generator protection reg670 pre-configured product guide · pdf file1. application the reg670...

Relion® 670 series

Generator protection REG670Pre-configuredProduct Guide

Contents

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

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

3. Differential protection....................................................13

4. Impedance protection..................................................15

5. Current protection........................................................16

6. Voltage protection........................................................18

7. Frequency protection....................................................20

8. Multipurpose protection................................................21

9. Secondary system supervision.....................................21

10. Control........................................................................22

11. Logic...........................................................................23

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

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

14. Basic IED functions.....................................................25

15. Human machine interface............................................25

16. Station communication ...............................................25

17. Remote communication..............................................26

18. Hardware description..................................................26

19. Connection diagrams..................................................30

20. Technical data.............................................................39

21. Ordering......................................................................89

Disclaimer

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

errors that may appear in this document.

© Copyright 2012 ABB.

All rights reserved.

Trademarks

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

trademarks of their respective holders.

Generator protection REG670 1MRK502032-BEN DPre-configured 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 analoginputs available enables, together with the large functionallibrary, integration of many functions in one IED. In typicalapplications two units can provide total functionality, alsoproviding a high degree of redundancy. REG670 can as wellbe used for protection and control of shunt reactors.

Stator earth fault protection, both traditional 95% as well as100% injection and 3rd harmonic based are included. Whenthe injection based protection is used, 100% of the machinestator winding, including the star point, is protected under alloperating modes. The 3rd harmonic based 100% stator earthfault protection uses 3rd harmonic differential voltageprinciple. Injection based 100% stator earth fault protectioncan operate even when machine is at standstill. Well provenalgorithms for pole slip, underexcitation, rotor earth fault,negative sequence current protections, and so on, areincluded in the IED.

The generator differential protection in the REG670 adaptedto operate correctly for generator applications where factorsas long DC time constants and requirement on short trip timehave been 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 anauxiliary power transformer integrated in the same IED havingmain protections for the generator. The concept thus enablesvery cost 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 anexcellent choice for both new installations and forrefurbishment in existing power plants.

Serial data communication is via optical connections toensure immunity against disturbances.

The wide application flexibility makes this product anexcellent choice for both new installations and therefurbishment of existing installations.

By using patented algorithm REG670 (or any other productfrom 670 series) can track the power system frequency inquite wide range from 9Hz to 95Hz. In order to do thatpreferably the three-phase voltage signal from the generatorterminals shall be connected to the IED. Then IED can adoptits filtering algorithm in order to properly measure phasors ofall current and voltage signals connected to the IED. Thisfeature is essential for proper operation of the protectionduring generator start-up and shut-down procedure.

Generator protection REG670 1MRK502032-BEN DPre-configured Product version: 1.2 Issued: February 2015

Revision: D

ABB 3

IEC11000068-1-en.vsd

GI

U

CCS RDIF

87CT I2d/I

CV GAPC

64R Re<

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>

Option

SDE PSDE

32N P0->

REG 670*1.2 – A20

Gen Diff + Back-up 12AI

ZMH PDIS

21 Z<

LEX PDIS

40 <

GUP PDUP

37 P<

GOP PDOP

32 P

CV GAPC

51/27 U

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

SES RSYN

25

CV GAPC

51V I>/U

PH PIOC

50 3I>>

CC RPLD

52PD PD

OC4 PTOC

51/67 3I>

Other functions available from the function library

+ RXTTE4

T2W PDIF

87T 3Id/I

HZ PDIF

87 IdN

Function alternatives for 87G/GEN PDIF

STTI PHIZ

64S RSE<

ROTI PHIZ

64R RRE<

AEG GAPC

50AE U/I>

CV MMXN

Meter.

ROV2 PTOV

59N UN>

YY

D

IEC11000068 V1 EN

Figure 1. Typical generator protection application with generator differential and back-up protection, including 12 analog inputstransformers in half 19" case size.


