


Stator Earth Faults




Rotor Earth Faults




Stator Short Circuits




Stator/Rotor Interturn faults




External faults

Generator Protection

Abnormal Operating Condition


overcurrent/overload




unbalanced load




overtemperature




over- and undervoltage




over- and underexcitation




over- and underfrequency




over-fluxing




asynchronous running




out of step




generator motoring




failures in the machine control system (i.e. AVR or governor failure)




failures in the machine cooling system




failures in the primary equipment (i.e. breaker head flashover)




open phase

• Following are the various protections recommended for the generator and generator transformer protection:

Type of fault GENERATOR STATOR Short Circuits

Asymmetry Stator overload Earth fault stator

© ABB Group October 10, 2011 | Slide 6

ANSI Device Protection Functions No.

87G 87GT 21G 51 / 27 G 46G 51G 64G1 64G2

Generator differential Overall differential Minimum impedance (or alternatively Over current / under voltage) Negative sequence Overload 95% stator earth fault 100% stator earth fault

Loss of excitation Out of step Monitoring

40G 98G 32G / 37G

Blade fatigue Inter turn fault Mag. Circuits Higher voltage Accidental energisation Monitoring

81G 95G 99G 59G 27 / 50 G

© ABB Group October 10, 2011 | Slide 7

60 G

Loss of excitation Pole slip Low forward power / reverse power (double protection for large generators) Minimum frequency Over voltage or over current Overfluxing volt / Hz Over voltage Dead machine PT fuse failure

GENERATOR ROTOR Rotor ground GENERATOR TRANSFORMER Short Circuits

Ground fault Overhang UNIT AUXILIARY TRANSFORMER Short circuit Ground fault

© ABB Group October 10, 2011 | Slide 8

64F

Rotor earth fault

87GT 51GT 87T 51NGT 87NT 87HV

Overall differential Overcurrent Transformer differential Earth fault over-current Restricted earth fault HV winding cum overhang differential

87 UAT 51 UAT 51 UAT 64 UAT

Transformer differential Over-current Restricted over-current Restricted earth fault

50/51 Unit aux. transformer

64F Field winding ground-fault RAGRA (RXNB4) 1) Instruments

© ABB Group October 10, 2011 | Slide 9

Protection and Monitoring

REG 670 – Different applications REG 670 provides extensive protection and monitoring functionality

1ph U

3ph U

3ph I




The REG 670 provides protection functions and concepts for:


Turbine (frequency, reverse power)




Generator (Main1/Main2, Main/Back-up)




Generator transformer/Step-up transformer




Auxiliary/Station service transformer




Excitation transformer

1ph U

G

1ph I

3ph I

1ph U

REG 670 focus on the optimized integration and function to protect your generator

IEC 61850

A Breakthrough for Substation Automation


One world




One technology




One standard

IEC 61850

“Combining the best properties in a new way...”

© ABB Group October 10, 2011 | Slide 12

Power transformers in a power system 400 kV AC Transmission

130 kV Subtransmission

Generation MV

Distribution

LV M

© ABB Group October 10, 2011 | Slide 13

315MVA Transformer

© ABB Group October 10, 2011 | Slide 14

Cooling
Outer Ci rcui t H eat D i ssi pati on

Pump opti onal

I nner Ci rcui t H eat Producti on
(Core and Wi ndi ngs)


F an opti onal

© ABB Group October 10, 2011 | Slide 15

Oi l i mmersed Tank

In principle the larger the losses in the Inner Circuit the larger the size of the Outer Circuit (coolers or radiators) There is nevertheless a limit either due to the size of the coolers or to the impossibility of cooling a certain spot (hot-spot) in the Inner Circuit A pump to move the oil is often unnecessary. The generated heat will act as a siphon

Types of Internal Faults

© ABB Group October 10, 2011 | Slide 16




Earth faults




Short-circuits




Inter turn Faults




Core Faults




Tank Faults




Reduced cooling

Abnormal Conditions

© ABB Group October 10, 2011 | Slide 17




Overload




Over voltage




Reduced system voltage




Over excitation

Overload Capability


It is possible to overload power transformers




Older transformers may withstand 140% continuously




Overloading and loss of cooling causes overheating

© ABB Group October 10, 2011 | Slide 18

Protective Relays Used ( Transformers > 5 MVA)


Gas detector relay ( Buchholz)




Over load protection


Thermal relays




Temperature monitoring relays




Over current protection




Ground fault protection




Differential protection




Interturn faults




Pressure relay for tap changer




Oil level monitor

© ABB Group October 10, 2011 | Slide 19

Protective Relays Used ( Transformers < 5 MVA)


Gas detector relay




Overload protection




Overcurrent protection




Ground fault protection

© ABB Group October 10, 2011 | Slide 20

Monitors Monitors are very important devices which detect faults and abnormal service conditions which may develop into fault.

