generator protection reg650 product guide - abb ltd · generator-transformer unit protection ied...

Relion® 650 series

Generator protection REG650Product Guide

Contents

1. 650 series overview........................................................3

2. Application.....................................................................3

3. Available functions..........................................................6

4. Differential protection....................................................14

5. Impedance protection..................................................15

6. Current protection........................................................16

7. Voltage protection........................................................18

8. Frequency protection....................................................20

9. Secondary system supervision.....................................20

10. Control........................................................................21

11. Logic...........................................................................22

12. Monitoring...................................................................23

13. Metering......................................................................25

14. Human Machine interface............................................26

15. Basic IED functions.....................................................26

16. Station communication................................................27

17. Hardware description..................................................28

18. Connection diagrams Customized...............................30

19. Connection diagrams Configured................................35

20. Technical data.............................................................48

21. Ordering for Customized IED.......................................82

22. Ordering for Configured IED........................................86

23. Ordering for Accessories.............................................89

Disclaimer

The information in this document is subject to change without notice and should not be construed as a commitment by ABB. ABB assumes no responsibility for any

errors that may appear in this document.

© Copyright 2012 ABB.

All rights reserved.

Trademarks

ABB and Relion are registered trademarks of the ABB Group. All other brand or product names mentioned in this document may be trademarks or registered

trademarks of their respective holders.

Generator protection REG650 1MRK 502 045-BEN -

Product version: 1.2

2 ABB

1. 650 series overviewThe 650 series IEDs provide both customized andconfigured solutions. With the customized IEDsyou have the freedom to completely adapt thefunctionality according to your needs.

The 650 series IEDs provide optimum 'off-the-shelf', ready-to-use solutions. It is configured withcomplete protection functionality and defaultparameters to meet the needs of a wide range ofapplications for generation, transmission and sub-transmission grids.

The 650 series IEDs include:• Customized versions providing the possibility to

adapt the functionality to the application needs.• Configured solutions are completely ready to

use solutions optimized for a wide range ofapplications for generation, transmission andsub-transmission grids.

• Support for user-defined names in the locallanguage for signal and function engineering.

• Minimized parameter settings based on defaultvalues and ABB's new global base valueconcept. You only need to set thoseparameters specific to your own application,such as the line data.

• GOOSE messaging for horizontalcommunication.

• Extended HMI functionality with 15 dynamicthree-color-indication LEDs per page, on up tothree pages, and configurable push-buttonshortcuts for different actions.

• Programmable LED text-based labels.• Settable 1A/5A -rated current inputs.

2. ApplicationREG650 is used for the protection and monitoringof generating plants. The IED is especially suitablefor applications in distributed control systemswith high demands on reliability. It is intended

mainly for small and medium size generationstations.

REG670 may be used when more extensiveprotection systems are required or in combinationwith REG650 to provide redundant schemes.

A wide range of protection functions is availableto achieve full and reliable protection for differenttypes of generating plants, for example hydropower plants and thermal power plants. Thisenables adaptation to the protection requirementsof most generating plants.

Protection functions are available for detectingand clearing internal faults, such as generatorstator short circuits and earth faults, generatorrotor earth faults, unit transformer short circuitsand earth faults and faults in the external powersystem, fed from the generating plant.

Two packages have been defined for the followingapplications:

• Generator protection IED including generatordifferential protection (B01)

• Generator-transformer unit protection IEDincluding transformer differential protection(B05)

In many generating plants, the protection systemcan be designed with a combination of the twopackages, that is, two IEDs of either same type ordifferent types, will give redundant protection fora generating unit (generator and unit transformer)depending on the requirements for the plantdesign.

The packages are configured and ready for use.Analogue inputs and binary input/output circuitsare pre-defined.

The pre-configured IED can be changed andadapted with the graphical configuration tool.


Product version: 1.2 Issued: June 2012Revision: -

ABB 3

A, B, C or D

~

59N UN>

STEF PHIZ

59THD U3d/N

REG650-B01

TR PTTR

49 Ith

LEX PDIS

40

OEX PVPH

24 U/f>

UV2 PTUV

27 3U<

OV2 PTOV

59 3U>

OC4 PTOC

51 3I>

GEN PDIF

87G 3Id/I

SA PTUF

81U f<

110kV HV Substation

VR2 PVOC

51V I>/U<ZGCPDIS

21 Z<

AEG GAPC

50AE U

SA PTOF

81O f>YY

SDD RFUF

60FL

Note:1) Input for independent non-directional OC and overload functions. It can be used for different purposes (e.g. OC protection for either Auxiliary trafo or Excitation trafo or Step-up transformer HV side)

I

U

NS2 PTOC

46 I2>

OC4 PTOC

51 3I>

CC RPLD

52PD PD

CC RBRF

50BF 3I> BF

YY

Generator CB

AuxiliaryTransformer

UnitTransformer

29MVA121/11kV

YNd5

ExcitationTransformer

HV CB

ROV2 PTOV

59N 3Uo>

TR PTTR

49 Ith

OOS PPAM

78 Ucos

SES RSYN

25 SC

1)

2)

3)

3) Input for independent directional (sensitive) EF function. It can be used for different purposes. (e.g. as rotor EF with RXTTE4 or stator EF for generators operating in parallel)

Fiel

d C

B

HZ PDIF

87N IdN

2) Input for independent non-directional EF function. It can be used for different purposes (e.g. as stator EF protection or turn-to-turn protection for generators with split winding or even HV side EF protection). Alternatively it can be used for High-Impedance REF protection.

ROV2 PTOV

59N 3Uo>

CV MMXN

Meter.

GUP PDOP

32

GOP PDUP

37 P<

TRM module with 4I+1I*+5U AIM module with 6I+4U

¤)

¤) Requires dedicated CT cores, external resistor and metrosil for correct operation

V MSQI

47 U2>

EF4 PTOC

67N

SDE PSDE

67N

Rotor EF protection 64R

GUP PDOP

32Q

SA PFRC

81R df/dt

390kVA11/0.37kV

Dyn11

50/5

1600/5

1600/5

10/1

1.6MVA11/0.4kV

EF4 PTOC

51N IN>

11 0.11 0.11/ /

33 3kV

11 0.11 0.11/ /

33 3kV

11/ 0.11

3kV

200/1

100/52500/5

1000

29MVA11kV

150rpm

RX

TTE

4

D

C B

A

H J, G or H

200/5

G

Y200/1

J

C MSQI

Meter.

IEC10000299-2-en.vsd

Q

P

IN> IN> <

IEC61850

Function Enabled in Settings

Function Disabled in Settings

IEC61850 IEC61850IECANSI ANSI IEC

IEC10000299 V2 EN

Figure 1. Generator protection IED including generator differential protection (B01)



4 ABB

~

STEF PHIZ

59THD U3d/N

REG650-B05

LEX PDIS

40

GUP PDOP

32

OEX PVPH

24 U/f>

UV2 PTUV

27 3U<

OV2 PTOV

59 3U>

T3D PDIF

87T 3Id/I

SA PTUF

81U f<

110kV HV Substation

VR2 PVOC

51V I>/U<ZGCPDIS

21 Z<

AEG GAPC

50AE U

SA PTOF

81O f>YY

I

U

NS2 PTOC

46 I2>

OC4 PTOC

51 3I>

CC RPLD

52PD PD

CC RBRF

50BF 3I> BF

YY

Generator CB

HV CB

ROV2 PTOV

59N 3Uo>

TR PTTR

49 Ith

OOS PPAM

78 Ucos

SES RSYN

25 SC

Note:

2) Input for independent non-directional EF function. It can be used for different purposes (e.g. as stator EF protection or turn-to-turn protection for generators with split winding or even HV side EF protection). Alternatively it can be used for High-Impedance REF protection.

1) Inputs for independent directional (sensitive) EF function. It can be used for different purposes (e.g. as rotor EF with RXTTE4 or stator EF for generators running in parallel)

1)

2)

Fiel

d C

B

TR PTTR

49 Ith

OC4 PTOC

51 3I>

HZ PDIF

87N IdN

EF4 PTOC

51N IN>

GT01

ROV2 PTOV

59N 3Uo>

59N UN>

YY

CV MMXN

Meter.

GOP PDUP

37 P<

TRM module with 4I+1I*+5U AIM module with 6I+4U

¤)

¤) Requires dedicated CT cores, external resistor and metrosil for correct operation

V MSQI

47 U2>

EF4 PTOC

67N

SDE PSDE

67N

Rotor EF protection 64R

CV MMXN

Meter.

GOP PDOP

32Q

SA PFRC

81R df/dt

3)

3) Alternatively step-up transformer HV side open delta VT can be connected here

Generator CB

AuxiliaryTransformer

UnitTransformer

29MVA121/11kV

YNd5

ExcitationTransformer

390kVA11/0.37kV

Dyn11

50/5

1600/5

29MVA11kV

150rpm

200/1

100/5

1.6MVA11/0.4kV

11 0.11 0.11/ /

33 3kV

110 0.11 0.11/ /

33 3kV

11/ 0.11

3kV

2500/5

1000

RX

TTE

4

C

B

E

A

D

A or B

D or E

200/5

G

1600/5

10/1H J, G or H

Y200/1

J

SDD RFUF

60FL

C MSQI

Meter.


IN> IN>

Q

P

<

IEC61850

Function Disabled in Settings

IEC61850 IEC61850IECANSI ANSI IECANSI

Function Enabled in Settings

IEC10000300 V2 EN

Figure 2. Generator-transformer unit protection IED including transformer differential protection (B05)



ABB 5

3. Available functions

Main protection functions

IEC 61850/Function blockname

ANSI Function description Generator

RE

G65

0

RE

G65

0 (B

01)

Gen

diff

RE

G65

0 (B

05)

Gen

+T

rafo

diff

Differential protection

T3WPDIF 87T Transformer differential protection, three winding 0–1 1

HZPDIF 87 1Ph High impedance differential protection 1 1 1

GENPDIF 87G Generator differential protection 0–1 1

Impedance protection

ZGCPDIS 21G Underimpedance protection for generators andtransformers

0–1 1 1

LEXPDIS 40 Loss of excitation 0–1 1 1

OOSPPAM 78 Out-of-step protection 0–1 1 1

LEPDIS Load encroachment 0–1 1 1



6 ABB

Back-up protection functions

IEC 61850/Functionblock name


RE

G65

0

RE

G65

0 (B

01)

Gen

diff

RE

G65

0 (B

05)

Gen

+T

rafo

diff

Current protection

OC4PTOC 51 Four step phase overcurrent protection, 3–phaseoutput

0–2 2 2

EF4PTOC 51N/67N Four step residual overcurrent protection, zero/negative sequence direction

0–2 2 2

SDEPSDE 67N Sensitive directional residual overcurrent andpower protection

0–1 1 1

TRPTTR 49 Thermal overload protection, two time constants 0–2 2 2

CCRBRF 50BF Breaker failure protection, 3–phase activation andoutput

0–1 1 1

CCRPLD 52PD Pole discordance protection 0–1 1 1

GUPPDUP 37 Directional underpower protection 0–1 1 1

GOPPDOP 32 Directional overpower protection 0–2 2 2

AEGGAPC 50AE Accidental energizing protection for synchronousgenerator

0–1 1 1

NS2PTOC 46I2 Negative-sequence time overcurrent protection formachines

0–1 1 1

VR2PVOC 51V Voltage-restrained time overcurrent protection 0–1 1 1

Voltage protection

UV2PTUV 27 Two step undervoltage protection 0–1 1 1

OV2PTOV 59 Two step overvoltage protection 0–1 1 1

ROV2PTOV 59N Two step residual overvoltage protection 0–2 2 2

OEXPVPH 24 Overexcitation protection 0–1 1 1

STEFPHIZ 59THD 100% Stator earth fault protection, 3rd harmonicbased

0–1 1 1

- 64R Rotor earth protection with RXTTE4 injection unit 0–1 0–1 0–1

Frequency protection

SAPTUF 81 Underfrequency function 0–4 4 4

SAPTOF 81 Overfrequency function 0–4 4 4

SAPFRC 81 Rate-of-change frequency protection 0–2 2 2



ABB 7

Control and monitoring functions



RE

G65

0

RE

G65

0 (B

01)

Gen

diff

RE

G65

0 (B

05)

Gen

+T

rafo

diff

Control

SESRSYN 25 Synchrocheck, energizing check, andsynchronizing

0–1 1 1

QCBAY Bay control 1 1 1

LOCREM Handling of LR-switch positions 1 1 1

LOCREMCTRL LHMI control of Permitted Source To Operate(PSTO)

1 1 1

CBC1 Circuit breaker for 1CB 0–1 1

CBC2 Circuit breaker for 2CB 0–1 1

SLGGIO Logic Rotating Switch for function selectionand LHMI presentation

15 15 15

VSGGIO Selector mini switch extension 20 20 20

DPGGIO IEC 61850 generic communication I/Ofunctions double point

16 16 16

SPC8GGIO Single point generic control 8 signals 5 5 5

AUTOBITS AutomationBits, command function for DNP3.0 3 3 3

I103CMD Function commands for IEC60870-5-103 1 1 1

I103IEDCMD IED commands for IEC60870-5-103 1 1 1

I103USRCMD Function commands user defined forIEC60870-5-103

4 4 4

I103GENCMD Function commands generic forIEC60870-5-103

50 50 50

I103POSCMD IED commands with position and select forIEC60870-5-103

50 50 50

Secondary system supervision

SDDRFUF Fuse failure supervision 0–1 1 1

TCSSCBR Breaker close/trip circuit monitoring 3 3 3

Logic

SMPPTRC 94 Tripping logic, common 3–phase output 1–6 6 6

TMAGGIO Trip matrix logic 12 12 12

OR Configurable logic blocks, OR gate 283 283 283

INVERTER Configurable logic blocks, Inverter gate 140 140 140



8 ABB



RE

G65

0

RE

G65

0 (B

01)

Gen

diff

RE

G65

0 (B

05)

Gen

+T

rafo

diff

PULSETIMER Configurable logic blocks, Pulse timer 40 40 40

GATE Configurable logic blocks, Controllable gate 40 40 40

XOR Configurable logic blocks, exclusive OR gate 40 40 40

LOOPDELAY Configurable logic blocks, loop delay 40 40 40

TIMERSET Configurable logic blocks, timer function block 40 40 40

AND Configurable logic blocks, AND gate 280 280 280

SRMEMORY Configurable logic blocks, set-reset memoryflip-flop gate

40 40 40

RSMEMORY Configurable logic blocks, reset-set memoryflip-flop gate

40 40 40

FXDSIGN Fixed signal function block 1 1 1

B16I Boolean 16 to Integer conversion 16 16 16

B16IFCVI Boolean 16 to Integer conversion with logicnode representation

16 16 16

IB16A Integer to Boolean 16 conversion 16 16 16

IB16FCVB Integer to Boolean 16 conversion with logicnode representation

16 16 16

Monitoring

CVMMXN Measurements 6 6 6

CMMXU Phase current measurement 10 10 10

VMMXU Phase-phase voltage measurement 6 6 6

CMSQI Current sequence component measurement 6 6 6

VMSQI Voltage sequence measurement 6 6 6

VNMMXU Phase-neutral voltage measurement 6 6 6

AISVBAS Function block for service values presentationof the analog inputs

1 1 1

TM_P_P2 Function block for service values presentationof primary analog inputs 600TRM

