Generator Protection

© ABB Group October 10, 2011 | Slide 1

Protection Application – An Overview

Part 2A

Bapuji S Palki, INCRC/PowerTechnologies, 15-11-200 9


Typical Parts of a Power PlantLayouts

G

Substation

Power plant

Busbar in Substation

HV - Breaker

Main Transformer Auxiliary Transformer

Generator Breaker

Excitation Transformer

Excitation System

Field Circuit Breaker

Turbine valve

Turbine - Generator

Earthing System

Possible Faults

� Stator Earth Faults

� Rotor Earth Faults

� Stator Short Circuits

� Stator/Rotor Interturn faults

� External faults

Generator Protection

� 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

Abnormal Operating ConditionGenerator Protection


Type of fault ANSI DeviceNo.

Protection Functions

GENERATORSTATORShort Circuits 87G

87GT21G

51 / 27 G

Generator differentialOverall differentialMinimum impedance (or alternativelyOver current / under voltage)

AsymmetryStator overloadEarth fault stator

46G51G

64G164G2

Negative sequenceOverload95% stator earth fault100% stator earth fault

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


Loss of excitation 40G Loss of excitation

Out of step 98G Pole slipMonitoring 32G / 37G Low forward power / reverse power

(double protection for large generators)Blade fatigue 81G Minimum frequency

Inter turn fault 95G Over voltage or over currentMag. Circuits 99G Overfluxing volt / HzHigher voltage 59G Over voltageAccidentalenergisation

27 / 50 G Dead machine

Monitoring 60 G PT fuse failure


GENERATORROTORRotor ground 64F Rotor earth faultGENERATORTRANSFORMER

Short Circuits 87GT51GT87T

Overall differentialOvercurrentTransformer differential

Ground fault 51NGT87NT

Earth fault over-currentRestricted earth fault

Overhang 87HV HV winding cum overhang differentialUNIT AUXILIARYTRANSFORMERShort circuit 87 UAT

51 UATTransformer differentialOver-current

Ground fault 51 UAT64 UAT

Restricted over-currentRestricted earth fault


1) Instruments

Field windingground-faultRAGRA(RXNB4)

64F

50/51

Unit aux.transformer

REG 670 – Different applications

� 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

REG 670 provides extensiveprotection and monitoring functionality

Protectionand Monitoring

REG 670 focus on the

optimized integration and function

to protect your generator

G

1ph U

3ph U

3ph I

3ph I

1ph U

1ph U

1ph I

A Breakthrough for Substation Automation� One world

� One technology

� One standard

IEC 61850

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

IEC 61850



Power transformers in a power system

400 kV AC Transmission

Generation

130 kV Subtransmission

Distribution

M

MV

LV


315MVA Transformer


Cooling� 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

F anoptional

Pumpoptional

Outer Ci rcui t I nner Ci rcui t

Oi l immersedTank

HeatProduction(Core andWindings)

HeatDissipation


Types of Internal Faults

� Earth faults

� Short-circuits

� Inter turn Faults

� Core Faults

� Tank Faults

� Reduced cooling


Abnormal Conditions

� 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


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


Protective Relays Used ( Transformers < 5 MVA)

� Gas detector relay

� Overload protection

� Overcurrent protection

� Ground fault protection


Monitors

Monitors are very important devices which detect

faults and abnormal service conditions which may

develop into fault.


Transformer Monitors

� Mechanical fault detectors� Sudden gas pressure protection

� Buchholz protection

� Oil level monitoring

� Temperature Monitoring� The oil thermometer

� The winding thermometer

© ABB GroupNovember 2009 | Slide 23

Transformer protection with 670/650 series

� 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 sub-transmission applications provide “off-the-shelf”, ready to use solutions for transformer protection applications primarily in sub-transmission networks.