© ABB Group October 10, 2011 | Slide 21

Transformer Monitors





Mechanical fault detectors


Sudden gas pressure protection




Buchholz protection




Oil level monitoring

Temperature Monitoring

© ABB Group October 10, 2011 | Slide 22




The oil thermometer




The winding thermometer

Transformer protection with 670/650 series

Introduction Transformer Protection 670/650 series Openness and flexibility Reliable Operation Complementary functionality Control Capabilities Communication Offering and application examples Technology Summary Relion® Summary

© ABB Group November 2009 | Slide 23




670 series – optimized for generation and transmission applications provide versatile functionality, maximum flexibility and performance to meet the highest requirements of any application in generation and transmission protection systems.




650 series – your best choice for subtransmission applications provide “off-the-shelf”, ready to use solutions for transformer protection applications primarily in subtransmission networks.

Fully compliant to the IEC 61850 standard Introduction Line Distance Protection 670/650 series Reliable Operation Complementary functionality Control Capabilities Communication Offering and application examples Technology Summary Relion® Summary

© ABB Group November 2009 | Slide 24




Unrivalled compatibility for new and retrofit installations




Designed for IEC 61850, implementing the core values of this standard




Ensures open, future-proof and flexible system architectures, with state-of-the-art performance




Interoperates with other IEC 61850 compliant IEDs

© ABB Group October 10, 2011 | Slide 25

The reactor absorbs the capacitive power generated in long lines

© ABB Group October 10, 2011 | Slide 26

Shunt Reactor

© ABB Group October 10, 2011 | Slide 27

AB C

A B C

L

R Lp Lp Lp

Ln

© ABB Group October 10, 2011 | Slide 28

General





Shunt reactors are used in EHV systems to limit the over voltages due to capacitive VAR generation in Long Transmission Lines The shunt reactors are normally connected


Through isolators to a line




Through circuit breakers to a busbar




© ABB Group October 10, 2011 | Slide 29

Through circuit breakers to the tertiary of a Interconnecting transformer

Different locations of reactor

© ABB Group October 10, 2011 | Slide 30

Internal Faults Faults occur in shunt reactors due to insulation breakdown, ageing of insulation, overheating due to over excitation, oil contamination and leakage

Dry air-core reactors





Phase-to-phase faults , resulting in high magnitude phase current




Phase-to-earth faults ,, resulting in a low-magnitude earth-fault current, dependent upon the size of the system earthing.




Turn-to-turn faults within the reactor bank, resulting in a very small change in phase current

Oil-immersed reactors


High current phase-to-phase and phase-to-earth faults.




Turn-to-turn faults within the reactor winding.




Miscellaneous failures such as loss of cooling or low oil

© ABB Group October 10, 2011 | Slide 31

Abnormal Conditions


Inrush currents





Inrush currents flow in connection with energisation Inrush currents usually lower than 200% of rated current




Transient overvoltages




Temporary overvoltages

© ABB Group October 10, 2011 | Slide 32

Shunt Reactor Protections




Differential protection




Distance protection




Phase over current protection




Restricted earth fault protection




Mechanical fault detectors




© ABB Group October 10, 2011 | Slide 33

Oil temperature and winding temperature protection

Monitors Monitors are very important devices which detect faults and abnormal service conditions which may develop into fault.

© ABB Group October 10, 2011 | Slide 34

Reactor Monitors





Mechanical fault detectors


Sudden gas pressure protection




Buchholz protection




Oil level monitoring

Temperature Monitoring

© ABB Group October 10, 2011 | Slide 35




The oil thermometer




The winding thermometer

Shunt reactor protection and control

Introduction Transformer Protection 670/650 series Openness and flexibility Reliable Operation Complementary functionality Control Capabilities Communication Offering and application examples Technology Summary Relion® Summary
















© ABB Group November 2009 | Slide 36

Protection Phase segregated biased differential protection Low impedance restricted earth-fault High impedance differential protection

Switching control for lines and buses

© ABB Group October 10, 2011 | Slide 37

Capacitor Construction

© ABB Group October 10, 2011 | Slide 38

Power PowerFactor FactorCorrection Correction Working Power (kW) Reactive Power (kVAR)




KW is the Working Power component




kVAR is the Non- Working Power or Reactive Power component to serve inductive loads, which require magnetizing current: Motors, Transformers, Lighting ballast




KVA is the Total Power required to serve a load




Capacitors supply the reactive power component




Power Factor is a measurement of how efficiently power is being used.

© ABB Group October 10, 2011 | Slide 39

Increased IncreasedSystem SystemCapacity Capacity Extra capacity for more KVA released system capacity

Total Power (KVA) = Working Power (KW) ÷ Power Factor Power Factor Real Power kW Reactive Power kVAR Total Power kVA


60% 600 800

70% 600 612

80% 600 450

90% 600 291

100% 600 Zero

1000

857

750

667

600

By supplying reactive current (kVAR) close to the load, capacitors release system capacity on the entire system and reduce costs.