4 ABB

GI

U

CV GAPC

64R Re<

ROV2 PTOV

59N UN>

STEF PHIZ

59THD U3d/N

SA PTUF

81 f<

SA PTOF

81 f>

SDD RFUF

60FL

OEX PVPH

24 U/f>

UV2 PTUV

27 3U<

OV2 PTOV

59 3U>

CV MMXN

Meter.

Option

Gen HiZ Diff + Back- up 12AI

ZMH PDIS

21 Z<

LEX PDIS

40 <

GUP PDUP

37 P<

GOP PDOP

32 P

ROV2 PTOV

59N

OC4 PTOC

50/51 3I>

CC RBRF

50BF 3 I> BF

NS2 PTOC

46 I2>

TR PTTR

49 Ith

PSP PPAM

78 Ucos

+ RXTTE4

HZ PDIF

87 IdN

AEG GAPC

50AE U/I>

CCS RDIF

87CT I2d/I

SDE PSDE

32N P0->

CV GAPC

51/27 U

SES RSYN

25

CV GAPC

51V I>/U

PH PIOC

50 3I>>

CC RPLD

52PD PD

OC4 PTOC

51/67 3I>



STTI PHIZ

64S RSE<

ROTI PHIZ

64R RRE<

T2W PDIF

87T 3Id/I

REG 670*1.2 – A20

3Uo>

YY

GroundingTransformer

D

IEC11000070 V1 EN

Figure 2. A20 application with high-impedance generator differential and back-up protection, including 12 analog inputs transformers in half19" case size.


ABB 5

CCS RDIF

87CT I2d/I

SDE PSDE

32N P0->

CV GAPC

51/27 U

SES RSYN

25

CV GAPC

51V I>/U

PH PIOC

50 3I>>

CC RPLD

52PD PD

OC4 PTOC

51/67 3I>


HZ PDIF

87 IdN


GI

U

CV GAPC

64R Re<

ROV2 PTOV

59N UN>

STEF PHIZ

59THD U3d/N

SA PTUF

81 f<

SA PTOF

81 f>

SDD RFUF

60FL

OEX PVPH

24 U/f>

UV2 PTUV

27 3U<

OV2 PTOV

59 3U>

CV MMXN

Meter.

Option

REG 670*1.2 – A20

Overall Diff + Back-up 12AI

ZMH PDIS

21 Z<

LEX PDIS

40 <

GUP PDUP

37 P<

GOP PDOP

32 P

ROV2 PTOV

59N 3Uo>

OC4 PTOC

50/51 3I>

CC RBRF

50BF 3I> BF

NS2 PTOC

46 I2>

TR PTTR

49 Ith

PSP PPAM

78 Ucos

AEG GAPC

50AE U/I>

+ RXTTE4

T2W PDIF

87O 3Id/I

STTI PHIZ

64S RSE<

ROTI PHIZ

64R RRE<

YY

Y

Uni

t Tra

fo

D

D

IEC11000069 V1 EN

Figure 3. A20 application with overall differential and back-up protection, including 12 analog inputs transformers in half 19" case size.


6 ABB

GI

U

CV GAPC

64R Re<

ROV2 PTOV

59N UN>

GEN PDIF

87G 3Id/I

SA PTUF

81 f<

SA PTOF

81 f>

SDD RFUF

60FL

Option

SDE PSDE

32N P0->

REG 670*1.2 – B30

Gen Diff + Back-up 24AI

ZMH PDIS

21 Z<

LEX PDIS

40 <

GUP PDUP

37 P<

GOP PDOP

32 P

CCS RDIF

87CT I2d/I

CV GAPC

51/27 U

OC4 PTOC

51/67 3I->

CC RBRF

50BF 3I> BF

NS2 PTOC

46 I2>

TR PTTR

49 Ith

PSP PPAM

78 Ucos

SES RSYN

25

CV GAPC

51V I>/U

PH PIOC

50 3I>>

AEG GAPC

50AE U/I>

CC RPLD

52PD PD


+ RXTTE4

STEF PHIZ

59THD U3d/N

T2W PDIF

87T 3Id/I

REF PDIF

87N IdN/I

Auxiliary Bus

OC4 PTOC

50/51 3I>

OC4 PTOC

50/51 3I>

CC RBRF

50BF 3I> BF

EF4 PTOC

51N IN>

OC4 PTOC

50/51 3I>

Main Protection

Back-up Protection

ROV2 PTOV

59N 3Uo>

T3W PDIF

87T 3Id/I

STTI PHIZ

64S RSE<

ROTI PHIZ

64R RRE<

CV MMXN

Meter.

