1mrk502031-ben a en product guide reg670 1.2 customized

Relion® 670 series

Generator protection REG670CustomizedProduct Guide

Contents

1. Application...........................................................3

2. Available functions...............................................9

3. Differential protection.........................................17

4. Impedance protection........................................19

5. Current protection..............................................21

6. Voltage protection..............................................24

7. Frequency protection.........................................26

8. Multipurpose protection.....................................27

9. Secondary system supervision..........................28

10. Control...............................................................28

11. Logic..................................................................30

12. Monitoring.........................................................30

13. Metering............................................................33

14. Basic IED functions...........................................33

15. Human machine interface.................................33

16. Station communication ....................................34

17. Remote communication....................................35

18. Hardware description........................................36

19. Connection diagrams........................................39

20. Technical data...................................................52

21. Ordering..........................................................108

Disclaimer

The information in this document is subject to change without notice and should not be construed as a commitment by ABB AB. ABB AB assumesno responsibility for any errors that may appear in this document.

© Copyright 2011 ABB AB.

All rights reserved.

Trademarks

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

Generator protection REG670 1MRK 502 031-BEN ACustomizedProduct version: 1.2 Issued: September 2011

2 ABB

1. Application

The REG670 is used for protection, controland monitoring of generators and generator-transformer blocks from relatively small unitsup to the largest generating units. The IEDhas a comprehensive function library,covering the requirements for most generatorapplications. The large number of analoginputs available enables, together with thelarge functional library, integration of manyfunctions in one IED. In typical applicationstwo units can provide total functionality, alsoproviding a high degree of redundancy.REG670 can as well be used for protectionand control of shunt reactors.

Stator earth fault protection, both traditional95% as well as 100% injection and 3rdharmonic based are included. When theinjection based protection is used, 100% ofthe machine stator winding, including thestar point, is protected under all operatingmodes. The 3rd harmonic based 100% statorearth fault protection uses 3rd harmonicdifferential voltage principle. Injection based100% stator earth fault protection can operateeven when machine is at standstill. Wellproven algorithms for pole slip,underexcitation, rotor earth fault, negativesequence current protections, and so on, areincluded in the IED.

The generator differential protection in theREG670 adapted to operate correctly forgenerator applications where factors as longDC time constants and requirement on shorttrip time have been considered.

As many of the protection functions can beused as multiple instances there are

possibilities to protect more than one objectin one IED. It is possible to have protectionfor an auxiliary power transformer integratedin the same IED having main protections forthe generator. The concept thus enables verycost effective solutions.

The REG670 also enables valuablemonitoring possibilities as many of theprocess values can be transferred to anoperator HMI.

The wide application flexibility makes thisproduct an excellent choice for both newinstallations and for refurbishment in existingpower plants.

Serial data communication is via opticalconnections to ensure immunity againstdisturbances.

The wide application flexibility makes thisproduct an excellent choice for both newinstallations and the refurbishment of existinginstallations.

By using patented algorithm REG670 (or anyother product from 670 series) can track thepower system frequency in quite wide rangefrom 9Hz to 95Hz. In order to do thatpreferably the three-phase voltage signalfrom the generator terminals shall beconnected to the IED. Then IED can adopt itsfiltering algorithm in order to properlymeasure phasors of all current and voltagesignals connected to the IED. This feature isessential for proper operation of theprotection during generator start-up and shut-down procedure.


Revision: A

ABB 3

IEC11000201-1-en.vsd

GU

U

STEF PHIZ

59THD U3d/N

GEN PDIF

87G 3Id/I

SA PTUF

81 f<

SA PTOF

81 f>

SDD RFUF

60FL

OEX PVPH

24 U/f>

UV2 PTUV

27 3U<

OV2 PTOV

59 3U>

REG 670*1.2

ZMH PDIS

21 Z<

LEX PDIS

40 <

GUP PDUP

37 P<

GOP PDOP

32 P

ROV2 PTOV

59N 3Uo>

OC4 PTOC

51/67 3I->

CC RBRF

50BF 3I> BF

NS2 PTOC

46 I2>

TR PTTR

49 Ith

PSP PPAM

78 Ucos

+ REX060, REX061

AEG GAPC

50AE U/I>

CV MMXU

Meter.

ROV2 PTOV

59N UN>

ROTI PHIZ

64R RRE<

STTI PHIZ

64S RSE<+ REX060

ROV2 PTOV

59N 3Uo>

VT

YY

D

IEC11000201 V1 EN

Figure 1. Generator protection application with generator differential, 100% stator earth faultand back-up protection


4 ABB


GU

U

GEN PDIF

87G 3Id/I

SA PTUF

81 f<

SA PTOF

81 f>

SDD RFUF

60FL

OEX PVPH

24 U/f>

UV2 PTUV

27 3U<

OV2 PTOV

59 3U>

REG 670*1.2

ZMH PDIS

21 Z<

LEX PDIS

40 <

GUP PDUP

37 P<

GOP PDOP

32 P

ROV2 PTOV

59N 3Uo>

OC4 PTOC

51/67 3I->

CC RBRF

50BF 3I> BF

NS2 PTOC

46 I2>

PSP PPAM

78 Ucos

+ REX060, REX061

AEG GAPC

50AE U/I>

CV MMXU

Meter.

ROTI PHIZ

64R RRE<

STTI PHIZ

64S RSE<+ REX060

ROV2 PTOV

59N 3Uo>

VT

EF4 PTOC

64W IN>

YY

S

D

IEC11000204 V1 EN

Figure 2. Generator protection application for generator with split winding includinggenerator phase differential, 100% stator earth fault and back-up protection


ABB 5


GU

U

STEF PHIZ

59THD U3d/N

GEN PDIF

87G 3Id/I

SA PTUF

81 f<

SA PTOF

81 f>

SDD RFUF

60FL

OEX PVPH

24 U/f>

UV2 PTUV

27 3U<

OV2 PTOV

59 3U>

REG 670*1.2

ZMH PDIS

21 Z<

LEX PDIS

40 <

GUP PDUP

37 P<

GOP PDOP

32 P

ROV2 PTOV

59N 3Uo>

OC4 PTOC

51/67 3I->

CC RBRF

50BF 3I> BF

NS2 PTOC

46 I2>

PSP PPAM

78 Ucos

+ REX060, REX061

AEG GAPC

50AE U/I>

CV MMXU

Meter.

ROV2 PTOV

59N UN>

ROTI PHIZ

64R RRE<

VT

EF4 PTOC

64W IN>

YY

STTI PHIZ

64S RSE<+ REX060

VT

GEN PDIF

87W 3Id/I

D

S

IEC11000206 V1 EN

Figure 3. Generator protection application for generator with split winding includinggenerator phase differential, generator split-phase differential, 100% stator earthfault and back-up protection


6 ABB


GU

U

ROV2 PTOV

59N UN>

GEN PDIF

87G 3Id/I

SA PTUF

81 f<

SA PTOF

81 f>

SDD RFUF

60FL

REG 670*1.2

ZMH PDIS

21 Z<

LEX PDIS

40 <

GUP PDUP

37 P<

GOP PDOP

32 P

OC4 PTOC

51/67 3I->

CC RBRF

50BF 3I> BF

NS2 PTOC

46 I2>

TR PTTR

49 Ith

PSP PPAM

78 Ucos

AEG GAPC

50AE U/I>

STEF PHIZ

59THD U3d/N

Auxiliary Bus

OC4 PTOC

50/51 3I>

OC4 PTOC

50/51 3I>

CC RBRF

50BF 3I> BF

OC4 PTOC

50/51 3I>

ROV2 PTOV

59N 3Uo>

T3W PDIF

87T 3Id/I

CV MMXU

Meter.

OEX PVPH

24 U/f>

UV2 PTUV

27 3U<

OV2 PTOV

59 3U>

ROV2 PTOV

59N 3Uo>+ REX060, REX061

STTI PHIZ

64S RSE<

ROTI PHIZ

64R RRE<

+ REX060, REX062

YY

YUnit Trafo

Aux

iliar

y Tr

afo

Exc

itatio

n Tr

afo

YY

GroundingTransformer

D

D

D

IEC11000202 V1 EN

Figure 4. Unit protection application with overall differential, generator differential, 100%stator earth fault and back-up protection. Stator winding grounded via groundingtransformer.


ABB 7


GU

U

STEF PHIZ

59THD U3d/N

TR PTTR

49 Ith

SA PTUF

81 f<

EF4 PTOC

50N/51N IN>

REF PDIF

87N IdN/I

T3W PDIF

87O 3Id/I

REG 670*1.2

T2W PDIF

87T 3Id/I

ROV2 PTOV

59N 3Uo>

NS2 PTOC

46 I2>

TR PTTR

49 Ith

SDD RFUF

60FL

ZMH PDIS

21 Z<

LEX PDIS

40 <

GUP PDUP

37 P<

GOP PDOP

32 P

PSP PPAM

78 Ucos

SA PTOF

81 f>

OEX PVPH

24 U/f>

UV2 PTUV

27 3U<

OV2 PTOV

59 3U>

OC4 PTOC

50/51 3I>

OC4 PTOC

50/51 3I>

CC RBRF

50BF 3I> BF

GEN PDIF

87G 3Id/I

ROV2 PTOV

59N UN>

CC RBRF

50BF 3I> BF

OC4 PTOC

51/67 3I->

AEG GAPC

50AE U/I>

CV MMXU

Meter.

+ REX060, REX061

STTI PHIZ

64S RSE<

ROTI PHIZ

64R RRE<

+ REX060

CV MMXU

Meter.

YY

Y

YY

Uni

t Tra

fo

VT

D

D

D

IEC11000203 V1 EN

Figure 5. Unit protection application with overall differential, unit transformer differential,generator differential, 100% stator earth fault and back-up protection. Ungroundedstator winding.


8 ABB

GU

U

TR PTTR

49 Ith

SA PTUF

81 f<

EF4 PTOC

50N/51N IN>

REF PDIF

87N IdN/I

T3W PDIF

87O 3Id/I

REG 670*1.2

T2W PDIF

87T 3Id/I

ROV2 PTOV

59N 3Uo>

NS2 PTOC

46 I2>

TR PTTR

49 Ith

SDD RFUF

60FL

ZMH PDIS

21 Z<

LEX PDIS

40 <

GUP PDUP

37 P<

GOP PDOP

32 P

PSP PPAM

78 Ucos

SA PTOF

81 f>

OEX PVPH

24 U/f>

UV2 PTUV

27 3U<

OV2 PTOV

59 3U>

OC4 PTOC

50/51 3I>

OC4 PTOC

50/51 3I>

CC RBRF

50BF 3I> BF

GEN PDIF

87G 3Id/I

CC RBRF

50BF 3I> BF

OC4 PTOC

51/67 3I->

AEG GAPC

50AE U/I>

CV MMXU

Meter.

+ REX060, REX061

STTI PHIZ

64S RSE<

ROTI PHIZ

64R RRE<

+ REX060

CV MMXU

Meter.

YY

Y

YY

Uni

t Tra

fo

ROV2 PTOV

59N 3Uo>

VT


D

D

D

IEC11000207 V1 EN

Figure 6. Unit protection application with overall differential, unit transformer differential,generator differential, 100% stator earth fault and back-up protection. Statorwinding grounded via primary resistor.


ABB 9

2. Available functions

Main protection functions

2 = number of basic instances

0-3 = option quantities

IEC 61850 ANSI Function description Generator

REG670

Differential protection

T2WPDIF 87T Transformer differential protection, two winding 0-2

T3WPDIF 87T Transformer differential protection, three winding 0-2

HZPDIF 87 1Ph high impedance differential protection 0-6

GENDIF 87G Generator differential protection 0-2

REFPDIF 87N Restricted earth fault protection, low impedance 0-3

Impedance protection

ZMHPDIS 21 Full-scheme distance protection, mho characteristic 0-4

ZDMRDIR 21D Directional impedance element for mhocharacteristic

0-2

PSPPPAM 78 Pole slip/out-of-step protection 0-1

LEXPDIS 40 Loss of excitation 0-2

ROTIPHIZ 64R Sensitive rotor earth fault protection, injection based 0-1

STTIPHIZ 64S 100% stator earth fault protection, injection based 0-1


10 ABB

Back-up protection functions


REG670

Current protection

PHPIOC 50 Instantaneous phase overcurrent protection 0-4

OC4PTOC 51_67 Four step phase overcurrent protection 0-6

EFPIOC 50N Instantaneous residual overcurrent protection 0-2

EF4PTOC 51N_67N

Four step residual overcurrent protection 0-6

NS4PTOC 46I2 Four step directional negative phase sequenceovercurrent protection

0-2

SDEPSDE 67N Sensitive directional residual overcurrent andpower protection

0-2

TRPTTR 49 Thermal overload protection, two time constant 0-3

CCRBRF 50BF Breaker failure protection 0-4

CCRPLD 52PD Pole discordance protection 0-4

GUPPDUP 37 Directional underpower protection 0-4

GOPPDOP 32 Directional overpower protection 0-4

NS2PTOC 46I2 Negative sequence time overcurrent protectionfor machines

0-2

AEGGAPC 50AE Accidental energizing protection for synchronousgenerator

0-2

Voltage protection

UV2PTUV 27 Two step undervoltage protection 0-2

OV2PTOV 59 Two step overvoltage protection 0-2

ROV2PTOV 59N Two step residual overvoltage protection 0-3

OEXPVPH 24 Overexcitation protection 0-2

VDCPTOV 60 Voltage differential protection 0-2

STEFPHIZ 59THD

100% stator earth fault protection, 3rd harmonicbased

0-1

Frequency protection

SAPTUF 81 Underfrequency protection 0-6

SAPTOP 81 Overfrequency protection 0-6

SAPFRC 81 Rate-of-change frequency protection 0-3


ABB 11


REG670

Multipurpose protection

CVGAPC General current and voltage protection 1-12

64R Rotor earth fault 1


12 ABB

Control and monitoring functions


REG670

Control

SESRSYN 25 Synchrocheck, energizing check and synchronizing 0-2

APC30 3 Apparatus control for up to 6 bays, max 30apparatuses (6CBs) incl. interlocking

0-1

QCBAY Apparatus control 1

LocalRemote

Handling of LRswitch positions 1

LocRemControl

LHMI control of PSTO 1

TCMYLTC 84 Tap changer control and supervision, 6 binaryinputs

0-4

TCLYLTC 84 Tap changer control and supervision, 32 binaryinputs

0-4

SLGGIO Logic rotating switch for function selection andLHMI presentation

15

VSGGIO Selector mini switch 20

DPGGIO IEC61850 generic communication I/O functions 16

SPC8GGIO Single pole generic control 8 signals 5

AutomationBits

AutomationBits, command function for DNP3.0 3

Single command, 16 signals 4

Secondary system supervision

CCSRDIF 87 Current circuit supervision 0-5

SDDRFUF Fuse failure supervision 0-3

Logic

SMPPTRC 94 Tripping logic 1-6

TMAGGIO Trip matrix logic 12

Configuration logic blocks 40-280

Fixed signal function blocks 1

B16I Boolean 16 to Integer conversion 16


ABB 13


REG670

B16IFCVI Boolean 16 to Integer conversion with Logic Noderepresentation

16

IB16 Integer to Boolean 16 conversion 16

IB16FVCB Integer to Boolean 16 conversion with Logic Noderepresentation

16

Monitoring

CVMMXN Measurements 6

CNTGGIO Event counter 5

Event Event function 20

DRPRDRE Disturbance report 1

SPGGIO IEC61850 generic communication I/O functions 64

SP16GGIO IEC61850 generic communication I/O functions 16inputs

16

MVGGIO IEC61850 generic communication I/O functions 24

BSStartReport

Logical signal status report 3

RANGE_XP Measured value expander block 66

Metering

PCGGIO Pulse-counter logic 16

ETPMMTR Function for energy calculation and demandhandling

6


14 ABB

Designed to communicate


REG670

Station communication

SPA communication protocol 1

LON communication protocol 1

IEC60870-5-103 communication protocol 20/1

Operation selection between SPA andIEC60870-5-103 for SLM

1

DNP3.0 for TCP/IP and EIA-485 communicationprotocol

1

DNP3.0 fault records for TCP/IP and EIA-485communication protocol

1

Redundant station bus communicationIEC61850-8-1, PRP

1

Parameter setting function for IEC61850 1

IntlReceive Horizontal communication via GOOSE forinterlocking

59

Goose binary receive 10

Multiple command and transmit 60/10

Ethernet configuration of links 1

DUODRV Duo driver configuration 0-1

Remote communication

Binary signal transfer receive/transmit 6/36

Transmission of analog data from LDCM 1

Receive binary status from remote LDCM 6/3/3


ABB 15

Basic IED functions

IEC 61850 Function description

Basic functions included in all products

IntErrorSig Self supervision with internal event list 1

TIME Time and synchronization error 1

TimeSynch Time synchronization 1

ActiveGroup Parameter setting groups 1

Test Test mode functionality 1

ChangeLock Change lock function 1

TerminalID IED identifiers 1

Productinfo Product information 1

MiscBaseCommon Misc Base Common 1

IEDRuntimeComp IED Runtime Comp 1

RatedFreq Rated system frequency 1

SMBI Signal Matrix for binary inputs 40

SMBO Signal Matrix for binary outputs 40

SMMI Signal Matrix for mA inputs 4

SMAI Signal Matrix for analog inputs 36

Sum3Ph Summation block 3 phase 18

LocalHMI Parameter setting function for HMI in PCM600 1

LocalHMI Local HMI signals 1

AuthStatus Authority status 1

AuthorityCheck Authority check 1

AccessFTP FTP access with password 1

SPACommMap SPA communication mapping 1

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

DOSOEMAB Denial of service, frame rate control for OEM port AB 1

DOSOEMCD Denial of service, frame rate control for OEM port CD 1


16 ABB

3. Differential protection

Generator differential protectionGENPDIF

Short circuit between the phases of the statorwindings causes normally very large faultcurrents. The short circuit gives risk ofdamages on insulation, windings and statoriron core. The large short circuit currentscause large forces, which can cause damageeven to other components in the powerplant, such as turbine and generator-turbineshaft.

To limit the damage due to stator windingshort circuits, the fault clearance must be asfast as possible (instantaneous). If thegenerator block is connected to the powersystem close to other generating blocks, thefast fault clearance is essential to maintain thetransient stability of the non-faultedgenerators.