© ABB Group October 10, 2011 | Slide 40

Voltage VoltageStability Stability







A feeder circuit will have a voltage drop related to the impedance of the line and the power factor Adding capacitance will actually cause a voltage rise by supplying reactive current to the bus

(less current = less voltage drop)

© ABB Group October 10, 2011 | Slide 41

Products Capacitors – HV Products / Filter Capacitor Banks

Improving the performance, quality and efficiency of electrical systems

© ABB Group October 10, 2011 | Slide 42

Capacitor banks- General


Normally used in MV networks to generate reactive power




Series reactors are used to limit inrush current




Harmonic filters for thyristor controlled reactors are also variation of capacitor banks having reactance tuned to capacitance


Shunt

Capacitors-General

Shunt Capacitor Faults


Terminal shunt faults




Capacitor unit failures




Capacitor unit over voltages




Capacitor rack arc-over

Abnormal Conditions


Inrush currents




Transient over voltages




Temporary over voltages




Out rush currents

Capacitor Bank Protections




Short -circuit protection

(3I >>)




Ground-fault protection

(I )




Overload protection(3I/U >)




Under current protection

(I/U <)




Unbalance protection

(IN-N)

Fusing Capacitor Fusing Internally Fused

Fuse

© ABB Group October 10, 2011 | Slide 48

Externally Fused

Discharge Resistor

Internal Strings

Fuseless

Conventional


SPAJ

160 C : Unbalance , Overload and Under current functions

Bapuji S Palki, INCRC/PowerTechnologies, 15-11-2009

Protection Application – An Overview Part 2B © ABB Group October 10, 2011 | Slide 50

© ABB Group October 10, 2011 | Slide 51

The Electric Utility

Power Evacuation Substation Transmission Substation Switching Substation Distribution Substation

© ABB Group October 10, 2011 | Slide 52

Transmission Line

© ABB Group October 10, 2011 | Slide 53

Electrical faults in the power system




Transmission lines

85%




Busbar

12%




Transformer/ Generator

3%

100%

© ABB Group October 10, 2011 | Slide 54

Fault types


Transient faults


are common on transmission lines, approximately 80-85%




lightnings are the most common reason










© ABB Group October 10, 2011 | Slide 55

can also be caused by birds, falling trees, swinging lines etc. will disappear after a short dead interval

Persistent faults


can be caused by a broken conductor fallen down




can be a tree falling on a line




must be located and repaired before normal service

Measuring principles

© ABB Group October 10, 2011 | Slide 56




Overcurrent protection




Differential protection




Phase comparison




Distance protection




Directional- wave protection

Overcurrent protection





Are normally used in radial networks with system voltage below 70 kV where relatively long operating time is acceptable. On transmission lines directional or nondirectional over current relays are used as back-up protections.

I>

block

© ABB Group October 10, 2011 | Slide 57

I>

I>

I>

Pilot wire differential protection



© ABB Group October 10, 2011 | Slide 58

Pilot wires can be in soil or on towers. The resistance in the wires will limit the use on longer lines. The use is mostly restricted to distances up to 10 km.

Digital differential communication L1 L2 L3

DL1 DL2 DL3

© ABB Group October 10, 2011 | Slide 59

Digital communication with optical fibres or by multiplexed channels

DL1 DL2 DL3

Phase comparison load I1 φ >




Phase comparison relays compare the angle difference between the two currents at both ends of the line.




The measured time for zero crossing is transmitted to the other end.




Normally a start criteria is added to the phase angle requirement.

I2 φ >

α I1 I2

e 1

e 2

α

e1 e -

2

I2

func- φ tion φ

I1 I2

© ABB Group October 10, 2011 | Slide 60

The principle of distance protection

ZK=Uk/Ik

Uk

Uk=0 metallic fault

Zk

A

Z< © ABB Group October 10, 2011 | Slide 61

Ik

B

Fault resistance


multi-phase faults





consist only of arc resistance

© ABB Group October 10, 2011 | Slide 62

L1

L1

L2

L2

L3

earth faults


consist of arc and tower




footing resistance

Warrington´s formula

Rarc =

L3

28707 x L 1.4

I

L= length of arc in meters I= the actual fault current in A

Footing resistance

Distance protection on short lines jX





Quadrilateral characteristic improves sensitivity for higher RF/XF ratio It still has some limitations:


RF XF

© ABB Group October 10, 2011 | Slide 63

R

the value of set RF/XF ratio is limited to 5

jX

Distance protection on long lines








Load impedance limits the reach in resistive direction High value of RF/XF ratio is generally not necessary Circular (mho) characteristic