OEX PVPH

24 U/f>

UV2 PTUV

27 3U<

OV2 PTOV

59 3U>

ROV2 PTOV

59N 3Uo>

YY

YY

YUnit Trafo

Aux

iliar

y Tr

afo

Exci

tatio

n Tr

afo

D

D

D

IEC11000071 V1 EN

Figure 4. Enhanced generator protection application with generator differential and back-up protection, including 24 analog inputs in full19" case size. Optional pole slip protection, 100% stator earth fault protection and overall differential protection can be added.


ABB 7

GI

U

CV GAPC

64R Re<

STEF PHIZ

59THD U3d/N

TR PTTR

49 Ith

SA PTUF

81 f<

CV MMXN

Meter.

EF4 PTOC

50N/51N IN>

REF PDIF

87N IdN/I

OV2 PTOV

59 3U>

T3W PDIF

87O 3Id/I

REG 670*1.2 – C30

T2W PDIF

87T 3Id/I

ROV2 PTOV

59N 3Uo>

Generator and block transformer protection 24AI

NS2 PTOC

46 I2>

TR PTTR

49 Ith

SDD RFUF

60FL

SDD RFUF

60FL

ZMH PDIS

21 Z<

LEX PDIS

40 <

GUP PDUP

37 P<

GOP PDOP

32 P

PSP PPAM

78 Ucos

Option

SA PTOF

81 f>

OEX PVPH

24 U/f>

UV2 PTUV

27 3U<

OV2 PTOV

59 3U>

SDE PSDE

32N P0->

CV GAPC

51/27 U

SES RSYN

25

CV GAPC

51V I>/U

PH PIOC

50 3I>>

CC RPLD

52PD PD

OC4 PTOC

51/67 3I>


CCS RDIF

87CT I2d/I

OC4 PTOC

50/51 3I>

OC4 PTOC

50/51 3I>

CC RBRF

50BF 3I> BF

GEN PDIF

87G 3Id/I+ RXTTE4

STTI PHIZ

64S RSE<

ROTI PHIZ

64R RRE<

ROV2 PTOV

59N UN>

CC RBRF

50BF 3I> BF

OC4 PTOC

51/67 3I->

AEG GAPC

50AE U/I>

CV MMXN

Meter.

YY

ROV2 PTOV

59N 3Uo>

YY

YY

Y

Uni

t Tra

fo

GroundingTransformer

D

D

D

D

IEC11000072 V1 EN

Figure 5. Unit protection including generator and generator transformer protection with 24 analog inputs in full 19" case size. Optional poleslip protection and 100% stator earthfault protection can be added.


8 ABB

2. Available functions

Main protection functions

2 = number of basic instances3-A03 = optional function included in packages A03 (refer to ordering details)

IEC 61850 ANSI Function description Generator

RE

G67

0 (A

20)

RE

G67

0 (B

30)

RE

G67

0 (C

30)

Differential protection

T2WPDIF 87T Transformer differential protection, two winding 1-A31 1-A33 1

T3WPDIF 87T Transformer differential protection, three winding 1-A33 1

HZPDIF 87 1Ph high impedance differential protection 3-A02 2 6

GENDIF 87G Generator differential protection 1 2 2

REFPDIF 87N Restricted earth fault protection, low impedance 1-A01 1

Impedance protection

ZMHPDIS 21 Full-scheme distance protection, mho characteristic 3 3 3

ZDMRDIR 21D Directional impedance element for mho characteristic 1 1 1

PSPPPAM 78 Pole slip/out-of-step protection 1-B21 1-B21 1-B21

LEXPDIS 40 Loss of excitation 1 2 2

ROTIPHIZ 64R Sensitive rotor earth fault protection, injection based 1-B31 1-B31 1-B31