Normally, the short circuit fault current isvery large, that is, significantly larger than thegenerator rated current. There is a risk that ashort circuit can occur between phases closeto the neutral point of the generator, thuscausing a relatively small fault current. Thefault current can also be limited due to lowexcitation of the generator. Therefore, it isdesired that the detection of generator phase-to-phase short circuits shall be relativelysensitive, detecting small fault currents.

It is also of great importance that thegenerator differential protection does not tripfor external faults, with large fault currentsflowing from the generator.

To combine fast fault clearance, as well assensitivity and selectivity, the generatordifferential protection is normally the bestchoice for phase-to-phase generator shortcircuits.

Generator differential protection GENPDIF isalso well suited to generate fast, sensitive andselective fault clearance, if used to protectshunt reactors or small busbars.

Transformer differential protectionT2WPDIF/T3WPDIF

The Transformer differential protection, two-winding (T2WPDIF) and Transformerdifferential protection, three-winding(T3WPDIF) are provided with internal CTratio matching and vector groupcompensation and settable zero sequencecurrent elimination.

The function can be provided with up tothree-phase sets of current inputs. All currentinputs are provided with percentage biasrestraint features, making the IED suitable fortwo- or three-winding transformer in multi-breaker station arrangements.


ABB 17

Two-winding applications

xx05000048.vsd

IEC05000048 V1 EN

two-windingpowertransformer

xx05000049.vsd

IEC05000049 V1 EN

two-windingpowertransformer withunconnecteddelta tertiarywinding

xx05000050.vsd

IEC05000050 V1 EN

two-windingpowertransformer withtwo circuitbreakers on oneside

xx05000051.vsd

IEC05000051 V1 EN

two-windingpowertransformer withtwo circuitbreakers and twoCT-sets on bothsides

Three-winding applications

xx05000052.vsd

IEC05000052 V1 EN

three-windingpowertransformer withall threewindingsconnected

xx05000053.vsd

IEC05000053 V1 EN

three-windingpowertransformer withtwo circuitbreakers and twoCT-sets on oneside

xx05000057.vsd

IEC05000057 V1 EN

Autotransformerwith two circuitbreakers and twoCT-sets on twoout of three sides

Figure 7. CT group arrangement fordifferential protection andother protections

The setting facilities cover the applications ofthe differential protection to all types ofpower transformers and auto-transformerswith or without load tap changer as well asfor shunt reactors or and local feeders withinthe station. An adaptive stabilizing feature isincluded for heavy through-faults.Byintroducing the load tap changer position, thedifferential protection pick-up can be set tooptimum sensitivity thus covering internalfaults with low fault level.

Stabilization is included for inrush currents aswell as for overexcitation conditions.Adaptive stabilization is also included forsystem recovery inrush and CT saturation forexternal faults. A high set unrestraineddifferential current protection is included fora very high speed tripping at a high internalfault currents.

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


18 ABB

1Ph High impedance differentialprotection HZPDIF

The 1Ph High impedance differentialprotection (HZPDIF) function can be usedwhen the involved CT cores have the sameturns ratio and similar magnetizingcharacteristics. It utilizes an external CTcurrent summation by wiring, a seriesresistor, and a voltage dependent resistorwhich are mounted externally connected tothe IED.

HZPDIF can be used to protect generatorstator windings, tee-feeders or busbars. Sixsingle phase function blocks are available toallow application for two three-phase zonesbusbar protection.

Restricted earth fault protection,low impedance REFPDIF

Restricted earth-fault protection, low-impedance function (REFPDIF) can be usedon all directly or low-impedance earthedwindings. The REFPDIF function provideshigh sensitivity (down to 5%) and high speedtripping as it measures each windingindividually and thus does not need inrushstabilization.

The low-impedance function is a percentagebiased function with an additional zerosequence current directional comparisoncriterion. This gives excellent sensitivity andstability during through faults. The functionallows the use of different CT ratios andmagnetizing characteristics on the phase andneutral CT cores and mixing with otherfunctions and protection IEDs on the samecores.

4. Impedance protection

Full-scheme distance measuring,Mho characteristic ZMHPDIS

The numerical mho line distance protection isa four zone full scheme protection for back-

up detection of short circuit and earth faults.The four zones have fully independentmeasuring and settings, which gives highflexibility for all types of lines.

The function can be used as underimpedance back-up protection fortransformers and generators.

Directional impedance element forMho characteristic ZDMRDIR

The phase-to-earth impedance elements canbe optionally supervised by a phaseunselective directional function (phaseunselective, because it is based onsymmetrical components).

Pole slip protection PSPPPAM

The situation with pole slip of a generatorcan be caused by different reasons.

A short circuit may occur in the externalpower grid, close to the generator. If the faultclearing time is too long, the generator willaccelerate so much, that the synchronismcannot be maintained.

Un-damped oscillations occur in the powersystem, where generator groups at differentlocations, oscillate against each other. If theconnection between the generators is tooweak the magnitude of the oscillations willincrease until the angular stability is lost.

The operation of a generator having pole slipwill give risk of damages to the generator,shaft and turbine.

• At each pole slip there will be significanttorque impact on the generator-turbineshaft.

• In asynchronous operation there will beinduction of currents in parts of thegenerator normally not carrying current,thus resulting in increased heating. Theconsequence can be damages oninsulation and stator/rotor iron.

The Pole slip protection (PSPPPAM) functionshall detect pole slip conditions and trip thegenerator as fast as possible if the locus ofthe measured impedance is inside the


ABB 19

generator-transformer block. If the centre ofpole slip is outside in the power grid, thefirst action should be to split the networkinto two parts, after line protection action. Ifthis fails there should be operation of thegenerator PSPPPAM in zone 2, to preventfurther damages to the generator, shaft andturbine.

Loss of excitation LEXPDIS

There are limits for the under-excitedoperation of a synchronous machine. Areduction of the excitation current weakensthe coupling between the rotor and thestator. The machine may lose thesynchronism and start to operate like aninduction machine. Then, the reactive powerconsumption will increase. Even if themachine does not loose synchronism it maynot be acceptable to operate in this state for along time. Reduction of excitation increasesthe generation of heat in the end region ofthe synchronous machine. The local heatingmay damage the insulation of the statorwinding and the iron core.

To prevent damages to the generator itshould be tripped when excitation is lost.

Sensitive rotor earth faultprotection, injection basedROTIPHIZ

The sensitive rotor earth fault protection(ROTIPHIZ) is used to detect earth faults inthe rotor windings of generators. ROTIPHIZis applicable for all types of synchronousgenerators.

To implement the above concept, a separateinjection box is required. The injection boxgenerates a square wave voltage signal at acertain preset frequency which is fed into therotor winding.

The magnitude of the injected voltage signaland the resulting injected current is measuredthrough a resistive shunt located within theinjection box. These two measured values arefed to the IED. Based on these two measuredquantities, the protection IED determines therotor winding resistance to ground. The

resistance value is then compared with thepreset fault resistance alarm and trip levels.

The protection function can detect earthfaults in the entire rotor winding andassociated connections.

Requires injection unit REX060 and acoupling capacitor unit REX061 for correctoperation.

100% stator earth fault protection,injection based STTIPHIZ

The 100% stator earth-fault protectionSTTIPHIZ is used to detect earth faults in thestator windings of generators and motors.STTIPHIZ is applicable for generatorsconnected to the power system through aunit transformer in a block connection. Anindependent signal with a certain frequencydifferent from the generator rated frequencyis injected into the stator circuit. Theresponce of this injected signal is used todetect stator earth faults.

To implement the above concept, a separateinjection box is required. The injection boxgenerates a square wave voltage signal whichfor example can be fed into the secondarywinding of the generator neutral pointvoltage transformer or groundingtransformer. This signal propagates throughthis transformer into the stator circuit.

The magnitude of the injected voltage signalis measured on the secondary side of theneutral point voltage transformer orgrounding transformer. In addition, theresulting injected current is measuredthrough a resistive shunt located within theinjection box. These two measured values arefed to the IED. Based on these two measuredquantities, the IED determines the statorwinding resistance to ground. The resistancevalue is then compared with the preset faultresistance alarm and trip levels.

The protection function can not only detectthe earth fault at the generator star point, butalso along the stator windings and at thegenerator terminals, including the connectedcomponents such as voltage transformers,


20 ABB

circuit breakers, excitation transformer and soon. The measuring principle used is notinfluenced by the generator operating modeand is fully functional even with thegenerator at standstill. It is still required tohave a standard 95% stator earth-faultprotection, based on the neutral pointfundamental frequency displacement voltage,operating in parallel with the 100% statorearth-fault protection function.

Requires injection unit REX060 and optionalshunt resistor unit REX062 for correctoperation.

5. Current protection

Instantaneous phase overcurrentprotection PHPIOC

The instantaneous three phase overcurrentfunction has a low transient overreach andshort tripping time to allow use as a high setshort-circuit protection function.

Four step phase overcurrentprotection OC4PTOC

The four step phase overcurrent protectionfunction OC4PTOC has an inverse or definitetime delay independent for step 1 and 4separately. Step 2 and 3 are always definitetime delayed.

All IEC and ANSI inverse time characteristicsare available together with an optional userdefined time characteristic.

The directional function is voltage polarizedwith memory. The function can be set to bedirectional or non-directional independentlyfor each of the steps.

A 2nd harmonic blocking can be setindividually for each step.

Instantaneous residual overcurrentprotection EFPIOC

The Instantaneous residual overcurrentprotection EFPIOC has a low transientoverreach and short tripping times to allow

the use for instantaneous earth-faultprotection, with the reach limited to less thanthe typical eighty percent of the line atminimum source impedance. EFPIOC can beconfigured to measure the residual currentfrom the three-phase current inputs or thecurrent from a separate current input.EFPIOC can be blocked by activating theinput BLOCK.

Four step residual overcurrentprotection EF4PTOC

The four step residual overcurrent protectionEF4PTOC has an inverse or definite timedelay independent for each step separately.

All IEC and ANSI time-delayed characteristicsare available together with an optional userdefined characteristic.

The directional function includes 3 options

• voltage polarized• current polarized• dual polarized

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

Second harmonic blocking can be setindividually for each step.

EF4PTOC can be used as main protection forphase-to-earth faults.

EF4PTOC can also be used to provide asystem back-up for example, in the case ofthe primary protection being out of servicedue to communication or voltage transformercircuit failure.

Directional operation can be combinedtogether with corresponding communicationlogic in permissive or blocking teleprotectionscheme. Current reversal and weak-endinfeed functionality are available as well.

EF4PTOC can be configured to measure theresidual current from the three-phase currentinputs or the current from a separate currentinput.


ABB 21

Four step negative sequenceovercurrent protection NS4PTOC

Four step negative sequence overcurrentprotection (NS4PTOC) has an inverse ordefinite time delay independent for each stepseparately.

All IEC and ANSI time delayed characteristicsare available together with an optional userdefined characteristic.

The directional function is voltage polarizedor dual polarized.

NS4PTOC can be set directional or non-directional independently for each of the steps.

NS4PTOC can be used as main protection forunsymmetrical fault; phase-phase shortcircuits, phase-phase-earth short circuits andsingle phase earth faults.

NS4PTOC can also be used to provide asystem back-up for example, in the case ofthe primary protection being out of servicedue to communication or voltage transformercircuit failure.

Directional operation can be combinedtogether with corresponding communicationlogic in permissive or blocking teleprotectionscheme. The same logic as for directionalzero sequence current can be used. Currentreversal and weak-end infeed functionalityare available.

Sensitive directional residualovercurrent and power protectionSDEPSDE

In isolated networks or in networks withhigh impedance earthing, the earth faultcurrent is significantly smaller than the shortcircuit currents. In addition to this, themagnitude of the fault current is almostindependent on the fault location in thenetwork. The protection can be selected touse either the residual current or residualpower component 3U0·3I0·cos j, foroperating quantity with maintained shortcircuit capacity. There is also available onenondirectional 3I0 step and one 3U0overvoltage tripping step.

Thermal overload protection, twotime constant TRPTTR

If a power transformer or generator reachesvery high temperatures the equipment mightbe damaged. The insulation within thetransformer/generator will have forcedageing. As a consequence of this the risk ofinternal phase-to-phase or phase-to-earthfaults will increase. High temperature willdegrade the quality of the transformer/generator insulation.

The thermal overload protection estimatesthe internal heat content of the transformer/generator (temperature) continuously. Thisestimation is made by using a thermal modelof the transformer/generator with two timeconstants, which is based on currentmeasurement.

Two warning levels are available. Thisenables actions in the power system to bedone before dangerous temperatures arereached. If the temperature continues toincrease to the trip value, the protectioninitiates a trip of the protected transformer/generator.

Breaker failure protection CCRBRF

Breaker failure protection (CCRBRF) ensuresfast back-up tripping of surrounding breakersin case the own breaker fails to open.CCRBRF can be current based, contact based,or an adaptive combination of these twoconditions.

Current check with extremely short reset timeis used as check criterion to achieve highsecurity against unnecessary operation.

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

CCRBRF can be single- or three-phaseinitiated to allow use with single phasetripping applications. For the three-phaseversion of CCRBRF the current criteria can beset to operate only if two out of four forexample, two phases or one phase plus theresidual current start. This gives a highersecurity to the back-up trip command.


22 ABB

CCRBRF function can be programmed to givea single- or three-phase re-trip of the ownbreaker to avoid unnecessary tripping ofsurrounding breakers at an incorrectinitiation due to mistakes during testing.

Pole discordance protectionCCRPLD

An open phase can cause negative and zerosequence currents which cause thermal stresson rotating machines and can causeunwanted operation of zero sequence ornegative sequence current functions.

Normally the own breaker is tripped tocorrect such a situation. If the situationpersists the surrounding breakers should betripped to clear the unsymmetrical loadsituation.

The Polediscordance protection functionCCRPLD operates based on information fromauxiliary contacts of the circuit breaker forthe three phases with additional criteria fromunsymmetrical phase currents when required.

Directional over/underpowerprotection GOPPDOP/GUPPDUP

The directional over-/under-power protectionGOPPDOP/GUPPDUP can be used wherevera high/low active, reactive or apparent powerprotection or alarming is required. Thefunctions can alternatively be used to checkthe direction of active or reactive power flowin the power system. There are a number ofapplications where such functionality isneeded. Some of them are:

• generator reverse power protection• generator low forward power protection• detection of over/under excited generator• detection of reversed active power flow• detection of high reactive power flow• excessive line/cable loading with active

or reactive power• generator reverse power protection

Each function has two steps with definitetime delay. Reset times for both steps can beset as well.

By using optional metering class CT inputsaccuracy of 0,5% can be achieved for steamturbine applications.

Negative sequence time overcurrentprotection for machines NS2PTOC

Negative-sequence time overcurrentprotection for machines NS2PTOC is intendedprimarily for the protection of generatorsagainst possible overheating of the rotorcaused by negative sequence component inthe stator current.

The negative sequence currents in agenerator may, among others, be caused by:

• 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 thenegative sequence current. NS2PTOC also hasa time delay characteristic which matches theheating characteristic of the generator

22I 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 of thegenerators size and design

NS2PTOC has a wide range of K settings andthe sensitivity and capability of detecting andtripping for negative sequence currents downto the continuous capability of a generator.

A separate output is available as an alarmfeature to warn the operator of a potentiallydangerous situation.


ABB 23

Accidental energizing protectionfor synchronous generatorAEGGAPC

Inadvertent or accidental energizing of off-line generators has occurred often enoughdue to operating errors, breaker headflashovers, control circuit malfunctions, or acombination of these causes. Inadvertentlyenergized generator operates as inductionmotor drawing a large current from thesystem. The voltage supervised overcurrentprotection is used to protect the inadvertentlyenergized generator.

Accidental energizing protection forsynchronous generator (AEGGAPC) takes themaximum phase current input from thegenerator terminal side or from generatorneutral side and maximum phase to phasevoltage inputs from the terminal side.AEGGAPC is enabled when the terminalvoltage drops below the specified voltagelevel for the preset time.

6. Voltage protection

Two step undervoltage protectionUV2PTUV

Undervoltages can occur in the power systemduring faults or abnormal conditions. Twostep undervoltage protection (UV2PTUV)function can be used to open circuit breakersto prepare for system restoration at poweroutages or as long-time delayed back-up toprimary protection.

UV2PTUV has two voltage steps, each withinverse or definite time delay.

Two step overvoltage protectionOV2PTOV

Overvoltages may occur in the power systemduring abnormal conditions such as suddenpower loss, tap changer regulating failures,open line ends on long lines etc.

Two step overvoltage protection (OV2PTOV)function can be used to detect open lineends, normally then combined with adirectional reactive over-power function tosupervise the system voltage. When triggered,the function will cause an alarm, switch inreactors, or switch out capacitor banks.

OV2PTOV has two voltage steps, each ofthem with inverse or definite time delayed.

OV2PTOV has an extremely high reset ratioto allow settings close to system servicevoltage.

Two step residual overvoltageprotection ROV2PTOV

Residual voltages may occur in the powersystem during earth faults.

Two step residual overvoltage protectionROV2PTOV function calculates the residualvoltage from the three-phase voltage inputtransformers or measures it from a singlevoltage input transformer fed from an opendelta or neutral point voltage transformer.

ROV2PTOV has two voltage steps, each withinverse or definite time delay.

Reset delay ensures operation for intermittentearth faults.

Overexcitation protectionOEXPVPH

When the laminated core of a powertransformer or generator is subjected to amagnetic flux density beyond its designlimits, stray flux will flow into non-laminatedcomponents not designed to carry flux andcause eddy currents to flow. The eddycurrents can cause excessive heating andsevere damage to insulation and adjacentparts in a relatively short time. The functionhas settable inverse operating curves andindependent alarm stages.

Voltage differential protectionVDCPTOV

A voltage differential monitoring function isavailable. It compares the voltages from two


24 ABB

three phase sets of voltage transformers andhas one sensitive alarm step and one trip step.

95% and 100% Stator earth faultprotection based on 3rd harmonicSTEFPHIZ

Stator earth fault is a fault type havingrelatively high fault rate. The generatorsystems normally have high impedanceearthing, that is, earthing via a neutral pointresistor. This resistor is normallydimensioned to give an earth fault current inthe range 3 – 15 A at a solid earth-faultdirectly at the generator high voltageterminal. The relatively small earth faultcurrents give much less thermal andmechanical stress on the generator, comparedto the short circuit case, which is betweenconductors of two phases. Anyhow, the earthfaults in the generator have to be detectedand the generator has to be tripped, even iflonger fault time compared to internal shortcircuits, can be allowed.