R

© ABB Group October 10, 2011 | Slide 64

Has no strictly defined reach in resistive direction Needs limitations in resistive direction (blinder)

The principle of distance protection

t t3 t2 t1

l

A

B f 1

Z<

C f 3

f 2

Z<

Z<

Z<

t t3 t2

l © ABB Group October 10, 2011 | Slide 65

t1

The principle of distance protection


Reach setting of zones




R/ X Relation




GFC (General Fault Criterion) GFC

ZL

ZL

Zb

© ABB Group October 10, 2011 | Slide 66

PLCC equipment

© ABB Group October 10, 2011 | Slide 67

Power Swing Blocking function X Power swing locus

R ∆t

∆t = 40 ms

© ABB Group October 10, 2011 | Slide 68

Series compensated system jX

B´

A

XC =70%

100%

Xl =100%

B

F1

gape flashed

Consideration for line distance protections

B A

70%

© ABB Group October 10, 2011 | Slide 69

R

gape not flashed

• Correct direction discrim-ination at voltage reversal (negative fault reactance) • variation in resulted line impedance

Line distance protection with Relion® 670/650 series For maximum reliability of your power system
Introduction
Line

Distance Protection


670/650

series


Reliable

Operation


Complementary
functionality
Control

Capabilities




Full scheme distance protection with independent phase selection




Power swing detection




Wide range of scheme communication logics




Five zone distance protection


Communication
Offering

and


application

examples


Technology ®


Relion


Summary

© ABB Group November 2009 Slide 70

Summary




Phase to phase




Phase to earth faults

Fully compliant to the IEC 61850 standard
Introduction
Line

Distance Protection


670/650

series


Reliable

Operation


Complementary




Unrivalled compatibility for new and retrofit installations




Designed for IEC 61850, implementing the core values of this standard




Ensures open, future-proof and flexible system architectures, with state-of-the-art performance




Interoperates with other IEC 61850 compliant IEDs


functionality
Control

Capabilities


Communication
Offering

and


application

examples


Technology

Summary

®


Relion


Summary

© ABB Group November 2009 Slide 71

© ABB Group October 10, 2011 | Slide 72

Auto Auto reclosing reclosing Cycle Cycle OH-lines High fault-rate (80-90%)

Fast simultaneous Fault clearing

© ABB Group October 10, 2011 | Slide 73

AUTORECLOSING AUTORECLOSINGCYCLE CYCLE

OH-lines Intermittent faults (80-90%)

Successful AR-rate : High (80-90%)

© ABB Group October 10, 2011 | Slide 74

Auto reclosing principles


95% of faults are transient type




3 Ph autoreclosing synchrocheck is used





1 Ph autoreclosing needs identification of faulty phase


© ABB Group October 10, 2011 | Slide 75

Helps verify phase angles are not out of phase e.g: due to heavy power swing

Phase identification is difficult for high resistance faults

Single-pole Reclosing Single-Pole Reclosing A B C

© ABB Group October 10, 2011 | Slide 76

A B C

Artificial extinction of secondary arc by Fixed Four-reactor Scheme ABC

ABC

L

R Lp Lp Lp

Ln

© ABB Group October 10, 2011 | Slide 77

Synchronism and Energizing check UBus

ULine

UBus

FreqDiff < 50-300 mHz o PhaseDiff < 5-75 UDiff < 5-50% Ur UHigh > 50-120% Ur

U Bus

1-ph

U Line

3-ph (or 1-ph)

ULow < 10-100% Ur SYNC-BLOCK

© ABB Group October 10, 2011 | Slide 78

Fuse fail

ULine

© ABB Group October 10, 2011 | Slide 79

Need for Busbar protection In its absence fault clearance takes place in Zone-II of distance relay by remote end tripping




This means slow and unselective tripping and wide spread black out




Effect of delayed clearance



© ABB Group October 10, 2011 | Slide 80

Greater damage at fault point Indirect shock to connected equipments like shafts of Generator and windings of transformer.

Types of BB Protections


High impedance




Medium impedance




Low impedance




© ABB Group October 10, 2011 | Slide 81

Blockable O/C relay ( For radial systems in distribution systems)

High impedance bus differential relay Basic features SETTING VR > IF ( RCT + 2 RL) VK > 2 VR

RL A

VR

RCT B

FOR VR TO BE ZERO FOR EXTERNAL FAULT nA = nB 1 + RA / ZA 1 + RB / ZB n = TURNS RATIO R = RCT + 2 RL Z = MAGNETIZING IMPEDANCE

