product guide, reg670 1.2 ansi customized (english - · pdf filerelion® 670 series...

Relion® 670 series

Generator protection REG670 ANSICustomizedProduct Guide

Contents

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

2. Available functions...........................................................11

3. Differential protection.......................................................15

4. Impedance protection......................................................18

5. Current protection............................................................18

6. Voltage protection............................................................21

7. Frequency protection.......................................................22

8. Multipurpose protection...................................................23

9. Secondary system supervision.........................................23

10. Control...........................................................................24

11. Logic..............................................................................25

12. Monitoring......................................................................26

13. Metering.........................................................................27

14. Basic IED functions.........................................................28

15. Human machine interface...............................................28

16. Station communication ..................................................28

17. Remote communication..................................................29

18. Hardware description......................................................29

19. Connection diagrams......................................................32

20. Technical data................................................................40

21. Ordering.........................................................................88

Disclaimer

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

that may appear in this document.

© Copyright 2012 ABB.

All rights reserved.

Trademarks

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

of their respective holders.

Generator protection REG670 ANSI 1MRK502031-BUS DCustomized Product version: 1.2

2 ABB

1. ApplicationThe REG670 is used for protection, control and monitoring ofgenerators and generator-transformer blocks from relativelysmall units up to the largest generating units. The IED has acomprehensive function library, covering the requirements formost generator applications. The large number of analog inputsavailable enables, together with the large functional library,integration of many functions in one IED. In typical applicationstwo units can provide total functionality, also providing a highdegree of redundancy. REG670 can as well be used forprotection and control of shunt reactors.

Stator ground fault protection, both traditional 95% as well as100% injection and 3rd harmonic based are included. When theinjection based protection is used, 100% of the machine statorwinding, including the star point, is protected under alloperating modes. The 3rd harmonic based 100% stator earthfault protection uses 3rd harmonic differential voltage principle.Injection based 100% stator ground fault protection canoperate even when machine is at standstill. Well provenalgorithms for pole slip, underexcitation, rotor ground fault,negative sequence current protections, and so on, are includedin the IED.

The generator differential protection in the REG670 adapted tooperate correctly for generator applications where factors aslong DC time constants and requirement on short trip time havebeen considered.

As many of the protection functions can be used as multipleinstances there are possibilities to protect more than one object

in one IED. It is possible to have protection for an auxiliarypower transformer integrated in the same IED having mainprotections for the generator. The concept thus enables verycost effective solutions.

The REG670 also enables valuable monitoring possibilities asmany of the process values can be transferred to an operatorHMI.

The wide application flexibility makes this product an excellentchoice for both new installations and for refurbishment inexisting power plants.

Serial data communication is via optical connections to ensureimmunity against disturbances.

The wide application flexibility makes this product an excellentchoice for both new installations and the refurbishment ofexisting installations.

By using patented algorithm REG670 (or any other productfrom 670 series) can track the power system frequency in quitewide range from 9Hz to 95Hz. In order to do that preferably thethree-phase voltage signal from the generator terminals shall beconnected to the IED. Then IED can adopt its filtering algorithmin order to properly measure phasors of all current and voltagesignals connected to the IED. This feature is essential for properoperation of the protection during generator start-up and shut-down procedure.

Generator protection REG670 ANSI 1MRK502031-BUS DCustomized Product version: 1.2 Issued: February 2015

Revision: D

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 ground fault and 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 including generator phase differential, 100% stator ground fault andback-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 including generator phase differential, generator split-phasedifferential, 100% stator ground fault 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 ground fault and back-up protection. Statorwinding grounded via grounding transformer.


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


8 ABB

Figure 5. Unit protection application with overall differential, unit transformer differential, generator differential, 100% stator ground fault andback-up protection. Ungrounded stator winding.


ABB 9

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 ground fault andback-up protection. Stator winding grounded via primary resistor.


10 ABB

2. Available functions

Main protection functions

2 = number of basic instances0-3 = 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 mho characteristic 0-2

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

LEXPDIS 40 Loss of excitation 0-2


ABB 11

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 sequence overcurrent protection 0-2

SDEPSDE 67N Sensitive directional residual overcurrent and power 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 protection for machines 0-2

AEGGAPC 50AE Accidental energizing protection for synchronous generator 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 harmonic based 0-1

Frequency protection

SAPTUF 81 Underfrequency protection 0-6

SAPTOF 81 Overfrequency protection 0-6

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

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 30 apparatuses (6CBs) incl. interlocking 0-1

QCBAY Apparatus control 1+5/APC30

LOCREM Handling of LRswitch positions 1+5/APC30

LOCREMCTRL

LHMI control of PSTO 1+5/APC30

TCMYLTC 84 Tap changer control and supervision, 6 binary inputs 0-4

TCLYLTC 84 Tap changer control and supervision, 32 binary inputs 0-4

SLGGIO Logic rotating switch for function selection and LHMI 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

SingleCommand16Signals

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

FixedSignals Fixed signal function block 1

B16I Boolean 16 to Integer conversion 16

B16IFCVI Boolean 16 to Integer conversion with Logic Node representation 16

IB16 Integer to Boolean 16 conversion 16

IB16FCVB Integer to Boolean 16 conversion with Logic Node representation 16

Monitoring

CVMMXN Measurements 6

EVENT Event function 20

DRPRDRE Disturbance report 1


ABB 13


REG670

SPGGIO IEC61850 generic communication I/O functions 64

SP16GGIO IEC61850 generic communication I/O functions 16 inputs 16

MVGGIO IEC61850 generic communication I/O functions 24

BSStatReport Logical signal status report 3

RANGE_XP Measured value expander block 66

Metering

PCGGIO Pulse-counter logic 16

ETPMMTR Function for energy calculation and demand handling 6

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 and IEC60870-5-103 for SLM 1

DNP3.0 for TCP/IP and EIA-485 communication protocol 1

DNP3.0 fault records for TCP/IP and EIA-485 communication protocol 1

Parameter setting function for IEC61850 1

IntlReceive Horizontal communication via GOOSE for interlocking 59

Goose binary receive 10

Multiple command and transmit 60/10

Ethernet configuration of links 1

IEC 62439-3 Edition 1 parallel redundancy protocol 0-1

IEC 62439-3 Edition 2 parallel redundancy protocol 0-1


14 ABB

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

3. Differential protection

Generator differential protection GENPDIF (87G)Short circuit between the phases of the stator windings causesnormally very large fault currents. The short circuit gives risk ofdamages on insulation, windings and stator iron core. The largeshort circuit currents cause large forces, which can cause

damage even to other components in the power plant, such asturbine and generator-turbine shaft.

To limit the damage due to stator winding short circuits, thefault clearance must be as fast as possible (instantaneous). Ifthe generator block is connected to the power system close toother generating blocks, the fast fault clearance is essential tomaintain the transient stability of the non-faulted generators.


ABB 15

Normally, the short circuit fault current is very large, that is,significantly larger than the generator rated current. There is arisk that a short circuit can occur between phases close to theneutral point of the generator, thus causing a relatively smallfault current. The fault current can also be limited due to lowexcitation of the generator. Therefore, it is desired that thedetection of generator phase-to-phase short circuits shall berelatively sensitive, detecting small fault currents.

It is also of great importance that the generator differentialprotection does not trip for external faults, with large faultcurrents flowing from the generator.

To combine fast fault clearance, as well as sensitivity andselectivity, the generator differential protection is normally thebest choice for phase-to-phase generator short circuits.

Generator differential protection GENPDIF (87G) is also wellsuited to generate fast, sensitive and selective fault clearance, ifused to protect shunt reactors or small busduct.

Transformer differential protection T2WPDIF/T3WPDIF (87T)The Transformer differential protection, two-winding (T2WPDIF,87T) and Transformer differential protection, three-winding(T3WPDIF, 87T) are provided with internal CT ratio matchingand phase shift compensation and settable zero sequencecurrent elimination.

The function can be provided with up to three-phase sets ofcurrent inputs. All current inputs are provided with percentagebias restraint features, making the IED suitable for two- or three-winding transformer in multi-breaker station arrangements.

Two-winding applications

xx05000048_ansi.vsd

152 352

ANSI05000048 V1 EN

two-winding power transformer

xx05000049_ansi.vsd

152 352

ANSI05000049 V1 EN

two-winding power transformer withunconnected delta tertiary winding

xx05000050_ansi.vsd

352

252

152

ANSI05000050 V1 EN

two–winding power transformer with two circuitbreakers on one side

xx05000051_ansi.vsd

252

152 352

452

ANSI05000051 V1 EN


16 ABB

two–winding power transformer with two circuitbreakers and two CT-sets on both sides

Three-winding applications

xx05000052_ansi.vsd

352152

452

ANSI05000052 V1 EN

three–winding power transformer with all threewindings connected

xx05000053_ansi.vsd

352

452

252

152

ANSI05000053 V1 EN

three–winding power transformer with two circuitbreakers and two CT-sets on one side

xx05000057_ansi.vsd

552

152 252

352 452

ANSI05000057 V1 EN

Autotransformer with two circuit breakers andtwo CT-sets on two out of three sides

Figure 7. CT group arrangement fordifferential protection and otherprotections

The setting facilities cover the application of the differentialprotection to all types of power transformers and auto-transformers with or without load tap changer as well as shuntreactors and local feeders within the station. An adaptivestabilizing feature is included for heavy through-faults.Byintroducing the load tap changer position, the differentialprotection pick-up can be set to optimum sensitivity thuscovering internal faults with low fault level.

Harmonic restraint is included for inrush and overexcitationcurrents respectively. Adaptive stabilization is also included forsystem recovery inrush and CT saturation during external faults.A high set unrestrained differential current protection element isincluded for a very high speed tripping at a high internal faultcurrents.

Included is an innovative sensitive differential protection elementbased on the theory of symmetrical components. This elementoffers the best possible coverage of power transformerwindings turn to turn faults.

1Ph High impedance differential protection HZPDIF (87)The 1Ph High impedance differential protection (HZPDIF, 87)function can be used when the involved CTs have the sameturns ratio and similar magnetizing characteristics. It utilizes anexternal CT current summation by wiring, a series resistor, anda voltage dependent resistor which are mounted externallyconnected to the IED.

HZPDIF (87) can be used to protect generator stator windings,tee-feeders or busbars. Six single phase function blocks areavailable to allow application for two three-phase zones busbarprotection.

Restricted earth-fault protection, low impedance REFPDIF (87N)Restricted fault protection, low-impedance function (REFPDIF,87N) can be used on all solidly or low-impedance groundedwindings. The REFPDIF (87N) function provides high sensitivityand high speed tripping as it protects each winding separatelyand thus does not need inrush stabilization.

The low-impedance function is a percentage biased functionwith an additional zero sequence current directional comparisoncriterion. This gives excellent sensitivity and stability duringthrough faults.

REFPDIF can also protect autotransformers. In this case, thenegative sequence current directional comparison must beused. The most typical and the most complicated configurationof an autotransformer is shown in figure 8. Five currents aremeasured in the case illustrated in figure 8.


ABB 17

The most typicalapplication

YNdx

dCB

CT

CT

CB Y

IED

CB CB

CB CB

Autotransformer

The most complicatedapplication - autotransformer

CT CT

CT CT


IEC05000058-2 V1 EN

Figure 8. Examples of applications of the REFPDIF

4. Impedance protection

Full-scheme distance measuring, Mho characteristic ZMHPDIS(21)The numerical mho line distance protection is a four zone fullscheme protection for back-up detection of short circuit andground faults. The four zones have fully independent measuringand settings, which gives high flexibility for all types of lines.

The function can be used as under impedance back-upprotection for transformers and generators.

Directional impedance element for Mho characteristic ZDMRDIRThe phase-to-ground impedance elements can be optionallysupervised by a phase unselective directional function (phaseunselective, because it is based on symmetrical components).

Pole slip protection PSPPPAM (78)The situation with pole slip of a generator can be caused bydifferent reasons.

A short circuit may occur in the external power grid, close tothe generator. If the fault clearing time is too long, the generatorwill accelerate so much, that the synchronism cannot bemaintained.

Un-damped oscillations occur in the power system, wheregenerator groups at different locations, oscillate against eachother. If the connection between the generators is too weak themagnitude of the oscillations will increase until the angularstability is lost.

The operation of a generator having pole slip will give risk ofdamages to the generator, shaft and turbine.

• At each pole slip there will be significant torque impact onthe generator-turbine shaft.

• In asynchronous operation there will be induction ofcurrents in parts of the generator normally not carryingcurrent, thus resulting in increased heating. Theconsequence can be damages on insulation and stator/rotor iron.

The Pole slip protection (PSPPPAM ,78) function shall detectpole slip conditions and trip the generator as fast as possible ifthe locus of the measured impedance is inside the generator-transformer block. If the centre of pole slip is outside in thepower grid, the first action should be to split the network intotwo parts, after line protection action. If this fails there shouldbe operation of the generator PSPPPAM (78) in zone 2, toprevent further damages to the generator, shaft and turbine.

Loss of excitation LEXPDIS (40)There are limits for the under-excited operation of asynchronous machine. A reduction of the excitation currentweakens the coupling between the rotor and the stator. Themachine may lose the synchronism and start to operate like aninduction machine. Then, the reactive power consumption willincrease. Even if the machine does not loose synchronism itmay not be acceptable to operate in this state for a long time.Reduction of excitation increases the generation of heat in theend region of the synchronous machine. The local heating maydamage the insulation of the stator winding and the iron core.

To prevent damages to the generator it should be tripped whenexcitation is lost.

5. Current protection

Instantaneous phase overcurrent protection PHPIOC (50)The instantaneous three phase overcurrent function has a lowtransient overreach and short tripping time to allow use as ahigh set short-circuit protection function.