1 1 1

AM_P_P4 Function block for service values presentationof primary analog inputs 600AIM

1 1 1

TM_S_P2 Function block for service values presentationof secondary analog inputs 600TRM

1 1 1

AM_S_P4 Function block for service values presentationof secondary analog inputs 600AIM

1 1 1



ABB 9



RE

G65

0

RE

G65

0 (B

01)

Gen

diff

RE

G65

0 (B

05)

Gen

+T

rafo

diff

CNTGGIO Event counter 5 5 5

DRPRDRE Disturbance report 1 1 1

AxRADR Analog input signals 4 4 4

BxRBDR Binary input signals 6 6 6

SPGGIO IEC 61850 generic communication I/O functions 64 64 64

SP16GGIO IEC 61850 generic communication I/Ofunctions 16 inputs

16 16 16

MVGGIO IEC 61850 generic communication I/O functions 16 16 16

MVEXP Measured value expander block 66 66 66

SPVNZBAT Station battery supervision 0–1 1 1

SSIMG 63 Insulation gas monitoring function 0–2 2 2

SSIML 71 Insulation liquid monitoring function 0–2 2 2

SSCBR Circuit breaker condition monitoring 0–1 1 1

I103MEAS Measurands for IEC60870-5-103 1 1 1

I103MEASUSR Measurands user defined signals forIEC60870-5-103

3 3 3

I103AR Function status auto-recloser forIEC60870-5-103

1 1 1

I103EF Function status earth-fault for IEC60870-5-103 1 1 1

I103FLTPROT Function status fault protection forIEC60870-5-103

1 1 1

I103IED IED status for IEC60870-5-103 1 1 1

I103SUPERV Supervison status for IEC60870-5-103 1 1 1

I103USRDEF Status for user defined signals forIEC60870-5-103

20 20 20

Metering

PCGGIO Pulse counter logic 16 16 16

ETPMMTR Function for energy calculation and demandhandling

3 3 3



10 ABB

Communication



RE

G65

0

RE

G65

0 (B

01)

Gen

diff

RE

G65

0 (B

05)

Gen

+T

rafo

diff

Station communication

IEC61850-8-1 IEC 61850 communication protocol 1 1 1

DNPGEN DNP3.0 for TCP/IP communication protocol 1 1 1

RS485DNP DNP3.0 for EIA-485 communicationprotocol

1 1 1

CH1TCP DNP3.0 for TCP/IP communication protocol 1 1 1




OPTICALDNP DNP3.0 for optical serial communication 1 1 1

MSTSERIAL DNP3.0 for serial communication protocol 1 1 1

MST1TCP DNP3.0 for TCP/IP communication protocol 1 1 1




RS485GEN RS485 1 1 1

OPTICALPROT Operation selection for optical serial 1 1 1

RS485PROT Operation selection for RS485 1 1 1

DNPFREC DNP3.0 fault records for TCP/IPcommunication protocol

1 1 1

OPTICAL103 IEC60870-5-103 Optical serialcommunication

1 1 1

RS485103 IEC60870-5-103 serial communication forRS485

1 1 1

GOOSEINTLKRCV Horizontal communication via GOOSE forinterlocking

59 59 59

GOOSEBINRCV GOOSE binary receive 4 4 4

ETHFRNTETHLAN1GATEWAY

Ethernet configuration of front port, LAN1port and gateway

1 1 1

GOOSEDPRCV GOOSE function block to receive a doublepoint value

32 32 32



ABB 11



RE

G65

0

RE

G65

0 (B

01)

Gen

diff

RE

G65

0 (B

05)

Gen

+T

rafo

diff

GOOSEINTRCV GOOSE function block to receive aninteger value

32 32 32

GOOSEMVRCV GOOSE function block to receive ameasurand value

16 16 16

GOOSESPRCV GOOSE function block to receive a singlepoint value

64 64 64



12 ABB

Basic IED functions


Function description

Basic functions included in all products

INTERRSIG Self supervision with internal event list 1

SELFSUPEVLST Self supervision with internal event list 1

TIMESYNCHGEN Time synchronization 1

SNTP Time synchronization 1

DTSBEGIN, DTSEND,TIMEZONE

Time synchronization, daylight saving 1

IRIG-B Time synchronization 1

SETGRPS Setting group handling 1

ACTVGRP Parameter setting groups 1

TESTMODE Test mode functionality 1

CHNGLCK Change lock function 1

TERMINALID IED identifiers 1

PRODINF Product information 1

SYSTEMTIME System time 1

RUNTIME IED Runtime comp 1

PRIMVAL Primary system values 1

SMAI_20_1 -SMAI_20_12

Signal matrix for analog inputs 2

3PHSUM Summation block 3 phase 12

GBASVAL Global base values for settings 6

ATHSTAT Authority status 1

ATHCHCK Authority check 1

SPACOMMMAP SPA communication mapping 1

FTPACCS FTP access with password 1

DOSFRNT Denial of service, frame rate control for front port 1

DOSLAN1 Denial of service, frame rate control for LAN1 1

DOSSCKT Denial of service, socket flow control 1

SAFEFILECOPY Safe file copy function 1

SPATD Date and time via SPA protocol 1

BCSCONF Basic communication system 1



ABB 13

4. Differential protection

Transformer differential protection T3WPDIFTransformer differential protection, three-winding(T3WPDIF) is provided with internal CT ratiomatching and vector group compensation andsettable zero sequence current elimination.

The function can be provided with -phase sets ofcurrent inputs. All current inputs are provided withpercentage bias restraint features, making the IEDsuitable for two- or three-winding transformerarrangements.

Three-winding applications

xx05000052.vsd

IEC05000052 V1 EN

three-winding powertransformer with allthree windingsconnected

xx05000049.vsd

IEC05000049 V1 EN

three-winding powertransformer withunconnected deltatertiary winding

Figure 3. CT group arrangement fordifferential protection and otherprotections

The setting facilities cover the applications of thedifferential protection to all types of powertransformers and auto-transformers with orwithout load tap changer as well as for shuntreactors and local feeders within the station. Anadaptive stabilizing feature is included for heavythrough-faults.

Stabilization is included for inrush currents as wellas for overexcitation conditions. Adaptivestabilization is also included for system recoveryinrush and CT saturation for external faults. A highset unrestrained differential current protection isincluded for a very high speed tripping at a highinternal fault currents.

An innovative sensitive differential protectionfeature, based on the theory of symmetricalcomponents, offers the best possible coveragefor power transformer winding turn-to-turn faults.

1Ph High impedance differential protectionHZPDIFThe 1Ph High impedance differential protection(HZPDIF) function can be used when the involvedCT cores have the same turns ratio and similarmagnetizing characteristics. It utilizes an externalsummation of the currents in the interconnectedCTs, a series resistor, and a voltage dependentresistor which are mounted externally connectedto the IED.

HZPDIF can be used as high impedance REFprotection.

Generator differential protection GENPDIFThe task of Generator differential protectionGENPDIF is to determine whether a fault is withinthe protected zone, or outside the protectedzone. If the fault is internal, the faulty generatormust be quickly tripped, that is, disconnectedfrom the network, the field breaker tripped andthe power to the prime mover interrupted.

To limit the damage due to stator winding shortcircuits, the fault clearance must be as fast aspossible (instantaneous). If the generator block isconnected to the power system close to othergenerating blocks, the fast fault clearance isessential to maintain the transient stability of thenon-faulted generators.

Normally, the short circuit fault current is verylarge, that is, significantly larger than thegenerator rated current. There is a risk that ashort circuit can occur between phases close tothe neutral point of the generator, thus causing arelatively small fault current. The fault current canalso be limited due to low excitation of thegenerator. Therefore, it is desired that thedetection of generator phase-to-phase shortcircuits shall be relatively sensitive, detectingsmall fault currents.

It is also of great importance that the generatordifferential protection does not trip for externalfaults, with large fault currents flowing from thegenerator. To combine fast fault clearance, aswell as sensitivity and selectivity, the generatordifferential protection is normally the best choicefor phase-to-phase generator short circuits. Anegative-sequence-current-based internal-external fault discriminator can also be used to



14 ABB

determine whether a fault is internal or external.The internal-external fault discriminator not onlypositively discriminates between internal andexternal faults, but can independently detectminor faults which may not be felt (until theydevelop into more serious faults) by the "usual"differential protection based on operate-restraincharacteristic.

An open CT circuit condition creates unexpectedoperations for Generator differential protectionunder the normal load conditions. It is alsopossible to damage secondary equipment due tohigh voltage produced from open CT circuitoutputs. Therefore, it may be a requirement fromsecurity and reliability points of view to have openCT detection function to block Generatordifferential protection function in case of open CTconditions and at the same time produce thealarm signal to the operational personal to makequick remedy actions to correct the open CTcondition.

Generator differential protection GENPDIF is alsowell suited to generate fast, sensitive andselective fault clearance, if used to protect shuntreactors or small busduct.

5. Impedance protection

Underimpedance protection for generators andtransformers ZGCPDISThe underimpedance protection for generatorsand transformers ZGCPDIS, has the offset mhocharacteristic as a three zone back-up protectionfor detection of phase-to-phase short circuits intransformers and generators. The three zoneshave independent measuring and settings thatgives high flexibility for all types of applications.

A load encroachment characteristic is availablefor the third zone as shown in figure 4.

en07000117.vsd

jX

Operation area Operation area

R

Operation area

No operation area No operation area

IEC07000117 V1 EN

Figure 4. Load encroachment influence on the offsetmho Z3 characteristic

Loss of excitation LEXPDISThere are limits for the low excitation of asynchronous machine. A reduction of theexcitation current weakens the coupling betweenthe rotor and the stator. The machine may losethe synchronism and start to operate like aninduction machine. Then, the reactive powerconsumption will increase. Even if the machinedoes not loose synchronism it may not beacceptable to operate in this state for a long time.Reduction of excitation increases the generationof heat in the end region of the synchronousmachine. The local heating may damage theinsulation of the stator winding and the iron core.

To prevent damages to the generator it should betripped when excitation becomes too low.

The impedance measurement is used forLEXPDIS function. Its operating characteristic isdesigned as two zone, offset mho circles and adirectional element restrain line.

Out-of-step protection OOSPPAMOut-of-step protection (OOSPPAM) function in theIED can be used both for generator protectionapplication as well as, line protection applications.

The main purpose of the OOSPPAM function is todetect, evaluate, and take the required actionduring pole slipping occurrences in the powersystem.



ABB 15

The OOSPPAM function detects pole slipconditions and trips the generator as fast aspossible, after the first pole-slip if the center ofoscillation is found to be in zone 1, whichnormally includes the generator and its step-uppower transformer. If the center of oscillation isfound to be further out in the power system, inzone 2, more than one pole-slip is usually allowedbefore the generator-transformer unit isdisconnected. If there are several out-of-steprelays in the power system, then the one whichfinds the center of oscillation in its zone 1 shouldoperate first.

Load encroachment LEPDISHeavy load transfer is common in many powernetworks and may make fault resistance coveragedifficult to achieve. In such a case, Loadencroachment (LEPDIS) function can be used toenlarge the resistive setting of theunderimpedance measuring zones withoutinterfering with the load.

6. Current protection

Four step phase overcurrent protection, 3-phaseoutput OC4PTOCThe four step phase overcurrent protectionfunction OC4PTOC has an inverse or definite timedelay independent for step 1 and 4 separately.Step 2 and 3 are always definite time delayed.

All IEC and ANSI inverse time characteristics areavailable.

The directional function is voltage polarized withmemory. The function can be set to be directionalor non-directional independently for each of thesteps.

A 2nd harmonic blocking can be set individuallyfor each step.

Four step residual overcurrent protection, zerosequence and negative sequence directionEF4PTOCThe four step residual overcurrent protection,zero or negative sequence direction (EF4PTOC)has a settable inverse or definite time delayindependent for step 1 and 4 separately. Step 2and 3 are always definite time delayed.

All IEC and ANSI inverse time characteristics areavailable.

EF4PTOC can be set directional or non-directional independently for each of the steps.

The directional part of the function can be set tooperate on following combinations:• Directional current (I3PDir) versus Polarizing

voltage (U3PPol)• Directional current (I3PDir) versus Polarizing

current (I3PPol)• Directional current (I3PDir) versus Dual

polarizing (UPol+ZPol x IPol) where ZPol = RPol+ jXPol

IDir, UPol and IPol can be independently selectedto be either zero sequence or negative sequence.

Second harmonic blocking restraint level can beset for the function and can be used to blockeach step individually.

Sensitive directional residual overcurrent andpower protection SDEPSDEIn isolated networks or in networks with highimpedance earthing, the earth fault current issignificantly smaller than the short circuit currents.In addition to this, the magnitude of the faultcurrent is almost independent on the fault locationin the network. The protection can be selected touse either the residual current or residual powercomponent 3U0·3I0·cos j, for operating quantity.

There is also available one non-directional 3I0step and one non-directional 3U0 overvoltage

tripping step.

Thermal overload protection, two time constantTRPTTRIf a power transformer or generator reaches veryhigh temperatures the equipment might bedamaged. The insulation within the transformer/generator will have forced ageing. As aconsequence of this the risk of internal phase-to-phase or phase-to-earth faults will increase. Hightemperature will degrade the quality of thetransformer/generator insulation.

The thermal overload protection estimates theinternal heat content of the transformer/generator(temperature) continuously. This estimation ismade by using a thermal model of the transformer/generator with two time constants, which isbased on current measurement.



16 ABB

Two warning levels are available. This enablesactions in the power system to be done beforedangerous temperatures are reached. If thetemperature continues to increase to the tripvalue, the protection initiates a trip of theprotected transformer/generator.

Breaker failure protection, 3-phase activation andoutputCCRBRF can be current based, contact based, oran adaptive combination of these two conditions.

Breaker failure protection, 3-phase activation andoutput (CCRBRF) ensures fast back-up tripping ofsurrounding breakers in case the own breakerfails to open. CCRBRF can be current based,contact based, or an adaptive combination ofthese two conditions.

Current check with extremely short reset time isused as check criterion to achieve high securityagainst unnecessary operation.

Contact check criteria can be used where thefault current through the breaker is small.

Breaker failure protection, 3-phase activation andoutput (CCRBRF) current criteria can be fulfilledby one or two phase currents the residual current,or one phase current plus residual current. Whenthose currents exceed the user defined settings,the function is triggered. These conditionsincrease the security of the back-up tripcommand.

CCRBRF function can be programmed to give athree-phase re-trip of the own breaker to avoidunnecessary tripping of surrounding breakers.

Pole discordance protection CCRPLDCircuit breakers and disconnectors can end upwith thes in different positions (close-open), dueto electrical or mechanical failures. An openphase can cause negative and zero sequencecurrents which cause thermal stress on rotatingmachines and can cause unwanted operation ofzero sequence or negative sequence currentfunctions.

Normally the own breaker is tripped to correctsuch a situation. If the situation persists thesurrounding breakers should be tripped to clearthe unsymmetrical load situation.

The pole discordance function operates based oninformation from the circuit breaker logic withadditional criteria from unsymmetrical phasecurrents when required.