In normal non-faulted operation of thegenerating unit the neutral point voltage isclose to zero, and there is no zero sequencecurrent flow in the generator. When a phase-to-earth fault occurs the neutral point voltagewill increase and there will be a current flowthrough the neutral point resistor.

To detect an earth fault on the windings of agenerating unit one may use a neutral point

overvoltage protection, a neutral pointovercurrent protection, a zero sequenceovervoltage protection or a residualdifferential protection. These protections aresimple and have served well during manyyears. However, at best these simple schemesprotect only 95% of the stator winding. Theyleave 5% close to the neutral endunprotected. Under unfavorable conditionsthe blind zone may extend up to 20% fromthe neutral.

The 95% stator earth fault protectionmeasures the fundamental frequency voltagecomponent in the generator star point and itoperates when it exceeds the preset value. Byapplying this principle approximately 95% ofthe stator winding can be protected. In orderto protect the last 5% of the stator windingclose to the neutral end the 3rd harmonicvoltage measurement can be performed. In100% Stator E/F 3rd harmonic protectioneither the 3rd harmonic voltage differentialprinciple, the neutral point 3rd harmonicundervoltage principle or the terminal side3rd harmonic overvoltage principle can beapplied. However, differential principle isstrongly recommended. Combination of thesetwo measuring principles provides coveragefor entire stator winding against earth faults.


ABB 25

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 8. Protection principles for STEFPHIZ function

7. Frequency protection

Underfrequency protection SAPTUF

Underfrequency occurs as a result of lack ofgeneration in the network.

Underfrequency protection SAPTUF is usedfor load shedding systems, remedial actionschemes, gas turbine startup and so on.

SAPTUF is provided with an undervoltageblocking.

The operation is based on positive sequencevoltage measurement and requires two phase-phase or three phase-neutral voltages to beconnected. For information about how toconnect analog inputs, refer to Applicationmanual/IED application/Analog inputs/Setting guidelines

Overfrequency protection SAPTOF

Overfrequency protection function SAPTOF isapplicable in all situations, where reliable

detection of high fundamental power systemfrequency is needed.

Overfrequency occurs at sudden load dropsor shunt faults in the power network. Closeto the generating plant, generator governorproblems can also cause over frequency.

SAPTOF is used mainly for generationshedding and remedial action schemes. It isalso used as a frequency stage initiating loadrestoring.

SAPTOF is provided with an undervoltageblocking.

The operation is based on positive sequencevoltage measurement and requires two phase-phase or three phase-neutral voltages to beconnected. For information about how toconnect analog inputs, refer to Applicationmanual/IED application/Analog inputs/Setting guidelines


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Rate-of-change frequencyprotection SAPFRC

Rate-of-change frequency protection function(SAPFRC) gives an early indication of a maindisturbance in the system. SAPFRC can beused for generation shedding, load sheddingand remedial action schemes. SAPFRC candiscriminate between positive or negativechange of frequency.

SAPFRC is provided with an undervoltageblocking. The operation is based on positivesequence voltage measurement and requirestwo phase-phase or three phase-neutralvoltages to be connected. For informationabout how to connect analog inputs, refer toApplication manual/IED application/Analog inputs/Setting guidelines.

8. Multipurposeprotection

General current and voltageprotection CVGAPC

The protection module is recommended as ageneral backup protection with manypossible application areas due to its flexiblemeasuring and setting facilities.

The built-in overcurrent protection featurehas two settable current levels. Both of themcan be used either with definite time orinverse time characteristic. The overcurrentprotection steps can be made directional withselectable voltage polarizing quantity.Additionally they can be voltage and/orcurrent controlled/restrained. 2nd harmonicrestraining facility is available as well. At toolow polarizing voltage the overcurrent featurecan be either blocked, made non directionalor ordered to use voltage memory inaccordance with a parameter setting.

Additionally two overvoltage and twoundervoltage steps, either with definite time

or inverse time characteristic, are availablewithin each function.

The general function suits applications withunderimpedance and voltage controlledovercurrent solutions. The general functioncan also be utilized for generator transformerprotection applications where positive,negative or zero sequence components ofcurrent and voltage quantities are typicallyrequired.

Additionally, generator applications such asloss of field, inadvertent energizing, stator orrotor overload, circuit breaker head flash-over and open phase detection are just a fewof possible protection arrangements withthese functions.

Rotor earth fault protection

The field winding, including the rotorwinding and the non-rotating excitationequipment, is always insulated from themetallic parts of the rotor. The insulationresistance is high if the rotor is cooled by airor by hydrogen. The insulation resistance ismuch lower if the rotor winding is cooled bywater. This is true even if the insulation isintact. A fault in the insulation of the fieldcircuit will result in a conducting path fromthe field winding to earth. This means thatthe fault has caused a field earth fault.

The field circuit of a synchronous generatoris normally unearthed. Therefore, a singleearth fault on the field winding will causeonly a very small fault current. Thus the earthfault does not produce any damage in thegenerator. Furthermore, it will not affect theoperation of a generating unit in any way.However, the existence of a single earth faultincreases the electric stress at other points inthe field circuit. This means that the risk for asecond earth fault at another point on thefield winding has increased considerably. Asecond earth fault will cause a field short-circuit with severe consequences.

The rotor earth fault protection is based oninjection of an AC voltage to the isolated fieldcircuit. In non-faulted conditions there willbe no current flow associated to this injected


ABB 27

voltage. If a rotor earth fault occurs, thiscondition will be detected by the rotor earthfault protection. Depending on the generatorowner philosophy this operational state willbe alarmed and/or the generator will betripped. An injection unit is required for rotorearth fault protection (RXTTE4) and aprotective resistor on plate for correctoperation.

9. Secondary systemsupervision

Current circuit supervisionCCSRDIF

Open or short circuited current transformercores can cause unwanted operation of manyprotection functions such as differential,earth-fault current and negative-sequencecurrent functions.

It must be remembered that a blocking ofprotection functions at an occurrence of openCT circuit will mean that the situation willremain and extremely high voltages willstress the secondary circuit.

Current circuit supervision (CCSRDIF)compares the residual current from a threephase set of current transformer cores withthe neutral point current on a separate inputtaken from another set of cores on thecurrent transformer.

A detection of a difference indicates a fault inthe circuit and is used as alarm or to blockprotection functions expected to giveunwanted tripping.

Fuse failure supervision SDDRFUF

The aim of the fuse failure supervisionfunction (SDDRFUF) is to block voltagemeasuring functions at failures in thesecondary circuits between the voltagetransformer and the IED in order to avoidunwanted operations that otherwise mightoccur.

The fuse failure supervision function basicallyhas three different algorithms, negativesequence and zero sequence basedalgorithms and an additional delta voltageand delta current algorithm.

The negative sequence detection algorithm isrecommended for IEDs used in isolated orhigh-impedance earthed networks. It is basedon the negative-sequence measuringquantities, a high value of voltage 3U2

without the presence of the negative-sequence current 3I2.

The zero sequence detection algorithm isrecommended for IEDs used in directly orlow impedance earthed networks. It is basedon the zero sequence measuring quantities, ahigh value of voltage 3U0 without the

presence of the residual current 3I0.

For better adaptation to system requirements,an operation mode setting has beenintroduced which makes it possible to selectthe operating conditions for negativesequence and zero sequence based function.The selection of different operation modesmakes it possible to choose differentinteraction possibilities between the negativesequence and zero sequence based algorithm.

A criterion based on delta current and deltavoltage measurements can be added to thefuse failure supervision function in order todetect a three phase fuse failure, which inpractice is more associated with voltagetransformer switching during stationoperations.

10. Control

Synchrocheck, energizing check,and synchronizing SESRSYN

The Synchronizing function allows closing ofasynchronous networks at the correctmoment including the breaker closing time,which improves the network stability.


28 ABB

Synchrocheck, energizing check, andsynchronizing (SESRSYN) function checksthat the voltages on both sides of the circuitbreaker are in synchronism, or with at leastone side dead to ensure that closing can bedone safely.

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

Manual closing as well as automatic reclosingcan be checked by the function and can havedifferent settings.

For systems which are running asynchronousa synchronizing function is provided. Themain purpose of the synchronizing functionis to provide controlled closing of circuitbreakers when two asynchronous systems aregoing to be connected. It is used for slipfrequencies that are larger than those forsynchrocheck and lower than a set maximumlevel for the synchronizing function.

However this function can not be used toautomatically synchronize the generator tothe network.

Apparatus control APC

The apparatus control functions are used forcontrol and supervision of circuit breakers,disconnectors and earthing switches within abay. Permission to operate is given afterevaluation of conditions from other functionssuch as interlocking, synchrocheck, operatorplace selection and external or internalblockings.

Apparatus control features:

• Select-Execute principle to give highreliability

• Selection function to prevent simultaneousoperation

• Selection and supervision of operator place• Command supervision• Block/deblock of operation• Block/deblock of updating of position

indications• Substitution of position indications• Overriding of interlocking functions

• Overriding of synchrocheck• Operation counter• Suppression of Mid position

Two types of command models can be used:

• Direct with normal security• SBO (Select-Before-Operate) with enhanced

security

In normal security, the command isprocessed and the resulting position is notsupervised. However with enhanced security,the command is processed and the resultingposition is supervised.

Normal security means that only thecommand is evaluated and the resultingposition is not supervised. Enhanced securitymeans that the command is evaluated with anadditional supervision of the status value ofthe control object. The command securitywith enhanced security is always terminatedby a CommandTermination service primitive.

Control operation can be performed from thelocal HMI under authority control if so defined.

Tap changer position readingTCMYLTC

On-load tap-changer position can bemonitored on-line. This can be done byeither using BCD coded binary input signalsor alternatively via an mA input signal. Theactual tap-position can be used by thetransformer or overall differential protectionfunction in order to enable more sensitivepickup setting. This will in turn makedifferential protection more sensitive for lowlevel internal faults such as winding turn-to-turn faults.

Logic rotating switch for functionselection and LHMI presentationSLGGIO

The logic rotating switch for functionselection and LHMI presentation function(SLGGIO) (or the selector switch functionblock) is used to get a selector switchfunctionality similar to the one provided by ahardware selector switch. Hardware selectorswitches are used extensively by utilities, in


ABB 29

order to have different functions operating onpre-set values. Hardware switches arehowever sources for maintenance issues,lower system reliability and an extendedpurchase portfolio. The logic selectorswitches eliminate all these problems.

Selector mini switch VSGGIO

The Selector mini switch VSGGIO functionblock is a multipurpose function used for avariety of applications, as a general purposeswitch.

VSGGIO can be controlled from the menu orfrom a symbol on the single line diagram(SLD) on the local HMI.

Single point generic control 8signals SPC8GGIO

The Single point generic control 8 signals(SPC8GGIO) function block is a collection of8 single point commands, designed to bringin commands from REMOTE (SCADA) tothose parts of the logic configuration that donot need extensive command receivingfunctionality (for example, SCSWI). In thisway, simple commands can be sent directlyto the IED outputs, without confirmation.Confirmation (status) of the result of thecommands is supposed to be achieved byother means, such as binary inputs andSPGGIO function blocks. The commands canbe pulsed or steady.

Single command, 16 signals

The IEDs can receive commands either froma substation automation system or from thelocal HMI. The command function block hasoutputs that can be used, for example, tocontrol high voltage apparatuses or for otheruser defined functionality.

11. Logic

Tripping logic SMPPTRC

A function block for protection tripping isprovided for each circuit breaker involved in

the tripping of the fault. It provides pulseprolongation to ensure a trip pulse ofsufficient length, as well as all functionalitynecessary for correct co-operation withautoreclosing functions.

The trip function block includes functionalityfor evolving faults and breaker lock-out.

Trip matrix logic TMAGGIO

Trip matrix logic TMAGGIO function is usedto route trip signals and other logical outputsignals to different output contacts on the IED.

TMAGGIO output signals and the physicaloutputs allows the user to adapt the signalsto the physical tripping outputs according tothe specific application needs.

Fixed signal function block

The Fixed signals function (FXDSIGN)generates a number of pre-set (fixed) signalsthat can be used in the configuration of anIED, either for forcing the unused inputs inother function blocks to a certain level/value,or for creating certain logic.

12. Monitoring

Measurements CVMMXN, CMMXU,VNMMXU, VMMXU, CMSQI, VMSQI

The 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• positive, negative and zero sequence

currents and voltages• mA, input currents• pulse counters


30 ABB

Supervision of mA input signals

The main purpose of the function is tomeasure and process signals from differentmeasuring transducers. Many devices used inprocess control represent various parameterssuch as frequency, temperature and DCbattery voltage as low current values, usuallyin the range 4-20 mA or 0-20 mA.

Alarm limits can be set and used as triggers,e.g. to generate trip or alarm signals.

The function requires that the IED isequipped with the mA input module.

Event counter CNTGGIO

Event counter (CNTGGIO) has six counterswhich are used for storing the number oftimes each counter input has been activated.

Disturbance report DRPRDRE

Complete and reliable information aboutdisturbances in the primary and/or in thesecondary system together with continuousevent-logging is accomplished by thedisturbance report functionality.

Disturbance report DRPRDRE, alwaysincluded in the IED, acquires sampled data ofall selected analog input and binary signalsconnected to the function block with a,maximum of 40 analog and 96 binary signals.

The Disturbance report functionality is acommon name for several functions:

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

The Disturbance report function ischaracterized by great flexibility regardingconfiguration, starting conditions, recordingtimes, and large storage capacity.

A disturbance is defined as an activation ofan input to the AxRADR or BxRBDR functionblocks, which are set to trigger thedisturbance recorder. All signals from start of

pre-fault time to the end of post-fault timewill be included in the recording.

Every disturbance report recording is savedin the IED in the standard Comtrade format.The same applies to all events, which arecontinuously saved in a ring-buffer. The localHMI is used to get information about therecordings. The disturbance report files maybe uploaded to PCM600 for further analysisusing the disturbance handling tool.

Event list DRPRDRE

Continuous event-logging is useful formonitoring the system from an overviewperspective and is a complement to specificdisturbance recorder functions.

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

Indications DRPRDRE

To get fast, condensed and reliableinformation about disturbances in theprimary and/or in the secondary system it isimportant to know, for example binarysignals that have changed status during adisturbance. This information is used in theshort 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 displaystatus information about the IED and theDisturbance report function (trigged).

The Indication list function shows all selectedbinary input signals connected to theDisturbance report function that havechanged status during a disturbance.

Event recorder DRPRDRE

Quick, complete and reliable informationabout disturbances in the primary and/or inthe secondary system is vital, for example,time-tagged events logged duringdisturbances. This information is used fordifferent purposes in the short term (forexample corrective actions) and in the longterm (for example functional analysis).


ABB 31

The event recorder logs all selected binaryinput signals connected to the Disturbancereport function. Each recording can containup to 150 time-tagged events.

The event recorder information is availablefor the disturbances locally in the IED.

The event recording information is anintegrated part of the disturbance record(Comtrade file).

Trip value recorder DRPRDRE

Information about the pre-fault and faultvalues for currents and voltages are vital forthe disturbance evaluation.

The Trip value recorder calculates the valuesof all selected analog input signals connectedto the Disturbance report function. The resultis magnitude and phase angle before andduring the fault for each analog input signal.

The trip value recorder information isavailable for the disturbances locally in theIED.

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

Disturbance recorder DRPRDRE

The Disturbance recorder function suppliesfast, complete and reliable information aboutdisturbances in the power system. Itfacilitates understanding system behavior andrelated primary and secondary equipmentduring and after a disturbance. Recordedinformation is used for different purposes inthe short perspective (for example correctiveactions) and long perspective (for examplefunctional analysis).

The Disturbance recorder acquires sampleddata from selected analog- and binary signalsconnected to the Disturbance report function(maximum 40 analog and 96 binary signals).The binary signals available are the same asfor the event recorder function.

The function is characterized by greatflexibility and is not dependent on theoperation of protection functions. It canrecord disturbances not detected by

protection functions. Up to ten seconds ofdata before the trigger instant can be saved inthe disturbance file.

The disturbance recorder information for upto 100 disturbances are saved in the IED andthe local HMI is used to view the list ofrecordings.

Event function

When using a Substation Automation systemwith LON or SPA communication, time-tagged events can be sent at change orcyclically from the IED to the station level.These events are created from any availablesignal in the IED that is connected to theEvent function (EVENT). The event functionblock is used for LON and SPAcommunication.

Analog and double indication values are alsotransferred through EVENT function.

IEC61850 generic communicationI/O function SPGGIO

IEC61850 generic communication I/Ofunctions (SPGGIO) is used to send onesingle logical signal to other systems orequipment in the substation.

IEC61850 generic communicationI/O functions MVGGIO

IEC61850 generic communication I/Ofunctions (MVGGIO) function is used to sendthe instantaneous value of an analog outputto other systems or equipment in thesubstation. It can also be used inside thesame IED, to attach a RANGE aspect to ananalog value and to permit measurementsupervision on that value.

Measured value expander blockRANGE_XP

The current and voltage measurementsfunctions (CVMMXN, CMMXU, VMMXU andVNMMXU), current and voltage sequencemeasurement functions (CMSQI and VMSQI)and IEC 61850 generic communication I/Ofunctions (MVGGIO) are provided withmeasurement supervision functionality. Allmeasured values can be supervised with four


32 ABB

settable limits: low-low limit, low limit, highlimit and high-high limit. The measure valueexpander block (RANGE_XP) has beenintroduced to enable translating the integeroutput signal from the measuring functions to5 binary signals: below low-low limit, belowlow limit, normal, above high-high limit orabove high limit. The output signals can beused as conditions in the configurable logicor for alarming purpose.

13. Metering

Pulse counter logic PCGGIO

Pulse counter (PCGGIO) function countsexternally generated binary pulses, forinstance pulses coming from an externalenergy meter, for calculation of energyconsumption values. The pulses are capturedby the binary input module and then read bythe function. A scaled service value isavailable over the station bus. The specialBinary input module with enhanced pulsecounting capabilities must be ordered toachieve this functionality.

Function for energy calculation anddemand handling ETPMMTR

Outputs from the Measurements (CVMMXN)function can be used to calculate energyconsumption. Active as well as reactivevalues are calculated in import and exportdirection. Values can be read or generated aspulses. Maximum demand power values arealso calculated by the function.

14. Basic IED functions

Time synchronization

The time synchronization source selector isused to select a common source of absolutetime for the IED when it is a part of aprotection system. This makes it possible to

compare event- and disturbance databetween all IEDs in a station automationsystem possible.