© ABB Group October 10, 2011 | Slide 82

Limitations of High impedance differential relay





© ABB Group October 10, 2011 | Slide 83

Puts stringent requirements on CTs




Need for dedicated CTs




Identical CT ratios , magnetising impedances




Aux CTs not acceptable

Inability to cope with increasing fault levels

RADSS medium impedance relay

IR1

T MD n MD

Ud3 dR D2

US

© ABB Group October 10, 2011 | Slide 84

D1

REB500 - Numerical Busbar and Breaker Failure Protection

ABB Network Partner AG

REB 500

C E

Distributed installation ABB Network Partner AG

REB 500

ABB Network Partner AG

C E Bay Unit

© ABB Group October 10, 2011 | Slide 85

Central Unit

REB 500

ABB Network Partner AG

C E Bay Unit

REB 500

ABB Network Partner AG

C E Bay Unit

REB 500

C E Bay Unit

Advantages of medium/ Low impedance relays


Free from any need for Identical CT ratios or matched CTs




Other relays can be included in the same CT core




Increasing fault levels have no impact

© ABB Group October 10, 2011 | Slide 86

1000/5

200/5

3.5 A

5/1

500 A

200 A

700 A

500/5

5A

5/0.5

5/0.2 0.7 A

0.2 A

Diff. relay RADSS IN SINGLE BUS © ABB Group October 10, 2011 | Slide 87

5A

0.5 A

REQUIREMENTS ON THE ISOLATOR AUXILIARY CONTACTS Isolator Aux. Contact ‘a’ should close before the primary contact a

b

closes and Aux contact’ b’ closes after the primary contact opens.

O

C Throw-over relay

0% Main contact Aux. Contact a Aux. Contact b © ABB Group October 10, 2011 | Slide 88

100%

DOUBLE BUSBAR SYSTEM WITH TRANSFER BUS BUS - A BUS - B

AUX. BUS

© ABB Group October 10, 2011 | Slide 89

1½- BREAKER SYSTEM RADSS - A L1

L3

L5

L2

L4

L6

BUS - A

BUS - B

RADSS - B

© ABB Group October 10, 2011 | Slide 90

Busbar Protection REB670

© ABB Group April 2009 Slide 91

© ABB Group October 10, 2011 | Slide 92

History - Circuit breaker development

Example: 420 kV

Air Blast

…around 1960

© ABB Group October 10, 2011 | Slide 93

Oil Minimum

SF6 Gas

…around 1980

…today’s technology

Interrupters Interrupter design

© ABB Group October 10, 2011 | Slide 94

+

Relay back-up RELAY SYSTEM

CHANNEL

52

50

-

52a

52 52a

RELAY SYSTEM

CHANNEL +

© ABB Group October 10, 2011 | Slide 95

Breaker back-up 5

1

6

2

Z<

7

8 3

4

For uncleared fault shown CB’s to be tripped are 1, 3, 4 & 6

© ABB Group October 10, 2011 | Slide 96

Classical CBFP Breaker Failure Protection

I> I>

I>

I>

+ if trip from relay

© ABB Group October 10, 2011 | Slide 97

t trip

© ABB Group October 10, 2011 | Slide 98

Introduction


Majority faults are earth faults




Earth fault protection depends on type of earthing




Effectively earthed




Reactance earthed




High resistance earthed




Resonance earthed

© ABB Group October 10, 2011 | Slide 99

Measurement of earth fault current

© ABB Group October 10, 2011 | Slide 100

Measurement of zero sequence voltage L1 L2 L3

U 0>

Earth fault protection in solidly earthed systems IDMT earth fault relays are used to detect earth faults in effectively earthed system

© ABB Group October 10, 2011 | Slide 102

Directional Earth Fault Relay

© ABB Group October 10, 2011 | Slide 103




Directional earth fault relays are used




Can use communication link




Inrush current stabilization may be required for sensitive settings

Directional earth fault relay for High resistance earthed system







Directional earth fault relay used when in feed of capacitive current from an object is higher than 60% of required sensitivity Measures active component of fault current

© ABB Group October 10, 2011 | Slide 104

Earth fault in resonance earthed network A B C

ΣI01

C0

ΣI02 L

RL

U0 Ief

R0

Earth fault in isolated network A B C

ΣI01

C0

U0 ΣI02

Ief

R0

Directional earth fault relay

© ABB Group October 10, 2011 | Slide 107

Restricted earth fault relay

© ABB Group October 10, 2011 | Slide 108

© ABB Group October 10, 2011 | Slide 109

What is Substation Automation ? A combination of:

© ABB Group October 10, 2011 | Slide 110




Protection




Monitoring




Control




Communication

What is Substation Automation ?