STTIPHIZ 64S 100% stator earth fault protection, injection based 1-B32 1-B32 1-B32


ABB 9

Back-up protection functions


RE

G67

0 (A

20)

RE

G67

0 (B

30)

RE

G67

0 (C

30)

Current protection

PHPIOC 50 Instantaneous phase overcurrent protection 1 2 2

OC4PTOC 51_67 Four step phase overcurrent protection 4 4 4

EFPIOC 50N Instantaneous residual overcurrent protection 1 2 2

EF4PTOC 51N_67N

Four step residual overcurrent protection 1 5 5

NS4PTOC 46I2 Four step directional negative phase sequence overcurrent protection 1-C41 2-C42 2-C42

SDEPSDE 67N Sensitive directional residual overcurrent and power protection 1-C16 1-C16 1-C16

TRPTTR 49 Thermal overload protection, two time constant 1 2 3

CCRBRF 50BF Breaker failure protection 2 4 4

CCRPLD 52PD Pole discordance protection 2 2 2

GUPPDUP 37 Directional underpower protection 2 4 4

GOPPDOP 32 Directional overpower protection 2 4 4

NS2PTOC 46I2 Negative sequence time overcurrent protection for machines 1 1 1

AEGGAPC 50AE Accidental energizing protection for synchronous generator 1 1 1

Voltage protection

UV2PTUV 27 Two step undervoltage protection 2 2 2

OV2PTOV 59 Two step overvoltage protection 2 2 2

ROV2PTOV 59N Two step residual overvoltage protection 3 3 3

OEXPVPH 24 Overexcitation protection 1 1 2

VDCPTOV 60 Voltage differential protection 2 2 2

STEFPHIZ 59THD 100% stator earth fault protection, 3rd harmonic based 1-D21 1 1

Frequency protection

SAPTUF 81 Underfrequency protection 3 6 6

SAPTOF 81 Overfrequency protection 3 6 6

SAPFRC 81 Rate-of-change frequency protection 1 3 3

Multipurpose protection

CVGAPC General current and voltage protection 6 6 6

64R Rotor earth fault 1 1 1


10 ABB

Control and monitoring functions


RE

G67

0 (A

20)

RE

G67

0 (B

30)

RE

G67

0 (C

30)

Control

SESRSYN 25 Synchrocheck, energizing check and synchronizing 1 2 2

APC30 3 Apparatus control for up to 6 bays, max 30 apparatuses (6CBs) incl. interlocking 1-H09 1-H09 1-H09

QCBAY Apparatus control 1+5/APC30

1+5/APC30

1+5/APC30

LOCREM Handling of LRswitch positions 1+5/APC30

1+5/APC30

1+5/APC30

LOCREMCTRL

LHMI control of PSTO 1+5/APC30

1+5/APC30

1+5/APC30

TCMYLTC 84 Tap changer control and supervision, 6 binary inputs 1-A31 2-A33 2

SLGGIO Logic rotating switch for function selection and LHMI presentation 15 15 15

VSGGIO Selector mini switch 20 20 20

DPGGIO IEC61850 generic communication I/O functions 16 16 16

SPC8GGIO Single pole generic control 8 signals 5 5 5

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

SingleCommand16Signals

Single command, 16 signals 4 4 4

Secondary system supervision

CCSRDIF 87 Current circuit supervision 4 5 5

SDDRFUF Fuse failure supervision 2 3 3

Logic

SMPPTRC 94 Tripping logic 2 4 4

TMAGGIO Trip matrix logic 12 12 12

Configuration logic blocks 40-280 40-280 40-280

FixedSignals Fixed signal function block 1 1 1

B16I Boolean 16 to Integer conversion 16 16 16

B16IFCVI Boolean 16 to Integer conversion with Logic Node representation 16 16 16