15. Human machineinterface

Human machine interface

The local human machine interface isavailable in a small and a medium sizedmodel. The difference between the twomodels is the size of the LCD. The small sizeLCD can display seven lines of text and themedium size LCD can display the single linediagram with up to 15 objects on each page.Up to 12 single line diagram pages can bedefined, depending on the product capability.

The local HMI is divided into zones withdifferent functionality.

• Status indication LEDs.• Alarm indication LEDs, which consist of

15 LEDs (6 red and 9 yellow) with userprintable label. All LEDs are configurablefrom PCM600.

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

and navigation purposes, switch forselection between local and remotecontrol and reset.

• Isolated RJ45 communication port.


ABB 33

IEC05000055-LITEN V1 EN

Figure 9. Small, alpha numeric HMI

IEC05000056-LITEN V1 EN

Figure 10. Example of medium graphic HMI

16. Stationcommunication

Overview

Each IED is provided with a communicationinterface, enabling it to connect to one ormany substation level systems or equipment,either on the Substation Automation (SA) busor Substation Monitoring (SM) bus.

Following communication protocols areavailable:

• IEC 61850-8-1 communication protocol• LON communication protocol• SPA or IEC 60870-5-103 communication

protocol• DNP3.0 communication protocol

Theoretically, several protocols can becombined in the same IED.

IEC 61850-8-1 communicationprotocol

The IED is equipped with single or doubleoptical Ethernet rear ports (order dependent)for IEC 61850-8-1 station bus communication.The IEC 61850-8-1 communication is alsopossible from the optical Ethernet front port.IEC 61850-8-1 protocol allows intelligentelectrical devices (IEDs) from differentvendors to exchange information andsimplifies system engineering. Peer-to-peercommunication according to GOOSE is partof the standard. Disturbance files uploadingis provided.

Serial communication, LON

Existing stations with ABB station bus LONcan be extended with use of the optical LONinterface. This allows full SA functionalityincluding peer-to-peer messaging andcooperation between existing ABB IED's andthe new IED 670.

SPA communication protocol

A single glass or plastic port is provided forthe ABB SPA protocol. This allows extensions


34 ABB

of simple substation automation systems butthe main use is for Substation MonitoringSystems SMS.

IEC 60870-5-103 communicationprotocol

A single glass or plastic port is provided forthe IEC60870-5-103 standard. This allowsdesign of simple substation automationsystems including equipment from differentvendors. Disturbance files uploading isprovided.

DNP3.0 communication protocol

An electrical RS485 and an optical Ethernetport is available for the DNP3.0communication. DNP3.0 Level 2communication with unsolicited events, timesynchronizing and disturbance reporting isprovided for communication to RTUs,Gateways or HMI systems.

Multiple command and transmit

When 670 IED's are used in SubstationAutomation systems with LON, SPA orIEC60870-5-103 communication protocols theEvent and Multiple Command function blocksare used as the communication interface forvertical communication to station HMI andgateway and as interface for horizontal peer-to-peer communication (over LON only).

Duo driver configuration DUODRV

Redundant station bus communication isused to assure communication, even thoughone communication channels might not beavailable for some reason. Redundantcommunication over station bus running IEC61850-8-1 use both port AB and CD on OEMmodule and IEC 62439-PRP protocol.

17. Remotecommunication

Analog and binary signal transferto remote end

Three analog and eight binary signals can beexchanged between two IEDs. Thisfunctionality is mainly used for the linedifferential protection. However it can beused in other products as well. An IED cancommunicate with up to 4 remote IEDs.

Binary signal transfer to remoteend, 192 signals

If the communication channel is used fortransfer of binary signals only, up to 192binary signals can be exchanged betweentwo IEDs. For example, this functionality canbe used to send information such as status ofprimary switchgear apparatus or intertrippingsignals to the remote IED. An IED cancommunicate with up to 4 remote IEDs.

Line data communication module,short and medium range LDCM

The line data communication module (LDCM)is used for communication between the IEDssituated at distances <60 km or from the IEDto optical to electrical converter with G.703or G.703E1 interface located on a distances<3 km away. The LDCM module sends andreceives data, to and from another LDCMmodule. The IEEE/ANSI C37.94 standardformat is used.

This feature can be for example used inpower stations to exchange up to 192 binarysignals (e.g. tripping, signaling, alarming)between the generator and HV station inpower plants


ABB 35

18. Hardware description

Hardware modules

Power supply module PSM

The power supply module is used to providethe correct internal voltages and full isolationbetween the terminal and the battery system.An internal fail alarm output is available.

Binary input module BIM

The binary input module has 16 opticallyisolated inputs and is available in twoversions, one standard and one withenhanced pulse counting capabilities on theinputs to be used with the pulse counterfunction. The binary inputs are freelyprogrammable and can be used for the inputof logical signals to any of the functions.They can also be included in the disturbancerecording and event-recording functions. Thisenables extensive monitoring and evaluationof operation of the IED and for all associatedelectrical circuits.

Binary output module BOM

The binary output module has 24independent output relays and is used fortrip output or any signaling purpose.

Static binary output module SOM

The static binary output module has six faststatic outputs and six change over outputrelays for use in applications with high speedrequirements.

Binary input/output module IOM

The binary input/output module is usedwhen only a few input and output channelsare needed. The ten standard output channelsare used for trip output or any signalingpurpose. The two high speed signal outputchannels are used for applications whereshort operating time is essential. Eightoptically isolated binary inputs cater forrequired binary input information.

mA input module MIM

The milli-ampere input module is used tointerface transducer signals in the –20 to +20mA range from for example OLTC position,temperature or pressure transducers. Themodule has six independent, galvanicallyseparated channels.

Optical ethernet module OEM

The optical fast-ethernet module is used toconnect an IED to the communication buses(like the station bus) that use the IEC61850-8-1 protocol (port A, B). The modulehas one or two optical ports with STconnectors.

Serial and LON communication moduleSLM, supports SPA/IEC 60870-5-103, LONand DNP 3.0

The serial and LON communication module(SLM) is used for SPA, IEC 60870-5-103,DNP3 and LON communication. The modulehas two optical communication ports forplastic/plastic, plastic/glass or glass/glass.One port is used for serial communication(SPA, IEC 60870-5-103 and DNP3 port ordedicated IEC 60870-5-103 port depending onordered SLM module) and one port isdedicated for LON communication.

Line data communication module LDCM

Each module has one optical port, one foreach remote end to which the IEDcommunicates.

Alternative cards for Medium range (1310 nmsingle mode) and Short range (850 nm multimode) are available.

Galvanic RS485 serial communicationmodule

The Galvanic RS485 communication module(RS485) is used for DNP3.0 communication.The module has one RS485 communicationport. The RS485 is a balanced serialcommunication that can be used either in 2-wire or 4-wire connections. A 2-wireconnection uses the same signal for RX andTX and is a multidrop communication with


36 ABB

no dedicated Master or slave. This variantrequires however a control of the output. The4-wire connection has separated signals forRX and TX multidrop communication with adedicated Master and the rest are slaves. Nospecial control signal is needed in this case.

GPS time synchronization module GTM

This module includes a GPS receiver used fortime synchronization. The GPS has one SMAcontact for connection to an antenna. It alsoincludes an optical PPS ST-connector output.

IRIG-B Time synchronizing module

The IRIG-B time synchronizing module isused for accurate time synchronizing of theIED from a station clock.

Electrical (BNC) and optical connection (ST)for 0XX and 12X IRIG-B support.

Transformer input module TRM

The transformer input module is used togalvanically separate and transform the

secondary currents and voltages generated bythe measuring transformers. The module hastwelve inputs in different combinations ofcurrents and voltage inputs. Either protectionclass or metering class CT inputs are available.

Alternative connectors of Ring lug orCompression type can be ordered.

High impedance resistor unit

The high impedance resistor unit, withresistors for pick-up value setting and avoltage dependent resistor, is available in asingle phase unit and a three phase unit.Both are mounted on a 1/1 19 inch apparatusplate with compression type terminals.

Layout and dimensions

Dimensions

xx05000003.vsd

CB

E

F

A

D

IEC05000003 V1 EN

Figure 11. 1/2 x 19” case with rear cover


ABB 37

xx05000004.vsd

IEC05000004 V1 EN

Figure 12. Side-by-side mounting

Case size A B C D E F

6U, 1/2 x 19” 265.9 223.7 201.1 242.1 252.9 205.7

6U, 3/4 x 19” 265.9 336.0 201.1 242.1 252.9 318.0

6U, 1/1 x 19” 265.9 448.1 201.1 242.1 252.9 430.3

(mm)

Mounting alternatives

The following mounting alternatives areavailable (IP40 protection from the front):

• 19” rack mounting kit• Wall mounting kit

See ordering for details about availablemounting alternatives.

Injection equipment hardware

Injection unit REX060

The injection unit REX060 is used to injectvoltage and current signals to the generatoror motor stator and rotor circuits. REX060generates two square wave signals withdifferent frequencies for injection into thestator and rotor circuits respectively. Theresponse from the injected voltage andcurrents are then measured by the REX060unit and amplified to a level suitable for theanalog voltage inputs of IED.

Stator injection module SIM

The SIM module is installed into the REX060enclosure. The SIM module generates asquare wave voltage signal for injection intothe stator circuit via the neutral point resistoror VT/DT. The SIM module measures thevoltage and current from the injected signaland the IED consecutively calculates thestator to earth impedance. If the calculatedimpedance is lower than the preset value anALARM and/or TRIP output is set.


38 ABB

Rotor injection module RIM

The RIM module is installed into the REX060enclosure. The RIM module generates asquare wave voltage signal for injection intothe rotor circuit via a capacitor unit REX061for isolation. The RIM module measures thevoltage and current from the injected signaland the IED consecutively calculates the rotorto earth impedance. If the calculatedimpedance is lower than the preset value anALARM and/or TRIP output is set.

Coupling capacitor unit REX061

REX061 isolates the injection circuit from therotor exciter voltage.

The REX061 coupling capacitor unitgrounding point and grounding brush of therotor shaft should be properly interconnected.

Shunt resistor unit REX062

REX062 is typically used when injection isdone via a grounding transformer.


ABB 39

19. Connection diagrams

Table 1. Designations for 1/2 x 19” casing with 1 TRM slot

1MRK002801-AC 2 670 1.2 PG V1 EN

Module Rear Positions

PSM X11

BIM, BOM, SOM, IOM orMIM

X31 and X32 etc. to X51and X52

SLM X301:A, B, C, D

LDCM, IRIG-B or RS485 X302

LDCM or RS485 X303

OEM X311:A, B, C, D

LDCM, RS485 or GTM X312, 313

TRM X401


40 ABB


1MRK002801-AC 3 670 1.2 PG V1 EN


PSM X11


X31 and X32 etc. toX101 and X102

SLM X301:A, B, C, D


LDCM or RS485 X303

OEM X311:A, B, C, D

LDCM, RS485 or GTM X312, X313

TRM X401


ABB 41


1MRK002801-AC 4 670 1.2 PG V1 EN


PSM X11


X31 and X32 etc. to X71 andX72

SLM X301:A, B, C, D


LDCM or RS485 X303

OEM X311:A, B, C, D

LDCM, RS485 or GTM X312, X313, X322, X323

TRM 1 X401

TRM 2 X411


42 ABB


1MRK002801-AC 5 670 1.2 PG V1 EN


PSM X11

BIM, BOM, SOM,IOM or MIM


SLM X301:A, B, C, D

LDCM, IRIG-B orRS485

X302

LDCM or RS485 X303

OEM X311:A, B, C, D

LDCM,RS485 orGTM

X312, X313

TRM X401

Table 5. Designations for 1/1 x 19” casing with 2 TRM slots

1MRK002801-AC 6 670 1.2 PG V1 EN


PSM X11

BIM, BOM, SOM,IOM or MIM


SLM X301:A, B, C, D

LDCM, IRIG-B orRS485

X302

LDCM or RS485 X303

OEM X311:A, B, C, D

LDCM, RS485 orGTM

X312, X313, X322, X323

TRM 1 X401

TRM 2 X411


ABB 43

1MRK002801-AC 10 670 1.2 PG V1 EN

Figure 13. Transformer input module (TRM)

￭ Indicates high polarity

CT/VT-input designation according to figure 13

Curr

ent/

volt

age

confi

gura

tion

(50/

60 H

z)

AI01 AI02 AI03 AI04 AI05 AI06 AI07 AI08 AI09 AI10 AI11 AI12

12I, 1A 1A 1A 1A 1A 1A 1A 1A 1A 1A 1A 1A 1A

12I, 5A 5A 5A 5A 5A 5A 5A 5A 5A 5A 5A 5A 5A

9I+3U,1A

1A 1A 1A 1A 1A 1A 1A 1A 1A 110-220V 110-220V 110-220V

9I+3U,5A

5A 5A 5A 5A 5A 5A 5A 5A 5A 110-220V 110-220V 110-220V

5I, 1A+4I, 5A+3U

1A 1A 1A 1A 1A 5A 5A 5A 5A 110-220V 110-220V 110-220V

7I+5U,1A

1A 1A 1A 1A 1A 1A 1A 110-220V 110-220V 110-220V 110-220V 110-220V

7I+5U,5A

5A 5A 5A 5A 5A 5A 5A 110-220V 110-220V 110-220V 110-220V 110-220V

6I, 5A+1I, 1A+5U

5A 5A 5A 5A 5A 5A 1A 110-220V 110-220V 110-220V 110-220V 110-220V

3I, 5A+4I, 1A+5U

5A 5A 5A 1A 1A 1A 1A 110-220V 110-220V 110-220V 110-220V 110-220V

3IM, 1A+4IP,1A+5U

1AM*)

1AM*)

1AM*)

1A 1A 1A 1A 110-220V 110-220V 110-220V 110-220V 110-220V

3IM, 5A+4IP,5A+5U

5AM*)

5AM*)

5AM*)

5A 5A 5A 5A 110-220V 110-220V 110-220V 110-220V 110-220V

6I+6U,1A

1A 1A 1A 1A 1A 1A 110-220V 110-220V 110-220V 110-220V 110-220V 110-220V

6I+6U,5A

5A 5A 5A 5A 5A 5A 110-220V 110-220V 110-220V 110-220V 110-220V 110-220V


44 ABB

3I, 5A+3I, 1A+6U

5 A 5 A 5 A 1A 1A 1A 110-220V 110-220V 110-220V 110-220V 110-220V 110-220V

6I, 1A 1A 1A 1A 1A 1A 1A - - - - - -

6I, 5A 5A 5A 5A 5A 5A 5A - - - - - -

*) Metering

Note that internal polarity can be adjusted by setting of analog input CT neutral direction and/or on SMAI pre-processing function blocks.

1MRK002801-AC 11 670 1.2 PG V1 EN

Figure 14. Binary input module (BIM). Inputcontacts named XA corresponds torear position X31, X41, and so on,and input contacts named XB torear position X32, X42, and so on.

1MRK002801-AC 15 670 1.2 PG V1 EN

Figure 15. mA input module (MIM)


ABB 45

1MRK002801-AC 8 670 1.2 PG V1 EN

Figure 16. IED with basic functionality and communication interfaces

1MRK002801-AC 7 670 1.2 PG V1 EN

Figure 17. Power supply module (PSM)


46 ABB

1MRK002801-AC 12 670 1.2 PG V1 EN

Figure 18. Binary output module (BOM). Output contacts named XA corresponds to rearposition X31, X41, and so on, and output contacts named XB to rear positionX32, X42, and so on.

1MRK002801-AC 13 670 1.2 PG V1 EN

Figure 19. Static output module (SOM)


ABB 47

1MRK002801-AC 14 670 1.2 PG V1 EN

Figure 20. Binary in/out module (IOM). Input contacts named XA corresponds to rear positionX31, X41, and so on, and output contacts named XB to rear position X32, X42,and so on.

Injection unit REX060

1MRK002501-BA 2 PG V1 EN

Figure 21. Designation for REX060 unit casing


48 ABB


Figure 22. Power supply module


Figure 23. Stator injection module


ABB 49


Figure 24. Rotor injection module

Coupling capacitor unit REX061


Figure 25. Designation for capacitor unit casing


50 ABB


Figure 26. Coupling capacitor module

Shunt resistor unit REX062


Figure 27. Designation for shunt resistor unit casing


ABB 51


Figure 28. Shunt resistor module


52 ABB

20. Technical data

General

Definitions

Referencevalue

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

Nominalrange

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

Operativerange

The range of values of a given energizing quantity for which the equipment,under specified conditions, is able to perform its intended functionsaccording to the specified requirements

Energizing quantities, rated valuesand limits

Analog inputs

Table 6. TRM - Energizing quantities, rated values and limits for protection transformermodules

Quantity Rated value Nominal range

Current Ir = 1 or 5 A (0.2-40) × Ir

Operative range (0-100) x Ir

Permissive overload 4 × Ir cont.

100 × Ir for 1 s *)

Burden < 150 mVA at Ir = 5 A

< 20 mVA at Ir = 1 A

Ac voltage Ur = 110 V 0.5–288 V

Operative range (0–340) V

Permissive overload 420 V cont.450 V 10 s

Burden < 20 mVA at 110 V

Frequency fr = 50/60 Hz ± 5%

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


ABB 53

Table 7. TRM - Energizing quantities, rated values and limits for measuring transformermodules


Current Ir = 1 or 5 A (0-1.8) × Irat Ir = 1 A

(0-1.6) × Irat Ir = 5 A

Permissive overload 1.1 × Ir cont.