Directional over/underpower protectionGOPPDOP/GUPPDUPThe directional over-/under-power protectionGOPPDOP/GUPPDUP can be used wherever ahigh/low active, reactive or apparent powerprotection or alarming is required. The functionscan alternatively be used to check the direction ofactive or reactive power flow in the power system.There are a number of applications where suchfunctionality is needed. Some of them are:

• detection of reversed active power flow• detection of high reactive power flow

Each function has two steps with definite timedelay. Reset times for both steps can be set aswell.

Accidental energizing protection for synchronousgenerator AEGGAPCInadvertent or accidental energizing of off-linegenerators has occurred often enough due tooperating errors, breaker head flashovers, controlcircuit malfunctions, or a combination of thesecauses. Inadvertently energized generatoroperates as induction motor drawing a largecurrent from the system. The voltage supervisedovercurrent protection is used to protect theinadvertently energized generator.

Accidental energizing protection for synchronousgenerator (AEGGAPC) takes the maximum phasecurrent input from the generator terminal side orfrom generator neutral side and maximum phaseto phase voltage inputs from the terminal side.AEGGAPC is enabled when the terminal voltagedrops below the specified voltage level for thepreset time.

Negative sequence time overcurrent protectionfor machines NS2PTOCNegative-sequence time overcurrent protectionfor machines NS2PTOC is intended primarily forthe protection of generators against possibleoverheating of the rotor caused by negativesequence current in the stator current.

The negative sequence currents in a generatormay, among others, be caused by:



ABB 17

• Unbalanced loads• Line to line faults• Line to earth faults• Broken conductors• Malfunction of one or more poles of a circuit

breaker or a disconnector

NS2PTOC can also be used as a backupprotection, that is, to protect the generator incase line protections or circuit breakers fail toclear unbalanced system faults.

To provide an effective protection for thegenerator for external unbalanced conditions,NS2PTOC is able to directly measure the negativesequence current. NS2PTOC also has a timedelay characteristic which matches the heating

characteristic of the generator 2

2I t K= as

defined in standard IEEE C50.13.

where:

I2 is negative sequence currentexpressed in per unit of the ratedgenerator current

t is operating time in seconds

K is a constant which depends ofthe generators size and design

NS2PTOC has a wide range of K settings and thesensitivity and capability of detecting and trippingfor negative sequence currents down to thecontinuous capability of a generator.

A separate output is available as an alarm featureto warn the operator of a potentially dangeroussituation.

Voltage-restrained time overcurrent protectionVR2PVOCVoltage-restrained time overcurrent protection(VR2PVOC) function is recommended as abackup protection for generators.

The overcurrent protection feature has a settablecurrent level that can be used either with definitetime or inverse time characteristic. Additionally, itcan be voltage controlled/restrained.

One undervoltage step with definite timecharacteristic is also available with the function inorder to provide funcionality for overcurrentprotection with undervoltage seal-in.

Rotor earth fault protectionGenerator rotor winding and its associated dcsupply electric circuit is typically fully insulatedfrom the earth. Therefore single connection of thiscircuit to earth will not cause flow of anysubstantial current. However, if second earth-faultappears in this circuit circumstances can be quitserious. Depending on the location of these twofaults such operating condition may cause:

• Partial or total generator loss of field• Large dc current flow through rotor magnetic

circuit• Rotor vibration• Rotor displacement sufficient to cause stator

mechanical damage

Therefore practically all bigger generators havesome dedicated protection which is capable todetect the first earth-fault in the rotor circuit andthen, depending on the fault resistance, either justto give an alarm to the operating personnel oractually to give stop command to the machine.An injection unit is required for rotor earth faultprotection (RXTTE4) and a protective resistor onplate for correct operation. Either SDEPSDE orEF4PTOC function can be used in conjunctionwith RXTTE4 as rotor earth-fault protection.

7. Voltage protection

Two step undervoltage protection UV2PTUVUndervoltages can occur in the power systemduring faults or abnormal conditions. Two stepundervoltage protection (UV2PTUV) function canbe used to open circuit breakers to prepare forsystem restoration at power outages or as long-time delayed back-up to primary protection.

UV2PTUV has two voltage steps, where step 1 issettable as inverse or definite time delayed. Step2 is always definite time delayed.

Two step overvoltage protection OV2PTOVOvervoltages may occur in the power systemduring abnormal conditions such as suddenpower loss, tap changer regulating failures, openline ends on long lines etc.

OV2PTOV has two voltage steps, where step 1can be set as inverse or definite time delayed.Step 2 is always definite time delayed.



18 ABB

OV2PTOV has an extremely high reset ratio toallow settings close to system service voltage.

Two step residual overvoltage protectionROV2PTOVResidual voltages may occur in the power systemduring earth faults.

Two step residual overvoltage protectionROV2PTOV function calculates the residualvoltage from the three-phase voltage inputtransformers or measures it from a single voltageinput transformer fed from an open delta orneutral point voltage transformer.

ROV2PTOV has two voltage steps, where step 1can be set as inverse or definite time delayed.Step 2 is always definite time delayed.

Overexcitation protection OEXPVPHWhen the laminated core of a power transformeror generator is subjected to a magnetic fluxdensity beyond its design limits, stray flux will flowinto non-laminated components not designed tocarry flux and cause eddy currents to flow. Theeddy currents can cause excessive heating andsevere damage to insulation and adjacent parts ina relatively short time. The function has settableinverse operating curves and independent alarmstages.

95% and 100% Stator earth fault protectionbased on 3rd harmonic STEFPHIZStator earth fault is a fault type having relativelyhigh fault rate. The generator systems normallyhave high impedance earthing, that is, earthingvia a neutral point resistor. This resistor isnormally dimensioned to give an earth faultcurrent in the range 3 – 15 A at a solid earth-faultdirectly at the generator high voltage terminal.The relatively small earth fault currents give muchless thermal and mechanical stress on thegenerator, compared to the short circuit case,which is between conductors of two phases.

Anyhow, the earth faults in the generator have tobe detected and the generator has to be tripped,even if longer fault time compared to internalshort circuits, can be allowed.

In normal non-faulted operation of the generatingunit the neutral point voltage is close to zero, andthere is no zero sequence current flow in thegenerator. When a phase-to-earth fault occursthe neutral point voltage will increase and therewill be a current flow through the neutral pointresistor.

To detect an earth fault on the windings of agenerating unit one may use a neutral pointovervoltage protection, a neutral point overcurrentprotection, a zero sequence overvoltageprotection or a residual differential protection.These protections are simple and have servedwell during many years. However, at best thesesimple schemes protect only 95% of the statorwinding. They leave 5% close to the neutral endunprotected. Under unfavorable conditions theblind zone may extend up to 20% from the neutral.

The 95% stator earth fault protection measuresthe fundamental frequency voltage component inthe generator star point and it operates when itexceeds the preset value. By applying thisprinciple approximately 95% of the stator windingcan be protected. In order to protect the last 5%of the stator winding close to the neutral end the3rd harmonic voltage measurement can beperformed. In 100% Stator E/F 3rd harmonicprotection either the 3rd harmonic voltagedifferential principle, the neutral point 3rdharmonic undervoltage principle or the terminalside 3rd harmonic overvoltage principle can beapplied. However, differential principle is stronglyrecommended. Combination of these twomeasuring principles provides coverage for entirestator winding against earth faults.



ABB 19

x E3

Rf

TCB 2(1-x) E3

overvoltage protection 10% – 100%

Differential0% – 30%

CB 1 may not exist

RN

NCB 1

stator winding

uTuN

x E3

Rf Transformer

TCB 2(1-x) E3

x

Neutral point fundamental frequency over-voltage protection 5% - 100%

3rd harmonic differential0% - 30%

CB 1 may not exist

1 or 100 %

RN

NNCB 1

stator winding

uTuN 1 - x1 - xSamples of the neutral voltage from which the

fundamental and 3rd harmonic voltages are filtered out

Samples of the terminal voltage from which the 3rd harmonic

voltage is filtered out


IEC10000202 V1 EN

Figure 5. Protection principles for STEFPHIZ function

8. Frequency protection

Underfrequency protection SAPTUFUnderfrequency occurs as a result of a lack ofsufficient generation in the network.

Underfrequency protection SAPTUF is used forload shedding systems, remedial action schemes,gas turbine startup and so on.

SAPTUF is also provided with undervoltageblocking.

Overfrequency protection SAPTOFOverfrequency protection function SAPTOF isapplicable in all situations, where reliabledetection of high fundamental power systemfrequency is needed.

Overfrequency occurs because of sudden loaddrops or shunt faults in the power network. Closeto the generating plant, generator governorproblems can also cause over frequency.

SAPTOF is used mainly for generation sheddingand remedial action schemes. It is also used as afrequency stage initiating load restoring.

SAPTOF is provided with an undervoltageblocking.

Rate-of-change frequency protection SAPFRCRate-of-change frequency protection function(SAPFRC) gives an early indication of a maindisturbance in the system. SAPFRC can be usedfor generation shedding, load shedding andremedial action schemes. SAPFRC candiscriminate between positive or negative changeof frequency.

SAPFRC is provided with an undervoltageblocking.

9. Secondary system supervision

Fuse failure supervision SDDRFUFThe aim of the fuse failure supervision function(SDDRFUF) is to block voltage measuringfunctions at failures in the secondary circuits



20 ABB

between the voltage transformer and the IED inorder to avoid unwanted operations thatotherwise might occur.

The fuse failure supervision function basically hasthree different algorithms, negative sequence andzero sequence based algorithms and anadditional delta voltage and delta currentalgorithm.

The negative sequence detection algorithm isrecommended for IEDs used in isolated or high-impedance earthed networks. It is based on thenegative-sequence measuring quantities, a highvalue of negative sequence voltage 3U2 without

the presence of the negative-sequence current3I2.

The zero sequence detection algorithm isrecommended for IEDs used in directly or lowimpedance earthed networks. It is based on thezero sequence measuring quantities, a high valueof zero sequence voltage 3U0 without the

presence of the zero sequence current 3I0.

For better adaptation to system requirements, anoperation mode setting has been introducedwhich makes it possible to select the operatingconditions for negative sequence and zerosequence based function. The selection ofdifferent operation modes makes it possible tochoose different interaction possibilities betweenthe negative sequence and zero sequence basedalgorithm.

A criterion based on delta current and deltavoltage measurements can be added to the fusefailure supervision function in order to detect athree phase fuse failure, which in practice is moreassociated with voltage transformer switchingduring station operations.

Breaker close/trip circuit monitoring TCSSCBRThe trip circuit supervision function TCSSCBR isdesigned to supervise the control circuit of thecircuit breaker. The invalidity of a control circuit isdetected by using a dedicated output contactthat contains the supervision functionality.

The function operates after a predefinedoperating time and resets when the faultdisappears.

10. Control

Synchrocheck, energizing check, andsynchronizing SESRSYNThe Synchronizing function allows closing ofasynchronous networks at the correct momentincluding the breaker closing time, whichimproves the network stability.

Synchrocheck, energizing check, andsynchronizing (SESRSYN) function checks thatthe voltages on both sides of the circuit breakerare in synchronism, or with at least one side deadto ensure that closing can be done safely.

SESRSYN function includes a built-in voltageselection scheme for double bus and 1½ breakeror ring busbar arrangements.

Manual closing as well as automatic reclosing canbe checked by the function and can have differentsettings.

For systems which are running asynchronous asynchronizing function is provided. The mainpurpose of the synchronizing function is toprovide controlled closing of circuit breakerswhen two asynchronous systems are going to beconnected. It is used for slip frequencies that arelarger than those for synchrocheck and lowerthan a set maximum level for the synchronizingfunction.

However this function can not be used toautomatically synchronize the generator to thenetwork.

Bay control QCBAYThe Bay control QCBAY function is used togetherwith Local remote and local remote controlfunctions to handle the selection of the operatorplace per bay. QCBAY also provides blockingfunctions that can be distributed to differentapparatuses within the bay.

Local remote LOCREM /Local remote controlLOCREMCTRLThe signals from the local HMI or from an externallocal/remote switch are applied via the functionblocks LOCREM and LOCREMCTRL to the Baycontrol (QCBAY) function block. A parameter infunction block LOCREM is set to choose if theswitch signals are coming from the local HMI or



ABB 21

from an external hardware switch connected viabinary inputs.

Circuit breaker control for circuit breakers, CBC1and CBC2The CBC1 and CBC2 consists of 3 functions each:

• SCILO - The Logical node for interlocking.SCILO function is used to enable a switchingoperation if the interlocking conditionspermit. SCILO function itself does notprovide any interlocking functionality. Theinterlocking conditions are generated inseparate function blocks containing theinterlocking logic.

• SCSWI - The Switch controller initializes andsupervises all functions to properly selectand operate switching primary apparatuses.The Switch controller may handle andoperate on one three-phase device.

• SXCBR - The purpose of SXCBR is toprovide the actual status of positions and toperform the control operations, that is, passall the commands to primary apparatuses inthe form of circuit breakers via output boardsand to supervise the switching operation andposition.

Logic rotating switch for function selection andLHMI presentation SLGGIOThe logic rotating switch for function selectionand LHMI presentation (SLGGIO) (or the selectorswitch function block) is used to get a selectorswitch functionality similar to the one provided bya hardware selector switch. Hardware selectorswitches are used extensively by utilities, in orderto have different functions operating on pre-setvalues. Hardware switches are however sourcesfor maintenance issues, lower system reliabilityand an extended purchase portfolio. The logicselector switches eliminate all these problems.

Selector mini switch VSGGIOThe Selector mini switch VSGGIO function blockis a multipurpose function used for a variety ofapplications, as a general purpose switch.

VSGGIO can be controlled from the menu or froma symbol on the single line diagram (SLD) on thelocal HMI.

IEC 61850 generic communication I/O functionsDPGGIOThe IEC 61850 generic communication I/Ofunctions (DPGGIO) function block is used tosend double indications to other systems orequipment in the substation. It is especially usedin the interlocking and reservation station-widelogics.

Single point generic control 8 signals SPC8GGIOThe Single point generic control 8 signals(SPC8GGIO) function block is a collection of 8single point commands, designed to bring incommands from REMOTE (SCADA) to those partsof the logic configuration that do not needextensive command receiving functionality (forexample, SCSWI). In this way, simple commandscan be sent directly to the IED outputs, withoutconfirmation. Confirmation (status) of the result ofthe commands is supposed to be achieved byother means, such as binary inputs and SPGGIOfunction blocks. The commands can be pulsed orsteady.

AutomationBits AUTOBITSThe Automation bits function (AUTOBITS) is usedto configure the DNP3 protocol commandhandling.

11. Logic

Tripping logic common 3-phase output SMPPTRCA function block for protection tripping isprovided for each circuit breaker involved in thetripping of the fault. It provides pulse prolongationto ensure a three-phase trip pulse of sufficientlength, as well as all functionality necessary forcorrect co-operation with autoreclosing functions.

The trip function block also includes functionalityfor breaker lock-out.

Trip matrix logic TMAGGIOThe Trip matrix logic TMAGGIO function is usedto route trip signals and other logical outputsignals to the tripping logics SMPPTRC andSPTPTRC or to different output contacts on theIED.