IntroductionTransformer Protection670/650 seriesOpennessand flexibilityReliable OperationComplementaryfunctionalityControl CapabilitiesCommunicationOffering andapplication examplesTechnology SummaryRelion®

Summary


Fully compliant to the IEC 61850 standard

� 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

Introduction Line Distance Protection670/650 seriesReliable OperationComplementaryfunctionalityControl CapabilitiesCommunicationOffering andapplication examplesTechnology SummaryRelion®

Summary



The reactor absorbs the capacitive power generated in long lines


Shunt Reactor


L R

A B C A B C

L p L p L p

L n


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

� Through circuit breakers to the tertiary of a Interconnecting transformer


Different locations of reactor


Internal FaultsFaults 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


Abnormal Conditions

� Inrush currents

� Inrush currents flow in connection with energisation

� Inrush currents usually lower than 200% of rated current

� Transient overvoltages

� Temporary overvoltages


Shunt Reactor Protections


� Distance protection

� Phase over current protection

� Restricted earth fault protection

� Mechanical fault detectors

� Oil temperature and winding temperature protection


Monitors

Monitors are very important devices which detect

faults and abnormal service conditions which may

develop into fault.


Reactor Monitors

� Mechanical fault detectors� Sudden gas pressure protection

� Buchholz protection

� Oil level monitoring

� Temperature Monitoring� The oil thermometer

� The winding thermometer


Shunt reactor protection and control

� Protection

� Phase segregated biased differential protection

� Low impedance restricted earth-fault

� High impedance differential protection

� Switching control for lines and buses

IntroductionTransformer Protection670/650 seriesOpennessand flexibilityReliable OperationComplementaryfunctionalityControl CapabilitiesCommunicationOffering andapplication examplesTechnology SummaryRelion®

Summary



Capacitor Construction


Power Factor CorrectionPower Factor Correction

� 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.

Working Power (kW)

Reactive Power (kVAR)


Increased System CapacityIncreased System Capacity

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

Power Factor 60% 70% 80% 90% 100%Real Power kW 600 600 600 600 600

Reactive Power kVAR 800 612 450 291 Zero

Total Power kVA 1000 857 750 667 600

Total Power (KVA) = Working Power (KW) ÷÷÷÷ Power Factor

Extra capacity for more KVA

released system capacity


Voltage StabilityVoltage 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)


ProductsCapacitors – HV Products / Filter Capacitor Banks

Improving the performance, quality and efficiency of electrical systems

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)


FusingCapacitor Fusing

Internally Fused Externally Fused Internal Strings Conventional

FuselessFuse Discharge Resistor

�SPAJ 160 C : Unbalance , Overload and Under current functions


Protection Application – An Overview

Part 2B

Bapuji S Palki, INCRC/PowerTechnologies, 15-11-200 9



The Electric UtilityThe Electric Utility

Power Evacuation Substation

Transmission Substation

Switching Substation

Distribution Substation


Transmission Line


Electrical faults in the power system

� Transmission lines 85%

� Busbar 12%

� Transformer/ Generator 3%

100%


Fault types

� Transient faults

� are common on transmission lines, approximately 80-85%

� lightnings are the most common reason

� 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

� Overcurrent 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 > I > I >

I >

block


Pilot wire differential protection

� 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

Digital communication withoptical fibres or by multiplexed channels

L1L2L3

DL1

DL2

DL3

DL1

DL2

DL3


Phase comparison

� 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.

I1 I2

e1

e2

e2

e1-

φφφφ>

φφφφ>

I1 I2

load

I2

I2

I1func-tion

αααα

αααα

φφφφφφφφ


The principle of distance protection

Z<

ZK=Uk/Ik

Uk=0Uk

Zk IkA B

metallic fault


Fault resistance

� multi-phase faults

� consist only of arc resistance

� earth faults

� consist of arc and tower

� footing resistance

L1

L3

L3

L1

L2

L2

Footing resistanceRarc =

28707 x L 1.4I

Warrington´sformula

L= length of arc in meters

I= the actual fault current in A


Distance protection on short lines

� Quadrilateral characteristic improves sensitivity for higher RF/XF ratio

� It still has some limitations:

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

jX

RXF

RF


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

� Has no strictly defined reach in resistive direction

� Needs limitations in resistive direction (blinder)

R

jX


The principle of distance protection

A

Z<

B

Z< Z<

C

Z<

t

t

lt1

t2t3

lt1t2t3

f1

f2

f3


The principle of distance protection� Reach setting of zones

� R/ X Relation

� GFC (General Fault Criterion)

ZL

Zb

ZL

GFC


PLCC equipment


Power Swing Blocking function

∆∆∆∆t

∆∆∆∆t = 40 ms

X

R

Power swing locus


Series compensated system

• Correct direction discrim-inationat voltage reversal (negative fault reactance)