1.8 × Ir for 30 min at Ir =

1 A1.6 × Ir for 30 min at Ir =

5 A

Burden < 350 mVA at Ir = 5 A

< 200 mVA at Ir = 1 A

Ac voltage Ur = 110 V 0.5–288 V

Operative range (0–340) V

Permissive overload 420 V cont.450 V 10 s

Burden < 20 mVA at 110 V

Frequency fr = 50/60 Hz ± 5%

Table 8. MIM - mA input module

Quantity: Rated value: Nominal range:

Input resistance Rin = 194 Ohm -

Input range ± 5, ± 10, ± 20mA0-5, 0-10, 0-20, 4-20mA

-

Power consumptioneach mA-boardeach mA input

£ 2 W£ 0.1 W

-

Table 9. OEM - Optical ethernet module

Quantity Rated value

Number of channels 1 or 2

Standard IEEE 802.3u 100BASE-FX

Type of fiber 62.5/125 mm multimode fibre

Wave length 1300 nm

Optical connector Type ST

Communication speed Fast Ethernet 100 MB


54 ABB

Auxiliary DC voltage

Table 10. PSM - Power supply module


Auxiliary dc voltage, EL (input) EL = (24 - 60) VEL = (90 - 250) V

EL ± 20%EL ± 20%

Power consumption 50 W typically -

Auxiliary DC power in-rush < 5 A during 0.1 s -

Binary inputs and outputs

Table 11. BIM - Binary input module


Binary inputs 16 -

DC voltage, RL 24/30 V48/60 V110/125 V220/250 V

RL ± 20%RL ± 20%RL ± 20%RL ± 20%

Power consumption24/30 V48/60 V110/125 V220/250 V

max. 0.05 W/inputmax. 0.1 W/inputmax. 0.2 W/inputmax. 0.4 W/input

-

Counter input frequency 10 pulses/s max -

Oscillating signal discriminator Blocking settable 1–40 HzRelease settable 1–30 Hz


ABB 55

Table 12. BIM - Binary input module with enhanced pulse counting capabilities


Binary inputs 16 -


RL ± 20%RL ± 20%RL ± 20%RL ± 20%



-

Counter input frequency 10 pulses/s max -

Balanced counter input frequency 40 pulses/s max -

Oscillating signal discriminator Blocking settable 1–40 HzRelease settable 1–30 Hz

Table 13. IOM - Binary input/output module


Binary inputs 8 -


RL ± 20%RL ± 20%RL ± 20%RL ± 20%



-


56 ABB

Table 14. IOM - Binary input/output module contact data (reference standard: IEC61810-2)

Function or quantity Trip and signal relays Fast signal relays(parallel reed relay)

Binary outputs 10 2

Max system voltage 250 V AC, DC 250 V AC, DC

Test voltage across open contact, 1 min 1000 V rms 800 V DC

Current carrying capacityContinuous1 s

8 A10 A

8 A10 A

Making capacity at inductive load withL/R>10 ms0.2 s1.0 s

30 A10 A

0.4 A0.4 A

Breaking capacity for AC, cos φ > 0.4 250 V/8.0 A 250 V/8.0 A

Breaking capacity for DC with L/R < 40ms

48 V/1 A110 V/0.4 A125 V/0.35 A220 V/0.2 A250 V/0.15 A

48 V/1 A110 V/0.4 A125 V/0.35 A220 V/0.2 A250 V/0.15 A

Maximum capacitive load - 10 nF


ABB 57

Table 15. SOM - Static Output Module (reference standard: IEC 61810-2): Static binaryoutputs

Function of quantity Static binary output trip

Rated voltage 48 - 60 VDC 110 - 250 VDC

Number of outputs 6 6

Impedance open state ~300 kΩ ~810 kΩ

Test voltage across opencontact, 1 min

No galvanic separation No galvanic separation

Current carrying capacity:

Continuous 5A 5A

1.0s 10A 10A

Making capacity at capacitiveload with the maximumcapacitance of 0.2 μF :

0.2s 30A 30A

1.0s 10A 10A

Breaking capacity for DC with L/R ≤ 40ms

48V / 1A 110V / 0.4A

60V / 0,75A 125V / 0.35A

220V / 0.2A

250V / 0.15A

Operating time <1ms <1ms


58 ABB

Table 16. SOM - Static Output module data (reference standard: IEC 61810-2):Electromechanical relay outputs

Function of quantity Trip and signal relays

Max system voltage 250V AC/DC

Number of outputs 6

Test voltage across open contact, 1 min 1000V rms

Current carrying capacity:

Continuous 8A

1.0s 10A

Making capacity at capacitive load with themaximum capacitance of 0.2 μF:

0.2s 30A

1.0s 10A

Breaking capacity for DC with L/R ≤ 40ms 48V / 1A

110V / 0.4A

125V / 0,35A

220V / 0,2A

250V / 0.15A

Table 17. BOM - Binary output module contact data (reference standard: IEC 61810-2)

Function or quantity Trip and Signal relays

Binary outputs 24

Max system voltage 250 V AC, DC

Test voltage across open contact, 1 min 1000 V rms

Current carrying capacityContinuous1 s

8 A10 A

Making capacity at inductive load with L/R>10 ms0.2 s1.0 s

30 A10 A

Breaking capacity for AC, cos j>0.4 250 V/8.0 A

Breaking capacity for DC with L/R < 40 ms 48 V/1 A110 V/0.4 A125 V/0.35 A220 V/0.2 A250 V/0.15 A


ABB 59

Influencing factors

Table 18. Temperature and humidity influence

Parameter Reference value Nominal range Influence

Ambienttemperature, operatevalue

+20 °C -10 °C to +55 °C 0.02% /°C

Relative humidityOperative range

10%-90%0%-95%

10%-90% -

Storage temperature -40 °C to +70 °C - -

Table 19. Auxiliary DC supply voltage influence on functionality during operation

Dependence on Referencevalue

Withinnominal range

Influence

Ripple, in DC auxiliary voltageOperative range

max. 2%Full waverectified

15% of EL 0.01% /%

Auxiliary voltage dependence,operate value

± 20% of EL 0.01% /%

Interrupted auxiliary DC voltage

24-60 V DC ±20%90-250 V DC ±20%

Interruptioninterval0–50 ms

No restart

0–∞ s Correct behaviour atpower down

Restart time <180 s

Table 20. Frequency influence (reference standard: IEC 60255–1)

Dependence on Within nominal range Influence

Frequency dependence, operatevalue

fr ± 2.5 Hz for 50 Hz

fr ± 3.0 Hz for 60 Hz

± 1.0% / Hz

Harmonic frequencydependence (20% content)

2nd, 3rd and 5th harmonic of fr ± 1.0%

Harmonic frequencydependence for high impedancedifferential protection (10%content)

2nd, 3rd and 5th harmonic of fr ±5.0%


60 ABB

Type tests according to standards

Table 21. Electromagnetic compatibility

Test Type test values Reference standards

1 MHz burst disturbance 2.5 kV IEC 60255-22-1

100 kHz slow damped oscillatorywave immunity test

2.5 kV IEC 61000-4-18, Class III

Ring wave immunity test, 100 kHz 2-4 kV IEC 61000-4-12, Class IV

Surge withstand capability test 2.5 kV, oscillatory4.0 kV, fast transient

IEEE/ANSI C37.90.1

Electrostatic dischargeDirect applicationIndirect application

15 kV air discharge8 kV contact discharge8 kV contact discharge

IEC 60255-22-2, Class IV IEC 61000-4-2, Class IV



IEEE/ANSI C37.90.1

Fast transient disturbance 4 kV IEC 60255-22-4, Class A

Surge immunity test 1-2 kV, 1.2/50 mshigh energy

IEC 60255-22-5

Power frequency immunity test 150-300 V, 50 Hz IEC 60255-22-7, Class A

Conducted common modeimmunity test

15 Hz-150 kHz IEC 61000-4-16, Class IV

Power frequency magnetic field test 1000 A/m, 3 s100 A/m, cont.

IEC 61000-4-8, Class V

Damped oscillatory magnetic fieldtest

100 A/m IEC 61000-4-10, Class V

Radiated electromagnetic fielddisturbance

20 V/m, 80-1000 MHz 1.4-2.7 GHz

IEC 60255-22-3

Radiated electromagnetic fielddisturbance

35 V/m26-1000 MHz

IEEE/ANSI C37.90.2

Conducted electromagnetic fielddisturbance

10 V, 0.15-80 MHz IEC 60255-22-6

Radiated emission 30-1000 MHz IEC 60255-25

Conducted emission 0.15-30 MHz IEC 60255-25


ABB 61

Table 22. Insulation

Test Type test values Reference standard

Dielectric test 2.0 kV AC, 1 min. IEC 60255-5

Impulse voltage test 5 kV, 1.2/50 ms, 0.5 J

Insulation resistance >100 MW at 500 VDC

Table 23. Environmental tests

Test Type test value Reference standard

Cold test Test Ad for 16 h at -25°C IEC 60068-2-1

Storage test Test Ad for 16 h at -40°C IEC 60068-2-1

Dry heat test Test Bd for 16 h at +70°C IEC 60068-2-2

Damp heat test, steady state Test Ca for 4 days at +40 °C andhumidity 93%

IEC 60068-2-78

Damp heat test, cyclic Test Db for 6 cycles at +25 to +55°C and humidity 93 to 95% (1 cycle= 24 hours)

IEC 60068-2-30

Table 24. CE compliance

Test According to

Immunity EN 50263

Emissivity EN 50263

Low voltage directive EN 50178

Table 25. Mechanical tests


Vibration response test Class II IEC 60255-21-1

Vibration endurance test Class I IEC 60255-21-1

Shock response test Class II IEC 60255-21-2

Shock withstand test Class I IEC 60255-21-2

Bump test Class I IEC 60255-21-2

Seismic test Class II IEC 60255-21-3


62 ABB

Injection equipment

Table 26. Electromagnetic compatibility tests


1 MHz burst disturbance 2.5 kV IEC 60255-22-1

100 kHz slow damped oscillatorywave immunity test

2.5 kV IEC 61000-4-18, Class III

Surge withstand capability test 2.5 kV, oscillatory4.0 kV, fast transient

IEEE/ANSI C37.90.1



IEC 60255-22-2, Class IV IEC 61000-4-2, Class IV



IEEE/ANSI C37.90.3

Fast transient disturbance test 4 kV IEC 60255-22-4, Class A

Surge immunity test 1-2 kV, and 2-4 kV,1.2/50 µsHigh energy

IEC 60255-22-5

Power frequency immunity test 150-300 V, 50 Hz IEC 60255-22-7, Class A

Power frequency magnetic field test 1000 A/m, 3 s100 A/m, cont.

IEC 61000-4-8, Class 5

Radiated electromagnetic fielddisturbance test

20 V/m, 80-1000 MHz1.4-2.7 GHz

IEC 60255-22-3

Radiated electromagnetic fielddisturbance test

20 V/m, 80-1000 MHz IEEE/ANSI C37.90.2

Conducted electromagnetic fielddisturbance test

10 V, 0.15-80 MHz IEC 60255-22-6

Voltage dips and short interruptions Dips:40% /200 ms70% /500 msInterruptions:0-50 ms: No restart0… ∞ s: Correctbehaviour at powerdown

IEC 60255-11

Radiated emission 30-1000 MHz IEC 60255-25

Conducted emission 0.15-30 MHz IEC 60255-25


ABB 63

Table 27. Insulation tests, REX060, REX062 and REG670


Dielectric test 2.0 kV AC, 1 min IEC 60255-5

Impulse voltage test 5.0 kV, 1.2/50 µs, 0.5 J IEC 60255-5

Insulation resistance >100 MΩ at 500V DC IEC 60255-5

Table 28. Insulation tests, REX061


Dielectric test 7.48 kV DC, 1min(connections to rotor) 2.8 kV DC, 1 min

IEEE 421.3 IEC 60255-5

Impulse voltage test 12.0 kV, 1.2/50 µs, 0.5J (connections to rotor) 5.0 kV, 1.2/50 µs, 0.5 J

IEC 60664-1 IEC 60255-5

Insulation resistance >100 MΩ at 500V DC IEC 60255-5

Table 29. Mechanical tests

Test Reference standards Requirements

Vibration response test IEC 60255-21-1 Class 2

Vibration endurance testREG670 and REX060REX061 and REX062

IEC 60255-21-1 Class 1Class 2

Shock response test IEC 60255-21-2 Class 2

Shock withstand testREG670 and REX060REX061 and REX062


Bump testREG670 and REX060REX061 and REX062


Seismic testREG670 and REX060REX061 and REX062

IEC 60255-21-3 Class 2Class 2 extended


64 ABB

Table 30. Environmental tests

Test Type test value Reference standard

Cold testoperationstorage

16 h at -25°C16 h at -40°C

IEC 60068-2-1

Dry heat testoperationstorage

16 h at +70°C16 h at +85°C

IEC 60068-2-2

Damp heat teststeady state cyclic

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

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

Table 31. Auxiliary DC supply voltage influence

Test Type test values Influence

Auxiliary voltagedependence, operate value

±20% of EL 0.01% /°C

Ripple in DC auxiliaryvoltage, operate value

15% of EL 0.01% /°C

Table 32. Temperature influence

Test Type test values Influence

Ambient temperature,operate value

-25° C to +55°C 0.01% /°C

Storage temperature -40° C to +85°C -

Table 33. Degree of protection

Description Values

REX060Front sidePanel mounted, frontRear side, connection terminals

IP40IP54IP20

REX061 and REX062Front and sideBottom side

IP41IP20


ABB 65


Table 34. Generator differential protection GENPDIF

Function Range or value Accuracy

Reset ratio > 95% -

Unrestrained differential currentlimit

(1-50)p.u. of IBase ± 2.0% of set value

Base sensitivity function (0.05–1.00)p.u. ofIBase

± 2.0% of Ir

Negative sequence current level (0.02–0.2)p.u. ofIBase

± 1.0% of Ir

Operate time, restrained function 25 ms typically at0 to 2 x set level

-

Reset time, restrained function 20 ms typically at2 to 0 x set level

-

Operate time, unrestrainedfunction

12 ms typically at0 to 5 x set level

-

Reset time, unrestrained function 25 ms typically at5 to 0 x set level

-

Operate time, negative sequenceunrestrained function

15 ms typically at0 to 5 x set level

-

Critical impulse time, unrestrainedfunction

2 ms typically at 0to 5 x set level

-


66 ABB

Table 35. Transformer differential protection T2WPDIF, T3WPDIF


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

Reset ratio >95% -

Unrestrained differential currentlimit

(100-5000)%ofIBase on highvoltage winding

± 1.0% of set value

Base sensitivity function (10-60)% of IBase ± 1.0% of Ir

Second harmonic blocking (5.0-100.0)% offundamentaldifferential current

± 2.0% of Ir

Fifth harmonic blocking (5.0-100.0)% offundamentaldifferential current

± 5.0% of Ir

Connection type for each of thewindings

Y or D -

Phase displacement between highvoltage winding, W1 and each ofthe windings, W2 and W3. Hournotation

0–11 -

Operate time, restrained function 25 ms typically at0 to 2 x Ib

-

Reset time, restrained function 20 ms typically at2 to 0 x Ib

-

Operate time, unrestrainedfunction

12 ms typically at0 to 5 x Ib

-

Reset time, unrestrained function 25 ms typically at5 to 0 x Ib

-

Critical impulse time 2 ms typically at 0to 5 x Ib

-


ABB 67

Table 36. Restricted earth fault protection, low impedance REFPDIF


Operate characteristic Adaptable ± 1.0% of Ir for I < IBase

± 1.0% of I for I > IBase

Reset ratio >95% -

Base sensitivity function (4.0-100.0)% of IBase ± 1.0% of Ir

Directional characteristic Fixed 180 degrees or ± 60to ± 90 degrees

± 2.0 degree

Operate time, trip function 20 ms typically at 0 to 10x IdMin

-

Reset time, trip function 25 ms typically at 10 to 0x IdMin

-

Second harmonic blocking (5.0-100.0)% offundamental

± 2.0% of IrBase

Table 37. 1Ph High impedance differential protection HZPDIF


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

± 1.0% of Ir

Reset ratio >95% -

Maximum continuous voltage U>Trip2/series resistor ≤200 W -

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

Reset time 90 ms typically at 10 to 0 x Ud -

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


68 ABB


Table 38. Full-scheme distance protection, Mho characteristic ZMHPDIS


Number of zones withselectable directions

4 with selectabledirection

-

Minimum operate current (10–30)% of IBase -

Positive sequenceimpedance, phase-to-earth loop

(0.005–3000.000) W/phase

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

Current range: (0.5-30) x IrAngle: at 0 degrees and 85 degrees

Positive sequenceimpedance angle, phase-to-earth loop

(10–90) degrees

Reverse reach, phase-to-earth loop (Magnitude)

(0.005–3000.000) Ω/phase

Magnitude of earth returncompensation factor KN

(0.00–3.00)

Angle for earthcompensation factor KN

(-180–180) degrees

Dynamic overreach <5% at 85 degreesmeasured with CVT’sand 0.5<SIR<30

-

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

Operate time 20 ms typically (withstatic outputs)

-

Reset ratio 105% typically -

Reset time 30 ms typically -

Table 39. Pole slip protection PSPPPAM


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 tripcounters

(1-20) -


ABB 69

Table 40. Loss of excitation LEXPDIS


X offset of Mho top point (–1000.00–1000.00)% ofZBase

± 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% ± 10 ms

Table 41. ROTIPHIZ technical data


Fault resistance sensitivity Can be reached 500 kΩ

Typically 50 kΩ

Injection frequency (75.000 - 250.000) Hz ±0.1 Hz

Trip limit of fault resistance (100 - 100000)Ω 5% of 1 kΩ at Rf ≤ 1 kΩ

5% of set value at 1 kΩ < Rf ≤ 20 kΩ

10% of set value at Rf > 20 kΩ

Alarm limit of fault resistance (100 - 1000000)Ω 5% of 1 kΩ at Rf ≤ 1 kΩ

5% of 10 kΩ at 1 kΩ < Rf ≤ 20 kΩ

10% of set value at 20 kΩ < Rf ≤ 200

kΩ

Operate time, start 1.00 s typically -

Operate time, trip 2.00 s typically -

Alarm time delay (0.00 - 600.00) s ±0.5% ±10 ms


70 ABB

Table 42. STTIPHIZ technical data


Fault resistance sensitivity Can be reached atsteady state operatingcondition of themachine

50 kΩ

Typically 10 kΩ

Injection frequency (50.000 - 250.000) Hz ±0.1 Hz

Trip limit of fault resistance (100 - 10000)Ω ±5% of 1 kΩ at Rf ≤ 1 kΩ

±10% of set value at Rf > 1 kΩ

Alarm limit of fault resistance (100 - 100000)Ω ±5% of 1 kΩ at Rf ≤ 1 kΩ

±10% of 10 kΩ at 1 kΩ < Rf ≤ 10 kΩ

±50% of set value at Rf > 10 kΩ

Operate time, start 1.00 s typically -

Operate time, trip 2.00 s typically -

Alarm time delay (0.00 - 600.00) s ±0.5% ±10 ms


ABB 71

Current protection

Table 43. Instantaneous phase overcurrent protection PHPIOC


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

Reset ratio > 95% -

Operate time 25 ms typically at 0 to 2 x Iset -

Reset time 25 ms typically at 2 to 0 x Iset -

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




Dynamic overreach < 5% at t = 100 ms -


72 ABB

Table 44. Four step phase overcurrent protection OC4PTOC

Function Setting range Accuracy

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

Reset ratio > 95% -

Min. operating current (1-100)% of lBase ± 1.0% of Ir at I ≤ Ir±1.0% of I at I > Ir