Substitution for conventional control panels




Substitution for other sub systems




A more efficient way of controlling your substation

© ABB Group October 10, 2011 | Slide 111




The conventional way Control Board

Telecontrol RTU

Alarming

Synchronization

Busbar Protection

MARSHALING RACK

Local ControlTELE-

© ABB Group October 10, 2011 | Slide 112

Interlocking ALARMING

Measuring NISATION

Bay BUSBAR Protection PROTECTION

System Engineering Tool

The New Way

Station Monitoring System

Station HMI Gateway Station Clock

Communication only during engineering IED Tool

Station bus Bay Control

Web Client

Object Protection

Control & Protection

Multi Object Protection

IEDs

Process bus

Merging Unit

© ABB Group October 10, 2011 | Slide 113

Merging Unit

Multi Bay Control

Conventional Control & Protection Fault Recording 225kV LIGNE ABOBO 1

Station Level

ABB

125VDC Distribut uion Batt ery A

=D04+R01

125VDC Distributuion Bat tery B

Bay Protection 225kV LIGNE ABOBO 1

ABB

125VDC Distribut uion Batt ery A

Busbar Protection 125VDC Distribut uion Batt ery A

225kV LIGNE ABOBO 1

ABB

=D04+R01

125VDC Distribut uion Batt ery A

125VDC Distributuion Bat tery B

125VDC Distributuion Bat tery B

Event Recording =D04+R01

225kV LIGNE ABOBO 1

ABB

125VDC Distribut uion Batt ery A

=D04+R01

125VDC Distributuion Bat tery B

R E L3146* A B w N oeP rtakn

ABB RTU 200 I N 1 IN 2 IN 3 IN 4 IN 5 IN 6 IN 7 IN 8 OUT 1

1

9

2

10

3

n d a ciI6 t5 0 n d a ciI6 t5 0

1

4

12

5

13

6

14

7

15

8

16

ON/OFF

056 ci tcadn I

056c i tcadn I

0 56c tic adn I

BAY CONTROL RELAY RE C316*4

=W 1

RTU 200 I N 1 IN 2 IN 3 IN 4 IN 5 IN 6 IN 7 IN 8 OUT =W 2

1

9

2

10

3

1 -Q 1

4

12

5

13

6

14

7

15

8

16

ON/OFF V o e in sr4 .2 b

E F R M

c c

LOCAL CO NTROL

METERI NG n d a ciI6 t5 0 R E L3146*

n d a ciI6 t5 0

A B w N oeP rtakn

RTU 200 I N 1 IN 2 IN 3 IN 4 IN 5 IN 6 IN 7 IN 8 OUT

ABB 3

1

9

2

10

3

1

4

12

5

8

13

6

14

7

15

8

16

ON/OFF

LI NE PROTECTION RELAY REL316*4 R E B 50 A B w N oeP rtakn

ABB

BUSBAR PROTECTION REB500

225kV LIGNE ABOBO 1

ABB

ABB

Bay Level

225kV LIGNE ABOBO 1

ABB

=D04+R01

125VDC Distributuion Bat tery B

SCADA RTU

For each function a dedicated device and separate Panel

Control Panel

ABB

=D04+R01

ABB

=W1

=W2

-Q1 SEL

-Q2 SEL

-Q0 SEL

TESTE LAMPE

Extensive station wide cabling

OUVRI RFERMER ABB

ESC

EXE

Local Control

DISTANCE LOC

Process Level

Marshalling

Extensive bay cabling

GIS or AIS Switchgear

-Q2 -Q0 -Q1

-Q9

-Q8

Substitution of Conventional Technology Bay Control/Protection Cubicles Fällanden Steuerung / Schutz

Fällanden Steuerung / Schutz

MicroSCADA

=AD17-KB2

=AD17-KB2

Feldsteuergerät REC216 mit Messung und Synchrocheck

Feldsteuergerät REC216 mit Messung und Synchrocheck

Interbay bus Ethernet Switches d gi ta l

LEITUNGSHA UPTSCHUTZ REL316* 4 PRÜFSTECKER I 0

I 0

STUFENVERL. WE-BLOCK

Reset AUS

I 0 SCHUTZ EIN/A US

di gi t al

LEITUNGSHA UPTSCHUTZ REL316* 4 PRÜFSTECKER I 0

I 0

STUFENVERL. WE-BLOCK

Reset AUS

I 0 SCHUTZ EIN/A US

-Q2

-Q1

COM 581 ABBPower Automation AG

COM581

NCC / RCC

Communication Converter

-Q0

Marshalling

-Q9

C

Control Cubicle Relays for control / logic Transducers, Meters Switches, Lamps Annunciators, Terminals