• variation in resulted line impedance

Consideration for line distance protections

BA

F1

X =70%C X =100%l

R

jX

AB

B´

70%

100%

gape not flashed

gape flashed

© ABB GroupNovember 2009Slide 70

Line distance protection with Relion® 670/650 seriesFor maximum reliability of your power system

� Full scheme distance protection with independent phase selection

� Power swing detection

� Wide range of scheme communication logics

� Five zone distance protection

� Phase to phase

� Phase to earth faults

�Introduction

�Line Distance Protection

�670/650 series

�Reliable Operation

�Complementary

�functionality

�Control Capabilities

�Communication

�Offering and

�application examples

�Technology Summary

�Relion®

�Summary

© ABB GroupNovember 2009Slide 71

Fully compliant to the IEC 61850 standard

� 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

�Introduction

�Line Distance Protection

�670/650 series

�Reliable Operation

�Complementary

�functionality

�Control Capabilities

�Communication

�Offering and

�application examples

�Technology Summary

�Relion®

�Summary



Auto reclosing CycleAuto reclosing Cycle

Fast

simultaneous

Fault clearing

OH-lines

High fault-rate

(80-90%)


AUTORECLOSING CYCLEAUTORECLOSING CYCLE

OH-lines

Intermittent faults

(80-90%)

Successful

AR-rate :

High (80-90%)


Auto reclosing principles

� 95% of faults are transient type

� 3 Ph autoreclosing synchrocheck is used

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

� 1 Ph autoreclosing needs identification of faulty phase

� Phase identification is difficult for high resistance faults


Single-pole Reclosing

A B C A B C

Single-Pole Reclosing


Artificial extinction of secondary arc by Fixed Four-reactor Scheme

L R

A B C A B C

L p L p L p

L n


ULine UBus

SYNC-BLOCK

UBus

ULine

Fuse fail

1-ph

3-ph (or 1-ph)

UBus

ULineUHigh > 50-120% Ur

ULow < 10-100% Ur

PhaseDiff < 5-75

UDiff < 5-50% Ur

FreqDiff < 50-300 mHzo

Synchronism and Energizing check



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

� 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

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


High impedance bus differential relayBasic features

SETTING VR > IF ( RCT + 2 RL)

VK > 2 VR

FOR VR TO BE ZERO FOREXTERNAL FAULT

nA = nB 1 + RA / ZA

1 + RB / ZB

n = TURNS RATIOR = RCT + 2 RLZ = MAGNETIZING IMPEDANCE

A BRCT

RL

VR


Limitations of High impedance differential relay

� 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


T MDn MD

D 1D 2

dR

IR1

Ud3

US

RADSS medium impedance relay


Distributed installationABB Network Partner AG REB 500

Bay Unit

CE

ABB Network Partner AG REB 500

Bay Unit

CE


Bay Unit

CE


Bay Unit

CE

Central Unit


CE

REB500 - Numerical Busbarand Breaker Failure Protection


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


Diff. relay

1000/5 200/5 500/5

3.5 A 5 A5 A

500 A200 A700 A

0.7 A 0.2 A 0.5 A

5/1 5/0.2 5/0.5

RADSS IN SINGLE BUS


REQUIREMENTS ON THE ISOLATOR AUXILIARY CONTACTS

Isolator Aux. Contact ‘a’ should

close before the primary contact

closes and

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

Throw-over relay

100%0%

Maincontact

Aux.Contact

a

Aux.Contact

b

a b

O C


DOUBLE BUSBAR SYSTEM WITH TRANSFER BUSBUS - A

BUS - B

AUX. BUS


1½- BREAKER SYSTEM

RADSS - A

RADSS - B

BUS - A

BUS - B

L1 L3 L5

L4 L6L2

© ABB Group April 2009Slide 91

Busbar Protection REB670



History - Circuit breaker development

Air Blast Oil Minimum SF6 GasExample: 420 kV

…around 1960 …around 1980 …today’s technology


InterruptersInterrupter design


Relay back -up

RELAYSYSTEM

RELAYSYSTEM

50

+

+

-

- 52 52a

5252a

CHANNEL

CHANNEL


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

Breaker back -up

Z <

5 1

7

3 4

2 6

8


Classical CBFP

I>

I>

I>

I>

t

Breaker Failure Protection

trip+if tripfromrelay



Introduction� Majority faults are earth faults

� Earth fault protection depends on type of earthing

� Effectively earthed

� Reactance earthed

� High resistance earthed

� Resonance earthed


Measurement of earth fault current

Measurement of zero sequence voltage

U0>

L1L2L3


Earth fault protection in solidly earthed systems

IDMT earth fault relays are used to detect earth faults in effectively earthed system