Relay characteristic angle(RCA)

(-70.0– -50.0) degrees ± 2.0 degrees

Maximum forward angle (40.0–70.0) degrees ± 2.0 degrees

Minimum forward angle (75.0–90.0) degrees ± 2.0 degrees

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

Independent time delay (0.000-60.000) s ± 0.5% ±10 ms

Minimum operate time (0.000-60.000) s ± 0.5% ±10 ms

Inverse characteristics,see table 105, table 106and table 107

19 curve types See table 105, table 106and table 107

Operate time, startfunction

25 ms typically at 0 to 2 x Iset -

Reset time, start function 25 ms typically at 2 to 0 x Iset -


Impulse margin time 15 ms typically -


ABB 73

Table 45. Instantaneous residual overcurrent protection EFPIOC



Reset ratio > 95% -







Dynamic overreach < 5% at t = 100 ms -


74 ABB

Table 46. Four step residual overcurrent protection EF4PTOC



Reset ratio > 95% -

Operate current fordirectional comparison

(1–100)% of lBase ± 1.0% of Ir

Timers (0.000-60.000) s ± 0.5% ±10 ms



Second harmonic restrainoperation

(5–100)% of fundamental ± 2.0% of Ir

Relay characteristic angle (-180 to 180) degrees ± 2.0 degrees

Minimum polarizingvoltage

(1–100)% of UBase ± 0.5% of Ur

Minimum polarizingcurrent

(1-30)% of IBase ±0.25% of Ir

Real part of source Zused for currentpolarization

(0.50-1000.00) W/phase -

Imaginary part of sourceZ used for currentpolarization

(0.50–3000.00) W/phase -







ABB 75

Table 47. Four step negative sequence overcurrent protection NS4PTOC


Operate value, negativesequence current, step 1-4

(1-2500)% 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



Minimum operate currentfor step 1 - 4

(1.00 - 10000.00)% of IBase ± 1.0% of Ir at I < Ir± 1.0% of I at I > Ir

Operate value, negativecurrent for directionalrelease

(1–100)% of IBase ± 1.0% of Ir

Relay characteristic angle (-180 to 180) degrees ± 2.0 degrees

Minimum polarizingvoltage

(1–100)% of UBase ± 0.5% of Ur

Minimum polarizingcurrent

(2-100)% of IBase ±1.0% of Ir

Real part of negativesequence sourceimpedance used forcurrent polarization

(0.50-1000.00) W/phase -

Imaginary part ofnegative sequence sourceimpedance used forcurrent polarization

(0.50–3000.00) W/phase -


25 ms typically at 0.5 to 2 x Iset -

Reset time, start function 25 ms typically at 2 to 0.5 x Iset -

Critical impulse time, startfunction


Impulse margin time,start function

15 ms typically -

Transient overreach <10% at τ = 100 ms -


76 ABB

Table 48. Sensitive directional residual overcurrent and power protection SDEPSDE


Operate level for 3I0·cosjdirectional 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

± 1.0% of Sr at S £ Sr

± 1.0% of S at S > Sr

± 10% of set value

Operate level for 3I0 and

j residual 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 currentfor all directional modes


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

Residual release voltagefor all directional modes

(0.01-200.00)% 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% ±10 ms



Relay characteristic angleRCA

(-179 to 180) degrees ± 2.0 degrees

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


ABB 77

Table 48. Sensitive directional residual overcurrent and power protection SDEPSDE,continued


Operate time, non-directional residual overcurrent


Reset time, non-directional residual overcurrent





Table 49. 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

overload occurs

Time constant τ = (1–500)minutes

IEC 60255–8, class 5 + 200 ms

Alarm level 1 and 2 (50–99)% of heat contenttrip value

± 2.0% of heat content trip

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

Reset level temperature (10–95)% of heat contenttrip

± 2.0% of heat content trip


78 ABB

Table 50. Breaker failure protection 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 forblocking of contact 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 currentdetection

10 ms typically -

Reset time for currentdetection

15 ms maximum -

Table 51. Pole discordance protection CCRPLD


Operate current (0–100)% of IBase ± 1.0% of Ir

Time delay (0.000-60.000) s ± 0.5% ± 10 ms

Table 52. Directional underpower protection GUPPDUP


Power level (0.0–500.0)% of SBase At low setting:(0.5-2.0)% of SBase(2.0-10)% of SBase

± 1.0% of Sr at S < Sr

± 1.0% of S at S > Sr

< ± 50% of set value< ± 20% of set value

Characteristic angle (-180.0–180.0) degrees 2 degrees

Timers (0.00-6000.00) s ± 0.5% ± 10 ms


ABB 79

Table 53. Directional overpower protection GOPPDOP


Power level (0.0–500.0)% of Sbase

At low setting:(0.5-2.0)% of Sbase

(2.0-10)% of Sbase

± 1.0% of Sr at S < Sr

± 1.0% of S at S > Sr

< ± 50% of set value< ± 20% of set value

Characteristic angle (-180.0–180.0) degrees 2 degrees

Timers (0.00-6000.00) s ± 0.5% ± 10 ms

Table 54. Negative sequence time overcurrent protection for machines NS2PTOC


Operate value, step 1 and 2,negative sequenceovercurrent

(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 20 ms typically at 0 to 2 x Iset

15 ms typically at 0 to 10 x Iset

-

Reset time, start 30 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 Class 5 + 40 ms

Reset time, inversecharacteristic step 1,

22I t K=

K=0.01-20.00 Class 10 + 40 ms

Maximum trip delay, step 1IDMT

(0.00-6000.00) s ± 0.5% ± 10 ms

Minimum trip delay, step 1IDMT

(0.000-60.000) s ± 0.5% ± 10 ms

Timers (0.00-6000.00) s ± 0.5% ± 10 ms


80 ABB

Table 55. 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,overcurrent function

<10% at τ = 100 ms -

Critical impulse time,overcurrent


Impulse margin time,overcurrent

10 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% ± 10 ms


ABB 81

Voltage protection

Table 56. Two step undervoltage protection UV2PTUV


Operate voltage, low andhigh step

(1–100)% of UBase ± 0.5% of Ur

Absolute hysteresis (0–100)% of UBase ± 0.5% of Ur

Internal blocking level, lowand high step

(1–100)% of UBase ± 0.5% of Ur

Inverse time characteristicsfor low and high step, seetable 109

- See table 109

Definite time delays (0.000-60.000) s ± 0.5% ±10 ms

Minimum operate time,inverse characteristics

(0.000–60.000) s ± 0.5% ± 10 ms

Operate time, start function 25 ms typically at 2 to 0 x Uset -

Reset time, start function 25 ms typically at 0 to 2 x Uset -

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


Table 57. Two step overvoltage protection OV2PTOV



(1-200)% of UBase ± 0.5% of Ur at U < Ur

± 0.5% of U at U > Ur

Absolute hysteresis (0–100)% of UBase ± 0.5% of Ur at U < Ur

± 0.5% of U at U > Ur


- See table 108

Definite time delays (0.000-60.000) s ± 0.5% ± 10 ms

Minimum operate time,Inverse characteristics

(0.000-60.000) s ± 0.5% ± 10 ms



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



82 ABB

Table 58. Two step residual overvoltage protection ROV2PTOV



(1-200)% of UBase ± 0.5% of Ur at U < Ur

± 1.0% of U at U > Ur

Absolute hysteresis (0–100)% of UBase ± 0.5% of Ur at U < Ur

± 1.0% of U at U > Ur


- See table 110

Definite time setting (0.000–60.000) s ± 0.5% ± 10 ms

Minimum operate time (0.000-60.000) s ± 0.5% ± 10 ms





Table 59. 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 or customer defined

2

(0.18 ):

( 1)k

IEEE tM

×=

-


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

Class 5 + 40 ms

Minimum time delay forinverse function

(0.000–60.000) s ± 0.5% ± 10 ms

Maximum time delay forinverse function

(0.00–9000.00) s ± 0.5% ± 10 ms

Alarm time delay (0.000–60.000) s ± 0.5% ± 10 ms


ABB 83

Table 60. Voltage differential protection VDCPTOV


Voltage difference foralarm and trip

(0.0–100.0) % of UBase ± 0.5 % of Ur

Under voltage level (0.0–100.0) % of UBase ± 0.5% of Ur

Timers (0.000–60.000)s ± 0.5% ± 10 ms

Table 61. 100% Stator E/F 3rd harmonic STEFPHIZ


Fundamental frequencylevel UN (95% Stator EF)

(1.0–50.0)% of UBase ± 0.5% of Ur

Third harmonicdifferential level

(0.5–10.0)% of UBase ± 0.5% of Ur

Third harmonicdifferential block level

(0.1–10.0)% of UBase ± 0.5% of Ur

Timers (0.020–60.000) s ± 0.5% ± 10 ms

Filter characteristic:FundamentalThird harmonic

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

-


84 ABB


Table 62. Underfrequency protection SAPTUF


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

Operate time, start function 100 ms typically -

Reset time, start function 100 ms typically -

Operate time, definite time function (0.000-60.000)s ± 0.5% ± 10 ms

Reset time, definite time function (0.000-60.000)s ± 0.5% ± 10 ms

Voltage dependent time delay

( )ExponentU UMin

t tMax tMin tMinUNom UMin

-= × - +

-é ùê úë û


U=Umeasured

Settings:UNom=(50-150)% ofUbase

UMin=(50-150)% of Ubase

Exponent=0.0-5.0tMax=(0.000-60.000)stMin=(0.000-60.000)s

Class 5 + 200 ms

Table 63. Overfrequency protection SAPTOF


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

Operate time, start function 100 ms typically at fset -0.5 Hz to

fset +0.5 Hz

-

Reset time, start function 100 ms typically -

Operate time, definite time function (0.000-60.000)s ± 0.5% ± 10 ms

Reset time, definite time function (0.000-60.000)s ± 0.5% ± 10 ms

Table 64. Rate-of-change frequency protection SAPFRC


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

Operate value, internal blockinglevel

(0-100)% of UBase ± 0.5% of Ur

Operate time, start function 100 ms typically -


ABB 85


Table 65. General current and voltage protection CVGAPC


Measuring current input phase1, phase2, phase3,PosSeq, NegSeq, 3*ZeroSeq,MaxPh, MinPh, UnbalancePh,phase1-phase2, phase2-phase3,phase3-phase1, MaxPh-Ph,MinPh-Ph, UnbalancePh-Ph

-

Base current (1 - 99999) A -

Measuring voltage input phase1, phase2, phase3,PosSeq, -NegSeq, -3*ZeroSeq,MaxPh, MinPh, UnbalancePh,phase1-phase2, phase2-phase3,phase3-phase1, MaxPh-Ph,MinPh-Ph, UnbalancePh-Ph

-

Base voltage (0.05 - 2000.00) kV -

Start overcurrent, step 1 and 2 (2 - 5000)% of IBase ± 1.0% of Ir for I<Ir± 1.0% of I for I>Ir

Start undercurrent, step 1and 2

(2 - 150)% of IBase ± 1.0% of Ir for I<Ir± 1.0% of I for I>Ir

Definite time delay (0.00 - 6000.00) s ± 0.5% ± 10 ms

Operate time startovercurrent


Reset time start overcurrent 25 ms typically at 2 to 0 x Iset -

Operate time startundercurrent


Reset time start undercurrent 25 ms typically at 0 to 2 x Iset -

See table 105 and table 106 Parameter ranges for customerdefined characteristic no 17:k: 0.05 - 999.00A: 0.0000 - 999.0000B: 0.0000 - 99.0000C: 0.0000 - 1.0000P: 0.0001 - 10.0000PR: 0.005 - 3.000TR: 0.005 - 600.000CR: 0.1 - 10.0

See table 105 and table 106


86 ABB

Table 65. General current and voltage protection CVGAPC , continued


Voltage level where voltagememory takes over

(0.0 - 5.0)% of UBase ± 0.5% of Ur

Start overvoltage, step 1 and 2 (2.0 - 200.0)% of UBase ± 0.5% of Ur for U<Ur

± 0.5% of U for U>Ur

Start undervoltage, step 1and 2

(2.0 - 150.0)% of UBase ± 0.5% of Ur for U<Ur


Operate time, startovervoltage

25 ms typically at 0 to 2 x Uset -

Reset time, start overvoltage 25 ms typically at 2 to 0 x Uset -

Operate time startundervoltage

25 ms typically 2 to 0 x Uset -

Reset time start undervoltage 25 ms typically at 0 to 2 x Uset -

High and low voltage limit,voltage dependent operation

(1.0 - 200.0)% of UBase ± 1.0% of Ur for U<Ur


Directional function Settable: NonDir, forward andreverse

-

Relay characteristic angle (-180 to +180) degrees ± 2.0 degrees

Relay operate angle (1 to 90) degrees ± 2.0 degrees

Reset ratio, overcurrent > 95% -

Reset ratio, undercurrent < 105% -

Reset ratio, overvoltage > 95% -

Reset ratio, undervoltage < 105% -

Overcurrent:



Undercurrent:



Overvoltage:




ABB 87

Table 65. General current and voltage protection CVGAPC , continued


Undervoltage:



Table 66. Rotor earth fault protection based on General current and voltage protection(CVGAPC) and RXTTE4


For machines with:

• rated field voltage up to 350 V DC -

• static exciter with ratedsupply voltage up to

700 V 50/60 Hz -

Supply voltage 120 or230 V

50/60 Hz -

Operate earth faultresistance value

Approx. 1–20 kΩ -

Influence of harmonics inthe DC field voltage

Negligible influence of 50V, 150 Hz or 50 V, 300 Hz

-

Permitted leakagecapacitance

(1–5) μF

Permitted shaft earthingresistance

Maximum 200 Ω -

Protective resistor 220 Ω, 100 W, plate 135 x160 mm

-


88 ABB


Table 67. Current circuit supervision CCSRDIF


Operate current (5-200)% of Ir ± 10.0% of Ir at I £ Ir± 10.0% of I at I > Ir

Block current (5-500)% of Ir ± 5.0% of Ir at I £ Ir± 5.0% of I at I > Ir

Table 68. 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, negativesequence

(1–100)% of UBase ± 0.5% of Ur

Operate current, negativesequence

(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

Operate time, start function 25 ms typically at 1 to 0Ubase

-

Reset time, start function 35 ms typically at 0 to 1Ubase

-


ABB 89

Control

Table 69. Synchronizing, synchrocheck and energizing check SESRSYN


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

Voltage ratio, Ubus/Uline (0.40-25.000) % ofUBaseBus and UBaseLIne

-

Voltage high limit for synchronizingand synchrocheck

(50.0-120.0)% ofUBaseBus and UBaseLIne

± 0.5% of Ur at U ≤ Ur

± 0.5% of U at U >Ur

Reset ratio, synchrocheck > 95% -

Frequency difference limit betweenbus and line

(0.003-1.000) Hz ± 2.0 mHz

Phase angle difference limitbetween bus and line

(5.0-90.0) degrees ± 2.0 degrees

Voltage difference limit betweenbus and line

(0.02-0.5) p.u ± 0.5% of Ur

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

Voltage high limit for energizingcheck

(50.0-120.0)% ofUBaseBus and UBaseLIne



Reset ratio, voltage high limit > 95% -

Voltage low limit for energizingcheck

(10.0-80.0)% of UBase ± 0.5% of Ur

Reset ratio, voltage low limit < 105% -

Maximum voltage for energizing (50.0-180.0)% ofUBaseBus and/orUBaseLIne



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

Operate time for synchrocheckfunction

160 ms typically -

Operate time for energizing function 80 ms typically -


90 ABB

Logic

Table 70. Tripping logic SMPPTRC


Trip action 3-ph, 1/3-ph, 1/2/3-ph -

Minimum trip pulse length (0.000-60.000) s ± 0.5% ± 10 ms

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

Table 71. Configurable logic blocks

Logic block Quantity with cycle time Range or value Accuracy

fast medium normal

LogicAND 60 60 160 - -

LogicOR 60 60 160 - -

LogicXOR 10 10 20 - -

LogicInverter 30 30 80 - -

LogicSRMemory 10 10 20 - -

LogicRSMemory 10 10 20 - -

LogicGate 10 10 20 - -

LogicTimer 10 10 20 (0.000–90000.000) s ± 0.5% ± 10 ms

LogicPulseTimer 10 10 20 (0.000–90000.000) s ± 0.5% ± 10 ms

LogicTimerSet 10 10 20 (0.000–90000.000) s ± 0.5% ± 10 ms

LogicLoopDelay 10 10 20 (0.000–90000.000) s ± 0.5% ± 10 ms

Trip Matrix Logic 6 6 - - -

Boolean 16 toInteger

4 4 8 - -

Boolean 16 tointeger withLogic Node

4 4 8 - -

Integer toBoolean 16

4 4 8 - -

Integer toBoolean 16 withLogic Node

4 4 8 - -


ABB 91

Monitoring

Table 72. Measurements CVMMXN


Frequency (0.95-1.05) × fr ± 2.0 mHz

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< U < 1.5 x Ur

0.2 x Ir < I < 4.0 x Ir

± 1.0% of Sr at S ≤ Sr

± 1.0% of S at S > Sr

Conditions:0.8 x Ur < U < 1.2 Ur

0.2 x Ir < I < 1.2 Ir

Reactive power, Q 0.1 x Ur< U < 1.5 x Ur

0.2 x Ir < I < 4.0 x Ir

Apparent power, S 0.1 x Ur < U < 1.5 x Ur

0.2 x Ir< I < 4.0 x Ir

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 73. Supervision of mA input signals


mA measuring function ± 5, ± 10, ± 20 mA0-5, 0-10, 0-20, 4-20 mA

± 0.1 % of set value ± 0.005 mA

Max current oftransducer to input

(-20.00 to +20.00) mA

Min current oftransducer to input

(-20.00 to +20.00) mA

Alarm level for input (-20.00 to +20.00) mA

Warning level for input (-20.00 to +20.00) mA

Alarm hysteresis forinput

(0.0-20.0) mA

Table 74. Event counter CNTGGIO


Counter value 0-10000 -

Max. count up speed 10 pulses/s -


92 ABB

Table 75. Disturbance report DRPRDRE


Pre-fault time (0.05–9.90) s -

Post-fault time (0.1–10.0) s -

Limit time (0.5–10.0) s -

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

Time tagging resolution 1 ms See table 101

Maximum number of analog inputs 30 + 10 (external +internally derived)