-Q8 Protection Cubicle

SER / Fault Recorder

SCADA RTU NCC / RCC

Modern SA Architecture

Station Level

Network Control Center NCC

ABB Network Partner AG

C

125VDC Distributuion Battery B REL316*4

ABBNetwor kPar nt er

ABB

1 2 3 4 5 6 7 8

Basic Functionality

125VDC Distributuion Battery A

Bay Level

=D04+R01

225kV LIGNE ABOBO 1

ABB

9 10 11 12 13 14 15 16

BAY CONTROL RELAY REC316*4 =D 04 A B OB O 1

ABB P OWE R

MON I T OR I N G U N I T

=W1 =W2 -Q1 SEL

-Q2 SEL

LAMPE TESTE

-Q0 SEL

OUVRIR

ESC

ABB

FERMER

LO C

LOCAL CONTROL ABB

METERING REL316*4

ABBNetwor kPar nt er

1 2 3 4 5 6 7 8

DIS T A NCE

EXE

9 10 11 12 13 14 15 16

LINE PROTECTION RELAY REL316*4 ABB

ABBNetwor kPar nt er

REB500

BUSBAR PROTECTION REB500

-Q2 -Q0 -Q1

-Q9

-Q8

Features and Benefits

E

Interbay Bus

Process Level

COM581

Implementation of Intelligent Technology Intelligent Primary Equipment

MicroSCADA =D04+R01

225kV LIGNE ABOBO 1

ABB

125VDC Distributuion Battery A

125VDC Distributuion Battery B REL316*4

ABBNetworkPartner

ABB

1 2 3 4 5 6 7 8

9 10 11 12 13 14 15 16

BAY CONTROL RELAY REC316*4 =D 04 A B OB O 1

ABB P OWE R

MON I T OR I N G U N I T

=W1 =W2 -Q1 SEL

M M

Interbay bus Ethernet Switches

-Q2 SEL

M OUVRIR

ESC

-Q2

-Q51

-Q0 PISA A

-Q8 -Q9 -Q8

LO C

METERING

9 10 11 12 13 14 15 16

di gi t al

i it l

LINE PROTECTION RELAY REL316*4

Drive control & monitoring circuitry

ABB

ABBNetworkPartner

REB500

BUSBAR PROTECTION REB500

COM 581 ABBPower Automation AG

COM581

NCC / RCC

Communication Converter

C

-Q0

-T1 -Q9

DIS T A NCE

EXE

REL316*4

ABBNetworkPartner

1 2 3 4 5 6 7 8

-Q2

-Q1

FERMER

LOCAL SET REMOTE OPERATION

PISA

PISA A PISA B

Feeder Marshalling

-Q1

ABB

t

d gi tal

LAMPE TESTE

-Q0 SEL

ABB

?

LOCAL CONTROL

Sampling AD-Conversion Signal Processing Signal Filtering

Process Bus

Station Level

Intelligent SA Architecture

Network Control Center NCC

ABB Network Partner AG

C

Interbay Bus 125VDC Distributuion Battery A

Bay Level

=D04+R01

225kV LIGNE ABOBO 1

ABB

125VDC Distributuion Battery B REL316*4

ABBNetworkPartner

ABB

1 2 3 4 5 6 7 8

9 10 11 12 13 14 15 16

BAY CONTROL RELAY REC316*4 =D 04 A B OB O 1

ABB P OWE R

MON I T OR I N G U N I T

=W1 =W2

M M

-Q1 SEL

-Q2 SEL

LAMPE TESTE

-Q0 SEL

M

ABB

OUVRIR

FERMER

ESC

EXE

LOCAL SET REMOTE OPERATION

?

LOCAL CONTROL

1 2 3 4 5 6 7 8

DIS T A NCE LO C

METERING REL316*4

ABBNetworkPartner

ABB

9 10 11 12 13 14 15 16

LINE PROTECTION RELAY REL316*4 ABB

ABBNetworkPartner

REB500

BUSBAR PROTECTION REB500

-Q2

-Q0 -Q1

-Q51

PISA B

PISA A

PISA A

PISA

Process Level

Process B u

-T1

-Q9

-Q8

s

Basic Functionality

E

FEATURES AND BENEFITS

COM581

Functional Structure of Modern SA

Station Level

Functions Allocation Network Control Center NCC

ABB Network Partner AG

COM581

C E

Scalable System Extensions SCADA Remote Communication Fault evaluation Monitoring Events and alarms Supervision & Control Data Exchange