Directional Earth Fault Relay

� 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

Earth fault in resonance earthed network

A B C

U0

C0

ΣI01

ΣI02

Ief

R0

L RL

Earth fault in isolated network

A B C

U0

C0

ΣI01

ΣI02

Ief

R0


Directional earth fault relay


Restricted earth fault relay



� Protection

� Monitoring

� Control

� Communication

What is Substation Automation ?

A combination of:


What is Substation Automation ?

� Substitution for conventional control panels

� Substitution for other sub systems

� A more efficient way of controlling your substation

�


The conventional way

MARSHALING RACK

TELE- ALARMING NISATIONBUSBAR

PROTECTION

LocalControl

Inter-locking Measuring

BayProtection

TelecontrolRTU

AlarmingSynchro-nization

BusbarProtection

Control Board


Station HMI

Gateway

Multi ObjectProtection

Merging Unit

Multi BayControl

ObjectProtection

Bay Control

Control &Protection

Merging Unit

IED Tool

System Engineering Tool

IEDsWeb Client

Station Clock

Station bus

Process bus

Communication onlyduring engineeringStation

MonitoringSystem

The New Way

Pro

cess

Lev

elB

ay L

evel

Sta

tion

Leve

l

GIS or AISSwitchgear

-Q1

-Q0 -Q8-Q9

-Q2

1

3

8

=D04+R01225kV LIGNE ABOBO 1ABB

125VDC Distributuion Battery A 125VDC Distributuion Bat te ry B

Fault Recording

Indactic 650 Indactic 650 Indactic 650



BAY CONTROL RELAY RE C316*4

1

ABBABB Network Partner

REL316*4

2

4

3

5

6

7

8

9

12

11

13

14

15

16

10

LOCAL CO NTROL METERING

LINE PROTECTION RELAY REL316*4

1


REL316*4

2

4

3

5

6

7

8

9

12

11

13

14

15

16

10

BUSBAR PROTECTION REB500


REB500

-Q1

=W1

=W2

FERMER

1

2

3

4

5

6

7

8

9

10

11

12

13

14

15

16

cc

Veriosn 4.2b

Bay Protection

LocalControl



Busbar ProtectionSCADA

RTU=D04+R01225kV LIGNE ABOBO 1ABB


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

ON/OFF


ON/OFF


ON/OFF



Indactic650Indactic650

Indactic650

Indactic650

Event Recording


ABB

-Q2SEL

-Q1SEL

-Q0

SEL

=W1

=W2

FERMEROUVRIR

EXEESC

LAMPETESTE

DISTANCE

LOC

ABB ABB ABB

For each function a dedicated device

and separate Panel Extensive station wide cabling

Extensive bay cabling

Conventional Control & Protection

Marshalling

Control Panel

SCADA RTUSER / Fault Recorder

Protection Cubicle

Control CubicleRelays for control / logic

Transducers, MetersSwitches, Lamps

Annunciators, Terminals

Interbay busEthernet Switches

d gi ta l

di gi tal

NCC / RCC

MicroSCADA

ABBPower Automation AG COM581

C

CommunicationConverter

=AD17-KB2Steuerung / SchutzFällanden

Feldsteuergerät REC216 mit Messung und Synchrocheck

LEITUNGSHA UPTSCHUTZ REL316* 4 PRÜFSTECKER

I

0

SCHUTZ EIN/A US

I

0

WE-BLOCK

I

0

STUFENVERL.

Reset

AUS

Bay Control/Protection Cubicles

-Q1

-Q0

-Q8

Mar

shal

ling

-Q9

-Q2

Substitution of Conventional Technology

=AD17-KB2Steuerung / SchutzFällanden

Feldsteuergerät REC216 mit Messung und Synchrocheck

LEITUNGSHA UPTSCHUTZ REL316* 4 PRÜFSTECKER

I

0

SCHUTZ EIN/A US

I

0

WE-BLOCK

I

0

STUFENVERL.