TMAGGIO output signals and the physical outputsallows the user to adapt the signals to thephysical tripping outputs according to the specificapplication needs.



22 ABB

Configurable logic blocksA number of logic blocks and timers are availablefor the user to adapt the configuration to thespecific application needs.

• OR function block.

• INVERTER function blocks that inverts the inputsignal.

• PULSETIMER function block can be used, forexample, for pulse extensions or limiting ofoperation of outputs, settable pulse time.

• GATE function block is used for whether or nota signal should be able to pass from the inputto the output.

• XOR function block.

• LOOPDELAY function block used to delay theoutput signal one execution cycle.

• TIMERSET function has pick-up and drop-outdelayed outputs related to the input signal. Thetimer has a settable time delay and must be Onfor the input signal to activate the output withthe appropriate time delay.

• AND function block.

• SRMEMORY function block is a flip-flop thatcan set or reset an output from two inputsrespectively. Each block has two outputs whereone is inverted. The memory setting controls ifthe block's output should reset or return to thestate it was, after a power interruption. The SETinput has priority if both SET and RESET inputsare operated simultaneously.

• RSMEMORY function block is a flip-flop thatcan reset or set an output from two inputsrespectively. Each block has two outputs whereone is inverted. The memory setting controls ifthe block's output should reset or return to thestate it was, after a power interruption. TheRESET input has priority if both SET andRESET are operated simultaneously.

Boolean 16 to Integer conversion B16IBoolean 16 to integer conversion function (B16I)is used to transform a set of 16 binary (logical)signals into an integer.

Boolean 16 to Integer conversion with logic noderepresentation B16IFCVIBoolean 16 to integer conversion with logic noderepresentation function (B16IFCVI) is used totransform a set of 16 binary (logical) signals intoan integer.

Integer to Boolean 16 conversion IB16AInteger to boolean 16 conversion function (IB16A)is used to transform an integer into a set of 16binary (logical) signals.

Integer to Boolean 16 conversion with logic noderepresentation IB16FCVBInteger to boolean conversion with logic noderepresentation function (IB16FCVB) is used totransform an integer to 16 binary (logic) signals.

IB16FCVB function can receive remote valuesover IEC61850 depending on the operatorposition input (PSTO).

12. Monitoring

IEC61850 generic communication I/O functionSPGGIOIEC61850 generic communication I/O functions(SPGGIO) is used to send one single logical signalto other systems or equipment in the substation.

IEC61850 generic communication 1/O function 16inputsIEC 61850 generic communication I/O functions16 inputs (SP16GGIO) function is used to send upto 16 logical signals to other systems orequipment in the substation.

Measurements CVMMXN, CMMXU, VNMMXU,VMMXU, CMSQI, VMSQIThe measurement functions are used to get on-line information from the IED. These servicevalues make it possible to display on-lineinformation on the local HMI and on theSubstation automation system about:

• measured voltages, currents, frequency,active, reactive and apparent power andpower factor

• primary and secondary phasors• current sequence components• voltage sequence components



ABB 23

Event counter CNTGGIOEvent counter (CNTGGIO) has six counters whichare used for storing the number of times eachcounter input has been activated.

Disturbance report DRPRDREComplete and reliable information aboutdisturbances in the primary and/or in thesecondary system together with continuous event-logging is accomplished by the disturbance reportfunctionality.

Disturbance report DRPRDRE, always included inthe IED, acquires sampled data of all selectedanalog input and binary signals connected to thefunction block with a, maximum of 40 analog and96 binary signals.

The Disturbance report functionality is a commonname for several functions:

• Event list• Indications• Event recorder• Trip value recorder• Disturbance recorder

The Disturbance report function is characterizedby great flexibility regarding configuration, startingconditions, recording times, and large storagecapacity.

A disturbance is defined as an activation of aninput to the AxRADR or BxRBDR function blocks,which are set to trigger the disturbance recorder.All signals from start of pre-fault time to the endof post-fault time will be included in the recording.

Every disturbance report recording is saved in theIED in the standard Comtrade format. The sameapplies to all events, which are continuouslysaved in a ring-buffer. The local HMI is used toget information about the recordings. Thedisturbance report files may be uploaded toPCM600 for further analysis using the disturbancehandling tool.

Event list DRPRDREContinuous event-logging is useful for monitoringthe system from an overview perspective and is acomplement to specific disturbance recorderfunctions.

The event list logs all binary input signalsconnected to the Disturbance report function. Thelist may contain up to 1000 time-tagged eventsstored in a ring-buffer.

Indications DRPRDRETo get fast, condensed and reliable informationabout disturbances in the primary and/or in thesecondary system it is important to know, forexample binary signals that have changed statusduring a disturbance. This information is used inthe short perspective to get information via thelocal HMI in a straightforward way.

There are three LEDs on the local HMI (green,yellow and red), which will display statusinformation about the IED and the Disturbancereport function (triggered).

The Indication list function shows all selectedbinary input signals connected to the Disturbancereport function that have changed status during adisturbance.

Event recorder DRPRDREQuick, complete and reliable information aboutdisturbances in the primary and/or in thesecondary system is vital, for example, time-tagged events logged during disturbances. Thisinformation is used for different purposes in theshort term (for example corrective actions) and inthe long term (for example functional analysis).

The event recorder logs all selected binary inputsignals connected to the Disturbance reportfunction. Each recording can contain up to 150time-tagged events.

The event recorder information is available for thedisturbances locally in the IED.

The event recording information is an integratedpart of the disturbance record (Comtrade file).

Trip value recorder DRPRDREInformation about the pre-fault and fault values forcurrents and voltages are vital for the disturbanceevaluation.

The Trip value recorder calculates the values of allselected analog input signals connected to theDisturbance report function. The result ismagnitude and phase angle before and during thefault for each analog input signal.



24 ABB

The trip value recorder information is available forthe disturbances locally in the IED.

The trip value recorder information is anintegrated part of the disturbance record(Comtrade file).

Disturbance recorder DRPRDREThe Disturbance recorder function supplies fast,complete and reliable information aboutdisturbances in the power system. It facilitatesunderstanding system behavior and relatedprimary and secondary equipment during andafter a disturbance. Recorded information is usedfor different purposes in the short perspective (forexample corrective actions) and long perspective(for example functional analysis).

The Disturbance recorder acquires sampled datafrom selected analog- and binary signalsconnected to the Disturbance report function(maximum 40 analog and 96 binary signals). Thebinary signals available are the same as for theevent recorder function.

The function is characterized by great flexibilityand is not dependent on the operation ofprotection functions. It can record disturbancesnot detected by protection functions. Up to threeseconds of data before the trigger instant can besaved in the disturbance file.

The disturbance recorder information for up to100 disturbances are saved in the IED and thelocal HMI is used to view the list of recordings.

Measured value expander block MVEXPThe current and voltage measurements functions(CVMMXN, CMMXU, VMMXU and VNMMXU),current and voltage sequence measurementfunctions (CMSQI and VMSQI) and IEC 61850generic communication I/O functions (MVGGIO)are provided with measurement supervisionfunctionality. All measured values can besupervised with four settable limits: low-low limit,low limit, high limit and high-high limit. Themeasure value expander block has beenintroduced to enable translating the integer outputsignal from the measuring functions to 5 binarysignals: below low-low limit, below low limit,normal, above high-high limit or above high limit.The output signals can be used as conditions inthe configurable logic or for alarming purpose.

Station battery supervision SPVNZBATThe station battery supervision functionSPVNZBAT is used for monitoring battery terminalvoltage.

SPVNZBAT activates the start and alarm outputswhen the battery terminal voltage exceeds the setupper limit or drops below the set lower limit. Atime delay for the overvoltage and undervoltagealarms can be set according to definite timecharacteristics.

In the definite time (DT) mode, SPVNZBAToperates after a predefined operate time andresets when the battery undervoltage orovervoltage condition disappears after reset time.

Insulation gas monitoring function SSIMGInsulation gas monitoring function SSIMG is usedfor monitoring the circuit breaker condition. Binaryinformation based on the gas pressure in thecircuit breaker is used as input signals to thefunction. In addition, the function generatesalarms based on received information.

Insulation liquid monitoring function SSIMLInsulation liquid monitoring function SSIML isused for monitoring the circuit breaker condition.Binary information based on the oil level in thecircuit breaker is used as input signals to thefunction. In addition, the function generatesalarms based on received information.

Circuit breaker monitoring SSCBRThe circuit breaker condition monitoring functionSSCBR is used to monitor different parameters ofthe circuit breaker. The breaker requiresmaintenance when the number of operations hasreached a predefined value. The energy iscalculated from the measured input currents as a

sum of Iyt values. Alarms are generated when thecalculated values exceed the threshold settings.

The function contains a blocking functionality. It ispossible to block the function outputs, if desired.

13. Metering

Pulse counter logic PCGGIOPulse counter (PCGGIO) function countsexternally generated binary pulses, for instance



ABB 25

pulses coming from an external energy meter, forcalculation of energy consumption values. Thepulses are captured by the BIO (binary input/output) module and then read by the PCGGIOfunction. A scaled service value is available overthe station bus.

Function for energy calculation and demandhandling ETPMMTROutputs from the Measurements (CVMMXN)function can be used to calculate energyconsumption. Active as well as reactive values arecalculated in import and export direction. Valuescan be read or generated as pulses. Maximumdemand power values are also calculated by thefunction.

14. Human Machine interface

Local HMI

IEC12000175 V1 EN

Figure 6. Local human-machine interface

The LHMI of the IED contains the followingelements:• Display (LCD)• Buttons• LED indicators• Communication port

The LHMI is used for setting, monitoring andcontrolling.

The Local human machine interface, LHMIincludes a graphical monochrome LCD with aresolution of 320x240 pixels. The character sizemay vary depending on selected language. Theamount of characters and rows fitting the viewdepends on the character size and the view thatis shown.

The LHMI is simple and easy to understand. Thewhole front plate is divided into zones, each witha well-defined functionality:

• Status indication LEDs• Alarm indication LEDs which can indicate

three states with the colors green, yellowand red, with user printable label. All LEDsare configurable from the PCM600 tool

• Liquid crystal display (LCD)• Keypad with push buttons for control and

navigation purposes, switch for selectionbetween local and remote control and reset

• Five user programmable function buttons• An isolated RJ45 communication port for

PCM600

15. Basic IED functions

Self supervision with internal event listThe Self supervision with internal event list(INTERRSIG and SELFSUPEVLST) function reactsto internal system events generated by thedifferent built-in self-supervision elements. Theinternal events are saved in an internal event list.

Time synchronizationUse a common global source for example GPStime synchronization inside each substation aswell as inside the area of the utility responsibilityto achieve a common time base for the IEDs in aprotection and control system. This makescomparison and analysis of events anddisturbance data between all IEDs in the powersystem possible.

Time-tagging of internal events and disturbancesare an excellent help when evaluating faults.Without time synchronization, only the eventswithin the IED can be compared to one another.With time synchronization, events anddisturbances within the entire station, and evenbetween line ends, can be compared duringevaluation.

In the IED, the internal time can be synchronizedfrom a number of sources:

• SNTP• IRIG-B• DNP• IEC60870-5-103

Parameter setting groups ACTVGRPUse the four different groups of settings tooptimize the IED operation for different power



26 ABB

system conditions. Creating and switchingbetween fine-tuned setting sets, either from thelocal HMI or configurable binary inputs, results ina highly adaptable IED that can cope with avariety of power system scenarios.

Test mode functionality TESTMODEThe protection and control IEDs may have manyincluded functions. To make the testingprocedure easier, the IEDs include the featurethat allows individual blocking of all functionsexcept the function(s) the shall be tested.

There are two ways of entering the test mode:

• By configuration, activating an input signal ofthe function block TESTMODE

• By setting the IED in test mode in the localHMI

While the IED is in test mode, all protectionfunctions are blocked.

Any function can be unblocked individuallyregarding functionality and event signaling. Thisenables the user to follow the operation of one orseveral related functions to check functionalityand to check parts of the configuration, and soon.

Change lock function CHNGLCKChange lock function (CHNGLCK) is used toblock further changes to the IED configurationand settings once the commissioning is complete.The purpose is to block inadvertent IEDconfiguration changes beyond a certain point intime.

Authority status ATHSTATAuthority status (ATHSTAT) function is anindication function block for user log-on activity.

Authority check ATHCHCKTo safeguard the interests of our customers, boththe IED and the tools that are accessing the IEDare protected, by means of authorizationhandling. The authorization handling of the IEDand the PCM600 is implemented at both accesspoints to the IED:

• local, through the local HMI• remote, through the communication ports

16. Station communication

IEC 61850-8-1 communication protocolThe IED supports the communication protocolsIEC 61850-8-1 and DNP3 over TCP/IP. Alloperational information and controls are availablethrough these protocols. However, somecommunication functions, for example, horizontalcommunication (GOOSE) between the IEDs, isonly enabled by the IEC 61850-8-1communication protocol.

The IED is equipped with an optical Ethernet rearport for the substation communication standardIEC 61850-8-1. IEC 61850-8-1 protocol allowsintelligent electrical devices (IEDs) from differentvendors to exchange information and simplifiessystem engineering. Peer-to-peer communicationaccording to GOOSE is part of the standard.Disturbance files uploading is provided.

Disturbance files are accessed using the IEC61850-8-1 protocol. Disturbance files areavailable to any Ethernet based application viaFTP in the standard Comtrade format. Further,the IED can send and receive binary values,double point values and measured values (forexample from MMXU functions), together withtheir quality bit, using the IEC 61850-8-1 GOOSEprofile. The IED meets the GOOSE performancerequirements for tripping applications insubstations, as defined by the IEC 61850standard. The IED interoperates with other IEC61850-compliant IEDs, tools, and systems andsimultaneously reports events to five differentclients on the IEC 61850 station bus.

The event system has a rate limiter to reduceCPU load. The event channel has a quota of 10events/second. If the quota is exceeded the eventchannel transmission is blocked until the eventchanges is below the quota, no event is lost.

All communication connectors, except for thefront port connector, are placed on integratedcommunication modules. The IED is connected toEthernet-based communication systems via thefibre-optic multimode LC connector (100BASE-FX).

The IED supports SNTP and IRIG-B timesynchronization methods with a time-stampingresolution of 1 ms.



ABB 27

• Ethernet based: SNTP and DNP3• With time synchronization wiring: IRIG-B

The IED supports IEC 60870-5-103 timesynchronization methods with a time stampingresolution of 5 ms.

Table 1. Supported station communication interfaces and protocols

Protocol Ethernet Serial

100BASE-FX LC Glass fibre (ST connector) EIA-485

IEC 61850–8–1 - -

DNP3

IEC 60870-5-103 - = Supported

Horizontal communication via GOOSE forinterlockingGOOSE communication can be used forexchanging information between IEDs via the IEC61850-8-1 station communication bus. This istypically used for sending apparatus positionindications for interlocking or reservation signalsfor 1-of-n control. GOOSE can also be used toexchange any boolean, integer, double point andanalog measured values between IEDs.

DNP3 protocolDNP3 (Distributed Network Protocol) is a set ofcommunications protocols used to communicatedata between components in process automationsystems. For a detailed description of the DNP3protocol, see the DNP3 Communication protocolmanual.