-

Maximum number of binary inputs 96 -

Maximum number of phasors in the TripValue recorder per recording

30 -

Maximum number of indications in adisturbance report

96 -

Maximum number of events in the Eventrecording per recording

150 -

Maximum number of events in the Eventlist

1000, first in - first out -

Maximum total recording time (3.4 srecording time and maximum number ofchannels, typical value)

340 seconds (100recordings) at 50 Hz, 280seconds (80 recordings)at 60 Hz

-

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

-

Recording bandwidth (5-300) Hz -

Table 76. Event list

Function Value

Buffer capacity Maximum number of events inthe list

1000

Resolution 1 ms

Accuracy Depending on timesynchronizing


ABB 93

Table 77. Indications

Function Value

Buffer capacity Maximum number of indications presentedfor single disturbance

96

Maximum number of recorded disturbances 100

Table 78. Event recorder

Function Value

Buffer capacity Maximum number of events in disturbance report 150

Maximum number of disturbance reports 100

Resolution 1 ms

Accuracy Depending ontimesynchronizing

Table 79. Trip value recorder

Function Value

Buffer capacity

Maximum number of analog inputs 30


Table 80. Disturbance recorder

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 andmaximum number of channels, typical value)

340 seconds (100 recordings)at 50 Hz280 seconds (80 recordings) at60 Hz


94 ABB

Metering

Table 81. Pulse counter PCGGIO

Function Setting range Accuracy

Input frequency See Binary Input Module (BIM) -

Cycle time for report ofcounter value

(1–3600) s -

Table 82. Energy metering ETPMMTR


Energy metering kWh Export/Import,kvarh Export/Import

Input from MMXU. No extra errorat steady load


ABB 95


Table 83. IEC 61850-8-1 communication protocol

Function Value

Protocol IEC 61850-8-1

Communication speed for the IEDs 100BASE-FX

Table 84. LON communication protocol

Function Value

Protocol LON

Communication speed 1.25 Mbit/s

Table 85. SPA communication protocol

Function Value

Protocol SPA

Communication speed 300, 1200, 2400, 4800, 9600, 19200 or 38400 Bd

Slave number 1 to 899

Table 86. IEC60870-5-103 communication protocol

Function Value


Communication speed 9600, 19200 Bd

Table 87. SLM – LON port

Quantity Range or value

Optical connector Glass fibre: type STPlastic fibre: type HFBR snap-in

Fibre, optical budget Glass fibre: 11 dB (1000 m typically *)Plastic fibre: 7 dB (10 m typically *)

Fibre diameter Glass fibre: 62.5/125 mmPlastic fibre: 1 mm

*) depending on optical budget calculation


96 ABB

Table 88. SLM – SPA/IEC 60870-5-103/DNP3 port


Optical connector Glass fibre: type STPlastic fibre: type HFBR snap-in

Fibre, optical budget Glass fibre: 11 dB (3000ft/1000 m typically *)Plastic fibre: 7 dB (80ft/25 m typically *)

Fibre diameter Glass fibre: 62.5/125 mmPlastic fibre: 1 mm

*) depending on optical budget calculation

Table 89. Galvanic RS485 communication module


Communication speed 2400–19200 bauds

External connectors RS-485 6-pole connectorSoft ground 2-pole connector

Table 90. Duo driver configuration DUODRV

Function Value


Communication speed 100 Base-FX


ABB 97

Remote communication

Table 91. Line data communication module

Characteristic Range or value

Type of LDCM Short range(SR)

Medium range(MR)

Long range (LR)

Type of fibre Graded-indexmultimode62.5/125 µmor 50/125 µm

Singlemode9/125 µm

Singlemode 9/125 µm

Wave length 850 nm 1310 nm 1550 nm

Optical budgetGraded-index multimode62.5/125 mm, Graded-index multimode50/125 mm

13 dB (typicaldistanceabout 3 km *)9 dB (typicaldistanceabout 2 km *)

22 dB (typicaldistance 80 km *)

26 dB (typical distance110 km *)

Optical connector Type ST Type FC/PC Type FC/PC

Protocol C37.94 C37.94implementation**)

C37.94 implementation **)

Data transmission Synchronous Synchronous Synchronous

Transmission rate / Data rate 2 Mb/s / 64kbit/s

2 Mb/s / 64 kbit/s

2 Mb/s / 64 kbit/s

Clock source Internal orderived fromreceivedsignal

Internal orderived fromreceived signal

Internal or derived fromreceived signal

*) depending on optical budget calculation**) C37.94 originally defined just for multimode; using same header, configuration and dataformat as C37.94


98 ABB

Hardware

IED

Table 92. Case

Material Steel sheet

Front plate Steel sheet profile with cut-out for HMI

Surface treatment Aluzink preplated steel

Finish Light grey (RAL 7035)

Table 93. Water and dust protection level according to IEC 60529

Front IP40 (IP54 with sealing strip)

Rear, sides, topand bottom

IP20

Table 94. Weight

Case size Weight

6U, 1/2 x 19” £ 10 kg

6U, 3/4 x 19” £ 15 kg

6U, 1/1 x 19” £ 18 kg

Connection system

Table 95. CT and VT circuit connectors

Connector type Rated voltage andcurrent

Maximum conductorarea

Screw compression type 250 V AC, 20 A 4 mm2 (AWG12)

2 x 2.5 mm2 (2 x AWG14)

Terminal blocks suitable for ringlug terminals

250 V AC, 20 A 4 mm2 (AWG12)

Table 96. Binary I/O connection system

Connector type Rated voltage Maximum conductorarea

Screw compression type 250 V AC 2.5 mm2 (AWG14)

2 × 1 mm2 (2 x AWG18)

Terminal blocks suitable for ringlug terminals

300 V AC 3 mm2 (AWG14)


ABB 99

Injection equipment hardware

Table 97. Injection unit REX060

Specifications Values

Case size 6U, 1/2 19”; 223.7 x 245 x 267 mm (W x D xH)

Weight 8.0 kg

Firmware 1p0r00, loaded in the HMI & Logic module

Table 98. Coupling capacitor unit REX061

Function Range or values Accuracy

For machines with:

• rated field voltage up to 800 V DC -

• static exciter with ratedsupply voltage up to

1600 V 50/60 Hz -


Case size 218 x 150 x 243 mm (W x D x H)

Weight 4.8 kg

Assembling 6 x 5 mm screws (3 at bottom and 3 at top)

Table 99. Shunt resistor unit REX062


Case size 218 x 150 x 243 mm (W x D x H)

Weight 4.5 kg

Assembling 6 x 5 mm screws (3 at bottom and 3 at top)


100 ABB

Basic IED functions

Table 100. Self supervision with internal event list

Data Value

Recording manner Continuous, event controlled

List size 1000 events, first in-first out

Table 101. Time synchronization, time tagging

Function Value

Time tagging resolution, events and sampled measurement values 1 ms

Time tagging error with synchronization once/min (minute pulsesynchronization), events and sampled measurement values

± 1.0 ms typically

Time tagging error with SNTP synchronization, sampledmeasurement values

± 1.0 ms typically

Table 102. GPS time synchronization module (GTM)


Receiver – ±1µs relative UTC

Time to reliable time reference withantenna in new position or after powerloss longer than 1 month

<30 minutes –

Time to reliable time reference after apower loss longer than 48 hours

<15 minutes –

Time to reliable time reference after apower loss shorter than 48 hours

<5 minutes –

Table 103. GPS – Antenna and cable

Function Value

Max antenna cable attenuation 26 db @ 1.6 GHz

Antenna cable impedance 50 ohm

Lightning protection Must be provided externally

Antenna cable connector SMA in receiver endTNC in antenna end


ABB 101

Table 104. IRIG-B

Quantity Rated value

Number of channels IRIG-B 1

Number of channels PPS 1

Electrical connector IRIG-B BNC

Optical connector PPS and IRIG-B Type ST

Type of fibre 62.5/125 μm multimode fibre

Pulse-width modulated 5 Vpp

Amplitude modulated– low level– high level

1-3 Vpp3 x low level, max 9 Vpp


102 ABB

Inverse characteristic

Table 105. ANSI Inverse time characteristics


Operating characteristic:

( )1= + ×

-

æ öç ÷ç ÷è ø

P

At B k

I

EQUATION1249-SMALL V1 EN

Reset characteristic:

( )2 1= ×

-

trt kI


I = Imeasured/Iset

k = (0.05-999) in steps of 0.01unless otherwise stated

-

ANSI Extremely Inverse A=28.2, B=0.1217, P=2.0 , tr=29.1 ANSI/IEEE C37.112,class 5 + 40 ms

ANSI Very inverse A=19.61, B=0.491, P=2.0 , tr=21.6

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, tr=4.85

ANSI Long Time ExtremelyInverse

A=64.07, B=0.250, P=2.0, tr=30

ANSI Long Time Very Inverse A=28.55, B=0.712, P=2.0, tr=13.46

ANSI Long Time Inverse k=(0.05-999) in steps of 0.01A=0.086, B=0.185, P=0.02, tr=4.6


ABB 103

Table 106. IEC Inverse time characteristics


Operating characteristic:

( )1= ×

-


P

At k

I


I = Imeasured/Iset

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

Time delay to reset, IEC inversetime

(0.000-60.000) s ± 0.5% of set time ±10 ms

IEC Normal Inverse A=0.14, P=0.02 IEC 60255-3, class 5+ 40 ms

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

Programmable characteristicOperate characteristic:

( )= + ×

-


P

At B k

I C


Reset characteristic:

( )= ×

-PR

TRt k

I CR


I = Imeasured/Iset

k = (0.05-999) in steps of 0.01A=(0.005-200.000) in steps of 0.001B=(0.00-20.00) in steps of 0.01C=(0.1-10.0) in steps of 0.1P=(0.005-3.000) in steps of 0.001TR=(0.005-100.000) in steps of 0.001CR=(0.1-10.0) in steps of 0.1PR=(0.005-3.000) in steps of 0.001

IEC 60255, class 5 +40 ms


104 ABB

Table 107. RI and RD type inverse time characteristics


RI type inverse characteristic

1

0.2360.339

= ×

-

t k

I


I = Imeasured/Iset

k = (0.05-999) in steps of 0.01 IEC 60255-3, class 5+ 40 ms

RD type logarithmic inversecharacteristic

5.8 1.35= - ×æ öç ÷è ø

tI

Ink


I = Imeasured/Iset

k = (0.05-999) in steps of 0.01 IEC 60255-3, class 5+ 40 ms


ABB 105

Table 108. 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 of0.01 unless otherwise stated

Class 5 +40 ms

Type B curve:

2.0

480

32 0.5 0.035

=×

- >× - -

>

æ öç ÷è ø

tk

U U

U



Type C curve:

3.0

480

32 0.5 0.035

=×

- >× - -

>

æ öç ÷è ø

tk

U U

U



Programmable curve:

×= +

- >× -

>

æ öç ÷è ø

P

k At D

U UB C

U


k = (0.05-1.10) in steps of0.01 unless otherwise statedA = (0.005-200.000) in stepsof 0.001B = (0.50-100.00) in steps of0.01C = (0.0-1.0) in steps of 0.1D = (0.000-60.000) in stepsof 0.001P = (0.000-3.000) in steps of0.001


106 ABB

Table 109. Inverse time characteristics for undervoltage protection


Type A curve:

=< -

<

æ öç ÷è ø

kt

U U

U


U< = Uset

U = UVmeasured


Class 5 +40 ms

Type B curve:

2.0

4800.055

32 0.5

×= +

< -× -

<

æ öç ÷è ø

kt

U U

U


U< = Uset

U = Umeasured


Programmable curve:

×= +

< -× -

<

é ùê úê úê úæ öê úç ÷ë è ø û

P

k At D

U UB C

U


U< = Uset

U = Umeasured

k = (0.05-1.10) in steps of0.01 unless otherwise statedA = (0.005-200.000) in stepsof 0.001B = (0.50-100.00) in steps of0.01C = (0.0-1.0) in steps of 0.1D = (0.000-60.000) in stepsof 0.001P = (0.000-3.000) in steps of0.001


ABB 107

Table 110. 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) insteps of 0.01

Class 5 +40 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) insteps 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) insteps of 0.01

Programmable curve:

×= +

- >× -

>

æ öç ÷è ø

P

k At D

U UB C

U


k = (0.05-1.10) insteps of 0.01A = (0.005-200.000)in steps of 0.001B = (0.50-100.00) insteps of 0.01C = (0.0-1.0) insteps of 0.1D = (0.000-60.000)in steps of 0.001P = (0.000-3.000) insteps of 0.001


108 ABB

21. Ordering

Guidelines

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

Please refer to the available functions table for included application functions.

Product specification

Basic IED 670 platform and common functions housed in selected casing

REG670 Quantity: 1MRK 002 826-AC

Default:

The IED connect CD contains configuration alternative. Use the PCM600 to create or modify the configuration. ThePCM600 can also be used for adaptation of an included example configuration.

Option:

Customer specific configuration On request

Connection type for Power supply modules and I/O modules

Rule: Same connection type for Power supply modules and I/O modules must be ordered

Compression terminals 1MRK 002 960-AA

Ring lug terminals 1MRK 002 960-BA

Power supply module

Rule: One Power supply module must be specified

Power supply module (PSM) 24-60 VDC 1MRK 002 239-AB

90-250 VDC 1MRK 002 239-BB

Logic

Rule: One Tripping logic must be ordered

Tripping logic (SMPPTRC) Qty: 1 2 3 4 5 6 1MRK 002 917-AC

Optional functions


ABB 109


Transformer differential protection, two winding (T2WPDIF)

Qty:

1 2 1MRK 002 901-AC

Transformer differential protection, three winding (T3WPDIF)

Qty:

1 2 1MRK 002 901-CC

1Ph High impedance differential protection (HZPDIF)

Qty:

1 2 3 4 5 6 1MRK 002 901-HB

Generator differential protection (GENPDIF)

Qty:

1 2 1MRK 002 901-PB

Restricted earth fault protection, low impedance (REFPDIF)

Qty:

1 2 3 1MRK 002 901-EB


Rule: If one of ZMHPDIS or ZDMRDIR is ordered, bothfunctions must be orderedFull scheme distance protection, mho characteristic(ZMHPDIS)

Qty:

1 2 3 4

1MRK 002 925-EB

Directional impedance element for mho characteristic(ZDMRDIR)

Qty:

1 2 1MRK 002 924-PA

Pole slip/out-of-step protection (PSPPPAM) Qty: 1MRK 002 925-LB

Loss of excitation (LEXPDIS)

Qty:

1 2 1MRK 002 925-MB

Note: If ROTIPHIZ or STTIPHIZ is ordered, Injection equipment isalso required, see section Accessories, "Injection equipment"

Sensitive rotor earth fault protection, injection based(ROTIPHIZ)

Qty: 1MRK 002 908-YA

100% stator earth fault protection, injection based(STTIPHIZ)

Qty: 1MRK 002 908-ZA


110 ABB

Current protection

Instantaneous phase overcurrent protection (PHPIOC)

Qty:

1 2 3 4 1MRK 002 906-AC

Four step phase overcurrent protection (OC4PTOC)

Qty:

1 2 3 4 5 6 1MRK 002 906-BD

Instantaneous residual overcurrent protection (EFPIOC)

Qty:

1 2 1MRK 002 906-CC

Four step residual overcurrent protection (EF4PTOC)

Qty:

1 2 3 4 5 6 1MRK 002 906-DD

Four step directional negative phase sequenceovercurrent protection (NS4PTOC)

Qty:

1 2 1MRK 002 906-DM

Sensitive directional residual overcurrent and powerprotection (SDEPSDE)

Qty:

1 2 1MRK 002 907-DC

Thermal overload protection, two time constants(TRPTTR)

Qty:

1 2 3 1MRK 002 906-NC

Breaker failure protection (CCRBRF)

Qty

1 2 3 4 1MRK 002 906-RC

Pole discordance protection (CCRPLD)

Qty:

1 2 3 4 1MRK 002 907-AC

Directional underpower protection (GUPPDUP)

Qty:

1 2 3 4 1MRK 002 902-FB

Directional overpower protection (GOPPDUP)

Qty:

1 2 3 4 1MRK 002 902-GB

Negative sequence time overcurrent protection formachines (NS2PTOC)

Qty:

1 2 1MRK 002 902-LA

Accidental energizing protection for synchronousgenerator (AEGGAPC)

Qty:

1 2 1MRK 002 902-NA


ABB 111

Voltage protection

Two step undervoltage protection (UV2PTUV)

Qty:

1 2 1MRK 002 908-AC

Two step overvoltage protection (OV2PTOV)

Qty:

1 2 1MRK 002 908-DC

Two step residual overvoltage protection (ROV2PTOV)

Qty:

1 2 3 1MRK 002 908-GC

Overexcitation protection (OEXPVPH)

Qty:

1 2 1MRK 002 908-MC

Voltage differential protection (VDCPTOV)

Qty:

1 2 1MRK 002 924-TB

100% Stator E/F 3rd harmonic (STEFPHIZ) Qty: 1MRK 002 908-TB


Underfrequency protection (SAPTUF)

Qty:

1 2 3 4 5 6 1MRK 002 908-NC

Overfrequency protection (SAPTOF)

Qty:

1 2 3 4 5 6 1MRK 002 908-RC

Rate-of-change frequency protection (SAPFRC)

Qty:

1 2 3 1MRK 002 908-SB


General current and voltage protection (CVGAPC)

Qty:

1 2 3 4 5 6

7 8 9 10 11 12

1MRK 002 902-AB


Current circuit supervision (CCSRDIF)

Qty:

1 2 3 4 5 1MRK 002 914-AB

Fuse failure supervision (SDDRFUF)

Qty:

1 2 3 1MRK 002 914-GC


112 ABB

Control

Synchrocheck, energizing check and synchronizing(SESRSYN)

Qty:

1 2 1MRK 002 916-AD

Apparatus control for up to 6 bays, max 30 apparatuses(6CBs) incl. interlocking

1MRK 002 916-RD

Tap changer control and supervision, 6 binary inputs,coded binary (Binary, BCD, Gray) (TCMYLTC)

Qty:

1 2 3 4 1MRK 002 925-PC

Tap changer control and supervision, 32 binary inputs,one per position (TCLYLTC)

Qty:

1 2 3 4 1MRK 002 924-UB


Duo driver configuration (DUODRV) 1MRK 002 924-YA

First local HMI user dialogue language

Rule: One must be ordered

HMI language, English IEC 1MRK 002 930-AA

HMI language, English US 1MRK 002 930-BA

Optional hardware

Human machine hardware interface

Rule: One must be ordered.