IB16 Integer to Boolean 16 conversion 16 16 16

IB16FCVB Integer to Boolean 16 conversion with Logic Node representation 16 16 16

Monitoring

CVMMXN Measurements 6 6 6

EVENT Event function 20 20 20

DRPRDRE Disturbance report 1 1 1


ABB 11


RE

G67

0 (A

20)

RE

G67

0 (B

30)

RE

G67

0 (C

30)

SPGGIO IEC61850 generic communication I/O functions 64 64 64

SP16GGIO IEC61850 generic communication I/O functions 16 inputs 16 16 16

MVGGIO IEC61850 generic communication I/O functions 24 24 24

BSStatReport Logical signal status report 3 3 3

RANGE_XP Measured value expander block 66 66 66

Metering

PCGGIO Pulse-counter logic 16 16 16

ETPMMTR Function for energy calculation and demand handling 6 6 6

Designed to communicate


RE

G67

0 (A

20)

RE

G67

0 (B

30)

RE

G67

0 (C

30)

Station communication

SPA communication protocol 1 1 1

LON communication protocol 1 1 1

IEC60870-5-103 communication protocol 20/1 20/1 20/1

Operation selection between SPA and IEC60870-5-103 for SLM 1 1 1

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

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

Parameter setting function for IEC61850 1 1 1

IntlReceive Horizontal communication via GOOSE for interlocking 59 59 59

Goose binary receive 10 10 10

Multiple command and transmit 60/10 60/10 60/10

Ethernet configuration of links 1 1 1

IEC 62439-3 Edition 1 parallel redundancy protocol 1-P01 1-P01 1-P01

IEC 62439-3 Edition 2 parallel redundancy protocol 1-P02 1-P02 1-P02


12 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 GENPDIFShort circuit between the phases of the stator windingscauses normally very large fault currents. The short circuitgives risk of damages on insulation, windings and stator ironcore. The large short circuit currents cause large forces,which can cause damage even to other components in thepower plant, such as turbine 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

to other generating blocks, the fast fault clearance is essentialto maintain the transient stability of the non-faultedgenerators.

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 tothe neutral point of the generator, thus causing a relativelysmall fault current. The fault current can also be limited due tolow excitation of the generator. Therefore, it is desired thatthe detection of generator phase-to-phase short circuits shallbe relatively sensitive, detecting small fault currents.


ABB 13

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 is also well suitedto generate fast, sensitive and selective fault clearance, ifused to protect shunt reactors or small busduct.

Transformer differential protection T2WPDIF/T3WPDIFThe Transformer differential protection, two-winding(T2WPDIF) and Transformer differential protection, three-winding (T3WPDIF) are provided with internal CT ratiomatching and vector group compensation and settable zerosequence current 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- orthree-winding transformer in multi-breaker stationarrangements.

Two-winding applications

xx05000048.vsd

IEC05000048 V1 EN

two-winding powertransformer

xx05000049.vsd

IEC05000049 V1 EN

two-winding powertransformer withunconnected deltatertiary winding

xx05000050.vsd

IEC05000050 V1 EN

two-winding powertransformer with twocircuit breakers onone side

xx05000051.vsd

IEC05000051 V1 EN

two-winding powertransformer with twocircuit breakers andtwo CT-sets on bothsides

Three-winding applications

xx05000052.vsd

IEC05000052 V1 EN

three-winding powertransformer with allthree windingsconnected

xx05000053.vsd

IEC05000053 V1 EN

three-winding powertransformer with twocircuit breakers andtwo CT-sets on oneside

xx05000057.vsd

IEC05000057 V1 EN

Autotransformer withtwo circuit breakersand two CT-sets ontwo out of three sides

Figure 6. 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


14 ABB

shunt reactors and local feeders within the station. Anadaptive stabilizing feature is included for heavy through-faults.By introducing the load tap changer position, thedifferential protection pick-up can be set to optimumsensitivity thus covering internal faults with low fault level.