Four step phase overcurrent protection OC4PTOC (51/67)The four step phase overcurrent protection function OC4PTOC(51/67) has independent inverse time delay settings for step 1and 4. Step 2 and 3 are always definite time delayed.

All IEC and ANSI inverse time characteristics are availabletogether with an optional user defined time characteristic.

The directional function is voltage polarized with memory. Thefunction can be set to be directional or non-directionalindependently for each of the steps.

Second harmonic blocking level can be set for the function andcan be used to block each step individually


18 ABB

Instantaneous residual overcurrent protection EFPIOC (50N)The Instantaneous residual overcurrent protection EFPIOC(50N) has a low transient overreach and short tripping times toallow the use for instantaneous ground-fault protection, with thereach limited to less than the typical eighty percent of the line atminimum source impedance. EFPIOC (50N) can be configuredto measure the residual current from the three-phase currentinputs or the current from a separate current input. EFPIOC(50N) can be blocked by activating the input BLOCK.

Four step residual overcurrent protection, zero sequence andnegative sequence direction EF4PTOC (51N_67N)The four step residual overcurrent protection EF4PTOC (51N/67N) has an inverse or definite time delay independent for eachstep separately.

All IEC and ANSI time-delayed characteristics are availabletogether with an optional user defined characteristic.

EF4PTOC (51N/67N) can be set directional or non-directionalindependently for each of the steps.

IDir, VPol and IPol can be independently selected to be eitherzero sequence or negative sequence.

Second harmonic blocking can be set individually for each step.

EF4PTOC (51N/67N) can be used as main protection for phase-to-ground faults.

EF4PTOC (51N/67N) can also be used to provide a systemback-up for example, in the case of the primary protectionbeing out of service due to communication or voltagetransformer circuit failure.

Directional operation can be combined together withcorresponding communication logic in permissive or blockingteleprotection scheme. Current reversal and weak-end infeedfunctionality are available as well.

EF4PTOC (51N/67N) can be configured to measure the residualcurrent from the three-phase current inputs or the current froma separate current input.

Four step negative sequence overcurrent protection NS4PTOC(4612)Four step negative sequence overcurrent protection (NS4PTOC,(4612) ) has an inverse or definite time delay independent foreach step separately.

All IEC and ANSI time delayed characteristics are availabletogether with an optional user defined characteristic.

The directional function is voltage polarized or dual polarized.

NS4PTOC (4612) can be set directional or non-directionalindependently for each of the steps.

NS4PTOC (4612) can be used as main protection forunsymmetrical fault; phase-phase short circuits, phase-phase-ground short circuits and single phase ground faults.

NS4PTOC (4612) can also be used to provide a system back-up for example, in the case of the primary protection being outof service due to communication or voltage transformer circuitfailure.

Directional operation can be combined together withcorresponding communication logic in permissive or blockingteleprotection scheme. The same logic as for directional zerosequence current can be used. Current reversal and weak-endinfeed functionality are available.

Sensitive directional residual overcurrent and power protectionSDEPSDE (67N)In isolated networks or in networks with high impedancegrounding, the ground fault current is significantly smaller thanthe short circuit currents. In addition to this, the magnitude ofthe fault current is almost independent on the fault location inthe network. The protection can be selected to use either theresidual current or residual power component 3V0·3I0·cos j,for operating quantity with maintained short circuit capacity.There is also available one nondirectional 3I0 step and one 3V0overvoltage tripping step.

No specific sensitive current input is needed.SDEPSDE can beset as low 0.25% of IBase.

Thermal overload protection, two time constant TRPTTR (49)If a power transformer or generator reaches very hightemperatures the equipment might be damaged. The insulationwithin the transformer/generator will have forced ageing. As aconsequence of this the risk of internal phase-to-phase orphase-to-ground faults will increase. High temperature willdegrade the quality of the transformer/generator insulation.

The thermal overload protection estimates the internal heatcontent of the transformer/generator (temperature)continuously. This estimation is made by using a thermal modelof the transformer/generator with two time constants, which isbased on current measurement.

Two warning pickup levels are available. This enables actionsin the power system to be done before dangerous temperaturesare reached. If the temperature continues to increase to the tripvalue, the protection initiates a trip of the protected transformer/generator.


ABB 19

Breaker failure protection CCRBRF (50BF)Breaker failure protection (CCRBRF) ensures fast back-uptripping of surrounding breakers in case the own breaker fails toopen. CCRBRF (50BF) can be current based, contact based, oran adaptive combination of these two conditions.

Current check with extremely short reset time is used as checkcriterion to achieve high security against inadvertent operation.

Contact check criteria can be used where the fault currentthrough the breaker is small.

CCRBRF (50BF) can be single- or three-phase initiated to allowuse with single pole tripping applications. For the three-phaseversion of CCRBRF (50BF) the current criteria can be set tooperate only if two out of four for example, two phases or onephase plus the residual current pickups. This gives a highersecurity to the back-up trip command.

CCRBRF (50BF) function can be programmed to give a single-or three-phase re-trip of the own breaker to avoid unnecessarytripping of surrounding breakers at an incorrect initiation due tomistakes during testing.

Pole discordance protection CCRPLD (52PD)An open phase can cause negative and zero sequence currentswhich cause thermal stress on rotating machines and cancause unwanted operation of zero sequence or negativesequence current functions.

Normally the own breaker is tripped to correct such a situation.If the situation warrants the surrounding breakers should betripped to clear the unsymmetrical load situation.

The Polediscrepancy protection function CCRPLD (52PD)operates based on information from auxiliary contacts of thecircuit breaker for the three phases with additional criteria fromunsymmetrical phase currents when required.

Directional over/underpower protection GOPPDOP/GUPPDUP(32/37)The directional over-/under-power protection GOPPDOP (32)/GUPPDUP (37) can be used wherever a high/low active,reactive or apparent power protection or alarming is required.The functions can alternatively be used to check the direction ofactive or reactive power flow in the power system. There are anumber of applications where such functionality is needed.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 definite time delay. Resettimes for both steps can be set as well.

By using optional metering class CT inputs accuracy of 0,5%can be achieved for steam turbine applications.

Negative sequence time overcurrent protection for machinesNS2PTOC (46I2)Negative-sequence time overcurrent protection for machinesNS2PTOC (46I2) is intended primarily for the protection ofgenerators against possible overheating of the rotor caused bynegative sequence current in the stator current.

The negative sequence currents in a generator may, amongothers, be caused by:

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

disconnector

NS2PTOC (46I2) can also be used as a backup protection, thatis, to protect the generator in case line protections or circuitbreakers fail to clear unbalanced system faults.

To provide an effective protection for the generator for externalunbalanced conditions, NS2PTOC (46I2) is able to directlymeasure the negative sequence current. NS2PTOC (46I2) alsohas a time delay characteristic which matches the heating

characteristic of the generator 2

2I t K= as defined in standard

IEEE C50.13.

where:

I2 is negative sequence current expressed inper unit of the rated generator current

t is operating time in seconds

K is a constant which depends of thegenerators size and design

NS2PTOC (46I2) has a wide range of K settings and thesensitivity and capability of detecting and tripping for negativesequence currents down to the continuous capability of agenerator.

A separate output is available as an alarm feature to warn theoperator of a potentially dangerous situation.


20 ABB

Accidental energizing protection for synchronous generatorAEGGAPC (50AE)Inadvertent or accidental energizing of off-line generators hasoccurred often enough due to operating errors, breaker headflashovers, control circuit malfunctions, or a combination ofthese causes. Inadvertently energized generator operates asinduction motor drawing a large current from the system. Thevoltage supervised overcurrent protection is used to protect theinadvertently energized generator.

Accidental energizing protection for synchronous generator(AEGGAPC, 50AE) takes the maximum phase current input fromthe generator terminal side or from generator neutral side andmaximum phase to phase voltage inputs from the terminal side.AEGGAPC (50AE) is enabled when the terminal voltage dropsbelow the specified voltage level for the preset time.

6. Voltage protection

Two step undervoltage protection UV2PTUV (27)Undervoltages can occur in the power system during faults orabnormal conditions. Two step undervoltage protection(UV2PTUV, 27) function can be used to open circuit breakers toprepare for system restoration at power outages or as long-timedelayed back-up to primary protection.

UV2PTUV (27) has two voltage steps, each with inverse ordefinite time delay.

Two step overvoltage protection OV2PTOV (59)Overvoltages may occur in the power system during abnormalconditions such as sudden power loss, tap changer regulatingfailures, open line ends on long lines etc.

Two step overvoltage protection (OV2PTOV, 59) function canbe used to detect open line ends, normally then combined witha directional reactive over-power function to supervise thesystem voltage. When triggered, the function will cause analarm, switch in reactors, or switch out capacitor banks.

OV2PTOV (59) has two voltage steps, each of them with inverseor definite time delayed.

OV2PTOV (59) has an extremely high reset ratio to allowsettings close to system service voltage.

Two step residual overvoltage protection ROV2PTOV (59N)Residual voltages may occur in the power system duringground faults.

Two step residual overvoltage protection ROV2PTOV (59N)function calculates the residual voltage from the three-phasevoltage input transformers or measures it from a single voltage

input transformer fed from a broken delta or neutral pointvoltage transformer.

ROV2PTOV (59N) has two voltage steps, each with inverse ordefinite time delay.

Reset delay ensures operation for intermittent ground faults.

Overexcitation protection OEXPVPH (24)When the laminated core of a power transformer or generator issubjected to a magnetic flux density beyond its design limits,stray flux will flow into non-laminated components not designedto carry flux and cause eddy currents to flow. The eddycurrents can cause excessive heating and severe damage toinsulation and adjacent parts in a relatively short time. Thefunction has settable inverse operating curves and independentalarm stages.

Voltage differential protection VDCPTOV (60)A voltage differential monitoring function is available. Itcompares the voltages from two three phase sets of voltagetransformers and has one sensitive alarm step and one trip step.

95% and 100% Stator earth fault protection based on 3rdharmonic STEFPHIZ (59TD)Stator ground fault is a fault type having relatively high faultrate. The generator systems normally have high impedancegrounding, that is, grounding via a neutral point resistor. Thisresistor is normally dimensioned to give an ground fault currentin the range 3 – 15 A at a solid ground-fault directly at thegenerator high voltage terminal. The relatively small ground faultcurrents give much less thermal and mechanical stress on thegenerator, compared to the short circuit case, which is betweenconductors of two phases. Anyhow, the ground faults in thegenerator have to be detected and the generator has to betripped, even if longer fault time compared to internal shortcircuits, can be allowed.

In normal non-faulted operation of the generating unit theneutral point voltage is close to zero, and there is no zerosequence current flow in the generator. When a phase-to-ground fault occurs the neutral point voltage will increase andthere will be a current flow through the neutral point resistor.

To detect a ground fault on the windings of a generating unitone may use a neutral point overvoltage protection, a neutralpoint overcurrent protection, a zero sequence overvoltageprotection or a residual differential protection. Theseprotections are simple and have served well during many years.However, at best these simple schemes protect only 95% of thestator winding. They leave 5% close to the neutral endunprotected. Under unfavorable conditions the blind zone mayextend up to 20% from the neutral.


ABB 21

The 95% stator ground fault protection measures thefundamental frequency voltage component in the generator starpoint and it operates when it exceeds the preset value. Byapplying this principle approximately 95% of the stator windingcan be protected. In order to protect the last 5% of the statorwinding close to the neutral end the 3rd harmonic voltagemeasurement can be performed. In 100% Stator E/F 3rd

harmonic protection either the 3rd harmonic voltage differentialprinciple, the neutral point 3rd harmonic undervoltage principleor the terminal side 3rd harmonic overvoltage principle can beapplied. However, differential principle is stronglyrecommended. Combination of these two measuring principlesprovides coverage for entire stator winding against groundfaults.

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

ANSI10000202-1-en.vsd

ANSI10000202 V1 EN

Figure 9. Protection principles for STEFPHIZ (59TD) function

7. Frequency protection

Underfrequency protection SAPTUF (81)Underfrequency occurs as a result of a lack of generation in thenetwork.

Underfrequency protection SAPTUF (81) is used for loadshedding systems, remedial action schemes, gas turbinestartup and so on.

SAPTUF (81) is also provided with undervoltage blocking.

The operation is based on positive sequence voltagemeasurement and requires two phase-phase or three phase-neutral voltages to be connected. For information about how to

connect analog inputs, refer to Application manual/IEDapplication/Analog inputs/Setting guidelines

Overfrequency protection SAPTOF (81)Overfrequency protection function SAPTOF (81) is applicable inall situations, where reliable detection of high fundamentalpower system frequency is needed.

Overfrequency occurs because of sudden load drops or shuntfaults in the power network. Close to the generating plant,generator governor problems can also cause over frequency.

SAPTOF (81) is used mainly for generation shedding andremedial action schemes. It is also used as a frequency stageinitiating load restoring.


22 ABB

SAPTOF (81) is provided with an undervoltage blocking.

The operation is based on positive sequence voltagemeasurement and requires two phase-phase or three phase-neutral voltages to be connected. For information about how toconnect analog inputs, refer to Application manual/IEDapplication/Analog inputs/Setting guidelines

Rate-of-change frequency protection SAPFRC (81)Rate-of-change frequency protection function (SAPFRC,81)gives an early indication of a main disturbance in the system.SAPFRC (81) can be used for generation shedding, loadshedding and remedial action schemes. SAPFRC (81) candiscriminate between positive or negative change of frequency.

SAPFRC (81) is provided with an undervoltage blocking. Theoperation is based on positive sequence voltage measurementand requires two phase-phase or three phase-neutral voltagesto be connected. For information about how to connect analoginputs, refer to Application manual/IED application/Analoginputs/Setting guidelines.

8. Multipurpose protection

General current and voltage protection CVGAPCThe protection module is recommended as a general backupprotection with many possible application areas due to itsflexible measuring and setting facilities.