Display type Keypad symbol Case size

Small, alpha numeric IEC 1/2 19" 1MRK 000 008-HB

Small, alpha numeric IEC 3/4 19" 1MRK 000 008-PB

Small, alpha numeric IEC 1/1 19" 1MRK 000 008-KB

Medium, graphic display IEC 1/2 19" 1MRK 000 008-LB

Medium, graphic display IEC 1/1 19" 1MRK 000 008-MB

Medium, graphic display IEC 3/4 19" 1MRK 000 008-NB

Medium, graphic display ANSI 1/2 19" 1MRK 000 008-LC

Medium, graphic display ANSI 3/4 19" 1MRK 000 008-NC

Medium, graphic display ANSI 1/1 19" 1MRK 000 008-MC


ABB 113

Analog system

Rule: One Transformer input module must be orderedNote: The same type of connection terminals has to be ordered for both TRMs

Transformer input module, compression terminals 12I, 1A, 50/60 Hz

Qty:

1 2 1MRK 002 247-CG


Qty:

1 2 1MRK 002 247-CH

Transformer input module, compression terminals 9I+3U, 1A, 50/60 Hz

Qty:

1 2 1MRK 002 247-BG


Qty:

1 2 1MRK 002 247-BH

Transformer input module, compression terminals 5I, 1A+4I, 5A+3U,50/60 Hz

Qty:

1 2 1MRK 002 247-BK


Qty:

1 2 1MRK 002 247-AP


Qty:

1 2 1MRK 002 247-AR


Qty:

1 2 1MRK 002 247-AU


Qty:

1 2 1MRK 002 247-AV

Transformer input module, compression terminals 3IM, 1A+4IP, 1A+5U,50/60 Hz

Qty: 1 2 1MRK 002 247-EA

Transformer input module, compression terminals 3IM, 5A+4IP, 5A+5U,50/60 Hz

Qty: 1 2 1MRK 002 247-EB


Qty:

1 2 1MRK 002 247-AG


Qty:

1 2 1MRK 002 247-AH


Qty:

1 2 1MRK 002 247-AE


Qty:

1 2 1MRK 002 247-DH


Qty:

1 1MRK 002 247-DG


114 ABB


Qty:

1 1MRK 002 247-DH

Transformer input module, ring lug terminals 12I, 1A, 50/60 Hz

Qty:

1 2 1MRK 002 247-CC


Qty:

1 2 1MRK 002 247-CD

Transformer input module, ring lug terminals 9I+3U, 1A, 50/60 Hz

Qty:

1 2 1MRK 002 247-BC

Transformer input module, ring lug terminals 9I+3U, 5A, 50/60 Hz Qty:

1 2 1MRK 002 247-BD

Transformer input module, ring lug terminals 5I, 1A+4I, 5A+3U,50/60 Hz

Qty:

1 2 1MRK 002 247-BF


Qty: 1 2 1MRK 002 247-AS

Transformer input module, ring lug terminals 7I+5U, 5A, 50/60 Hz Qty:

1 2 1MRK 002 247-AT


Qty:

1 2 1MRK 002 247-AX


Qty:

1 2 1MRK 002 247-AY

Transformer input module, ring lug terminals 3IM, 1A+4IP, 1A+5U,50/60 Hz

Qty: 1 2 1MRK 002 247-EC

Transformer input module, ring lug terminals 3IM, 5A+4IP, 5A+5U,50/60 Hz

Qty: 1 2 1MRK 002 247-ED


Qty:

1 2 1MRK 002 247-AC


Qty:

1 2 1MRK 002 247-AD


Qty:

1 2 1MRK 002 247-AF


ABB 115


Qty:

1 1MRK 002 247-DC


Qty:

1 1MRK 002 247-DD

Note: One Analog digital conversion module, with time synchronization is always delivered with each Transformerinput module.

Case size

When ordering I/O modules, observe the maximum quantities according to tables below.

Note: Standard order of location for I/O modules is BIM-BOM-SOM-IOM-MIM from left to right as seen from therear side of the IED, but can also be freely placed.

Note: Maximum quantity of I/O modules depends on the type of connection terminals.

Maximum quantity of I/O modules

Case sizes BIM IOM BOM/SOM

MIM Maximum in case

1/1 x 19”, one (1) TRM 14 6 4 4 14 (max 4 BOM+SOM+MIM)

1MRK 000 151-NC

1/1 x 19”, two (2) TRM 11 6 4 4 11 (max 4 BOM+SOM+MIM)

1MRK 000 151-ND

3/4 x 19”, one (1) TRM 8 6 4 1 8 (max 4 BOM+SOM+1MIM)

1MRK 000 151-NB

3/4 x 19”, two (2) TRM 5 5 4 1 5 (max 4 BOM+SOM+1MIM)

1MRK 000 151-NE

1/2 x 19”, one (1) TRM 3 3 3 0 3 1MRK 000 151-NA

Maximum quantity of I/O modules, with ring lug terminals,module limits see above

Case sizes Maximum in case Possible locations for I/O moduleswith ringlugs

1/1 x 19”, one (1) TRM 7 P3, P5, P7, P9, P11, P13, P15 1MRK 000 151-NC

1/1 x 19”, two (2) TRM 5 P3, P5, P7, P9, P11 1MRK 000 151-ND

3/4 x 19”, one (1) TRM 4 P3, P5, P7, P9 1MRK 000 151-NB

3/4 x 19”, two (2) TRM 2 P3, P5 1MRK 000 151-NE

1/2 x 19”, one (1) TRM 1 P3 1MRK 000 151-NA


116 ABB

Binary input/output modules

Make BIM with 50 mA inrush current the primary choice. BIM with 50 mA inrush currentfulfill additional standards. As a consequence the EMC withstand capability is furtherincreased.BIM with 30 mA inrush current is still available.For pulse counting, for example kWh metering, the BIM with enhanced pulse countingcapabilities must be used.

Binary input module (BIM) 16 inputs

RL 24-30 VDC, 30 mA Qty: 1 2 3 4 5 6

8 9 10 11 12 13

7

14

1MRK 000 508-DB

RL 48-60 VDC, 30 mA Qty: 1 2 3 4 5 6

8 9 10 11 12 13

7

14

1MRK 000 508-AB

RL 110-125 VDC, 30 mA Qty: 1 2 3 4 5 6

8 9 10 11 12 13

7

14

1MRK 000 508-BB

RL 220-250 VDC, 30 mA Qty: 1 2 3 4 5 6

8 9 10 11 12 13

7

14

1MRK 000 508-CB

RL 24-30 VDC, 50 mA Qty: 1 2 3 4 5 6

8 9 10 11 12 13

7

14

1MRK 000 508-DD

RL 48-60 VDC, 50 mA Qty: 1 2 3 4 5 6

8 9 10 11 12 13

7

14

1MRK 000 508-AD

RL 110-125 VDC, 50 mA Qty: 1 2 3 4 5 6

8 9 10 11 12 13

7

14

1MRK 000 508-BD


ABB 117

RL 220-250 VDC, 50 mA Qty: 1 2 3 4 5 6

8 9 10 11 12 13

7

14

1MRK 000 508-CD

Binary input module (BIM) with enhanced pulsecounting capabilities, 16 inputs

RL 24-30 VDC Qty: 1 2 3 4 5 6

8 9 10 11 12 13

7

14

1MRK 000 508-HA

RL 48-60 VDC Qty: 1 2 3 4 5 6

8 9 10 11 12 13

7

14

1MRK 000 508-EA

RL 110-125 VDC Qty: 1 2 3 4 5 6

8 9 10 11 12 13

7

14

1MRK 000 508-FA

RL 220-250 VDC Qty: 1 2 3 4 5 6

8 9 10 11 12 13

7

14

1MRK 000 508-GA

Binary output module 24 output relays (BOM) Qty: 1 2 3 4 1MRK 000 614-AB

Static binary output module (SOM)

RL 48-60 VDC Qty: 1 2 3 4 1MRK 002 614-BA

RL 110-250 VDC Qty: 1 2 3 4 1MRK 002 614-CA


118 ABB

Make IOM with 50 mA inrush current the primary choice. IOM with 50 mA inrush currentfulfill additional standards. As a consequence the EMC withstand capability is furtherincreased.IOM with 30 mA inrush current is still available.

Binary input/output module (IOM) 8 inputs, 10 outputs, 2 high-speed outputs

RL 24-30 VDC, 30 mA Qty: 1 2 3 4 5 6 1MRK 000 173-GB

RL 48-60 VDC, 30 mA Qty: 1 2 3 4 5 6 1MRK 000 173-AC

RL 110-125 VDC, 30 mA Qty: 1 2 3 4 5 6 1MRK 000 173-BC

RL 220-250 VDC, 30 mA Qty: 1 2 3 4 5 6 1MRK 000 173-CC

RL 24-30 VDC, 50 mA Qty: 1 2 3 4 5 6 1MRK 000 173-GD

RL 48-60 VDC, 50 mA Qty: 1 2 3 4 5 6 1MRK 000 173-AE

RL 110-125 VDC, 50 mA Qty: 1 2 3 4 5 6 1MRK 000 173-BE

RL 220-250 VDC, 50 mA Qty: 1 2 3 4 5 6 1MRK 000 173-CE

Binary input/output module (IOM with MOV), 8 inputs, 10 outputs, 2 high-speed outputs

RL 24-30 VDC Qty: 1 2 3 4 5 6 1MRK 000 173-GC

RL 48-60 VDC Qty: 1 2 3 4 5 6 1MRK 000 173-AD

RL 110-125 VDC Qty: 1 2 3 4 5 6 1MRK 000 173-BD

RL 220-250 VDC Qty: 1 2 3 4 5 6 1MRK 000 173-CD

mA input module 6 channels (MIM) Qty: 1 2 3 4 1MRK 000 284-AB


ABB 119

Station communication ports

Note: Optical ethernet module, 2 glass interfaces is not allowed together with SLM.

Optical ethernet module, 1 channel glass 1MRK 002 266-AA

Optical ethernet module, 2 channel glass 1MRK 002 266-BA

Serial and LON communication module, supports SPA/IEC 60870-5-103, LON and DNP3.0

Serial/LON plastic interface 1MRK 001 608-AA

Serial plastic/LON glass interface 1MRK 001 608-BA

Serial/LON glass interface 1MRK 001 608-CA

Serial IEC 60870-5-103 plastic interface 1MRK 001 608-DA

Serial IEC 60870-5-103 plastic/glass interface 1MRK 001 608--EA

Serial IEC 60870-5-103 glass interface 1MRK 001 608-FA

Galvanic RS485 communication module for DNP 3.0 1MRK 002 309-AA

Remote end serial communication for C37.94

Rule: Max two LDCM can be ordered

Optical short range line data communication module(Multi mode 850 nm) (SR LDCM)

Qty:

1 2 1MRK 002 122-AB

Optical medium range line data communication module(Single mode 1310 nm) (MR LDCM)

Qty:

1 2 1MRK 002 311-AA

Time synchronization

Rule: Only one Time synchronization can be ordered.

GPS Time module (GTM) 1MRK 002 282-AB

IRIG-B Time synchronization module 1MRK 002 305-AA

Engineering facilities

19” rack mounting kit for 1/2 x 19” case or 2 x RHGS6 or RHGS12 Quantity: 1MRK 002 420-BB

19” rack mounting kit for 3/4 x 19” case or 3 x RHGS6 Quantity: 1MRK 002 420-BA

19” rack mounting kit for 1/1 x 19” case Quantity: 1MRK 002 420-CA


120 ABB

Note: Wall mounting not recommended with communication moduleswith fibre connection (SLM, OEM, LDCM)Wall mounting kit for terminal

Quantity: 1MRK 002 420-DA

Flush mounting kit for terminal Quantity: 1MRK 000 020-Y

Flush mounting kit + IP54 sealing (factory mounted). Cannot beordered separately thus must be specified when ordering a terminal.

Quantity: 1MRK 002 420-EA

Accessories

GPS antenna and mounting details

GPS antenna, including mounting kits Quantity: 1MRK 001 640-AA

Cable for antenna, 20 m Quantity: 1MRK 001 665-AA

Cable for antenna, 40 m Quantity: 1MRK 001 665-BA

Interface converter (for remote end data communication)

External interface converter from C37.94 to G703 Quantity: 1 2 1MRK 002 245-AA

External interface converter from C37.94 to G703.E1 Quantity: 1 2 1MRK 002 245-BA

Test switch

The test system COMBITEST intended for usewith the IED 670 products is described in1MRK 512 001-BEN and 1MRK 001024-CA.Please refer to the website: www.abb.com/substationautomation for detailed information.

Due to the high flexibility of our product andthe wide variety of applications possible thetest switches needs to be selected for eachspecific application.

Select your suitable test switch based on theavailable contacts arrangements shown in thereference documentation.

However our proposals for suitable variantsare:

Two winding transformer with internalneutral on current circuits. Two pcs can beused in applications for three windingtransformers in single or multi-breakerarrangement (ordering number RK926 215-BD)

Two winding transformer with externalneutral on current circuits. Two pcs can beused in applications for three windingtransformers in single or multi-breakerarrangement (ordering number RK926 215-BH).

Three winding transformer with internalneutral on current circuits (ordering numberRK926 215-BX).

The normally open "In test mode" contact29-30 on the RTXP test switches should beconnected to the input of the test function


ABB 121

HTTP://WWW.ABB.COM/SUBSTATIONAUTOMATION


block to allow activation of functionsindividually during testing.

Test switches type RTXP 24 is orderedseparately. Please refer to Section "Relateddocuments" for reference to correspondingdocuments.

RHGS 6 Case or RHGS 12 Case with mountedRTXP 24 and the on/off switch for dc-supplyare ordered separately. Please refer to Section"Related documents" for reference tocorresponding documents.

Protection cover

Protective cover for rear side of RHGS6, 6U, 1/4 x 19” Quantity: 1MRK 002 420-AE

Protective cover for rear side of terminal, 6U, 1/2 x 19” Quantity: 1MRK 002 420-AC

Protective cover for rear side of terminal, 6U, 3/4 x 19” Quantity: 1MRK 002 420-AB

Protective cover for rear side of terminal, 6U, 1/1 x 19” Quantity: 1MRK 002 420-AA

External resistor unit

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

Quantity:

1 2 3 RK795101-MA


Quantity: RK795101-MB


Quantity:

1 2 3 RK795101-CB


Quantity: RK795101-DC


122 ABB

Injection equipment

Rule: If ROTIPHIZ or STTIPHIZ is ordered, Injection equipment is required.

Injection unit (REX060) Quantity: 1MRK 002 500-AA

Casing

1/2 x 19" rack casing Basic

Backplane module (BPM) Basic

Human machine interface

HMI and logic module (HLM) Basic

Injection modules

Rule: Stator injection module (SIM) is required if 100% statorearth fault protection, injection based (STTIPHIZ) is selected/active in REG670

Stator injection module (SIM) 1MRK 002 544-AA

Rule: Rotor injection module (RIM) is required if Sensitiverotor earth fault protection, injection based (ROTIPHIZ) isselected/active in REG670

Rotor injection module (RIM) 1MRK 002 544-BA

Power supply module

Rule: One Power supply module must be specified

Power supply module (PSM) 24-60 VDC 1MRK 002 239-AB

90-250 VDC 1MRK 002 239-BB

Mounting details with IP40 of protection from the front

19" rack mounting kit 1MRK 002 420-BB

Wall mounting kit for terminal 1MRK 002 420-DA

Flush mounting kit for terminal 1MRK 000 020-Y

Extra IP54 mounting seal + Flush mounting kit for terminal 1MRK 002 420-EA

Rule: REX061 requires REX060 and that Rotor injection module(RIM) is selected in REX060 and that Sensitive rotor earth faultprotection, injection based (ROTIPHIZ) is selected/active inREG670.

Coupling capacitor unit (REX061) Quantity: 1MRK 002 550-AA

Rule: REX062 requires REX060 and that Stator injection module(SIM) is selected in REX060 and that 100% stator earth faultprotection, injection based (STTIPHIZ) is selected/active in REG670

Shunt resistor unit (REX062) Quantity: 1MRK 002 555-AA

Combiflex


ABB 123

Key switch for settings

Key switch for lock-out of settings via LCD-HMI Quantity: 1MRK 000 611-A

Note: To connect the key switch, leads with 10 A Combiflex socket on one end must be used.

Side-by-side mounting kit Quantity: 1MRK 002 420-Z

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

Protective resistor on plate Quantity: RK795102-AD

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

Manuals

Note: One (1) IED Connect CD containing user documentation (Operator’s manual, Technical referencemanual, Installation and commissioning manual, Application manual and Getting started guide),Connectivity packages and LED label template is always included for each IED.

Rule: Specify additional quantity of IED Connect CD requested. Quantity: 1MRK 002 290-AB


124 ABB

User documentation

Rule: Specify the number of printed manuals requestedOperator’s manual

IEC Quantity: 1MRK 502 028-UEN

ANSI Quantity: 1MRK 502 028-UUS

Technical reference manual IEC Quantity: 1MRK 502 027-UEN


Installation and commissioning manual IEC Quantity: 1MRK 502 029-UEN


Application manual IEC Quantity: 1MRK 502 030-UEN


Engineering guide IED 670 products Quantity: 1MRK 511 179-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

Generator manufacturer: Rated power: MVA

Type of prime mover: steam , gas , hydro , pumpstorage , nuclear , other ______________________


ABB 125

Related documents

Documents related to REG670 Identity number

Operator’s manual 1MRK 502 028-UEN

Installation and commissioning manual 1MRK 502 029-UEN

Technical reference manual 1MRK 502 027-UEN

Application manual 1MRK 502 030-UEN

Product guide customized 1MRK 502 031-BEN

Product guide pre-configured 1MRK 502 032-BEN

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

Connection and Installation components 1MRK 513 003-BEN

Test system, COMBITEST 1MRK 512 001-BEN

Accessories for 670 series IEDs 1MRK 514 012-BEN

670 series SPA and signal list 1MRK 500 092-WEN

IEC 61850 Data objects list for 670 series 1MRK 500 091-WEN

Engineering manual 670 series 1MRK 511 240-UEN

Buyer’s guide REG 216 1MRB520004-BEN

Communication set-up for Relion 670 series 1MRK 505 260-UEN

More information can be found on www.abb.com/substationautomation.


126 ABB


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

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