Stabilization is included for inrush and overexcitation currentsrespectively. Adaptive stabilization is also included for systemrecovery inrush and CT saturation during external faults. Ahigh set unrestrained differential current protection element isincluded for a very high speed tripping at a high internal faultcurrents.

Included is an innovative sensitive differential protectionelement based on the theory of symmetrical components.This element offers the best possible coverage of powertransformer windings turn to turn faults.

1Ph High impedance differential protection HZPDIFThe 1Ph High impedance differential protection (HZPDIF)function can be used when the involved CT cores have thesame turns ratio and similar magnetizing characteristics. Itutilizes an external CT current summation by wiring, a seriesresistor, and a voltage dependent resistor which are mountedexternally connected to the IED.

HZPDIF 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 zonesbusbar protection.

Restricted earth-fault protection, low impedance REFPDIFRestricted earth-fault protection, low-impedance function(REFPDIF) can be used on all directly or low-impedanceearthed windings. The REFPDIF function provides highsensitivity and high speed tripping as it protects each windingseparately and thus does not need inrush stabilization.

The low-impedance function is a percentage biased functionwith an additional zero sequence current directionalcomparison criterion. This gives excellent sensitivity andstability during through faults.

REFPDIF can also protect autotransformers. In this case, thenegative sequence current directional comparison must beused. The most typical and the most complicatedconfiguration of an autotransformer is shown in figure 7. Fivecurrents are measured in the case illustrated in figure 7.

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 7. Examples of applications of the REFPDIF

4. Impedance protection

Full-scheme distance measuring, Mho characteristicZMHPDISThe numerical mho line distance protection is athree zone fullscheme protection for back-up detection of short circuit andearth faults. The three zones have fully independentmeasuring and settings, which gives high flexibility for alltypes of lines.

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

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

Pole slip protection PSPPPAMThe 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, thegenerator will accelerate so much, that the synchronismcannot be maintained.

Un-damped oscillations occur in the power system, wheregenerator groups at different locations, oscillate against eachother. If the connection between the generators is too weakthe magnitude 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.


ABB 15

• At each pole slip there will be significant torque impacton the 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) function shall detect poleslip conditions and trip the generator as fast as possible if thelocus 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 in zone 2, to preventfurther damages to the generator, shaft and turbine.

Loss of excitation LEXPDISThere 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 likean induction machine. Then, the reactive power consumptionwill increase. Even if the machine does not loose synchronismit may not be acceptable to operate in this state for a longtime. Reduction of excitation increases the generation of heatin the end region of the synchronous machine. The localheating may damage the insulation of the stator winding andthe iron core.

To prevent damages to the generator it should be trippedwhen excitation is lost.

Sensitive rotor earth fault protection, injection basedROTIPHIZThe sensitive rotor earth fault protection (ROTIPHIZ) is usedto detect earth faults in the rotor windings of generators.ROTIPHIZ is applicable for all types of synchronousgenerators.

To implement the above concept, a separate injection box isrequired. The injection box generates a square wave voltagesignal at a certain preset frequency which is fed into the rotorwinding.

The magnitude of the injected voltage signal and the resultinginjected current is measured through a resistive shunt locatedwithin the injection box. These two measured values are fedto the IED. Based on these two measured quantities, theprotection IED determines the rotor winding resistance toground. The resistance value is then compared with thepreset fault resistance alarm and trip levels.

The protection function can detect earth faults in the entirerotor winding and associated connections.

Requires injection unit REX060 and a coupling capacitor unitREX061 for correct operation.

100% stator earth fault protection, injection based STTIPHIZThe 100% stator earth-fault protection STTIPHIZ is used todetect earth faults in the stator windings of generators andmotors. STTIPHIZ is applicable for generators connected tothe power system through a unit transformer in a blockconnection. An independent signal with a certain frequencydifferent from the generator rated frequency is injected intothe stator circuit. The responce of this injected signal is usedto detect stator earth faults.

To implement the above concept, a separate injection box isrequired. The injection box generates a square wave voltagesignal which for example can be fed into the secondarywinding of the generator neutral point voltage transformer orgrounding transformer. This signal propagates through thistransformer into the stator circuit.