The built-in overcurrent protection feature has two settablecurrent pickups. Both of them can be used either with definitetime or inverse time characteristic. The overcurrent protectionsteps can be made directional with selectable voltage polarizingquantity. Additionally they can be voltage and/or currentcontrolled/restrained. 2nd harmonic restraining facility isavailable as well. At too low polarizing voltage the overcurrentfeature can be either blocked, made non directional or orderedto use voltage memory in accordance with a parameter setting.

Additionally two overvoltage and two undervoltage steps, eitherwith definite time or inverse time characteristic, are availablewithin each function.

The general function suits applications with underimpedanceand voltage controlled overcurrent solutions. The generalfunction can also be utilized for generator transformerprotection applications where positive, negative or zerosequence components of current and voltage quantities aretypically required.

Additionally, generator applications such as loss of field,inadvertent energizing, stator or rotor overload, circuit breakerhead flash-over and open phase detection are just a few ofpossible protection arrangements with these functions.

Rotor ground fault protection (64R)The field winding, including the rotor winding and the non-rotating excitation equipment, is always insulated from themetallic parts of the rotor. The insulation resistance is high if therotor is cooled by air or by hydrogen. The insulation resistanceis much lower if the rotor winding is cooled by water. This istrue even if the insulation is intact. A fault in the insulation of thefield circuit will result in a conducting path from the field windingto ground. This means that the fault has caused a field groundfault.

The field circuit of a synchronous generator is normallyungrounded. Therefore, a single ground fault on the fieldwinding will cause only a very small fault current. Thus theground fault does not produce any damage in the generator.Furthermore, it will not affect the operation of a generating unitin any way. However, the existence of a single ground faultincreases the electric stress at other points in the field circuit.This means that the risk for a second ground fault at anotherpoint on the field winding has increased considerably. A secondground fault will cause a field short-circuit with severeconsequences.

The rotor ground fault protection is based on injection of an ACvoltage to the isolated field circuit. In non-faulted conditionsthere will be no current flow associated to this injected voltage.If a rotor ground fault occurs, this condition will be detected bythe rotor ground fault protection. Depending on the generatorowner philosophy this operational state will be alarmed and/orthe generator will be tripped. An injection unit is required forrotor ground fault protection (RXTTE4) and a protective resistoron plate for correct operation.

9. Secondary system supervision

Current circuit supervision CCSRDIF (87)Open or short circuited current transformer cores can causeunwanted operation of many protection functions such asdifferential, ground-fault current and negative-sequence currentfunctions.

It must be remembered that a blocking of protection functionsat an occurrence of open CT circuit will mean that the situationwill remain and extremely high voltages will stress thesecondary circuit.

Current circuit supervision (CCSRDIF, 87) compares theresidual current from a three phase set of current transformercores with the neutral point current on a separate input takenfrom another set of cores on the current transformer.


ABB 23

A detection of a difference indicates a fault in the circuit and isused as alarm or to block protection functions expected to giveunwanted tripping.

Fuse failure supervision SDDRFUFThe aim of the fuse failure supervision function (SDDRFUF) is toblock voltage measuring functions at failures in the secondarycircuits between the voltage transformer and the IED in order toavoid unwanted operations that otherwise might occur.

The fuse failure supervision function basically has three differentalgorithms, negative sequence and zero sequence basedalgorithms and an additional delta voltage and delta currentalgorithm.

The negative sequence detection algorithm is recommended forIEDs used in isolated or high-impedance grounded networks. Itis based on the negative-sequence measuring quantities, a highvalue of voltage without the presence of the negative-sequencecurrent 3I2.

The zero sequence detection algorithm is recommended forIEDs used in directly or low impedance grounded networks. Itis based on the zero sequence measuring quantities, a highvalue of voltage 3V0 without the presence of the residual

current 3I0.

For better adaptation to system requirements, an operationmode setting has been introduced which makes it possible toselect the operating conditions for negative sequence and zerosequence based function. The selection of different operationmodes makes it possible to choose different interactionpossibilities between the negative sequence and zero sequencebased algorithm.

A criterion based on delta current and delta voltagemeasurements can be added to the fuse failure supervisionfunction in order to detect a three phase fuse failure, which inpractice is more associated with voltage transformer switchingduring station operations.

10. Control

Synchrocheck, energizing check, and synchronizing SESRSYN(25)The Synchronizing function allows closing of asynchronousnetworks at the correct moment including the breaker closingtime, which improves the network stability.

Synchrocheck, energizing check, and synchronizing (SESRSYN,25) function checks that the voltages on both sides of thecircuit breaker are in synchronism, or with at least one sidedead to ensure that closing can be done safely.

SESRSYN (25) function includes a built-in voltage selectionscheme for double bus and breaker-and-a-half or ring busbararrangements.

Manual closing as well as automatic reclosing can be checkedby the function and can have different settings.

For systems which are running asynchronous a synchronizingfunction is provided. The main purpose of the synchronizingfunction is to provide controlled closing of circuit breakers whentwo asynchronous systems are going to be connected. It isused for slip frequencies that are larger than those forsynchronism check and lower than a set maximum level for thesynchronizing function.

However this function can not be used to automaticallysynchronize the generator to the network.

Apparatus control APCThe apparatus control functions are used for control andsupervision of circuit breakers, disconnectors and groundingswitches within a bay. Permission to operate is given afterevaluation of conditions from other functions such asinterlocking, synchronism check, operator place selection andexternal or internal blockings.

Apparatus control features:• Select-Execute principle to give high reliability• Selection function to prevent simultaneous operation• 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 is processed and the resultingposition is not supervised. However with enhanced security, thecommand is processed and the resulting position is supervised.

Normal security means that only the command is evaluated andthe resulting position is not supervised. Enhanced securitymeans that the command is evaluated with an additionalsupervision of the status value of the control object. Thecommand security with enhanced security is always terminatedby a CommandTermination service primitive.


24 ABB

Control operation can be performed from the local HMI underauthority control if so defined.

Tap changer position reading TCMYLTCOn-load tap-changer position can be monitored on-line. Thiscan be done by either using BCD coded binary input signals oralternatively via an mA input signal. The actual tap-position canbe used by the transformer or overall differential protectionfunction in order to enable more sensitive pickup setting. Thiswill in turn make differential protection more sensitive for lowlevel internal faults such as winding turn-to-turn faults.

Logic rotating switch for function selection and LHMIpresentation SLGGIOThe logic rotating switch for function selection and LHMIpresentation (SLGGIO) (or the selector switch function block) isused to get a selector switch functionality similar to the oneprovided by a hardware selector switch. Hardware selectorswitches are used extensively by utilities, in order to havedifferent functions operating on pre-set values. Hardwareswitches are however sources for maintenance issues, lowersystem reliability and an extended purchase portfolio. The logicselector switches eliminate all these problems.

Selector mini switch VSGGIOThe Selector mini switch VSGGIO function block is amultipurpose function used for a variety of applications, as ageneral purpose switch.

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

IEC 61850 generic communication I/O functions DPGGIOThe IEC 61850 generic communication I/O functions (DPGGIO)function block is used to send double indications to othersystems or equipment in the substation. It is especially used inthe interlocking and reservation station-wide logics.

Single point generic control 8 signals SPC8GGIOThe Single point generic control 8 signals (SPC8GGIO) functionblock is a collection of 8 single point commands, designed tobring in commands from REMOTE (SCADA) to those parts ofthe logic configuration that do not need extensive commandreceiving functionality (for example, SCSWI). In this way, simplecommands can be sent directly to the IED outputs, withoutconfirmation. Confirmation (status) of the result of thecommands is supposed to be achieved by other means, suchas binary inputs and SPGGIO function blocks. The commandscan be pulsed or steady.

AutomationBits, command function for DNP3.0 AUTOBITSAutomationBits function for DNP3 (AUTOBITS) is used withinPCM600 to get into the configuration of the commands comingthrough the DNP3 protocol. The AUTOBITS function plays the

same role as functions GOOSEBINRCV (for IEC 61850) andMULTICMDRCV (for LON).

Single command, 16 signalsThe IEDs can receive commands either from a substationautomation system or from the local HMI. The commandfunction block has outputs that can be used, for example, tocontrol high voltage apparatuses or for other user definedfunctionality.

11. Logic

Tripping logic SMPPTRC (94)A function block for protection tripping is provided for eachcircuit breaker involved in the tripping of the fault. It provides asettable pulse prolongation to ensure a trip pulse of sufficientlength, as well as all functionality necessary for correct co-operation with autoreclosing functions.

The trip function block also includes a settable latchfunctionality for evolving faults and breaker lock-out.

Trip matrix logic TMAGGIOTrip matrix logic TMAGGIO function is used to route trip signalsand other logical output signals to different output contacts onthe IED.

TMAGGIO output signals and the physical outputs allows theuser to adapt the signals to the physical tripping outputsaccording to the specific application needs.

Configurable logic blocksA number of logic blocks and timers are available for the user toadapt the configuration to the specific application needs.

• OR function block.

• INVERTER function blocks that inverts the input signal.

• PULSETIMER function block can be used, for example, forpulse extensions or limiting of operation of outputs, settablepulse time.

• GATE function block is used for whether or not a signalshould be able to pass from the input to the output.

• XOR function block.

• LOOPDELAY function block used to delay the output signalone execution cycle.

• TIMERSET function has pick-up and drop-out delayedoutputs related to the input signal. The timer has a settabletime delay.


ABB 25

• AND function block.

• SRMEMORY function block is a flip-flop that can set or resetan output from two inputs respectively. Each block has twooutputs where one is inverted. The memory setting controls ifthe block's output should reset or return to the state it was,after a power interruption.

• RSMEMORY function block is a flip-flop that can reset or setan output from two inputs respectively. Each block has twooutputs where one is inverted. The memory setting controls ifthe block's output should reset or return to the state it was,after a power interruption. RESET input has priority.

Fixed signal function blockThe Fixed signals function (FXDSIGN) generates a number ofpre-set (fixed) signals that can be used in the configuration ofan IED, either for forcing the unused inputs in other functionblocks to a certain level/value, or for creating certain logic.

12. Monitoring

Measurements CVMMXN, CMMXU, VNMMXU, VMMXU,CMSQI, VMSQIThe measurement functions are used to get on-line informationfrom the IED. These service values make it possible to displayon-line information on the local HMI and on the Substationautomation system about:

• measured voltages, currents, frequency, active, reactiveand apparent power and power factor

• primary and secondary phasors• positive, negative and zero sequence currents and voltages• mA, input currents• pulse counters

Supervision of mA input signalsThe main purpose of the function is to measure and processsignals from different measuring transducers. Many devicesused in process control represent various parameters such asfrequency, temperature and DC battery voltage as low currentvalues, usually in the range 4-20 mA or 0-20 mA.

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

The function requires that the IED is equipped with the mA inputmodule.

Event counter CNTGGIOEvent counter (CNTGGIO) has six counters which are used forstoring the number of times each counter input has beenactivated.

Disturbance report DRPRDREComplete and reliable information about disturbances in theprimary and/or in the secondary system together withcontinuous event-logging is accomplished by the disturbancereport functionality.

Disturbance report DRPRDRE, always included in the IED,acquires sampled data of all selected analog input and binarysignals connected to the function block with a, maximum of 40analog and 96 binary signals.

The Disturbance report functionality is a common name forseveral functions:

• Sequential of events• Indications• Event recorder• Trip value recorder• Disturbance recorder

The Disturbance report function is characterized by greatflexibility regarding configuration, initiating conditions, recordingtimes, and large storage capacity.

A disturbance is defined as an activation of an input to theAxRADR or BxRBDR function blocks, which are set to triggerthe disturbance recorder. All signals from start of pre-fault timeto the end of post-fault time will be included in the recording.

Every disturbance report recording is saved in the IED in thestandard Comtrade format. The same applies to all events,which are continuously saved in a ring-buffer. The local HMI isused to get information about the recordings. The disturbancereport files may be uploaded to PCM600 for further analysisusing the disturbance handling tool.

Sequential of events DRPRDREContinuous event-logging is useful for monitoring the systemfrom an overview perspective and is a complement to specificdisturbance recorder functions.

The sequential of events logs all binary input signals connectedto the Disturbance report function. The list may contain up to1000 time-tagged events stored in a ring-buffer.

Indications DRPRDRETo get fast, condensed and reliable information aboutdisturbances in the primary and/or in the secondary system it isimportant to know, for example binary signals that havechanged status during a disturbance. This information is used inthe short perspective to get information via the local HMI in astraightforward way.


26 ABB

There are three LEDs on the local HMI (green, yellow and red),which will display status information about the IED and theDisturbance report function (triggered).

The Indication list function shows all selected binary inputsignals connected to the Disturbance report function that havechanged status during a disturbance.

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

The event recorder logs all selected binary input signalsconnected to the Disturbance report function. Each recordingcan contain up to 150 time-tagged events.

The event recorder information is available for the disturbanceslocally in the IED.

The event recording information is an integrated part of thedisturbance record (Comtrade file).

Trip value recorder DRPRDREInformation about the pre-fault and fault values for currents andvoltages are vital for the disturbance evaluation.

The Trip value recorder calculates the values of all selectedanalog input signals connected to the Disturbance reportfunction. The result is magnitude and phase angle before andduring the fault for each analog input signal.

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

The trip value recorder information is an integrated part of thedisturbance record (Comtrade file).

Disturbance recorder DRPRDREThe Disturbance recorder function supplies fast, complete andreliable information about disturbances in the power system. Itfacilitates understanding system behavior and related primaryand secondary equipment during and after a disturbance.Recorded information is used for different purposes in the shortperspective (for example corrective actions) and longperspective (for example functional analysis).