IEC 60870-5-103 communication protocolIEC 60870-5-103 is an unbalanced (master-slave)protocol for coded-bit serial communicationexchanging information with a control system,

and with a data transfer rate up to 19200 bit/s. InIEC terminology, a primary station is a master anda secondary station is a slave. Thecommunication is based on a point-to-pointprinciple. The master must have software that caninterpret IEC 60870-5-103 communicationmessages.

IEC 60870-5-103 protocol can be configured touse either the optical serial or RS485 serialcommunication interface on the COM05communication module. The functions Operationselection for optical serial (OPTICALPROT) andOperation selection for RS485 (RS485PROT) areused to select the communication interface.

The functions IEC60870-5-103 Optical serialcommunication (OPTICAL103) andIEC60870-5-103 serial communication for RS485(RS485103) are used to configure thecommunication parameters for either the opticalserial or RS485 serial communication interfaces.

17. Hardware description

Layout and dimensionsMounting alternativesThe following mounting alternatives are available(IP40 protection from the front):

• 19” rack mounting kit

See ordering for details about available mountingalternatives.



28 ABB

Rack mounting a single 3U IED

B

A C

D

IEC11000248 V1 EN

Figure 7. Rack mounted 3U IED

A 224 mm + 12 mm with ring-lug connectors

B 22.5 mm

C 482 mm

D 132 mm, 3U



ABB 29

18. Connection diagrams Customized

Connection diagrams for 650 series

IEC12000593 V1 EN

Figure 8. Designation for 3U, 1/1x19" casing with 1 TRM

IEC12000594 V1 EN

Figure 9. Designation for 3U, 1/1x19" casing with 1 TRM and 1 AIM



30 ABB

IEC12000595 V1 EN

Figure 10. Communication module (COM)



ABB 31

IEC12000596 V1 EN

Figure 11. Power supply module (PSM) 48-125V DC



32 ABB

IEC12000597 V1 EN

Figure 12. Power supply module (PSM) 110-250V DC, 100–240V AC

IEC12000598 V1 EN

Figure 13. Transformer module (TRM)



ABB 33

IEC12000599 V1 EN

Figure 14. Analog input (AIM)

IEC12000600 V1 EN

Figure 15. Binary input/output (BIO) option



34 ABB

19. Connection diagrams Configured

IEC12000497 V1 EN

Figure 16. Designation for 3U, 1/1x19" casing with 1 TRM and 1 AIM



ABB 35

Connection diagrams for REG650 B01

IEC12000498 V1 EN




36 ABB

IEC12000499 V1 EN




ABB 37

IEC12000500 V1 EN

Figure 19. Power supply module (PSM), 110-250V DC, 100–240V AC



38 ABB

IEC12000501 V1 EN




ABB 39

IEC12000502 V1 EN

Figure 21. Analog input module (AIM)



40 ABB

IEC12000503 V1 EN




ABB 41

Connection diagrams for REG650 B05

IEC12000505 V1 EN




42 ABB

IEC12000506 V1 EN




ABB 43

IEC12000507 V1 EN

Figure 25. Power supply module (PSM), 110-250V DC, 100–240V AC



44 ABB

IEC12000508 V1 EN




ABB 45

IEC12000509 V1 EN

Figure 27. Analog input module (AIM)



46 ABB

IEC12000510 V1 EN




ABB 47

20. Technical data

General

Definitions

Reference value The specified value of an influencing factor to which are referred the characteristics of the equipment

Nominal range The range of values of an influencing quantity (factor) within which, under specified conditions,the equipment meets the specified requirements

Operative range The range of values of a given energizing quantity for which the equipment, under specifiedconditions, is able to perform its intended functions according to the specified requirements

Energizing quantities, rated values and limitsAnalog inputs

Table 2. Energizing inputs

Description Value

Rated frequency 50/60 Hz

Operating range Rated frequency ± 5 Hz

Current inputs Rated current, In 0.1/0.5 A1) 1/5 A2)

Thermal withstand capability:

• Continuously 4 A 20 A

• For 1 s 100 A 500 A *)

• For 10 s 20 A 100 A

Dynamic current withstand:

• Half-wave value 250 A 1250 A

Input impedance <100 mΩ <20 mΩ

Voltage inputs Rated voltage, Un 100 V AC/ 110 V AC/ 115 V AC/ 120 V AC

Voltage withstand:

• Continuous 420 V rms

• For 10 s 450 V rms

Burden at rated voltage <0.05 VA

*) max. 350 A for 1 s when COMBITEST test switch is included.

1) Residual current2) Phase currents or residual current



48 ABB

Auxiliary AC and DC voltage

Table 3. Power supply

Description 600PSM02 600PSM03

Uauxnominal 48, 60, 110, 125 V DC 100, 110, 120, 220, 240 V AC, 50and 60 Hz

110, 125, 220, 250 V DC

Uauxvariation 80...120% of Un (38.4...150 V DC) 85...110% of Un (85...264 V AC)

80...120% of Un (88...300 V DC)

Maximum load of auxiliary voltagesupply

35 W for DC40 W for AC

Ripple in the DC auxiliary voltage Max 15% of the DC value (at frequency of 100 and 120 Hz)

Maximum interruption time in theauxiliary DC voltage without resettingthe IED

50 ms at Uaux

Binary inputs and outputs

Table 4. Binary inputs

Description Value

Operating range Maximum input voltage 300 V DC

Rated voltage 24...250 V DC

Current drain 1.6...1.8 mA

Power consumption/input <0.38 W

Threshold voltage 15...221 V DC (parametrizable in the range in steps of 1% ofthe rated voltage)

Table 5. Signal output and IRF output

IRF relay change over - type signal output relay

Description Value

Rated voltage 250 V AC/DC

Continuous contact carry 5 A

Make and carry for 3.0 s 10 A

Make and carry 0.5 s 30 A

Breaking capacity when the control-circuit time constant L/R<40 ms, at U< 48/110/220 V DC

≤0.5 A/≤0.1 A/≤0.04 A



ABB 49

Table 6. Power output relays without TCS function

Description Value

Rated voltage 250 V AC/DC





≤1 A/≤0.3 A/≤0.1 A

Table 7. Power output relays with TCS function

Description Value

Rated voltage 250 V DC





≤1 A/≤0.3 A/≤0.1 A

Control voltage range 20...250 V DC

Current drain through the supervision circuit ~1.0 mA

Minimum voltage over the TCS contact 20 V DC

Table 8. Ethernet interfaces

Ethernet interface Protocol Cable Data transfer rate

100BASE-TX - CAT 6 S/FTP or better 100 MBits/s

100BASE-FX TCP/IP protocol Fibre-optic cable with LCconnector

100 MBits/s

Table 9. Fibre-optic communication link

Wave length Fibre type Connector Permitted path

attenuation1)

Distance

1300 nm MM 62.5/125 μmglass fibre core

LC <8 dB 2 km

1) Maximum allowed attenuation caused by connectors and cable together



50 ABB

Table 10. X8/IRIG-B and EIA-485 interface

Type Protocol Cable

Screw terminal, pin rowheader

IRIG-B Shielded twisted pair cableRecommended: CAT 5, Belden RS-485 (9841- 9844) orAlpha Wire (Alpha 6222-6230)

Screw terminal, pin rowheader

Shielded twisted pair cableRecommended: DESCAFLEX RD-H(ST)H-2x2x0.22mm2,Belden 9729, Belden 9829

Table 11. IRIG-B

Type Value Accuracy

Input impedance 430 Ohm —

Minimum input voltageHIGH

4.3 V —

Maximum input voltageLOW

0.8 V —

Table 12. EIA-485 interface

Type Value Conditions

Minimum differential driveroutput voltage

1.5 V —

Maximum output current 60 mA —

Minimum differentialreceiver input voltage

0.2 V —

Supported bit rates 300, 600, 1200, 2400,4800, 9600, 19200, 38400,57600, 115200

—

Maximum number of 650IEDs supported on thesame bus

32 —

Max. cable length 925 m (3000 ft) Cable: AWG24 or better, stub lines shall be avoided

Table 13. Serial rear interface

Type Counter connector

Serial port (X9) Optical serial port, type ST for IEC 60870-5-103 and DNPserial



ABB 51

Table 14. Optical serial port (X9)

Wave length Fibre type Connector Permitted path attenuation1)

820 nm MM 62,5/125 µmglass fibre core

ST 6.8 dB (approx. 1700m length with 4 db / kmfibre attenuation)

820 nm MM 50/125 µm glassfibre core

ST 2.4 dB (approx. 600m length with 4 db / kmfibre attenuation)

1) Maximum allowed attenuation caused by fibre

Influencing factors

Table 15. Degree of protection of rack-mounted IED

Description Value

Front side IP 40

Rear side, connection terminals IP 20

Table 16. Degree of protection of the LHMI

Description Value

Front and side IP40

Table 17. Environmental conditions

Description Value

Operating temperature range -25...+55ºC (continuous)

Short-time service temperature range -40...+70ºC (<16h)Note: Degradation in MTBF and HMI performanceoutside the temperature range of -25...+55ºC

Relative humidity <93%, non-condensing

Atmospheric pressure 86...106 kPa

Altitude up to 2000 m

Transport and storage temperature range -40...+85ºC



52 ABB

Table 18. Environmental tests

Description Type test value Reference

Cold tests operation storage

96 h at -25ºC16 h at -40ºC 96 h at -40ºC

IEC 60068-2-1/ANSI C37.90-2005(chapter 4)

Dry heat tests operation storage

16 h at +70ºC 96 h at +85ºC

IEC 60068-2-2/ANSI C37.90-2005(chapter 4)

Damp heat tests steady state cyclic

240 h at +40ºChumidity 93% 6 cycles at +25 to +55ºChumidity 93...95%

IEC 60068-2-78 IEC 60068-2-30



ABB 53

Type tests according to standards

Table 19. Electromagnetic compatibility tests


100 kHz and 1 MHz burstdisturbance test

IEC 61000-4-18, level 3IEC 60255-22-1ANSI C37.90.1-2002

• Common mode 2.5 kV

• Differential mode 2.5 kV

Electrostatic discharge test IEC 61000-4-2, level 4IEC 60255-22-2ANSI C37.90.3-2001

• Contact discharge 8 kV

• Air discharge 15 kV

Radio frequency interference tests

• Conducted, common mode 10 V (emf), f=150 kHz...80 MHz IEC 61000-4-6 , level 3IEC 60255-22-6

• Radiated, amplitude-modulated 20 V/m (rms), f=80...1000 MHz andf=1.4...2.7 GHz

IEC 61000-4-3, level 3IEC 60255-22-3ANSI C37.90.2-2004

Fast transient disturbance tests IEC 61000-4-4IEC 60255-22-4, class AANSI C37.90.1-2002

• Communication ports 4 kV

• Other ports 4 kV

Surge immunity test IEC 61000-4-5, level 3/2IEC 60255-22-5

• Communication 1 kV line-to-earth

• Other ports 2 kV line-to-earth, 1 kV line-to-line

Power frequency (50 Hz) magneticfield

IEC 61000-4-8, level 5

• 3 s 1000 A/m

• Continuous 100 A/m

Pulse magnetic field immunity test 1000A/m IEC 61000–4–9, level 5

Power frequency immunity test IEC 60255-22-7, class AIEC 61000-4-16

• Common mode 300 V rms

• Differential mode 150 V rms



54 ABB

Table 19. Electromagnetic compatibility tests, continued


Voltage dips and short interruptionscon DC power supply

Dips:40%/200 ms70%/500 msInterruptions:0-50 ms: No restart0...∞ s : Correct behaviour at powerdown

IEC 60255-11IEC 61000-4-11

Voltage dips and interruptions on ACpower supply

Dips:40% 10/12 cycles at 50/60 Hz70% 25/30 cycles at 50/60 HzInterruptions:0–50 ms: No restart0...∞ s: Correct behaviour at powerdown

IEC 60255–11IEC 61000–4–11

Electromagnetic emission tests EN 55011, class AIEC 60255-25

• Conducted, RF-emission (mainsterminal)

0.15...0.50 MHz < 79 dB(µV) quasi peak< 66 dB(µV) average

0.5...30 MHz < 73 dB(µV) quasi peak< 60 dB(µV) average

• Radiated RF-emission

30...230 MHz < 40 dB(µV/m) quasi peak, measuredat 10 m distance

230...1000 MHz < 47 dB(µV/m) quasi peak, measuredat 10 m distance



ABB 55

Table 20. Insulation tests


Dielectric tests: IEC 60255-5ANSI C37.90-2005

• Test voltage 2 kV, 50 Hz, 1 min1 kV, 50 Hz, 1 min, communication

Impulse voltage test: IEC 60255-5ANSI C37.90-2005

• Test voltage 5 kV, unipolar impulses, waveform1.2/50 μs, source energy 0.5 J1 kV, unipolar impulses, waveform1.2/50 μs, source energy 0.5 J,communication

Insulation resistance measurements IEC 60255-5ANSI C37.90-2005

• Isolation resistance >100 MΏ, 500 V DC

Protective bonding resistance IEC 60255-27

• Resistance <0.1 Ώ (60 s)

Table 21. Mechanical tests

Description Reference Requirement

Vibration response tests (sinusoidal) IEC 60255-21-1 Class 2

Vibration endurance test IEC60255-21-1 Class 1

Shock response test IEC 60255-21-2 Class 1

Shock withstand test IEC 60255-21-2 Class 1

Bump test IEC 60255-21-2 Class 1

Seismic test IEC 60255-21-3 Class 2

Product safety

Table 22. Product safety

Description Reference

LV directive 2006/95/EC

Standard EN 60255-27 (2005)



56 ABB

EMC compliance

Table 23. EMC compliance

Description Reference

EMC directive 2004/108/EC

Standard EN 50263 (2000)EN 60255-26 (2007)



ABB 57

Table 24. Transformer differential protection T2WPDIF, T3WPDIF

Function Range or value Accuracy

Operating characteristic Adaptable ± 1.0% of Ir for I < Ir± 1.0% of I for I > Ir

Reset ratio >94% -

Unrestrained differential current limit (1.00-50.00)xIBase onhigh voltage winding

± 1.0% of set value

Base sensitivity function (0.05 - 0.60) x IBase ± 1.0% of Ir

Minimum negative sequence current (0.02 - 0.20) x IBase ± 1.0% of Ir

Operate angle, negative sequence (30.0 - 90.0) degrees ± 1.0 degrees

Second harmonic blocking (5.0-100.0)% offundamental differentialcurrent

± 2.0% of applied harmonic magnitude

Fifth harmonic blocking (5.0-100.0)% offundamental differentialcurrent

± 12.0% of applied harmonic magnitude

Connection type for each of the windings Y or D -

Phase displacement between high voltagewinding, W1 and each of the windings, W2and W3. Hour notation