Reset

AUS

COM 581

NCC / RCC

Interbay Bus

ABB Network Partner AG

C

E

COM581

Network ControlCenter NCC

-Q1

-Q0 -Q8-Q9

-Q2


125VDC Distributuion Battery A 125VDC Distributuion Battery B

BAY CONTROL RELAY REC316*4

1

ABB ABB Networ k Par tner REL316*4

2

43

5678

9

1211

13141516

10

LOCAL CONTROL METERING


1

ABB ABB Networ k Par tner REL316*4

2

43

5678

9

1211

13141516

10


ABB ABB Networ k Par tner REB500

ABB

=D04 ABOBO 1

-Q2S E L

-Q1S E L

-Q0S E L

=W1

=W2

FERMEROUVRIR

EXEESC

LAMPETESTE

D I S T A N C E

LOC

ABBP OWE R MONI T ORI NG UNI T

Pro

cess

Lev

elB

ay L

evel

Sta

tion

Leve

l

Fea

ture

s an

d B

enef

itsF

eatu

res

and

Ben

efits

Bas

ic F

unct

iona

lity

Bas

ic F

unct

iona

lity

Modern SA Architecture

t

i i t l

-Q1

-Q0

-Q8

Fee

der

Mar

shal

ling

-Q9

-Q2

Intelligent Primary Equipment

PISA

PISAA

PISAB

PISA A

-Q1 -Q2

-Q51

-Q0

-T1

-Q9

-Q8

ProcessBus

Interbay busEthernet Switches

d gi tal

di gi tal

NCC / RCC

MicroSCADA

ABBPower Automation AG COM581

C

CommunicationConverter




1

ABB ABB Network Par tner REL316*4

2

43

5678

9

1211

13141516

10



1


2

43

5678

9

1211

13141516

10


ABB ABB Network Par tner REB500

ABB

=D04 ABOBO 1

-Q2S E L

-Q1S E L

-Q0S E L

=W1

=W2

FERMEROUVRIR

EXEESC

LAMPETESTE

D I S T A N C E

LOC


? LOCAL

REMOTE

SET

OPERATION

M

M

M

Drive control & monitoring

circuitry

SamplingAD-Conversion

Signal ProcessingSignal Filtering

Implementation of Intelligent Technology

COM 581

Process Bus

Interbay Bus

Intelligent SA Architecture


C

E

COM581


PIS

A

PIS

AA

PIS

AB

PIS

A

A

-Q1

-Q2

-Q51

-Q0 -T1 -Q9 -Q8




1


2

43

5678

9

1211

13141516

10



1


2

43

5678

9

1211

13141516

10



ABB

=D04 ABOBO 1

-Q2S E L

-Q1S E L

-Q0S E L

=W1

=W2

FERMEROUVRIR

EXEESC

LAMPETESTE

D I S T A N C E

LOC


? LOCAL

REMOTE

SET

OPERATION

M

M

M

Pro

cess

Lev

elB

ay L

evel

Sta

tion

Leve

l

Bas

ic F

unct

iona

lity

Bas

ic F

unct

iona

lity

FE

AT

UR

ES

AN

D B

EN

EF

ITS

FE

AT

UR

ES

AN

D B

EN

EF

ITS

Interbay Bus

GIS or AIS SwitchgearInstrument TransformersPower TransformersSurge Arresters

-Q1

-Q0 -Q8-Q9

-Q2

Functions Allocation


C

E

COM581





1


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Functional Structure Functions Allocation




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Busbar Protection

Switches

Process Bus

Sensors forcurrent &voltage measurement

Actuator forcircuit breakercontrol

Actuator forisolator & earthingswitch control

Intelligent SA: Control, Protection and Sensors




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IED Parameter

Station level supervisionSingle Line Diagram:

Diagnostic: Fault Recording and Evaluation

Automatic fault location printout

Remote Control via Network Control Centre (NCC)


Interoperability The ability for IED’s from one or several manufacturer to exchangeinformation and usethe information for the their own functions.

Long Term Stability The standard shall be future proof, i.e. it must be able to follow the progress in communication technologyas well as evolving system requirements.

Free Configuration The standard shall support different philosophiesand allow a free allocation of functions e.g. it will work equally well for centralized (RTU like) or decentralized (SCS like) systems.

The goal of the IEC 61850 standard


Documents

Generator Protection