The Disturbance recorder acquires sampled data from selectedanalog- and binary signals connected to the Disturbance reportfunction (maximum 40 analog and 96 binary signals). The binarysignals available are the same as for the event recorder function.

The function is characterized by great flexibility and is notdependent on the operation of protection functions. It canrecord disturbances not detected by protection functions. Up toten seconds of data before the trigger instant can be saved inthe disturbance file.

The disturbance recorder information for up to 100disturbances are saved in the IED and the local HMI is used toview the list of recordings.

Event functionWhen using a Substation Automation system with LON or SPAcommunication, time-tagged events can be sent at change orcyclically from the IED to the station level. These events arecreated from any available signal in the IED that is connected tothe Event function (EVENT). The event function block is used forremote communication.

Analog and double indication values are also transferredthrough EVENT function.

IEC61850 generic communication I/O function SPGGIOIEC61850 generic communication I/O functions (SPGGIO) isused to send one single logical signal to other systems orequipment in the substation.

IEC61850 generic communication I/O functions MVGGIOIEC61850 generic communication I/O functions (MVGGIO)function is used to send the instantaneous value of an analogsignal to other systems or equipment in the substation. It canalso be used inside the same IED, to attach a RANGE aspect toan analog value and to permit measurement supervision on thatvalue.

Measured value expander block RANGE_XPThe current and voltage measurements functions (CVMMXN,CMMXU, VMMXU and VNMMXU), current and voltage sequencemeasurement functions (CMSQI and VMSQI) and IEC 61850generic communication I/O functions (MVGGIO) are providedwith measurement supervision functionality. All measuredvalues can be supervised with four settable limits: low-low limit,low limit, high limit and high-high limit. The measure valueexpander block (RANGE_XP) has been introduced to enabletranslating the integer output signal from the measuringfunctions to 5 binary signals: below low-low limit, below lowlimit, normal, above high-high limit or above high limit. Theoutput signals can be used as conditions in the configurablelogic or for alarming purpose.

13. Metering

Pulse counter logic PCGGIOPulse counter (PCGGIO) function counts externally generatedbinary pulses, for instance pulses coming from an external


ABB 27

energy meter, for calculation of energy consumption values. Thepulses are captured by the binary input module and then readby the function. A scaled service value is available over thestation bus. The special Binary input module with enhancedpulse counting capabilities must be ordered to achieve thisfunctionality.

Function for energy calculation and demand handling ETPMMTROutputs from the Measurements (CVMMXN) function can beused to calculate energy consumption. Active as well asreactive values are calculated in import and export direction.Values can be read or generated as pulses. Maximum demandpower values are also calculated by the function.

14. Basic IED functions

Time synchronizationThe time synchronization source selector is used to select acommon source of absolute time for the IED when it is a part ofa protection system. This makes it possible to compare eventand disturbance data between all IEDs in a station automationsystem.

15. Human machine interface

Human machine interfaceThe local human machine interface is available in a mediumsized model. Up to 12 single line diagram pages can bedefined, depending on the product capability.

The local HMI is divided into zones with different functionality.

• Status indication LEDs.• Alarm indication LEDs, which consist of 15 LEDs (6 red

and 9 yellow) with user printable label. All LEDs areconfigurable from PCM600.

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

purposes, switch for selection between local and remotecontrol and reset.

• Isolated RJ45 communication port.

ANSI07000083 V1 EN

Figure 10. Example of medium graphic HMI

16. Station communication

OverviewEach IED is provided with a communication interface, enablingit to connect to one or many substation level systems orequipment, either on the Substation Automation (SA) bus orSubstation Monitoring (SM) bus.

Following communication protocols are available:

• 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 be combined in the sameIED.

IEC 61850-8-1 communication protocolThe IED is equipped with single or double optical Ethernet rearports (order dependent) for IEC 61850-8-1 station buscommunication. The IEC 61850-8-1 communication is alsopossible from the optical Ethernet front port. IEC 61850-8-1protocol allows intelligent electrical devices (IEDs) from differentvendors to exchange information and simplifies system


28 ABB

engineering. Peer-to-peer communication according to GOOSEis part of the standard. Disturbance files uploading is provided.

Serial communication, LONExisting stations with ABB station bus LON can be extendedwith use of the optical LON interface. This allows full SAfunctionality including peer-to-peer messaging and cooperationbetween existing ABB IED's and the new IED 670.

SPA communication protocolA single glass or plastic port is provided for the ABB SPAprotocol. This allows extensions of simple substationautomation systems but the main use is for SubstationMonitoring Systems SMS.

IEC 60870-5-103 communication protocolA single glass or plastic port is provided for theIEC60870-5-103 standard. This allows design of simplesubstation automation systems including equipment fromdifferent vendors. Disturbance files uploading is provided.

DNP3.0 communication protocolAn electrical RS485 and an optical Ethernet port is available forthe DNP3.0 communication. DNP3.0 Level 2 communicationwith unsolicited events, time synchronizing and disturbancereporting is provided for communication to RTUs, Gateways orHMI systems.

Multiple command and transmitWhen 670 IED's are used in Substation Automation systemswith LON, SPA or IEC60870-5-103 communication protocolsthe Event and Multiple Command function blocks are used asthe communication interface for vertical communication tostation HMI and gateway and as interface for horizontal peer-to-peer communication (over LON only).

IEC 62439-3 Parallel Redundant ProtocolRedundant station bus communication according to IEC62439-3 Edition 1 and IEC 62439-3 Edition 2 are available asoptions in 670 series IEDs. IEC 62439-3 parallel redundantprotocol is an optional quantity and the selection is made atordering. Redundant station bus communication according toIEC 62439-3 uses both port AB and port CD on the OEMmodule.

Select IEC 62439-3 Edition 1 protocol at thetime of ordering when an existing redundantstation bus DuoDriver installation is extended.Select IEC 62439-3 Edition 2 protocol at thetime of ordering for new installations withredundant station bus.IEC 62439-3 Edition 1 is NOT compatiblewith IEC 62439-3 Edition 2.

17. Remote communication

Analog and binary signal transfer to remote endThree analog and eight binary signals can be exchangedbetween two IEDs. This functionality is mainly used for the linedifferential protection. However it can be used in other productsas well. An IED can communicate with up to 4 remote IEDs.

Binary signal transfer to remote end, 192 signalsIf the communication channel is used for transfer of binarysignals only, up to 192 binary signals can be exchangedbetween two IEDs. For example, this functionality can be usedto send information such as status of primary switchgearapparatus or intertripping signals to the remote IED. An IED cancommunicate with up to 4 remote IEDs.

Line data communication module, short and medium rangeLDCMThe line data communication module (LDCM) is used forcommunication between the IEDs situated at distances<37miles or from the IED to optical to electrical converter withG.703 or G.703E1 interface located on a distances <1.9 milesaway. The LDCM module sends and receives data, to and fromanother LDCM module. The IEEE/ANSI C37.94 standard formatis used.

This feature can be for example used in power stations toexchange up to 192 binary signals (e.g. tripping, signaling,alarming) between the generator and HV station in power plants

18. Hardware description

Hardware modulesPower supply module PSMThe power supply module is used to provide the correct internalvoltages and full isolation between the terminal and the batterysystem. An internal fail alarm output is available.

Binary input module BIMThe binary input module has 16 optically isolated inputs and isavailable in two versions, one standard and one with enhancedpulse counting capabilities on the inputs to be used with thepulse counter function. The binary inputs are freelyprogrammable and can be used for the input of logical signalsto any of the functions. They can also be included in thedisturbance recording and event-recording functions. Thisenables extensive monitoring and evaluation of operation of theIED and for all associated electrical circuits.


ABB 29

Binary output module BOMThe binary output module has 24 independent output relaysand is used for trip output or any signaling purpose.

Static binary output module SOMThe static binary output module has six fast static outputs andsix change over output relays for use in applications with highspeed requirements.

Binary input/output module IOMThe binary input/output module is used when only a few inputand output channels are needed. The ten standard outputchannels are used for trip output or any signaling purpose. Thetwo high speed signal output channels are used for applicationswhere short operating time is essential. Eight optically isolatedbinary inputs cater for required binary input information.

mA input module MIMThe milli-ampere input module is used to interface transducersignals in the –20 to +20 mA range from for example OLTCposition, temperature or pressure transducers. The module hassix independent, galvanically separated channels.

Optical ethernet module OEMThe optical fast-ethernet module is used to connect an IED tothe communication buses (like the station bus) that use the IEC61850-8-1 protocol (port A, B). The module has one or twooptical ports with ST connectors.

Serial and LON communication module SLM, supports SPA/IEC 60870-5-103, LON and DNP 3.0The serial and LON communication module (SLM) is used forSPA, IEC 60870-5-103, DNP3 and LON communication. Themodule has two optical communication ports for plastic/plastic,plastic/glass or glass/glass. One port is used for serialcommunication (SPA, IEC 60870-5-103 and DNP3 port ordedicated IEC 60870-5-103 port depending on ordered SLMmodule) and one port is dedicated for LON communication.

Line data communication module LDCMEach module has one optical port, one for each remote end towhich the IED communicates.

Alternative cards for Medium range (1310 nm single mode) andShort range (850 nm multi mode) are available.

Galvanic RS485 serial communication moduleThe Galvanic RS485 communication module (RS485) is usedfor DNP3.0 communication. The module has one RS485communication port. The RS485 is a balanced serialcommunication that can be used either in 2-wire or 4-wireconnections. A 2-wire connection uses the same signal for RXand TX and is a multidrop communication with no dedicatedMaster or slave. This variant requires however a control of theoutput. The 4-wire connection has separated signals for RX andTX multidrop communication with a dedicated Master and therest are slaves. No special control signal is needed in this case.

GPS time synchronization module GTMThis module includes a GPS receiver used for timesynchronization. The GPS has one SMA contact for connectionto an antenna. It also includes an optical PPS ST-connectoroutput.

IRIG-B Time synchronizing moduleThe IRIG-B time synchronizing module is used for accurate timesynchronizing of the IED from a station clock.

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

Transformer input module TRMThe transformer input module is used to galvanically separateand transform the secondary currents and voltages generatedby the measuring transformers. The module has twelve inputs indifferent combinations of currents and voltage inputs. Eitherprotection class or metering class CT inputs are available.

Alternative connectors of Ring lug or Compression type can beordered.

High impedance resistor unitThe high impedance resistor unit, with resistors for pick-upvalue setting and a voltage dependent resistor, is available in asingle phase unit and a three phase unit. Both are mounted ona 1/1 19 inch apparatus plate with compression type terminals.

Layout and dimensionsDimensions


30 ABB

xx05000003.vsd

CB

E

F

A

D

IEC05000003 V1 EN

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

xx05000004.vsdIEC05000004 V1 EN

Figure 12. Side-by-side mounting

Case size A B C D E F

6U, 1/2 x 19” 10.47 8.81 7.92 9.53 9.96 8.10

6U, 3/4 x 19” 10.47 13.23 7.92 9.53 9.96 12.52

6U, 1/1 x 19” 10.47 17.65 7.92 9.53 9.96 16.94

(inches)

Mounting alternatives• 19” rack mounting kit• Wall mounting kit

See ordering for details about available mounting alternatives.


ABB 31

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


32 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 33


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


34 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


ABB 35

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

1MRK002802-AB-10-670-1.2-PG-ANSI V1 EN

Figure 13. Transformer input module (TRM)

￭ Indicates high polarity. See table 6

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


36 ABB

Table 6. CT/VT-input designation

Cur

rent

/vo

ltag

eco

nfig

urat

ion

(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 1A12I, 5A 5A 5A 5A 5A 5A 5A 5A 5A 5A 5A 5A 5A9I+3V, 1A 1A 1A 1A 1A 1A 1A 1A 1A 1A 110-220V 110-220V 110-220V9I+3V, 5A 5A 5A 5A 5A 5A 5A 5A 5A 5A 110-220V 110-220V 110-220V5I, 1A+4I, 5A+3V 1A 1A 1A 1A 1A 5A 5A 5A 5A 110-220V 110-220V 110-220V7I+5V, 1A 1A 1A 1A 1A 1A 1A 1A 110-220V 110-220V 110-220V 110-220V 110-220V7I+5V, 5A 5A 5A 5A 5A 5A 5A 5A 110-220V 110-220V 110-220V 110-220V 110-220V6I, 5A+1I, 1A+5V 5A 5A 5A 5A 5A 5A 1A 110-220V 110-220V 110-220V 110-220V 110-220V3I, 5A+4I, 1A+5V 5A 5A 5A 1A 1A 1A 1A 110-220V 110-220V 110-220V 110-220V 110-220V3IM, 1A+4IP, 1A+5V 1AM

*)1AM*)

1AM*)

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

3IM, 5A+4IP, 5A+5V 5AM*)

5AM*)

5AM*)

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

6I+6V, 1A 1A 1A 1A 1A 1A 1A 110-220V 110-220V 110-220V 110-220V 110-220V 110-220V6I+6V, 5A 5A 5A 5A 5A 5A 5A 110-220V 110-220V 110-220V 110-220V 110-220V 110-220V3I, 5A+3I, 1A+6V 5 A 5 A 5 A 1A 1A 1A 110-220V 110-220V 110-220V 110-220V 110-220V 110-220V6I, 1A 1A 1A 1A 1A 1A 1A - - - - - -6I, 5A 5A 5A 5A 5A 5A 5A - - - - - -*) Metering

1MRK002802-AB-7-670-1.2-PG-ANSI V1 EN

Figure 14. Power supply module (PSM)


ABB 37

1MRK002802-AB-11-670-1.2-PG-ANSI V1 EN

Figure 15. Binary input module (BIM). Input contacts named XA corresponds to rear position X31, X41, etc. and input contacts named XB torear position X32, X42, etc.