0–11 -

Operate time, restrained function 25 ms typically at 0 to 5x set level

-

Reset time, restrained function 25 ms typically at 5 to 0x set level

-

Operate time, unrestrained function 20 ms typically at 0 to 5x set level

-

Reset time, unrestrained function 25 ms typically at 5 to 0x set level

-

Table 25. 1Ph High impedance differential protection HZPDIF


Operate voltage (20-400) VI=U/R

± 1.0% of Ir

Reset ratio >95% -

Maximum continuous power U>Trip2/SeriesResistor ≤200 W -

Operate time 10 ms typically at 0 to 10 x Ud -

Reset time 105 ms typically at 10 to 0 x Ud -

Critical impulse time 2 ms typically at 0 to 10 x Ud -



58 ABB

Table 26. Generator differential protection GENPDIF


Unrestrained differential current limit (1-50)p.u. of IBase ± 1.0% of set value

Reset ratio > 90% -

Base sensitivity function (0.05–1.00)p.u. of IBase ± 1.0% of Ir

Negative sequence current level (0.02–0.2)p.u. of IBase ± 1.0% of Ir

Operate time, restrained function 40 ms typically at 0 to 2x set level

-

Reset time, restrained function 40 ms typically at 2 to 0x set level

-

Operate time, unrestrained function 20 ms typically at 0 to 5x set level

-

Reset time, unrestrained function 40 ms typically at 5 to 0x set level

-

Operate time, negative sequenceunrestrained function

15 ms typically at 0 to 5x set level

-

Critical impulse time, unrestrained function 3 ms typically at 0 to 5x set level

-



ABB 59

Impedance protection

Table 27. Underimpedance protection for generators and transformers ZGCPDIS


Number of zones 3 -

Forward positive sequence impedance (0.005-3000.000) Ω/phase

± 2.0% static accuracyConditions:• Voltage range: (0.1-1.1) x Ur

• Current range: (0.5-30) x Ir• Angle: at 85 degrees

Reverse positive sequence impedance (0.005-3000.000) Ω/phase

-

Angle for positive sequence impedance, (10-90) degrees -

Timers (0.000-60.000) s ± 0.5% ± 10 ms

Operate time 25 ms typically -

Reset ratio 105% typically -

Table 28. Loss of excitation LEXPDIS


X offset of Mho top point (–1000.00–1000.00)% of ZBase ± 2.0% of Ur/Ir

Diameter of Mho circle (0.00–3000.00)% of ZBase ± 2.0% of Ur/Ir

Timers (0.00–6000.00) s ± 0.5% ± 25 ms

Operate time 55 ms typically —

Reset ratio 105% typically —

Table 29. Out-of-step protection OOSPPAM


Impedance reach (0.00–1000.00)% of Zbase ± 2.0% of Ur/Ir

Characteristic angle (72.00–90.00) degrees ± 5.0 degrees

Start and trip angles (0.0–180.0) degrees ± 5.0 degrees

Zone 1 and Zone 2 trip counters (1-20) -

Table 30. Load enchroachment LEPDIS


Load encroachment criteria:Load resistance, forward andreverseSafety load impedance angle

(1.00–3000.00) Ω/phase(5-85) degrees

± 5.0% static accuracy± 2.0 degrees static angular accuracyConditions:Voltage range: (0.1-1.1) x Ur

Current range: (0.5-30) x Ir

Reset ratio 105% typically -



60 ABB

Current protection

Table 31. Four step phase overcurrent protection, 3-phase output OC4PTOC

Function Setting range Accuracy

Operate current (5-2500)% of lBase ± 1.0% of Ir at I ≤ Ir± 1.0% of I at I > Ir

Reset ratio > 95% -

Min. operating current (1-10000)% of lBase ± 1.0% of Ir at I ≤ Ir±1.0% of I at I > Ir

2nd harmonic blocking (5–100)% of fundamental ± 2.0% of Ir

Independent time delay (0.000-60.000) s ± 0.5% ±25 ms

Minimum operate time forinverse characteristics

(0.000-60.000) s ± 0.5% ±25 ms

Inverse characteristics, seetable 72, table 73 and table 74

17 curve types 1) ANSI/IEEE C37.112IEC 60255–151±3% or ±40 ms0.10 ≤ k ≤ 3.001.5 x Iset ≤ I ≤ 20 x Iset

Operate time, nondirectionalstart function

25 ms typically at 0 to 2 x Iset -

Reset time, nondirectional startfunction


Operate time, directional startfunction


Reset time, directional startfunction


Critical impulse time 10 ms typically at 0 to 2 x Iset -

Impulse margin time 15 ms typically -

1) Note: Timing accuracy only valid when 2nd harmonic blocking is turned off



ABB 61

Table 32. Four step residual overcurrent protection EF4PTOC


Operate current (1-2500)% of lBase ± 1.0% of Ir at I < Ir± 1.0% of I at I > Ir

Reset ratio > 95% -

Operate current for directionalcomparison, Zero sequence

(1–100)% of lBase ± 2.0% of Ir

Operate current for directionalcomparison, Negative sequence

(1–100)% of lBase ± 2.0% of Ir

Min. operating current (1-10000)% of lBase ± 1.0% of Ir at I < Ir± 1.0% of I at I >Ir

Minimum operate time forinverse characteristics

(0.000-60.000) s ± 0.5% ± 25 ms

Timers (0.000-60.000) s ± 0.5% ±25 ms

Inverse characteristics, see table72, table 73 and table 74

17 curve types 1) ANSI/IEEE C37.112IEC 60255–151±3% or ±40 ms0.10 ≤ k ≤ 3.001.5 x Iset ≤ I ≤ 20 x Iset

Minimum polarizing voltage, Zerosequence

(1–100)% of UBase ± 0.5% of Ur

Minimum polarizing voltage,Negative sequence

(1–100)% of UBase ± 0.5% of Ur

Minimum polarizing current, Zerosequence

(2–100)% of IBase ±1.0% of Ir

Minimum polarizing current,Negative sequence

(2–100)% of IBase ±1.0% of Ir

Real part of source Z used forcurrent polarization

(0.50-1000.00) W/phase -

Imaginary part of source Z usedfor current polarization

(0.50–3000.00) W/phase -

Operate time, non-directionalstart function

30 ms typically at 0.5 to 2 x Iset -

Reset time, non-directional startfunction

30 ms typically at 2 to 0.5 x Iset -

Operate time, directional startfunction

30 ms typically at 0,5 to 2 x IN -

Reset time, directional startfunction

30 ms typically at 2 to 0,5 x IN -

1) Note: Timing accuracy only valid when 2nd harmonic blocking is turned off.



62 ABB

Table 33. Sensitive directional residual overcurrent and power protection SDEPSDE


Operate level for 3I0·cosj

directional residualovercurrent

(0.25-200.00)% of lBase At low setting:(2.5-10) mA(10-50) mA

± 1.0% of Ir at I £ Ir± 1.0% of I at I > Ir ±0.5 mA±1.0 mA

Operate level for 3I0·3U0 ·cosj directional residualpower

(0.25-200.00)% of SBase At low setting:(0.25-5.00)% of SBase

± 2.0% of Sr at S £ Sr

± 2.0% of S at S > Sr

± 10% of set value

Operate level for 3I0 and jresidual overcurrent


± 1.0% of Ir at £ Ir± 1.0% of I at I > Ir ±0.5 mA±1.0 mA

Operate level for non-directional overcurrent

(1.00-400.00)% of lBase At low setting:(10-50) mA

± 1.0% of Ir at I £ Ir± 1.0% of I at I > Ir ± 1.0 mA

Operate level for non-directional residualovervoltage

(1.00-200.00)% of UBase ± 0.5% of Ur at U£Ur

± 0.5% of U at U > Ur

Residual release current forall directional modes


± 1.0% of Ir at I £ Ir± 1.0% of I at I > Ir ±0.5 mA± 1.0 mA

Residual release voltage forall directional modes

(1.00 - 300.00)% of UBase ± 0.5% of Ur at U£Ur

± 0.5% of U at U > Ur

Reset ratio > 95% -

Timers (0.000-60.000) s ± 0.5% ±25 ms

Inverse characteristics, seetable 72, table 73 and table 74

17 curve types ANSI/IEEE C37.112IEC 60255–151+100 ms±(3% or 90 ms)0.10 ≤ k ≤ 3.001.5 x Iset ≤ I ≤ 20 x Iset

Relay characteristic angleRCA

(-179 to 180) degrees ± 2.0 degrees

Relay open angle ROA (0-90) degrees ± 2.0 degrees

Operate time, non-directionalresidual over current


Reset time, non-directionalresidual over current

90 ms typically at 1.2 to 0.5 x Iset -

Operate time, non-directionalresidual overvoltage

70 ms typically at 0.8 to 1.5 x Uset -



ABB 63

Table 33. Sensitive directional residual overcurrent and power protection SDEPSDE, continued


Reset time, non-directionalresidual overvoltage

120 ms typically at 1.2 to 0.8 x Uset -

Operate time, directionalresidual over current


Reset time, directionalresidual over current

170 ms typically at 2 to 0.5 x Iset -

Critical impulse time non-directional residual overcurrent

100 ms typically at 0 to 2 x Iset


--

Impulse margin time non-directional residual overcurrent

25 ms typically -

Table 34. Thermal overload protection, two time constants TRPTTR


Base current 1 and 2 (30–250)% of IBase ± 1.0% of Ir

Operate time:

2 2

2 2ln p

b

I It

I It

æ ö-ç ÷= ×ç ÷-è ø

EQUATION1356 V1 EN (Equation 1)

I = Imeasured

Ip = load current before overloadoccursTime constant τ = (1–500)minutes

IEC 60255–8, ±5% + 200 ms

Alarm level 1 and 2 (50–99)% of heat content tripvalue

± 2.0% of heat content trip

Operate current (50–250)% of IBase ± 1.0% of Ir

Reset level temperature (10–95)% of heat content trip ± 2.0% of heat content trip



64 ABB

Table 35. Breaker failure protection, 3-phase activation and output CCRBRF


Operate phase current (5-200)% of lBase ± 1.0% of Ir at I £ Ir± 1.0% of I at I > Ir

Reset ratio, phase current > 95% -

Operate residual current (2-200)% of lBase ± 1.0% of Ir at I £ Ir± 1.0% of I at I > Ir

Reset ratio, residual current > 95% -

Phase current level for blocking ofcontact function

(5-200)% of lBase ± 1.0% of Ir at I £ Ir± 1.0% of I at I > Ir

Reset ratio > 95% -

Timers (0.000-60.000) s ± 0.5% ±10 ms

Operate time for current detection 35 ms typically -

Reset time for current detection 10 ms maximum -

Table 36. Pole discordance protection CCRPLD


Operate value, currentasymmetry level

(0-100) % ± 1.0% of Ir

Reset ratio >95% -

Time delay (0.000-60.000) s ± 0.5% ± 25 ms

Table 37. Directional over/underpower protection GOPPDOP, GUPPDUP


Power level (0.0–500.0)% of SBase ± 1.0% of Sr at S < Sr

± 1.0% of S at S > Sr

(1.0-2.0)% of SBase < ± 50% of set value

(2.0-10)% of SBase < ± 20% of set value

Characteristic angle (-180.0–180.0) degrees 2 degrees

Timers (0.010 - 6000.000) s ± 0.5% ± 25 ms



ABB 65

Table 38. Accidental energizing protection for synchronous generator AEGGAPC


Operate value, overcurrent (2-900)% of IBase ± 1,0% of Ir at I<Ir± 1.0% of I at I>Ir

Reset ratio, overcurrent >95% -

Transient overreach, overcurrentfunction

<20% at τ = 100 ms -

Critical impulse time, overcurrent 10 ms typically at 0 to 2 x Iset -

Impulse margin time, overcurrent 15 ms typically -

Operate value, undervoltage (2-200)% of UBase ± 0.5% of Ur at U<Ur

± 0.5% of U at U>Ur

Critical impulse time, undervoltage 10 ms typically at 2 to 0 x Uset -

Impulse margin time, undervoltage 15 ms typically -

Operate value, overvoltage (2-200)% of UBase ± 0.5% of Ur at U<Ur

± 0.5% of U at U>Ur

Timers (0.000-60.000) s ± 0.5% ± 25 ms

Table 39. Negative sequence time overcurrent protection for machines NS2PTOC


Operate value, step 1 and 2, negativesequence overcurrent

(3-500)% of IBase ± 1.0% of Ir at I < Ir± 1.0% of I at I > Ir

Reset ratio, step 1 and 2 >95% -

Operate time, start 30 ms typically at 0 to 2 x Iset


-

Reset time, start 40 ms typically at 2 to 0 x Iset -

Time characteristics Definite or Inverse -

Inverse time characteristic step 1,2

2I t K=

K=1.0-99.0 ± 3% or ± 40 ms1 ≤ K ≤ 20

Reset time, inverse characteristic

step 1, 2

2I t K=

K=0.01-20.00 ± 10% or ± 50 ms1 ≤ K ≤ 20

Maximum trip delay, step 1 IDMT (0.00-6000.00) s ± 0.5% ± 25 ms

Minimum trip delay, step 1 IDMT (0.000-60.000) s ± 0.5% ± 25 ms

Timers (0.00-6000.00) s ± 0.5% ± 25 ms



66 ABB

Table 40. Voltage-restrained time overcurrent protectionVR2PVOC


Start overcurrent (2 - 5000)% of IBase ± 1.0% of Ir at I<Ir± 1.0% of I at I>Ir

Definite time delay (0.00 - 6000.00) s ± 0.5% ± 25 ms

Inverse characteristics, see table 72,table 73 and table 74

17 curves type ANSI/IEEE C37.112IEC 60255–151±3% or ±40 ms0.10 ≤ k ≤ 3.001.5 x Iset ≤ I ≤ 20 x Iset

Operate time start overcurrent 30 ms typically at 0 to 2 x Iset


-

Reset time start overcurrent 40 ms typically at 2 to 0 x Iset -

Start undervoltage (2.0 - 100.0)% of UBase ± 0.5% of Ur

Operate time start undervoltage 30 ms typically 2 to 0 x Uset -

Reset time start undervoltage 40 ms typically at 0 to 2 x Uset -

High voltage limit, voltage dependentoperation

(30 - 100)% of UBase ± 1.0% of Ur

Reset ratio, overcurrent > 95% -

Reset ratio, undervoltage < 105% -

Overcurrent:Critical impulse timeImpulse margin time


15 ms typically

-

Voltage protection

Table 41. Two step undervoltage protection UV2PTUV


Operate voltage, low and high step (1–100)% of UBase ± 0.5% of Ur

Reset ratio <105% -

Inverse time characteristics for lowand high step, see table 76

- See table 76

Definite time delay, step 1 (0.00 - 6000.00) s ± 0.5% ± 25 ms

Definite time delays, step 2 (0.000-60.000) s ± 0.5% ±25 ms

Minimum operate time, inversecharacteristics

(0.000–60.000) s ± 0.5% ± 25 ms

Operate time, start function 30 ms typically at 1.2 to 0.5 x Uset -

Reset time, start function 40 ms typically at 0.5 to 1.2 xUset -

Critical impulse time 10 ms typically at 1.2 to 0.8 x Uset -




ABB 67

Table 42. Two step overvoltage protection OV2PTOV


Operate voltage, low and high step (1-200)% of UBase ± 0.5% of Ur at U < Ur

± 0.5% of U at U > Ur

Reset ratio >95% -


- See table 75

Definite time delay, step 1 (0.00 - 6000.00) s ± 0.5% ± 25 ms

Definite time delays, step 2 (0.000-60.000) s ± 0.5% ± 25 ms

Minimum operate time, Inversecharacteristics

(0.000-60.000) s ± 0.5% ± 25 ms

Operate time, start function 30 ms typically at 0 to 2 x Uset -

Reset time, start function 40 ms typically at 2 to 0 x Uset -

Critical impulse time 10 ms typically at 0 to 2 x Uset -


Table 43. Two step residual overvoltage protection ROV2PTOV


Operate voltage, step 1 (1-200)% of UBase ± 0.5% of Ur at U < Ur

± 0.5% of U at U > Ur

Operate voltage, step 2 (1–100)% of UBase ± 0.5% of Ur at U < Ur

± 0.5% of U at U > Ur

Reset ratio >95% -


- See table 77

Definite time setting, step 1 (0.00–6000.00) s ± 0.5% ± 25 ms

Definite time setting, step 2 (0.000–60.000) s ± 0.5% ± 25 ms

Minimum operate time for step 1inverse characteristic

(0.000-60.000) s ± 0.5% ± 25 ms

Operate time, start function 30 ms typically at 0 to 2 x Uset -

Reset time, start function 40 ms typically at 2 to 0 x Uset -

Critical impulse time 10 ms typically at 0 to 1.2 xUset -




68 ABB

Table 44. Overexcitation protection OEXPVPH


Operate value, start (100–180)% of (UBase/frated) ± 0.5% of U

Operate value, alarm (50–120)% of start level ± 0.5% of Ur at U ≤ Ur

± 0.5% of U at U > Ur

Operate value, high level (100–200)% of (UBase/frated) ± 0.5% of U

Curve type IEEE

2

(0.18 ):