Interbay Bus 125VDC Distributuion Battery A

1 2 3 4 5 6 7 8

Bay Level

125VDC Distributuion Battery B REL316*4

ABBNetworkPartner

ABB

Process Level

=D04+R01

225kV LIGNE ABOBO 1

ABB

9 10 11 12 13 14 15 16

BAY CONTROL RELAY REC316*4 =D 04 A B OB O 1

ABB P OWE R

Monitoring

MON I T OR I N G U N I T

=W1 =W2 -Q1 SEL

-Q2 SEL

LAMPE TESTE

-Q0 SEL

OUVRIR

ESC

ABB

FERMER

LO C

LOCAL CONTROL ABB

METERING REL316*4

ABBNetworkPartner

1 2 3 4 5 6 7 8

DIS T A NCE

EXE

9 10 11 12 13 14 15 16

LINE PROTECTION RELAY REL316*4 ABB

ABBNetworkPartner

REB500

BUSBAR PROTECTION REB500

GIS or AIS Switchgear Instrument Transformers Power Transformers Surge Arresters

-Q2 -Q0 -Q1

-Q9

-Q8

Intelligent Substation Automation Functional Structure

Functions Allocation

Station Level

Network Control Center NCC

ABB Network Partner AG

C E

Interbay Bus 125VDC Distributuion Battery A

125VDC Distributuion Battery B REL316*4

ABBNetworkPartner

ABB

1 2 3 4 5 6 7 8

Bay Level

=D04+R01

225kV LIGNE ABOBO 1

ABB

9 10 11 12 13 14 15 16

BAY CONTROL RELAY REC316*4 =D 04 A B OB O 1

ABB P OWE R

MON I T OR I N G U N I T

=W1 =W2

M M

-Q1 SEL

-Q2 SEL

Monitoring

LAMPE TESTE

-Q0 SEL

M OUVRIR

ESC

ABB

FERMER

LOCAL SET REMOTE OPERATION

?

LOCAL CONTROL ABB

LO C

METERING REL316*4

ABBNetworkPartner

1 2 3 4 5 6 7 8

DIS T A NCE

EXE

9 10 11 12 13 14 15 16

LINE PROTECTION RELAY REL316*4 ABB

ABBNetworkPartner

REB500

BUSBAR PROTECTION REB500

s

-Q2

-Q0 -Q1

-Q51

PISA B

PISA A

PISA A

PISA

Process B u

Process Level

COM581

Scalable System Extensions SCADA Remote Communication Fault evaluation Monitoring Events and alarms Supervision & Control Data Exchange

-T1

-Q9

-Q8

Intelligent or “smart” AIS / GIS Switchgear Data acquisition Sensors & Actuators Power Transformers Surge Arrestors

Intelligent SA: Control, Protection and Sensors ABB

=D04+R01

225kV LIGNE ABOBO 1

ABB

Actuator for isolator & earthing switch control

PISA PISA

PISA

PISA

125VDC Distributuion Battery A ABB

125VDC Distributuion Battery B REL316*4

ABB Network Partner

1 2 3 4 5 6 7 8

9 10 11 12 13 14 15 16

Line Protection 1 I Abgangsschutz

BAY CONTROL RELAY REC316*4 ABB

=D04 ABOBO 1

POWER MONITORING UNIT =W1

=W2

M

-Q1 SEL

M

-Q2 SEL

LAMPE TESTE

-Q0 SEL

Feldleitgerät Bay Controller

M

Switches

? ABB

LOCAL

OUVRIR

FERMER

ESC

EXE

LOC

OPERATION

LOCAL CONTROL

Actuator for circuit breaker control

ABB

1 2 3 4 5 6 7 8

DISTANCE

SET

REMOTE

METERING REL316*4

ABB Network Partner

9 10 11 12 13 14 15 16

PISA A

Line Protection 2 II Abgangsschutz LINE PROTECTION RELAY REL316*4

PISA A

ABB

ABB Network Partner

REB500

PISA B

Busbar Protection

Sensors for current & voltage measurement

Process Bus

BUSBAR PROTECTION REB500

Interbay bus 1 Interbay bus 2

Monitoring via IEDs for Protection

Advanced analysis tools

Alarm Classes

Automatic printing Summary report

GPS

User friendly visualization Universal Time synchronization

CONCISE / FAST Distance to Fault Mo 12. 11. 96

GMT 17:02.43.305

Ayer Rajah & Labrador

Feeder One

Sequence of Events ABB Network Partner AG

IED Parameter

# Of trips C E

ABB Network Partner AG

REL 316*4

ABB Network Partner AG

REL 316*4 ABB Network Partner AG

1

9

1

9

2

10

2

10

1

9

3

11

3

11

2

10

4

12

4

12

3

11

5

13

5

13

4

12

6

14

6

14

5

13

7

15

7

15

6

14

8

16

8

16

7

15

8

16

C

C

E

E

REL 316*4

C E

Station level supervision

Single Line Diagram:

Diagnostic: Fault Recording and Evaluation

Automatic fault location printout

Remote Control via Network Control Centre (NCC)

The goal of the IEC 61850 standard Interoperability

The ability for IED’s from one or several manufacturer to exchange information and use the information for the their own functions.

Free Configuration The standard shall support different philosophies and allow a free allocation of functions e.g. it will work equally well for centralized (RTU like) or decentralized (SCS like) systems. Long Term Stability The standard shall be future proof, i.e. it must be able to follow the progress in communication technology as well as evolving system requirements.

© ABB Group October 10, 2011 | Slide 127

© ABB Group October 10, 2011 | Slide 128