1MRK002802-AB-12-670-1.2-PG-ANSI V1 EN

Figure 16. Binary output module (BOM). Output contacts named XA corresponds to rear position X31, X41, etc. and output contacts namedXB to rear position X32, X42, etc.

1MRK002802-AB-13-670-1.2-PG-ANSI V1 EN

Figure 17. Static output module (SOM). Output contacts named XA corresponds to rear position X31, X41, etc. and output contacts named XBto rear position X32, X42, etc.

1MRK002802-AB-14-670-1.2-PG-ANSI V1 EN

Figure 18. Binary in/out module (IOM). Input contacts named XA corresponds to rear position X31, X41, etc. and output contacts named XB torear position X32, X42, etc.

1MRK002802-AB-15-670-1.2-PG-ANSI V1 EN

Figure 19. mA input module (MIM)


38 ABB

1MRK002802-AB-8-670-1.2-PG-ANSI V1 EN

Figure 20. IED with basic functionality communication interfaces


ABB 39

20. Technical data

General

Definitions

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

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

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

Energizing quantities, rated values and limitsAnalog inputs

Table 7. TRM - Energizing quantities, rated values and limits for protection transformer modules

Quantity Rated value Nominal range

Current In = 1 or 5 A (0.2-40) × In

Operative range (0-100) x In

Permissive overload 4 × In cont.100 × In for 1 s *)

Burden < 150 mVA at In = 5 A< 20 mVA at In = 1 A

Ac voltage Vn = 120 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 fn = 60/50 Hz ± 5%

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


40 ABB

Table 8. TRM - Energizing quantities, rated values and limits for measuring transformer modules


Current In = 1 or 5 A (0-1.8) × In at In = 1 A(0-1.6) × In at In = 5 A

Permissive overload 1.1 × In cont.1.8 × In for 30 min at In = 1 A1.6 × In for 30 min at In = 5 A

Burden < 350 mVA at In = 5 A< 200 mVA at In = 1 A

Ac voltage Vn = 120 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 fn = 60/50 Hz ± 5%

Table 9. 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 10. 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


ABB 41

Auxiliary DC voltage

Table 11. 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 12. BIM - Binary input module


Binary inputs 16 -

DC voltage, RL 24/30 V48/60 V125 V220/250 V

RL ± 20%RL ± 20%RL ± 20%RL ± 20%

Power consumption24/30 V, 50mA48/60 V, 50mA125 V, 50mA220/250 V, 50mA220/250 V, 110mA

max. 0.05 W/inputmax. 0.1 W/inputmax. 0.2 W/inputmax. 0.4 W/inputmax. 0.5 W/input

-

Counter input frequency 10 pulses/s max -

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

Debounce filter Settable 1–20ms

Maximum 176 binary input channels may beactivated simultaneously with influencingfactors within nominal range.


42 ABB

Table 13. BIM - Binary input module with enhanced pulse counting capabilities


Binary inputs 16 -


RL ± 20%RL ± 20%RL ± 20%RL ± 20%

Power consumption24/30 V48/60 V125 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 -

Balanced counter input frequency 40 pulses/s max -

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


Table 14. IOM - Binary input/output module


Binary inputs 8 -


RL ± 20%RL ± 20%RL ± 20%RL ± 20%

Power consumption24/30 V, 50 mA48/60 V, 50 mA125 V, 50 mA220/250 V, 50 mA220/250 V, 110 mA

max. 0.05 W/inputmax. 0.1 W/inputmax. 0.2 W/inputmax. 0.4 W/inputmax. 0.5 W/input

-

Counter input frequency 10 pulses/s max

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

Debounce filter Settable 1-20 ms



ABB 43

Table 15. IOM - Binary input/output module contact data (reference standard: IEC 61810-2)

Function or quantity Trip and signal relays Fast signal relays (parallelreed relay)

Binary outputs 10 2

Max system voltage 250 V AC, DC 250 V DC

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

Current carrying capacityPer relay, continuousPer relay, 1 sPer process connector pin, continuous

8 A10 A12 A

8 A10 A12 A

Making capacity at inductive load with L/R>10 ms 0.2 s1.0 s

30 A10 A

0.4 A0.4 A

Making capacity at resistive load 0.2 s1.0 s

30 A10 A

220–250 V/0.4 A110–125 V/0.4 A48–60 V/0.2 A24–30 V/0.1 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 < 40 ms 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


44 ABB

Table 16. IOM with MOV and IOM 220/250 V, 110mA - contact data (reference standard: IEC 61810-2)

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

Binary outputs IOM: 10 IOM: 2

Max system voltage 250 V AC, DC 250 V DC

Test voltage across opencontact, 1 min

250 V rms 250 V rms

Current carrying capacityPer relay, continuousPer relay, 1 sPer process connector pin,continuous

8 A10 A12 A

8 A10 A12 A

Making capacity at inductiveloadwith L/R>10 ms0.2 s1.0 s

30 A10 A

0.4 A0.4 A

Making capacity at resistive load 0.2 s1.0 s

30 A10 A

220–250 V/0.4 A110–125 V/0.4 A48–60 V/0.2 A24–30 V/0.1 A

Breaking capacity for AC, cosj>0.4

250 V/8.0 A 250 V/8.0 A

Breaking capacity for DC with L/R < 40 ms

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

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

Maximum capacitive load - 10 nF


ABB 45

Table 17. SOM - Static Output Module (reference standard: IEC 61810-2): Static binary outputs

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 open contact, 1 min No galvanic separation No galvanic separation

Current carrying capacity:

Continuous 5A 5A

1.0s 10A 10A

Making capacity at capacitive load with themaximum capacitance 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

Table 18. 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 the maximum capacitance of 0.2μF:

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


46 ABB

Table 19. 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 capacityPer relay, continuousPer relay, 1 sPer process connector pin, continuous

8 A10 A12 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

Influencing factors

Table 20. Temperature and humidity influence

Parameter Reference value Nominal range Influence

Ambient temperature, operate value +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 21. Auxiliary DC supply voltage influence on functionality during operation

Dependence on Reference value Within nominalrange

Influence

Ripple, in DC auxiliary voltageOperative range

max. 2%Full wave rectified

15% of EL 0.01% /%

Auxiliary voltage dependence, operatevalue

± 20% of EL 0.01% /%

Interrupted auxiliary DC voltage

24-60 V DC ± 20% 90-250 V DC ± 20%

Interruption interval0–50 ms

No restart

0–∞ s Correct behaviour at power down

Restart time <300 s


ABB 47

Table 22. Frequency influence (reference standard: IEC 60255–1)

Dependence on Within nominal range Influence

Frequency dependence, operate value fn ± 2.5 Hz for 50 Hzfn ± 3.0 Hz for 60 Hz

± 1.0% / Hz

Harmonic frequency dependence (20% content) 2nd, 3rd and 5th harmonic of fn ± 1.0%

Harmonic frequency dependence for high impedance differentialprotection (10% content)

2nd, 3rd and 5th harmonic of fn ±5.0%

Type tests according to standards

Table 23. Electromagnetic compatibility

Test Type test values Reference standards

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

100 kHz slow damped oscillatory wave 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

Electrostatic dischargeDirect applicationIndirect application

15 kV air discharge8 kV contact discharge8 kV contact discharge

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 IEC 60255-22-7, Class A

Conducted common mode immunity 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 field test 100 A/m IEC 61000-4-10, Class V

Radiated electromagnetic field disturbance 20 V/m, 80-1000 MHz 1.4-2.7 GHz

IEC 60255-22-3

Radiated electromagnetic field disturbance 35 V/m26-1000 MHz

IEEE/ANSI C37.90.2

Conducted electromagnetic field disturbance 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


48 ABB

Table 24. Insulation

Test Type test values Reference standard

Dielectric test 2.0 kV AC, 1 min. ANSI C37.90

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

Insulation resistance >100 MW at 500 VDC

Table 25. 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 and humidity 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 = 24hours)

IEC 60068-2-30

Table 26. CE compliance

Test According to

Immunity EN 50263

Emissivity EN 50263

Low voltage directive EN 50178

Table 27. Mechanical tests

Test Type test values Reference standards

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


ABB 49


Table 28. Generator differential protection GENPDIF (87G)

Function Range or value Accuracy

Unrestrained differential current limit (1-50)p.u. of IBase ± 2.0% of set value

Reset ratio > 95% -

Base sensitivity function (0.05–1.00)p.u. of IBase ± 2.0% of In

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

Operate time, restrained function 25 ms typically at 0 to 2x set level

-

Reset time, restrained function 20 ms typically at 2 to 0x set level

-

Operate time, unrestrained function 12 ms typically at 0 to 5x set level

-

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

-

Operate time, negative sequenceunrestrained function

15 ms typically at 0 to 5x set level

-

Critical impulse time, unrestrained function 2 ms typically at 0 to 5x set level

-


50 ABB

Table 29. Transformer differential protection T2WPDIF, T3WPDIF (87T)


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

Reset ratio >95% -

Unrestrained differential current limit (100-5000)% ofIBaseon high voltage winding

± 1.0% of set value

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

Second harmonic blocking (5.0-100.0)% offundamental differentialcurrent

± 2.0% of applied harmonic magnitude

Fifth harmonic blocking (5.0-100.0)% offundamental differentialcurrent

± 5.0% of applied harmonic magnitude

Connection type for each of the windings Wye or delta -

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

0–11 -

Operate time, restrained function 25 ms typically at 0 to 2x set level

-

Reset time, restrained function 20 ms typically at 2 to 0x set level

-

Operate time, unrestrained function 12 ms typically at 0 to 5x set level

-

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

-

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

-

Table 30. Restricted earth fault protection, low impedance REFPDIF (87N)


Operate characteristic Adaptable ± 1% of2%(The above is valid if IBase is equal to the protected winding rated current).

Reset ratio 0.95 -

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

± 1 degree at Ibias = IBase± 2 degrees at Ibias = 2 * IBase± 3 degrees at Ibias = 4 * IBase(The above valid if IBase equal to the protected winding rated current)

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

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

Second harmonic blocking (5.0-100.0)% of fundamental ± 2.0% of Irn


ABB 51

Table 31. 1Ph High impedance differential protection HZPDIF (87)


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

± 1.0% of In

Reset ratio >95% -

Maximum continuous power V>Pickup2/SeriesResistor ≤200 W -

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

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

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


52 ABB


Table 32. Full-scheme distance protection, Mho characteristic ZMHPDIS (21)


Number of zones with selectabledirections

4 with selectable direction -

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

Positive sequence impedance,phase-to-ground loop

(0.005–3000.000) W/phase ± 2.0% static accuracyConditions:Voltage range: (0.1-1.1) x Vn

Current range: (0.5-30) x InAngle: 85 degrees

Positive sequence impedanceangle, phase-to-ground loop

(10–90) degrees

Reverse reach, phase-to-groundloop (Magnitude)

(0.005–3000.000) Ω/phase

Magnitude of ground returncompensation factor KN

(0.00–3.00)

Angle for ground compensationfactor KN

(-180–180) degrees

Dynamic overreach <5% at 85 degrees measuredwith CVT’s and 0.5<SIR<30

-

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

Operate time 20 ms typically (with staticoutputs)

-

Reset ratio 105% typically -

Reset time 30 ms typically -

Table 33. Pole slip protection PSPPPAM (78)


Impedance reach (0.00–1000.00)% of Zbase ± 2.0% of Vn/In

Characteristic angle (72.00–90.00) degrees ± 5.0 degrees

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

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

Table 34. Loss of excitation LEXPDIS (40)


X offset of Mho top point (–1000.00–1000.00)% of ZBase ± 2.0% of Vn/In

Diameter of Mho circle (0.00–3000.00)% of ZBase ± 2.0% of Vn/In

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


ABB 53

Current protection

Table 35. Instantaneous phase overcurrent protection PHPIOC (50)


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

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 -

Table 36. Four step phase overcurrent protection OC4PTOC (51/67)

Function Setting range Accuracy

Trip current (5-2500)% of lBase ± 1.0% of In at I ≤ In± 1.0% of I at I > In

Reset ratio > 95% at (50–2500)% of lBase -

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

Relay characteristic angle (RCA) (40.0–65.0) degrees ± 2.0 degrees

Relay operating angle (ROA) (40.0–89.0) degrees ± 2.0 degrees

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

Independent time delay at 0 to 2 xIset

(0.000-60.000) s ± 0.2 % or ± 35 ms whichever isgreater

Minimum trip time (0.000-60.000) s ± 2.0 % or ± 40 ms whichever isgreater

Inverse characteristics, seetable 99, table 100 and table 101

16 curve types See table 99, table 100 and table 101

Trip time, pickup non-directional at0 to 2 x Iset

Min. = 15 ms

Max. = 30 ms

Reset time, pickup non-directionalat 2 to 0 x Iset

Min. = 15 ms

Max. = 30 ms


Impulse margin time 15 ms typically -


54 ABB

Table 37. Instantaneous residual overcurrent protection EFPIOC (50N)


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

Reset ratio > 95% -







Dynamic overreach < 5% at t = 100 ms -

Table 38. Four step residual overcurrent protection EF4PTOC (51N/67N)


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

Reset ratio > 95% -

Operate current for directionalcomparison

(1–100)% of lBase ± 1.0% of In

Timers (0.000-60.000) s ± 0.5% ±10 ms

Inverse characteristics, see table99, table 100 and table 101

18 curve types See table 99, table 100 and table101

Second harmonic restrainoperation

(5–100)% of fundamental ± 2.0% of In

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

Minimum polarizing voltage (1–100)% of VBase ± 0.5% of Vn

Minimum polarizing current (1-30)% of IBase ±0.25 % of In

Real part of source Z used forcurrent polarization

(0.50-1000.00) W/phase -

Imaginary part of source Z usedfor current polarization

(0.50–3000.00) W/phase -

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

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




ABB 55

Table 39. Four step negative sequence overcurrent protection NS4PTOC (46I2)