( 1)k

IEEE tM

×=

-

EQUATION1319 V1 EN (Equation 2)

where M = (E/f)/(Ur/fr)

± 5% + 40 ms

Minimum time delay for inversefunction

(0.000–60.000) s ± 0.5% ± 25 ms

Alarm time delay (0.000–60.000) s ± 0.5% ± 25 ms

Table 45. 100% Stator E/F 3rd harmonic STEFPHIZ


Fundamental frequency level UN(95% Stator EF)

(1.0–50.0)% of UBase ± 0.5% of Ur

Third harmonic differential level (0.5–10.0)% of UBase ± 5.0% of Ur

Third harmonic differential blocklevel

(0.1–10.0)% of UBase ± 5.0% of Ur

Timers (0.020–60.000) s ± 0.5% ± 25 ms

Filter characteristic:FundamentalThird harmonic

Reject third harmonic by 1–40Reject fundamental harmonic by1–40

-



ABB 69

Table 46. Under frequency protection SAPTUF


Operate value, start function (35.00-75.00) Hz ± 2.0 mHz

Operate value, restore frequency (45 - 65) Hz ± 2.0 mHz

Reset ratio <1.001 -

Operate time, start function At 50 Hz: 200 ms typically at fset +0.5 Hz tofset -0.5 HzAt 60 Hz: 170 ms typically at fset +0.5 Hz tofset -0.5 Hz

-

Reset time, start function At 50 Hz: 60 ms typically at fset -0.5 Hz to fset

+0.5 HzAt 60 Hz: 50 ms typically at fset -0.5 Hz to fset

+0.5 Hz

-

Operate time delay (0.000-60.000)s <250 ms

Restore time delay (0.000-60.000)s <150 ms

Table 47. Overfrequency protection SAPTOF


Operate value, start function (35.00-75.00) Hz ± 2.0 mHz atsymmetrical three-phase voltage

Reset ratio >0.999 -

Operate time, start function At 50 Hz: 200 ms typically at fset -0.5 Hz tofset +0.5 HzAt 60 Hz: 170 ms typically at fset -0.5 Hz tofset +0.5 Hz

-

Reset time, start function At 50 and 60 Hz: 55 ms typically at fset +0.5Hz to fset-0.5 Hz

-

Timer (0.000-60.000)s <250 ms

Table 48. Rate-of-change frequency protection SAPFRC


Operate value, start function (-10.00-10.00) Hz/s ± 10.0 mHz/s

Operate value, restore enable frequency (45.00 - 65.00) Hz ± 2.0 mHz

Timers (0.000 - 60.000) s <130 ms

Operate time, start function At 50 Hz: 100 ms typicallyAt 60 Hz: 80 ms typically

-



70 ABB


Table 49. Fuse failure supervision SDDRFUF


Operate voltage, zero sequence (1-100)% of UBase ± 1.0% of Ur

Operate current, zero sequence (1–100)% of IBase ± 1.0% of Ir

Operate voltage, negative sequence (1–100)% of UBase ± 0.5% of Ur

Operate current, negative sequence (1–100)% of IBase ± 1.0% of Ir

Operate voltage change level (1–100)% of UBase ± 5.0% of Ur

Operate current change level (1–100)% of IBase ± 5.0% of Ir

Operate phase voltage (1-100)% of UBase ± 0.5% of Ur

Operate phase current (1-100)% of IBase ± 1.0% of Ir

Operate phase dead line voltage (1-100)% of UBase ± 0.5% of Ur

Operate phase dead line current (1-100)% of IBase ± 1.0% of Ir

Table 50. Breaker close/trip circuit monitoring TCSSCBR


Operate time delay (0.020 - 300.000) s ± 0,5% ± 110 ms



ABB 71

Control

Table 51. Synchronizing, synchrocheck and energizing check SESRSYN


Phase shift, jline - jbus (-180 to 180) degrees -

Voltage ratio, Ubus/Uline 0.500 - 2.000 -

Reset ratio, synchrocheck > 95% -

Frequency difference limit between bus andline for synchrocheck

(0.003-1.000) Hz ± 2.0 mHz

Phase angle difference limit between bus andline for synchrocheck

(5.0-90.0) degrees ± 2.0 degrees

Voltage difference limit between bus and linefor synchronizing and synchrocheck

0.03-0.50 p.u ± 0.5% of Ur

Time delay output for synchrocheck (0.000-60.000) s ± 0.5% ± 25 ms

Frequency difference minimum limit forsynchronizing

(0.003-0.250) Hz ± 2.0 mHz

Frequency difference maximum limit forsynchronizing

(0.050-0.500) Hz ± 2.0 mHz

Maximum allowed frequency rate of change (0.000-0.500) Hz/s ± 10.0 mHz/s

Closing time of the breaker (0.000-60.000) s ± 0.5% ± 10 ms

Breaker closing pulse duration (0.000-60.000) s ± 0.5% ± 10 ms

tMaxSynch, which resets synchronizingfunction if no close has been made before settime

(0.000-60.000) s ± 0.5% ± 10 ms

Minimum time to accept synchronizingconditions

(0.000-60.000) s ± 0.5% ± 10 ms

Frequency difference minimum limit forsynchronizing

(0.003-0.250) Hz ± 2.0 mHz

Frequency difference maximum limit forsynchronizing

(0.050-0.500) Hz ± 2.0 mHz

Closing time of the breaker (0.000-60.000) s ± 0.5% ± 10 ms

Breaker closing time duration (0.050-60.000) s ± 0.5% ± 10 ms

tMaxSynch, which resets synchronizingfunction if no close has been made before settime

(0.00-6000.00) s ± 0.5% ± 10 ms

Time delay output for energizing check (0.000-60.000) s ± 0.5% ± 10 ms

Operate time for synchrocheck function 160 ms typically -

Operate time for energizing function 80 ms typically -

Minimum time to accept synchronizingconditions

(0.000-60.000) s ± 0.5% ± 10 ms

Maximum allowed frequency rate of change (0.000-0.500) Hz/s ± 10.0 mHz/s



72 ABB

Logic

Table 52. Tripping logic common 3-phase output SMPPTRC


Trip action 3-ph -

Timers (0.000-60.000) s ± 0.5% ± 10 ms

Table 53. Configurable logic blocks

Logic block Quantity with cycle time Range or value Accuracy

5 ms 20 ms 100 ms

AND 60 60 160 - -

OR 60 60 160 - -

XOR 10 10 20 - -

INVERTER 30 30 80 - -

SRMEMORY 10 10 20 - -

RSMEMORY 10 10 20 - -

GATE 10 10 20 - -

PULSETIMER 10 10 20 (0.000–90000.000) s ± 0.5% ± 25 ms for20 ms cycle time

TIMERSET 10 10 20 (0.000–90000.000) s ± 0.5% ± 25 ms for20 ms cycle time

LOOPDELAY 10 10 20



ABB 73

Monitoring

Table 54. Technical datacovering measurement functions:CVMMXN, CMMXU, VMMXU, CMSQI, VMSQI, VNMMXU


Voltage (0.1-1.5) ×Ur ± 0.5% of Ur at U£Ur

± 0.5% of U at U > Ur

Connected current (0.2-4.0) × Ir ± 0.5% of Ir at I £ Ir± 0.5% of I at I > Ir

Active power, P 0.1 x Ur Sr

Reactive power, Q 0.1 x Ur Sr

Apparent power, S 0.1 x Ur Sr

Apparent power, S Three phasesettings

cos phi = 1 ± 0.5% of S at S > Sr

± 0.5% of Sr at S ≤ Sr

Power factor, cos (φ) 0.1 x Ur < U < 1.5 x Ur

0.2 x Ir< I < 4.0 x Ir< 0.02

Table 55. Event counter CNTGGIO


Counter value 0-10000 -

Max. count up speed 10 pulses/s -



74 ABB

Table 56. Disturbance report DRPRDRE


Current recording - ± 1,0% of Ir at I ≤ Ir± 1,0% of I at I > Ir

Voltage recording - ± 1,0% of Ur at U ≤ Ur

± 1,0% of U at U > Ur

Pre-fault time (0.05–3.00) s -

Post-fault time (0.1–10.0) s -

Limit time (0.5–8.0) s -

Maximum number of recordings 100, first in - first out -

Time tagging resolution 1 ms See time synchronizationtechnical data

Maximum number of analog inputs 30 + 10 (external + internallyderived)

-

Maximum number of binary inputs 96 -

Maximum number of phasors in the Trip Valuerecorder per recording

30 -

Maximum number of indications in a disturbance report 96 -

Maximum number of events in the Event recording perrecording

150 -

Maximum number of events in the Event list 1000, first in - first out -

Maximum total recording time (3.4 s recording timeand maximum number of channels, typical value)

340 seconds (100 recordings) at50 Hz, 280 seconds (80recordings) at 60 Hz

-

Sampling rate 1 kHz at 50 Hz1.2 kHz at 60 Hz

-

Recording bandwidth (5-300) Hz -

Table 57. Event list DRPRDRE

Function Value

Buffer capacity Maximum number of events in the list 1000

Resolution 1 ms

Accuracy Depending on time synchronizing

Table 58. Indications DRPRDRE

Function Value

Buffer capacity Maximum number of indications presented for singledisturbance

96

Maximum number of recorded disturbances 100



ABB 75

Table 59. Event recorder DRPRDRE

Function Value

Buffer capacity Maximum number of events in disturbance report 150

Maximum number of disturbance reports 100

Resolution 1 ms

Accuracy Depending on timesynchronizing

Table 60. Trip value recorder DRPRDRE

Function Value

Buffer capacity

Maximum number of analog inputs 30


Table 61. Disturbance recorder DRPRDRE

Function Value

Buffer capacity Maximum number of analog inputs 40

Maximum number of binary inputs 96


Maximum total recording time (3.4 s recording time and maximum numberof channels, typical value)

340 seconds (100 recordings) at 50 Hz280 seconds (80 recordings) at 60 Hz

Table 62. Station battery supervision SPVNZBAT


Lower limit for the battery terminalvoltage

(60-140) % of Ubat ± 1.0% of set battery voltage

Reset ratio, lower limit <105 % -

Upper limit for the battery terminalvoltage

(60-140) % of Ubat ± 1.0% of set battery voltage

Reset ratio, upper limit >95 % -

Timers (0.000-60.000) s ± 0.5% ± 110 ms

Table 63. Insulation gas monitoring function SSIMG


Pressure alarm 0.00-25.00 -

Pressure lockout 0.00-25.00 -

Temperature alarm -40.00-200.00 -

Temperature lockout -40.00-200.00 -

Timers (0.000-60.000) s ± 0.5% ± 110 ms



76 ABB

Table 64. Insulation liquid monitoring function SSIML


Alarm, oil level 0.00-25.00 -

Oil level lockout 0.00-25.00 -

Temperature alarm -40.00-200.00 -

Temperature lockout -40.00-200.00 -

Timers (0.000-60.000) s ± 0.5% ± 110 ms

Table 65. Circuit breaker condition monitoring SSCBR


Alarm levels for open and close traveltime

(0-200) ms ± 0.5% ± 25 ms

Alarm levels for number of operations (0 - 9999) -

Setting of alarm for spring chargingtime

(0.00-60.00) s ± 0.5% ± 25 ms

Time delay for gas pressure alarm (0.00-60.00) s ± 0.5% ± 25 ms

Time delay for gas pressure lockout (0.00-60.00) s ± 0.5% ± 25 ms

Metering

Table 66. Pulse counter PCGGIO

Function Setting range Accuracy

Cycle time for report of countervalue

(1–3600) s -

Table 67. Function for energy calculation and demand handling ETPMMTR


Energy metering MWh Export/Import, MVArhExport/Import

Input from MMXU. No extra error at steady load



ABB 77

Station communication

Table 68. Communication protocol

Function Value

Protocol TCP/IP Ethernet

Communication speed for the IEDs 100 Mbit/s

Protocol IEC 61850–8–1

Communication speed for the IEDs 100BASE-FX

Protocol DNP3.0/TCP

Communication speed for the IEDs 100BASE-FX

Protocol, serial IEC 60870–5–103

Communication speed for the IEDs 9600 or 19200 Bd

Protocol, serial DNP3.0

Communication speed for the IEDs 300–19200 Bd

HardwareIED

Table 69. Degree of protection of rack-mounted IED

Description Value

Front side IP 40

Rear side, connection terminals IP 20

Table 70. Degree of protection of the LHMI

Description Value

Front and side IP40

Dimensions

Table 71. Dimensions of the IED - 3U full 19" rack

Description Value

Width 442 mm (17.40 inches)

Height 132 mm (5.20 inches), 3U

Depth 249.5 mm (9.82 inches)

Weight box 10 kg (<22.04 lbs)

Weight LHMI 1.3 kg (2.87 lbs)



78 ABB

Inverse time characteristics

Table 72. ANSI Inverse time characteristics


Operating characteristic:

( )1= + ×

-

æ öç ÷ç ÷è ø

P

At B k

I

EQUATION1249-SMALL V1 EN

I = Imeasured/Iset

k = (0.05-999) in steps of 0.01 -

ANSI Extremely Inverse A=28.2, B=0.1217, P=2.0

ANSI Very inverse A=19.61, B=0.491, P=2.0

ANSI Normal Inverse A=0.0086, B=0.0185, P=0.02, tr=0.46

ANSI Moderately Inverse A=0.0515, B=0.1140, P=0.02

ANSI Long Time Extremely Inverse A=64.07, B=0.250, P=2.0

ANSI Long Time Very Inverse A=28.55, B=0.712, P=2.0

ANSI Long Time Inverse A=0.086, B=0.185, P=0.02

Table 73. IEC Inverse time characteristics


Operating characteristic:

( )1= ×

-

æ öç ÷ç ÷è ø

P

At k

I


I = Imeasured/Iset

k = (0.05-999) in steps of 0.01 -

IEC Normal Inverse A=0.14, P=0.02

IEC Very inverse A=13.5, P=1.0

IEC Inverse A=0.14, P=0.02

IEC Extremely inverse A=80.0, P=2.0

IEC Short time inverse A=0.05, P=0.04

IEC Long time inverse A=120, P=1.0



ABB 79

Table 74. RI and RD type inverse time characteristics


RI type inverse characteristic

1

0.2360.339

= ×

-

t k

IEQUATION1137-SMALL V1 EN

I = Imeasured/Iset

k = (0.05-999) in steps of 0.01

RD type logarithmic inverse characteristic

5.8 1.35= - ×æ öç ÷è ø

tI

Ink


I = Imeasured/Iset

k = (0.05-999) in steps of 0.01

Table 75. Inverse time characteristics for overvoltage protection


Type A curve:

=- >

>

æ öç ÷è ø

tk

U U

U


U> = Uset

U = Umeasured

k = (0.05-1.10) in steps of 0.01 ±5% +60 ms

Type B curve:

2.0

480

32 0.5 0.035

=×

- >× - -

>

æ öç ÷è ø

tk

U U

U


k = (0.05-1.10) in steps of 0.01

Type C curve:

3.0

480

32 0.5 0.035

=×

- >× - -

>

æ öç ÷è ø

tk

U U

U


k = (0.05-1.10) in steps of 0.01



80 ABB

Table 76. Inverse time characteristics for undervoltage protection


Type A curve:

=< -

<

æ öç ÷è ø

kt

U U

UEQUATION1431-SMALL V1 EN

U< = Uset

U = UVmeasured

k = (0.05-1.10) in steps of 0.01 ±5% +60 ms

Type B curve:

2.0

4800.055

32 0.5

×= +

< -× -

<

æ öç ÷è ø

kt

U U

U


U< = Uset

U = Umeasured

k = (0.05-1.10) in steps of 0.01

Table 77. Inverse time characteristics for residual overvoltage protection


Type A curve:

=- >

>

æ öç ÷è ø

tk

U U

U


U> = Uset

U = Umeasured

k = (0.05-1.10) in steps of0.01

±5% +70 ms

Type B curve:

2.0

480

32 0.5 0.035

=×

- >× - -

>

æ öç ÷è ø

tk

U U

U


k = (0.05-1.10) in steps of0.01

Type C curve:

3.0

480

32 0.5 0.035

=×

- >× - -

>

æ öç ÷è ø

tk

U U

U


k = (0.05-1.10) in steps of0.01



ABB 81

21. Ordering for Customized IED

Guidelines

Carefully read and follow the set of rules to ensure problem-free order management. Be aware that certain functionscan only be ordered in combination with other functions and that some functions require specific hardware selections.

Product specification

Basic IED 650 platform and common functions housed in 3U 1/1 sized 19” casing

REG650 Quantity: 1MRK 006 526-AC

Option:

Customer specific configuration On request

Connection type for Analog modules

Rule: One connection type must be selected

Compression terminals 1MRK 002 960-CA

Ring lug terminals 1MRK 002 960-DA

Connection type for Power supply, Input/Output and communication modules

Rule: One connection type must be selected

Compression terminals 1MRK 002 960-EA

Ring lug terminals 1MRK 002 960-FA

Power supply module

Rule: One Power supply module must be specified

Power supply module(PSM) 48-125 VDC 1KHL178073R0001

110-250 VDC, 100–240V AC 1KHL178082R0001


Rule: One and only one of Transformer differential protection or Generator differential protection must be ordered

Transformer differential protection, three winding (T3WPDIF) Qty: 1MRK 004 904-BB

Generator differential protection (GENPDIF) Qty: 1MRK 004 904-EA

Control

Rule: One and only one of Circuit breaker must be ordered

Circuit breaker for 1 CB (CBC1) Qty: 1MRK 004 918-AA

Circuit breaker for 2 CB (CBC2) Qty: 1MRK 004 918-BA



82 ABB

Logic

Rule: One Tripping logic must be ordered

Tripping logic, common 3–phase output (SMPPTRC)

Qty:

1 2 3 4 5 6 1MRK 004 922-AA

Optional functionsImpedance protection

Underimpedance protection for generators andtransformers (ZGCPDIS )

Qty: 1MRK 004 906–SA

Loss of excitation (LEXPDIS) Qty: 1MRK 004 906-LA

Out-of-step protection (OOSPPAM ) Qty: 1MRK 004 906-MA

Load enchroachment (LEPDIS) Qty: 1MRK 004 906-NA

Current protection

Four step phase overcurrent protection, 3–phase output(OC4PTOC)

Qty:

1 2 1MRK 004 908-BB

Four step residual overcurrent protection, zero/negativesequence direction (EF4PTOC)

Qty:

1 2 1MRK 004 908-FA

Sensitive directional residual overcurrent and powerprotection (SDEPSDE)

Qty: 1MRK 004 908-EA

Thermal overload protection, two time constants(TRPTTR)

Qty:

1 2 1MRK 004 908-KA

Breaker failure protection, 3–phase activation and output(CCRBRF)

Qty: 1MRK 004 908-LA

Pole discordance protection (CCRPLD) Qty: 1MRK 004 908-NA

Directional underpower protection (GUPPDUP) Qty: 1MRK 004 908-RB

Directional overpower protection (GOPPDUP)

Qty:

1 2 1MRK 004 908-SB

Accidental energizing protection for synchronousgenerator (AEGGAPC)

Qty:

1MRK 004 908-WA

Negative sequence time overcurrent protection formachines (NS2PTOC)

Qty: 1MRK 004 908-YA

Voltage-restrained time overcurrent protection(VR2PVOC)

Qty: 1MRK 004 908-ZA



ABB 83

Voltage protection

Two step undervoltage protection (UV2PTUV) Qty: 1MRK 004 910-AB

Two step overvoltage protection (OV2PTOV) Qty: 1MRK 004 910-BB

Two step residual overvoltage protection (ROV2PTOV)

Qty:

1 2 1MRK 004 910-CB

Overexcitation protection (OEXPVPH) Qty: 1MRK 004 910-DC

100% Stator earth faule protection, 3rd harmonic based(STEFPHIZ)

Qty: 1MRK 004 910-FA


Underfrequency protection (SAPTUF)

Qty:

1 2 3 4 1MRK 004 912-AA

Overfrequency protection (SAPTOF)

Qty:

1 2 3 4 1MRK 004 912-BA

Rate-of-change frequency protection (SAPFRC)

Qty:

1 2 1MRK 004 912-CA


Fuse failure supervision (SDDRFUF) Qty: 1MRK 004 914-BA

Control

Synchrocheck, energizing check and synchronizing(SESRSYN)

Qty: 1MRK 004 917-AC

Monitoring

Station battery supervision (SPVNZBAT) Qty: 1MRK 004 925-HB

Insulation gas monitoring function (SSIMG)

Qty:

1 2 1MRK 004 925-KA

Insulation liquid monitoring function (SSIML)

Qty:

1 2 1MRK 004 925-LA

Circuit breaker condition monitoring (SSCBR) Qty: 1MRK 004 925-MA

First local HMI user dialogue language

HMI language, English IEC Always included

Additional local HMI user dialogue language

HMI language, English US 1MRK 002 940-MA

Optional hardware



84 ABB

Human machine interface

Rule: One must be ordered.

Display type Keypad symbol Case size

Local human machine interface (LHMI) IEC 3U 1/1 19" 1KHL160055R0001

Local human machine interface (LHMI) ANSI 3U 1/1 19" 1KHL160042R0001

Analog system

Rule: One Transformer input module must be ordered

Transformer module (TRM) 6I+4U, 1/5A,100/220V Qty: 1KHL178083R0001

Transformer module (TRM) 8I+2U, 1/5A, 100/220V Qty: 1KHL178083R0013

Transformer module (TRM) 4I, 1/5A+1I, 0.1/0.5A+5U, 100/220V Qty: 1KHL178083R0016

Transformer module (TRM) 4I+6U, 1/5A, 100/220V Qty: 1KHL178083R0003

Rule: Only one Analog input module can be ordered

Analog input module (AIM) 6I+4U, 1/5A, 100/220V Qty: 1KHL178083R5001

Analog input module (AIM) 4I, 1/5A+1I, 0.1/0.5A+5U, 100/220V Qty: 1KHL178083R5016

Binary input/output modules

Note: If analog input module (AIM) is ordered only 2 BIO modulescan be ordered

Binary input/output module (BIO) Qty: 1 2 3 4 1KHL178074R0001

Rack mounting kit

Rack mounting kit for 3U 1/1 x 19” case Quantity: 1KHL400352R0001



ABB 85

22. Ordering for Configured IED

GuidelinesCarefully read and follow the set of rules to ensure problem-free order management.Please refer to the available functions table for included application functions.

To obtain the complete ordering code, please combine code from the tables, as given in the example below.

Exemple code: REG650*1.2-B01X00-X00-B1A5-B-A-SA-AB1-RA3B1-AX-E. Using the code of each position #1-11specified as REG650*1-2 2-3-4 4-5-6-7 7-8 8-9 9 9-10 10 10 10-11

# 1 - 2 - 3 - 4 - 5 6 - 7 - 8 - 9 - 10 - 11

REG650* - - - - - - - - -

P

osi

tion

SOFTWARE #1 Notes and Rules

Version number

Version no 1.2

Selection for position #1. 1.2

Configuration alternatives #2 Notes and Rules

Generator protection B01

Generator-Transformer protection B05

ACT configuration

ABB standard configuration X00

Selection for position #2. X00

Software options #3 Notes and Rules

No option X00

Selection for postition #3 X00

First HMI language #4 Notes and Rules

English IEC B1

Selection for position #4.

Additional HMI language #4

No second HMI language X0

Selection for position #4. B1 X0

Casing #5 Notes and Rules

Rack casing, 3U 1/1 x 19" D

Selection for position #5. D



86 ABB

Mounting details with IP40 of protection from the front #6 Notes and Rules

No mounting kit included X

Rack mounting kit for 3U 1/1 x 19" H


Connection type for Power supply, Input/output andCommunication modules

#7 Notes and Rules

Compression terminals S

Ringlug terminals R

Power supply

Slot position:

pPSM

100-240V AC, 110-250V DC, 9BO A

48-125V DC, 9BO B


Human machine interface #8 Notes and Rules

Local human machine interface, OL8000, IEC3U 1/1 x 19", Basic

E

Detached LHMI

No detached mounting of LHMI X0

Selection for position #8. E X0

Connection type for Analog modules #9 Notes and Rules

Compression terminals S

Ringlug terminals R

Analog system

Slot position: p2

Transformer module, 4I, 1/5A+1I, 0.1/0.5A+5U,100/220V

A3

Slot position: p4

Analog input module, 6I + 4U, 1/5A, 100/220V B1

Selection for position #9. A3 B1

Binary input/output module #10 Notes and Rules

Slot position (rear view) p5 p6

Available slots in 1/1 case

No board in slot X X AIM in p4

Binary input/output module 9 BI, 3 NO Trip, 5 NOSignal, 1 CO Signal

A A p5 basic, p6 optional

Selection for position #10. A



ABB 87

Communication and processing module #11 Notes and Rules

Slot position (rear view)

pCO

M

12BI, IRIG-B, RS485, Ethernet, LC optical, ST serial F

Selection for position #11. F



88 ABB

23. Ordering for Accessories

External resistor unit

High impedance resistor unit 1-ph with resistor and voltagedependent resistor for 20-100V operating voltage

Quantity: RK795101-MA

High impedance resistor unit 1-ph with resistor and voltagedependent resistor for 100-400V operating voltage

Quantity: RK795101-CB

Configuration and monitoring tools

Front connection cable between LCD-HMI and PC Quantity: 1MRK 001 665-CA

LED Label special paper A4, 1 pc Quantity: 1MRK 002 038-CA

LED Label special paper Letter, 1 pc Quantity: 1MRK 002 038-DA

External interface units for Rotor earth fault protection

Injection unit for Rotor earth fault protection (RXTTE 4) Quantity: 1MRK 002 108-BA

Protective resistor on plate Quantity: RK795102-AD

Manuals

Note: One (1) IED Connect DVD containing user documentationOperation manualTechnical manualInstallation manualCommissioning manualApplication manualCommunication protocol manual, DNP3Communication protocol manual, IEC61850-8-1Communication protocol manual, IEC60870-5-103Cyber security deployment guidelinesType test certificateEngineering manualPoint list manual, DNP3Connectivity packages and LED label template is always included for each IED

Rule: Specify additional quantity of IED Connect DVD requested

User documentation Quantity: 1MRK 003 500-AA



ABB 89

Rule: Specify the number of printed manuals requested

Operation manual IEC Quantity: 1MRK 500 095-UEN

Technical manual IEC Quantity: 1MRK 502 043-UEN

Commissioning manual IEC Quantity: 1MRK 502 044-UEN

Application manual IEC Quantity: 1MRK 502 042-UEN

Communication protocol manual, DNP3 IEC Quantity: 1MRK 511 257-UEN

Communication protocol manual, IEC 61850-8-1 IEC Quantity: 1MRK 511 258-UEN

Communication protocol manual, IEC 60870-5-103 IEC Quantity: 1MRK 511 259-UEN

Engineering manual IEC Quantity: 1MRK 511 261-UEN

Installation manual IEC Quantity: 1MRK 514 015-UEN

Point list manual, DNP3 IEC Quantity: 1MRK 511 260-UEN

Cyber Security deployment guidelines IEC Quantity: 1MRK 511 268-UEN

Reference information

For our reference and statistics we would be pleased to be provided with the following application data:

Country: End user:

Station name: Voltage level: kV



90 ABB

Related documents

Documents related to REG650 Identity number

Application manual 1MRK 502 042-UEN

Technical manual 1MRK 502 043-UEN

Commissioning manual 1MRK 502 044-UEN

Product Guide 1MRK 502 045-BEN

Type test certificate 1MRK 502 045-TEN

Rotor Earth Fault Protection with Injection Unit RXTTE4 and REG670 1MRG001910

Application notes for Circuit Breaker Control 1MRG006806

650 series manuals Identity number

Communication protocol manual, DNP3 1MRK 511 257-UEN

Communication protocol manual, IEC 61850–8–1 1MRK 511 258-UEN

Communication protocol manual, IEC 60870-5-103 1MRK 511 259-UEN

Cyber Security deployment guidelines 1MRK 511 268-UEN

Point list manual, DNP3 1MRK 511 260-UEN

Engineering manual 1MRK 511 261-UEN

Operation manual 1MRK 500 095-UEN

Installation manual 1MRK 514 015-UEN



ABB 91

Contact us

ABB ABSubstation Automation ProductsSE-721 59 Västerås, SwedenPhone +46 (0) 21 32 50 00Fax +46 (0) 21 14 69 18

www.abb.com/substationautomation

1MR

K 5

02 0

45-B

EN

-©

Cop

yrig

ht 2

012

AB

B. A

ll rig

hts

rese

rved

.