Operate value, negativesequence current, step 1-4

(1-2500)% of lBase ± 1.0% of In at I £ In± 1.0% of I at I > In

Reset ratio > 95% -

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

Inverse characteristics, see table99, table 100 and table 101

18 curve types See table 99, table 100 and table101

Minimum operate current for step1 - 4

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

Operate value, negative currentfor directional release

(1–100)% of IBase ± 1.0% of In

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

Minimum polarizing voltage (1–100)% of VBase ± 0.5% of Vn

Minimum polarizing current (2-100)% of IBase ±1.0% of In

Real part of negative sequencesource impedance used forcurrent polarization

(0.50-1000.00) W/phase -

Imaginary part of negativesequence source impedanceused for current polarization

(0.50–3000.00) W/phase -

Operate time, pickup function 25 ms typically at 0.5 to 2 x Iset -

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

Critical impulse time, pickupfunction

10 ms typically at 0 to 2 x Iset -

Impulse margin time, pickupfunction

15 ms typically -

Transient overreach <10% at τ = 100 ms -


56 ABB

Table 40. Sensitive directional residual overcurrent and power protection SDEPSDE (67N)


Operate level for 3I0·cosj

directional residualovercurrent

(0.25-200.00)% of lBase ± 1.0% of In at I £ In± 1.0% of I at I > In At low setting:(0.25-1.00)% of In: ±0.05% of In(1.00-5.00)% of In: ±0.1% of In

Operate level for ·3I0·3V0·cosj directional residualpower

(0.25-200.00)% of SBase ± 1.0% of Sn at S £ Sn

± 1.0% of S at S > Sn

At low setting:(0.25-5.00)% of SBase ± 10% of set value

Operate level for 3I0 and jresidual overcurrent

(0.25-200.00)% of lBase ± 1.0% of In at £ In± 1.0% of I at I > In At low setting:(0.25-1.00)% of In: ±0.05% of In(1.00-5.00)% of In: ±0.1% of In

Operate level for non-directional overcurrent

(1.00-400.00)% of lBase ± 1.0% of In at I £ In± 1.0% of I at I > In At low setting <5% of In:±0.1% of In

Operate level for non-directional residualovervoltage

(1.00-200.00)% of VBase ± 0.5% of Vn at V£Vn

± 0.5% of V at V > Vn

Residual release current forall directional modes

(0.25-200.00)% of lBase ± 1.0% of In at I £ In± 1.0% of I at I > In At low setting:(0.25-1.00)% of In: ±0.05% of In(1.00-5.00)% of In: ±0.1% of In

Residual release voltage forall directional modes

(0.01-200.00)% of VBase ± 0.5% of Vn at V£Vn

± 0.5% of V at V > Vn

Reset ratio > 95% -

Timers (0.000-60.000) s ± 0.5% ±10 ms

Inverse characteristics, seetable 99, table 100 and table101

19 curve types See table 99, table 100 and table 101

Relay characteristic angleRCA

(-179 to 180) degrees ± 2.0 degrees

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


ABB 57

Table 40. Sensitive directional residual overcurrent and power protection SDEPSDE (67N) , continued


Operate time, non-directionalresidual over current


Reset time, non-directionalresidual over current


Operate time, pickup function 150 ms typically at 0 to 2 x Iset -

Reset time, pickup function 50 ms typically at 2 to 0 x Iset -

Table 41. Thermal overload protection, two time constants TRPTTR (49)


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

Operate time:

2 2

2 2ln p

b

I It

I It

æ ö-ç ÷= ×ç ÷-è ø

EQUATION1356 V1 EN (Equation 1)

I = Imeasured

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

IEC 60255–8, ±5% + 200 ms

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

± 2.0% of heat content trip

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

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

Table 42. Breaker failure protection CCRBRF (50BF)


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

Reset ratio, phase current > 95% -

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

Reset ratio, residual current > 95% -

Phase current pickup for blocking of contact function (5-200)% of lBase ± 1.0% of In at I £ In± 1.0% of I at I > In

Reset ratio > 95% -

Timers (0.000-60.000) s ± 0.5% ±10 ms

Operate time for current detection 10 ms typically -

Reset time for current detection 15 ms maximum -


58 ABB

Table 43. Pole discrepancy protection CCRPLD (52PD)


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

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

Table 44. Directional underpower protection GUPPDUP (37)


Power level (0.0–500.0)% of SBase When TRM module withmeasuring current transformerinputs is used the followingaccuracy can be obtained for lowpickup settings which are typicalfor reverse power protectionapplication:

± 1.0% of Sr at S < Sr

± 1.0% of S at S > Sr

Pickup value=0.5% of Sr accuracy of ± 0.20% of Sr*)Pickup value=0.25% of Sr accuracy of ± 0.15% of Sr*) where: Sr=√3 x Ur x Ir

Characteristic angle (-180.0–180.0) degrees 2 degrees

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

*) To achieve this accuracy for reverse power protection it is also recommended to apply setting AngleN=-179.3 degrees instead of standard 180degrees. This setting will help to minimize the overall measurement error ensuring the above stated accuracy for this application.

Table 45. Directional overpower protection GOPPDOP (32)


Power level (0.0–500.0)% of Sbase

When TRM module withmeasuring current transformerinputs is used the followingaccuracy can be obtained for lowpickup settings which are typicalfor reverse power protectionapplication:

± 1.0% of Sr at S < Sr

± 1.0% of S at S > Sr

Pickup value=0.5% of Sr accuracy of ± 0.20% of Sr*)Pickup value=0.25% of Sr accuracy of ± 0.15% of Sr*) where: Sr=√3 x Ur x Ir

Characteristic angle (-180.0–180.0) degrees 2 degrees

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

*) To achieve this accuracy for reverse power protection it is also recommended to apply setting AngleN=-179.3 degrees instead of standard 180degrees. This setting will help to minimize the overall measurement error ensuring the above stated accuracy for this application.


ABB 59

Table 46. Negative sequence time overcurrent protection for machines NS2PTOC (46I2)


Operate value, step 1 and 2, negative sequence overcurrent (3-500)% of IBase ± 1.0% of In at I < In± 1.0% of I at I > In

Reset ratio, step 1 and 2 >95% -

Operate time, pickup 20 ms typically at 0 to 2 x Iset

15 ms typically at 0 to 10 x Iset

-

Reset time, pickup 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 ± 5% + 40 ms

Reset time, inverse characteristic step 1, 2

2I t K=K=0.01-20.00 ± 10% + 40 ms

Maximum trip delay, step 1 IDMT (0.00-6000.00) s ± 0.5% ± 10 ms

Minimum trip delay, step 1 IDMT (0.000-60.000) s ± 0.5% ± 10 ms

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

Table 47. Accidental energizing protection for synchronous generator AEGGAPC (50AE)


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

Reset ratio, overcurrent >95% -

Transient overreach, overcurrent function <10% at τ = 100 ms -

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

Impulse margin time, overcurrent 10 ms typically -

Operate value, undervoltage (2-200)% of VBase ± 0.5% of Vn at V<Vn

± 0.5% of V at V>Vn

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

Impulse margin time, undervoltage 15 ms typically -

Operate value, overvoltage (2-200)% of VBase ± 0.5% of Vn at V<Vn

± 0.5% of V at V>Vn

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


60 ABB

Voltage protection

Table 48. Two step undervoltage protection UV2PTUV (27)


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

Absolute hysteresis (0–100)% of VBase ± 0.5% of Vn

Internal blocking level, step 1 and step 2 (1–100)% of VBase ± 0.5% of Vn

Inverse time characteristics for step 1 and step 2, see table 103 - See table 103

Definite time delay, step 1 (0.00 - 6000.00) s ± 0.5% ± 10 ms

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, pickup function 25 ms typically at 2 x Vset to 0 0 -

Reset time, pickup function -

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


Table 49. Two step overvoltage protection OV2PTOV (59)


Operate voltage, step 1 and 2 (1-200)% of VBase ± 0.5% of Vn at V < Vn

± 0.5% of V at V > Vn

Absolute hysteresis (0–100)% of VBase ± 0.5% of Vn at V < Vn

± 0.5% of V at V > Vn

Inverse time characteristics for steps 1 and 2, see table 102 - See table 102

Definite time delay, step 1 (0.00 - 6000.00) s ± 0.5% ± 10 ms

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, pickup function 25 ms typically at 0 to 2 x Vset -

Reset time, pickup function 25 ms typically at 2 to 0 x Vset -

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



ABB 61

Table 50. Two step residual overvoltage protection ROV2PTOV (59N)


Operate voltage, step 1 and step 2 (1-200)% of VBase ± 0.5% of Vn at V < Vn

± 1.0% of V at V > Vn

Absolute hysteresis (0–100)% of VBase ± 0.5% of Vn at V < Vn

± 1.0% of V at V > Vn

Inverse time characteristics for low and high step, see table 104 - See table 104

Definite time setting, step 1 (0.00–6000.00) s ± 0.5% ± 10 ms

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

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

Operate time, pickup function 25 ms typically at 0 to 2 x Vset -

Reset time, pickup function 25 ms typically at 2 to 0 x Vset -



Table 51. Overexcitation protection OEXPVPH (24)


Pickup value, pickup (100–180)% of (VBase/fn) ± 0.5% of V

Pickup value, alarm (50–120)% of pickup level ± 0.5% of Vn at V ≤ Vn

± 0.5% of V at V > Vn

Pickup value, high level (100–200)% of (VBase/fn) ± 0.5% of V

Curve type IEEE or customer defined

2

(0.18 ):

( 1)×

=-

TDIEEE t

M


where M = (E/f)/(Vn/fn)

± 5% + 40 ms

Minimum time delay for inversefunction

(0.000–60.000) s ± 0.5% ± 10 ms

Maximum time delay for inversefunction

(0.00–9000.00) s ± 0.5% ± 10 ms

Alarm time delay (0.00–9000.00) ± 0.5% ± 10 ms

Table 52. Voltage differential protection VDCPTOV (60)


Voltage difference for alarm andtrip

(0.0–100.0) % of VBase ± 0.5 % of Vn

Under voltage level (0.0–100.0) % of VBase ± 0.5% of Vn

Timers (0.000–60.000)s ± 0.5% ± 10 ms


62 ABB

Table 53. 100% Stator E/F 3rd harmonic STEFPHIZ (59THD)


Fundamental frequency level UN(95% Stator EF)

(1.0–50.0)% of VBase ± 0.5% of Vn

Third harmonic differential level (0.5–10.0)% of VBase ± 0.5% of Vn

Third harmonic differential blocklevel

(0.1–10.0)% of VBase ± 0.5% of Vn

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

Filter characteristic:FundamentalThird harmonic

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

-


ABB 63


Table 54. Underfrequency protection SAPTUF (81)


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

Operate time, pickup function 100 ms typically -

Reset time, pickup 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

()

__

_Exponent

VVM

int

tMaxTripDelay

tMinTripDelay

tMinTripDelay

VNom

VMin

-=

×-

+-

éù

êú

ëû


V=Vmeasured

Settings:VNom=(50-150)% of Vbase

VMin=(50-150)% of Vbase

Exponent=0.0-5.0t_MaxTripDelay=(0.000-60.000)st_MinTripDelay=(0.000-60.000)s

5% + 200 ms

Table 55. Overfrequency protection SAPTOF (81)


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

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

Reset time, pickup 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


64 ABB

Table 56. Rate-of-change frequency protection SAPFRC (81)


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

Operate value, internal blocking level (0-100)% of VBase ± 0.5% of Vn

Operate time, pickup function 100 ms typically -


ABB 65


Table 57. General current and voltage protection CVGAPC


Measuring current input Phase A, Phase B, Phase C, PosSeq,NegSeq, 3*ZeroSeq, MaxPh, MinPh,UnbalancePh, Phase A-Phase B, PhaseB-Phase C, Phase C-Phase A, MaxPh-Ph, MinPh-Ph, UnbalancePh-Ph

-

Base current (1 - 99999) A -

Measuring voltage input Phase A, Phase B, Phase C, PosSeq, -NegSeq, -3*ZeroSeq, MaxPh, MinPh,UnbalancePh, Phase A-Phase B, PhaseB-Phase C, Phase C-Phase A, MaxPh-Ph, MinPh-Ph, UnbalancePh-Ph

-

Base voltage (0.05 - 2000.00) kV -

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

Pickup undercurrent, step 1 and 2 (2 - 150)% of IBase ± 1.0% of In for I<In± 1.0% of I for I>In

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

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

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

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

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

See table 99 and table 100 Parameter ranges for customer definedcharacteristic no 17:TD: 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 99 and table 100

Voltage level where voltage memory takes over (0.0 - 5.0)% of VBase ± 0.5% of Vn

Pickup overvoltage, step 1 and 2 (2.0 - 200.0)% of VBase ± 0.5% of Vn for V<Vn

± 0.5% of V for V>Vn

Pickup undervoltage, step 1 and 2 (2.0 - 150.0)% of VBase ± 0.5% of Vn for V<Vn


Operate time, pickup overvoltage 25 ms typically at 0 to 2 x Vset -

Reset time, pickup overvoltage 25 ms typically at 2 to 0 x Vset -

Operate time pickup undervoltage 25 ms typically 2 to 0 x Vset -


66 ABB

Table 57. General current and voltage protection CVGAPC , continued


Reset time pickup undervoltage 25 ms typically at 0 to 2 x Vset -

High and low voltage limit, voltage dependent operation (1.0 - 200.0)% of VBase ± 1.0% of Vn for V<Vn


Directional function Settable: NonDir, forward and reverse -

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:



Undervoltage:




ABB 67

Table 58. Rotor earth fault protection (64R) based on General current and voltage protection (CVGAPC) and RXTTE4


For machines with:

• rated field voltage up to 350 V DC -

• static exciter with rated supplyvoltage up to

700 V 50/60 Hz -

Supply voltage 120 or 230 V 50/60 Hz -

Operate ground fault resistancevalue

Approx. 1–20 kΩ -

Influence of harmonics in the DCfield voltage

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

-

Permitted leakage capacitance (1–5) μF

Permitted shaft groundingresistance

Maximum 200 Ω -

Protective resistor 220 Ω, 100 W, plate 135 x 160mm

-


68 ABB


Table 59. Current circuit supervision CCSRDIF (87)


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

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

Table 60. Fuse failure supervision SDDRFUF


Operate voltage, zero sequence (1-100)% of VBase ± 1.0% of Vn

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

Operate voltage, negative sequence (1–100)% of VBase ± 0.5% of Vn

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

Operate voltage change pickup (1–100)% of VBase ± 5.0% of Vn

Operate current change pickup (1–100)% of IBase ± 5.0% of In

Operate phase voltage (1-100)% of VBase ± 0.5% of Vn

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

Operate phase dead line voltage (1-100)% of VBase ± 0.5% of Vn

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

Operate time, general pickup of function 25 ms typically at 1 to 0 of Vbase -

Reset time, general pickup of function 35 ms typically at 0 to 1 of Vbase -


ABB 69

Control

Table 61. Synchronizing, synchronism check and energizing check SESRSYN (25)


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

Voltage ratio, Vbus/Vline 0.500 - 2.000 -

Voltage high limit for synchronism check (50.0-120.0)% of VBaseBus andVBaseLine

± 0.5% of Vn at V ≤ Vn

± 0.5% of V at V > Vn

Reset ratio, synchronism check > 95% -

Frequency difference limit between bus and line for synchrocheck (0.003-1.000) Hz ± 2.0 mHz

Phase angle difference limit between bus and line for synchrocheck (5.0-90.0) degrees ± 2.0 degrees

Voltage difference limit between bus and line for synchronizing andsynchrocheck

(0.02-0.5) p.u ± 0.5% of Vn

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

Frequency difference minimum limit for synchronizing (0.003-0.250) Hz ± 2.0 mHz

Frequency difference maximum limit for synchronizing (0.050-0.500) Hz ± 2.0 mHz

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

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

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

tMaxSynch, which resets synchronizing function if no close has been madebefore set time

(0.000-60.000) s ± 0.5% ± 10 ms

Minimum time to accept synchronizing conditions (0.000-60.000) s ± 0.5% ± 10 ms

Voltage high limit for energizing check (50.0-120.0)% of VBaseBus andVBaseLine


± 0.5% of V at V > Vn

Reset ratio, voltage high limit > 95% -

Voltage low limit for energizing check (10.0-80.0)% of VBaseBus andVBaseLine

± 0.5% of Vn

Reset ratio, voltage low limit < 105% -

Maximum voltage for energizing (50.0-180.0)% of VBaseBus and/or VBaseLine


± 0.5% of V at V > Vn

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

Operate time for synchronism check function 160 ms typically -

Operate time for energizing function 80 ms typically -


70 ABB

Logic

Table 62. Tripping logic SMPPTRC (94)


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 63. 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 to Integer 4 4 8 - -

Boolean 16 to integerwith Logic Node

4 4 8 - -

Integer to Boolean 16 4 4 8 - -

Integer to Boolean 16with Logic Node

4 4 8 - -


ABB 71

Monitoring

Table 64. Measurements CVMMXN


Frequency (0.95-1.05) × fn ± 2.0 mHz

Voltage (0.1-1.5) ×Vn ± 0.5% of Vn at V£Vn

± 0.5% of V at V > Vn

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

Active power, P 0.1 x Vn< V < 1.5 x Vn

0.2 x In < I < 4.0 x In± 1.0% of Sn at S ≤ Sn

± 1.0% of S at S > Sn

Conditions:0.8 x Vn < V < 1.2 Vn

0.2 x In < I < 1.2 In

Reactive power, Q 0.1 x Vn< V < 1.5 x Vn

0.2 x In < I < 4.0 x In

Apparent power, S 0.1 x Vn < V < 1.5 x Vn

0.2 x In< I < 4.0 x In

Power factor, cos (φ) 0.1 x Vn < V < 1.5 x Vn

0.2 x In< I < 4.0 x In± 0.02

Table 65. Phase current measurement CMMXU


Current (0.1-4.0) × In ± 0.2% of In at I ≤ 0.5 × In± 0.2% of I at I > 0.5 × In

Phase angle (0.1–4.0) x In ± 0.5° at 0.2 × In < I < 0.5 × In± 0.2° at 0.5 × In ≤ I < 4.0 × In

Table 66. Phase-phase voltage measurement VMMXU


Voltage (10 to 300) V ± 0.3% of V at V ≤ 50 V± 0.2% of V at V > 50 V

Phase angle (10 to 300) V ± 0.3° at V ≤ 50 V± 0.2° at V > 50 V

Table 67. Phase-neutral voltage measurement VNMMXU


Voltage (10 to 300) V ± 0.3% of V at V ≤ 50 V± 0.2% of V at V > 50 V



72 ABB

Table 68. Current sequence component measurement CMSQI


Current positive sequence, I1Three phase settings

(0.1–4.0) × In ± 0.2% of In at I ≤ 0.5 × In± 0.2% of I at I > 0.5 × In

Current zero sequence, 3I0Three phase settings


Current negative sequence, I2Three phase settings


Phase angle (0.1–4.0) × In ± 0.5° at 0.2 × In < I < 0.5 × In± 0.2° at 0.5 × In ≤ I < 4.0 × In

Table 69. Voltage sequence measurement VMSQI


Voltage positive sequence, U1 (10 to 300) V ± 0.3% of V at V ≤ 50 V± 0.2% of V at V > 50 V

Voltage zero sequence, 3U0 (10 to 300) V ± 0.3% of V at V ≤ 50 V± 0.2% of V at V > 50 V

Voltage negative sequence, U2 (10 to 300) V ± 0.3% of V at V ≤ 50 V± 0.2% of V at V > 50 V


Table 70. 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 of transducer toinput

(-20.00 to +20.00) mA

Min current of transducer toinput

(-20.00 to +20.00) mA

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

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

Alarm hysteresis for input (0.0-20.0) mA

Table 71. Event counter CNTGGIO


Counter value 0-100000 -

Max. count up speed 10 pulses/s (50% duty cycle) -


ABB 73

Table 72. 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 95

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

-

Maximum number of binary inputs 96 -

Maximum number of phasors in the Trip Value recorder per recording 30 -

Maximum number of indications in a disturbance report 96 -

Maximum number of events in the Event recording per recording 150 -

Maximum number of events in the Sequence of events 1000, first in - first out -

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

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

-

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

-

Recording bandwidth (5-300) Hz -

Table 73. Event list

Function Value

Buffer capacity Maximum number of events in the list 1000

Resolution 1 ms

Accuracy Depending on time synchronizing

Table 74. Indications

Function Value

Buffer capacity Maximum number of indications presented for single disturbance 96

Maximum number of recorded disturbances 100

Table 75. 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 on timesynchronizing


74 ABB

Table 76. Trip value recorder

Function Value

Buffer capacity

Maximum number of analog inputs 30


Table 77. 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 and maximum numberof channels, typical value)

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


ABB 75

Metering

Table 78. Pulse counter PCGGIO

Function Setting range Accuracy

Input frequency See Binary Input Module (BIM) -

Cycle time for report of countervalue

(1–3600) s -

Table 79. Energy metering ETPMMTR


Energy metering kWh Export/Import, kvarh Export/Import

Input from MMXU. No extra error at steady load


76 ABB


Table 80. IEC 61850-8-1 communication protocol

Function Value

Protocol IEC 61850-8-1

Communication speed for the IEDs 100BASE-FX

Protocol IEC 608–5–103

Communication speed for the IEDs 9600 or 19200 Bd

Protocol DNP3.0

Communication speed for the IEDs 300–19200 Bd

Protocol TCP/IP, Ethernet

Communication speed for the IEDs 100 Mbit/s

Table 81. LON communication protocol

Function Value

Protocol LON

Communication speed 1.25 Mbit/s

Table 82. SPA communication protocol

Function Value

Protocol SPA

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

Slave number 1 to 899

Table 83. IEC60870-5-103 communication protocol

Function Value


Communication speed 9600, 19200 Bd

Table 84. SLM – LON port

Quantity Range or value

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

Fiber, optical budget Glass fiber: 11 dB (3000 ft typically *)Plastic fiber: 7 dB (35 ft 10 m typically *)

Fiber diameter Glass fiber: 62.5/125 mmPlastic fiber: 1 mm

*) depending on optical budget calculation


ABB 77

Table 85. SLM – SPA/IEC 60870-5-103/DNP3 port


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

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

diameter Glass fiber: 62.5/125 mmPlastic fiber: 1 mm

*) depending on optical budget calculation

Table 86. Galvanic RS485 communication module


Communication speed 2400–19200 bauds

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

Table 87. IEC 62439-3 Edition 1 and Edition 2 parallel redundancy protocol

Function Value


Communication speed 100 Base-FX


78 ABB

Remote communication

Table 88. Line data communication module

Characteristic Range or value

Type of LDCM Short range (SR) Medium range (MR) Long range (LR)

Type of fiber Graded-indexmultimode62.5/125 µm or50/125 µm

Singlemode 9/125 µm Singlemode 9/125 µm

Wave length 850 nm 1310 nm 1550 nm

Optical budgetGraded-index multimode 62.5/125 mm, Graded-index multimode 50/125 mm

13 dB (typicaldistance about 2mile *)9 dB (typicaldistance about 1mile *)

22 dB (typicaldistance 50 mile *)

26 dB (typical distance 68 mile *)

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 / 64 kbit/s 2 Mb/s / 64 kbit/s 2 Mb/s / 64 kbit/s

Clock source Internal or derivedfrom receivedsignal

Internal or derivedfrom received signal

Internal or derived from receivedsignal

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


ABB 79

HardwareIED

Table 89. 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 90. Water and dust protection level according to IEC 60529

Front IP40 (IP54 with sealing strip)

Sides, top and bottom IP20

Rear side IP20 with screw compression typeIP10 with ring lug terminals

Table 91. Weight

Case size Weight

6U, 1/2 x 19” £ 22 lb

6U, 3/4 x 19” £ 33 lb

6U, 1/1 x 19” £ 40 lb

Connection system

Table 92. CT and VT circuit connectors

Connector type Rated voltage and current Maximum conductor area

Screw compression type 250 V AC, 20 A 4 mm2 (AWG12)2 x 2.5 mm2 (2 x AWG14)

Terminal blocks suitable for ring lug terminals 250 V AC, 20 A 4 mm2 (AWG12)

Table 93. Binary I/O connection system

Connector type Rated voltage Maximum conductor area

Screw compression type 250 V AC 2.5 mm2 (AWG14)2 × 1 mm2 (2 x AWG18)

Terminal blocks suitable for ring lug terminals 300 V AC 3 mm2 (AWG14)


80 ABB

Basic IED functions

Table 94. Self supervision with internal event list

Data Value

Recording manner Continuous, event controlled

List size 40 events, first in-first out

Table 95. Time synchronization, time tagging

Function Value

Time tagging resolution, events and sampled measurement values 1 ms

Time tagging error with synchronization once/min (minute pulse synchronization), events and sampled measurementvalues

± 1.0 ms typically

Time tagging error with SNTP synchronization, sampled measurement values ± 1.0 ms typically

Table 96. GPS time synchronization module (GTM)


Receiver – ±1µs relative UTC

Time to reliable time reference with antenna in newposition or after power loss longer than 1 month

<30 minutes –

Time to reliable time reference after a power losslonger than 48 hours

<15 minutes –

Time to reliable time reference after a power lossshorter than 48 hours

<5 minutes –

Table 97. 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

Accuracy +/-2μs


ABB 81

Table 98. IRIG-B

Quantity Rated value

Number of channels IRIG-B 1

Number of channels PPS 1

Electrical connector:

Electrical connector IRIG-B BNC

Pulse-width modulated 5 Vpp

Amplitude modulated– low level– high level

1-3 Vpp3 x low level, max 9 Vpp

Supported formats IRIG-B 00x, IRIG-B 12x

Accuracy +/-10μs for IRIG-B 00x and +/-100μs for IRIG-B 12x

Input impedance 100 k ohm

Optical connector:

Optical connector PPS and IRIG-B Type ST

Type of fibre 62.5/125 μm multimode fibre

Supported formats IRIG-B 00x, PPS

Accuracy +/- 2μs


82 ABB

Inverse characteristic

Table 99. ANSI Inverse time characteristics


Operating characteristic:

( )= + ×

-

æ öç ÷ç ÷è ø1P

At B td

I

EQUATION1651 V1 EN

Reset characteristic:

( )= ×

-2 1

trt tdI

EQUATION1652 V1 EN

I = Imeasured/Iset

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

ANSI Extremely Inverse A=28.2, B=0.1217, P=2.0 , tr=29.1 ANSI/IEEE C37.112, 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 Extremely Inverse 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 A=0.086, B=0.185, P=0.02, tr=4.6


ABB 83

Table 100. IEC Inverse time characteristics


Operating characteristic:

( )= ×

-

æ öç ÷ç ÷è ø1P

At td

I

EQUATION1653 V1 EN

I = Imeasured/Iset

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

Time delay to reset, IEC inverse time (0.000-60.000) s ± 0.5% of set time ± 10 ms

IEC Normal Inverse A=0.14, P=0.02 IEC 60255-151, 5% + 40ms

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:

( )= + ×

-

æ öç ÷ç ÷è ø

P

At B td

I C

EQUATION1654 V1 EN

Reset characteristic:

( )= ×

-PR

TRt td

I CR

EQUATION1655 V1 EN

I = Imeasured/Iset

td = (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


84 ABB

Table 101. RI and RD type inverse time characteristics


RI type inverse characteristic

= ×

-

1

0.2360.339

t td

IEQUATION1656 V1 EN

I = Imeasured/Iset

td = (0.05-999) in steps of 0.01 IEC 60255-151, 5% + 40ms

RD type logarithmic inverse characteristic

= - ×æ öç ÷è ø

5.8 1.35tI

Intd

EQUATION1657 V1 EN

I = Imeasured/Iset

td = (0.05-999) in steps of 0.01

Table 102. Inverse time characteristics for overvoltage protection


Type A curve:

=-æ ö

ç ÷è ø

ttd

V VPickup

VPickup

EQUATION1661 V1 EN

V = Vmeasured

td = (0.05-1.10) in steps of 0.01 5% +40 ms

Type B curve:

=×

-× - -

æ öç ÷è ø

2.0

480

32 0.5 0.035

ttd

V VPickup

VPickup

EQUATION1662 V1 EN

td = (0.05-1.10) in steps of 0.01

Type C curve:

=×

-× - -

æ öç ÷è ø

3.0

480

32 0.5 0.035

ttd

V VPickup

VPickup

EQUATION1663 V1 EN

td = (0.05-1.10) in steps of 0.01

Programmable curve:

×= +

-× -

æ öç ÷è ø

P

td At D

V VPickupB C

VPickup

EQUATION1664 V1 EN

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


ABB 85

Table 103. Inverse time characteristics for undervoltage protection


Type A curve:

=-æ ö

ç ÷è ø

tdt

VPickup V

VPickup

EQUATION1658 V1 EN

V = Vmeasured

td = (0.05-1.10) in steps of 0.01 5% +40 ms

Type B curve:

×= +

-× -

æ öç ÷è ø

2.0

4800.055

32 0.5

tdt

VPickup V

VPickup

EQUATION1659 V1 EN

V = Vmeasured

td = (0.05-1.10) in steps of 0.01

Programmable curve:

×= +

-× -

é ùê úê úê úæ öê úç ÷ëè ø û

P

td At D

VPickup VB C

VPickup

EQUATION1660 V1 EN

V = Vmeasured

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


86 ABB

Table 104. Inverse time characteristics for residual overvoltage protection


Type A curve:

=-æ ö

ç ÷è ø

ttd

V VPickup

VPickup

EQUATION1661 V1 EN

V = Vmeasured

td = (0.05-1.10) in stepsof 0.01

5% +40 ms

Type B curve:

=×

-× - -

æ öç ÷è ø

2.0

480

32 0.5 0.035

ttd

V VPickup

VPickup

EQUATION1662 V1 EN

td = (0.05-1.10) in stepsof 0.01

Type C curve:

=×

-× - -

æ öç ÷è ø

3.0

480

32 0.5 0.035

ttd

V VPickup

VPickup

EQUATION1663 V1 EN

td = (0.05-1.10) in stepsof 0.01

Programmable curve:

×= +

-× -

æ öç ÷è ø

P

td At D

V VPickupB C

VPickup

EQUATION1664 V1 EN

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


ABB 87

21. Ordering

Guidelines

Carefully read and follow the set of rules to ensure problem-free order management. Be aware that certain functions can only be ordered incombination with other functions and that some functions require specific hardware 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. The PCM600 can also be used foradaptation 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, 94) Qty: 1 2 3 4 5 6 1MRK 002 917-AC

Optional functions


88 ABB


Transformer differential protection, two winding (T2WPDIF, 87T)

Qty:

1 2 1MRK 002 901-AC

Transformer differential protection, three winding (T3WPDIF, 87T)

Qty:

1 2 1MRK 002 901-CC

1Ph High impedance differential protection (HZPDIF, 87)

Qty:

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

Generator differential protection (GENPDIF, 87G)

Qty:

1 2 1MRK 002 901-PB

Restricted earth fault protection, low impedance (REFPDIF, 87N)

Qty:

1 2 3 1MRK 002 901-EB


Rule: If one of ZMHPDIS or ZDMRDIR is ordered, both functions must be orderedFull scheme distance protection, mho characteristic (ZMHPDIS, 21)

Qty:

1 2 3 4

1MRK 002 925-EB

Directional impedance element for mho characteristic (ZDMRDIR, 21D)

Qty:

1 2 1MRK 002 924-PA

Pole slip/out-of-step protection (PSPPPAM, 78) Qty: 1MRK 002 925-LB

Loss of excitation (LEXPDIS, 40)

Qty:

1 2 1MRK 002 925-MB

Note: If ROTIPHIZ or STTIPHIZ is ordered, Injection equipment is also required, see sectionAccessories, "Injection equipment"

Sensitive rotor earth fault protection, injection based (ROTIPHIZ, 64R) Qty: 1MRK 002 908-YA

100% stator earth fault protection, injection based (STTIPHIZ, 64S)

Qty: 1MRK 002 908-ZA


ABB 89

Current protection

Instantaneous phase overcurrent protection (PHPIOC, 50)

Qty:

1 2 3 4 1MRK 002 906-AC

Four step phase overcurrent protection (OC4PTOC, 51/67)

Qty:

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

Instantaneous residual overcurrent protection (EFPIOC, 50N)

Qty:

1 2 1MRK 002 906-CC

Four step residual overcurrent protection (EF4PTOC, 51N/67N)

Qty:

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

Four step directional negative phase sequence overcurrent protection (NS4PTOC, 46I2)

Qty:

1 2 1MRK 002 906-DM

Sensitive directional residual overcurrent and power protection (SDEPSDE, 67N)

Qty:

1 2 1MRK 002 907-DC

Thermal overload protection, two time constants (TRPTTR, 49)

Qty:

1 2 3 1MRK 002 906-NC

Breaker failure protection (CCRBRF, 50BF)

Qty

1 2 3 4 1MRK 002 906-RC

Pole discrepancy protection (CCRPLD, 52PD)

Qty:

1 2 3 4 1MRK 002 907-AC

Directional underpower protection (GUPPDUP, 37)

Qty:

1 2 3 4 1MRK 002 902-FB

Directional overpower protection (GOPPDUP, 32)

Qty:

1 2 3 4 1MRK 002 902-GB

Negative sequence time overcurrent protection for machines (NS2PTOC, 46I2)

Qty:

1 2 1MRK 002 902-LA

Accidental energizing protection for synchronous generator (AEGGAPC, 50AE)

Qty:

1 2 1MRK 002 902-NA


90 ABB

Voltage protection

Two step undervoltage protection (UV2PTUV, 27)

Qty:

1 2 1MRK 002 908-AC

Two step overvoltage protection (OV2PTOV, 59)

Qty:

1 2 1MRK 002 908-DC

Two step residual overvoltage protection (ROV2PTOV, 59N)

Qty:

1 2 3 1MRK 002 908-GC

Overexcitation protection (OEXPVPH, 24)

Qty:

1 2 1MRK 002 908-MC

Voltage differential protection (VDCPTOV, 60)

Qty:

1 2 1MRK 002 924-TB

100% Stator E/F 3rd harmonic (STEFPHIZ, 59THD) Qty: 1MRK 002 908-TB


Underfrequency protection (SAPTUF, 81)

Qty:

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

Overfrequency protection (SAPTOF, 81)

Qty:

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

Rate-of-change frequency protection (SAPFRC, 81)

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, 87)

Qty:

1 2 3 4 5 1MRK 002 914-AB

Fuse failure supervision (SDDRFUF)

Qty:

1 2 3 1MRK 002 914-GC


ABB 91

Control

Synchrocheck, energizing check and synchronizing (SESRSYN, 25)

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, 84)

Qty:

1 2 3 4 1MRK 002 925-PC

Tap changer control and supervision, 32 binary inputs, one per position (TCLYLTC, 84)

Qty:

1 2 3 4 1MRK 002 924-UB


Note: Require 2-channel OEM

IEC 62439-3 Edition 1 parallel redundancy protocol 1MRK 002 924-YR

IEC 62439-3 Edition 2 parallel redundancy protocol 1MRK 002 924-YS

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

Additional local HMI user dialogue language

Rule: Maximum one alternative

HMI language, German 1MRK 002 920-AB

HMI language, Russian 1MRK 002 920-BB

HMI language, French 1MRK 002 920-DB

HMI language, Spanish 1MRK 002 920-DB

HMI language, Polish 1MRK 002 920-GB

HMI language, Hungarian 1MRK 002 920-FB

HMI language, Czech 1MRK 002 920-HB

HMI language, Swedish 1MRK 002 920-KB

Optional hardwareHuman machine hardware interface

Rule: One must be ordered.


92 ABB

Display type Keypad symbol Case size

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 93

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+3V, 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+3V,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


94 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+3V, 1A, 50/60 Hz

Qty:

1 2 1MRK 002 247-BC

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

1 2 1MRK 002 247-BD

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

Qty:

1 2 1MRK 002 247-BF


Qty: 1 2 1MRK 002 247-AS

Transformer input module, ring lug terminals 7I+5V, 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 95


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 Transformer input 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 the rear side of the IED, but can also befreely 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


96 ABB

Binary input/output modules

Make BIM with 50 mA inrush current the primary choice. BIM with 50 mA inrush current fulfill additional standards. As a consequence the EMCwithstand capability is further increased.For pulse counting, for example kWh metering, the BIM with enhanced pulse counting capabilities 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

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


ABB 97

Binary input module (BIM) with enhanced pulse counting 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 5 6

8 9 10 11 12 13

7

14

1MRK 000 614-AB

Static binary output module (SOM)

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

8 9 10 11 12 13

7

14

1MRK 002 614-BA

RL 110-250 VDC Qty: 1 2 3 4 5 6

8 9 10 11 12 13

7

14

1MRK 002 614-CA


98 ABB

Make IOM with 50 mA inrush current the primary choice. IOM with 50 mA inrush current fulfill additional standards. As aconsequence the EMC withstand capability is further increased.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 99

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 DNP 3.0

Serial/LON plastic interface 1MRK 001 608-AB

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

Serial/LON glass interface 1MRK 001 608-CB

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

Note: Wall mounting not recommended with communication modules with 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 be ordered separately thus must bespecified when ordering a terminal.

Quantity: 1MRK 002 420-EA


100 ABB

AccessoriesGPS antenna and mounting details

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

Cable for antenna, (Appx. 65 ft) Quantity: 1MRK 001 665-AA

Cable for antenna, (Appx. 131 ft) 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 switchThe test system COMBITEST intended for use with the IED 670products is described in 1MRK 512 001-BEN and 1MRK001024-CA. Please refer to the website:www.abb.com/substationautomation for detailed information.

Due to the high flexibility of our product and the wide variety ofapplications possible the test switches needs to be selected foreach specific application.

Select your suitable test switch based on the available contactsarrangements shown in the reference documentation.

However our proposals for suitable variants are:

Two winding transformer with internal neutral on currentcircuits. Two pcs can be used in applications for three windingtransformers in single or multi-breaker arrangement (orderingnumber RK926 315-BD)

Two winding transformer with external neutral on currentcircuits. Two pcs can be used in applications for three winding

transformers in single or multi-breaker arrangement (orderingnumber RK926 315-BH).

Three winding transformer with internal neutral on currentcircuits (ordering number RK926 315-BX).

The normally open "In test mode" contact 29-30 on the RTXPtest switches should be connected to the input of the testfunction block to allow activation of functions individually duringtesting.

Test switches type RTXP 24 is ordered separately. Please referto Section "Related documents" for reference to correspondingdocuments.

RHGS 6 Case or RHGS 12 Case with mounted RTXP 24 andthe on/off switch for dc-supply are ordered separately. Pleaserefer to Section "Related documents" for reference tocorresponding documents.


ABB 101

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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 voltage dependent resistor for 20-100Voperating voltage

Quantity:

1 2 3 RK795101-MA


Quantity: RK795101-MB


Quantity:

1 2 3 RK795101-CB


Quantity: RK795101-DC


102 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% stator earth fault protection, injectionbased (STTIPHIZ) is selected/active in REG670

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

Rule: Rotor injection module (RIM) is required if Sensitive rotor earth fault protection, injectionbased (ROTIPHIZ) is selected/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 andthat Sensitive rotor earth fault protection, injection based (ROTIPHIZ) is selected/active in REG670.

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

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

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

Combiflex


ABB 103

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


104 ABB

Rule: Specify the number of printed manuals requested

Operator’s manual 1MRK502

028-UEN

ANSI Quantity: 1MRK 502 028-UUS

Technical reference manual 1MRK502

027-UEN


Installation and commissioning manual 1MRK502

029-UEN


Application manual 1MRK502

030-UEN


Engineering manual, 670 series Quantity: 1MRK 511 240-UUS

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 105

Related documents

Documents related to REG670 Identity number

Operator’s manual 1MRK 502 028-UUS

Installation and commissioning manual 1MRK 502 029-UUS

Technical reference manual 1MRK 502 027-UUS

Application manual 1MRK 502 030-UUS

Product guide customized 1MRK 502 031-BUS

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-WUS

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

Engineering manual 670 series 1MRK 511 240-UUS

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.


106 ABB

HTTP://WWW.ABB.COM/SUBSTATIONAUTOMATION

Contact us

ABB Inc.1021 Main Campus DriveRaleigh, NC 27606, USAPhone Toll Free: 1-800-HELP-365,menu option #8

ABB Inc.3450 Harvester RoadBurlington, ON L7N 3W5, CanadaPhone Toll Free: 1-800-HELP-365,menu option #8

ABB Mexico S.A. de C.V.Paseo de las Americas No. 31 LomasVerdes 3a secc.53125, Naucalpan, Estado De Mexico,MEXICOPhone (+1) 440-585-7804, menuoption #8

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