The magnitude of the injected voltage signal is measured onthe secondary side of the neutral point voltage transformer orgrounding transformer. In addition, the resulting injectedcurrent is measured through a resistive shunt located withinthe injection box. These two measured values are fed to theIED. Based on these two measured quantities, the IEDdetermines the stator winding resistance to ground. Theresistance value is then compared with the preset faultresistance alarm and trip levels.

The protection function can not only detect the earth fault atthe generator star point, but also along the stator windingsand at the generator terminals, including the connectedcomponents such as voltage transformers, circuit breakers,excitation transformer and so on. The measuring principleused is not influenced by the generator operating mode andis fully functional even with the generator at standstill. It is stillrequired to have a standard 95% stator earth-fault protection,based on the neutral point fundamental frequencydisplacement voltage, operating in parallel with the 100%stator earth-fault protection function.

Requires injection unit REX060 and optional shunt resistorunit REX062 for correct operation.

5. Current protection

Instantaneous phase overcurrent protection PHPIOCThe 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 OC4PTOCThe four step phase overcurrent protection functionOC4PTOC has an inverse or definite time delay independentfor step 1 and 4 separately. Step 2 and 3 are always definitetime delayed.

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


16 ABB

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 functionand can be used to block each step individually

Instantaneous residual overcurrent protection EFPIOCThe Instantaneous residual overcurrent protection EFPIOChas a low transient overreach and short tripping times toallow the use for instantaneous earth-fault protection, with thereach limited to less than the typical eighty percent of the lineat minimum source impedance. EFPIOC can be configured tomeasure the residual current from the three-phase currentinputs or the current from a separate current input. EFPIOCcan be blocked by activating the input BLOCK.

Four step residual overcurrent protection, zero sequence andnegative sequence direction EF4PTOCThe four step residual overcurrent protection EF4PTOC hasan inverse or definite time delay independent for each stepseparately.

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

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

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

Second harmonic blocking can be set individually for eachstep.

EF4PTOC can be used as main protection for phase-to-earthfaults.

EF4PTOC can also be used to provide a system back-up forexample, in the case of the primary protection being out ofservice due to communication or voltage transformer circuitfailure.

EF4PTOC can be configured to measure the residual currentfrom the three-phase current inputs or the current from aseparate current input.

Four step negative sequence overcurrent protectionNS4PTOCFour step negative sequence overcurrent protection(NS4PTOC) has an inverse or definite time delay independentfor each 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 can be set directional or non-directionalindependently for each of the steps.

NS4PTOC can be used as main protection for unsymmetricalfault; phase-phase short circuits, phase-phase-earth shortcircuits and single phase earth faults.

NS4PTOC can also be used to provide a system back-up forexample, in the case of the primary protection being out ofservice due to communication or voltage transformer circuitfailure.

Sensitive directional residual overcurrent and powerprotection SDEPSDEIn isolated networks or in networks with high impedanceearthing, the earth 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 3U0·3I0·cos j,for operating quantity with maintained short circuit capacity.There is also available one nondirectional 3I0 step and one3U0 overvoltage tripping step.

No specific sensitive current input is needed.SDEPSDE canbe set as low 0.25% of IBase.

Thermal overload protection, two time constant TRPTTRIf a power transformer or generator reaches very hightemperatures the equipment might be damaged. Theinsulation within the transformer/generator will have forcedageing. As a consequence of this the risk of internal phase-to-phase or phase-to-earth faults will increase. High temperaturewill degrade 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 thermalmodel of the transformer/generator with two time constants,which is based on current measurement.

Two warning levels are available. This enables actions in thepower system to be done before dangerous temperatures arereached. If the temperature continues to increase to the tripvalue, the protection initiates a trip of the protectedtransformer/generator.

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

Current check with extremely short reset time is used ascheck criterion to achieve high security against inadvertentoperation.

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

CCRBRF can be single- or three-phase initiated to allow usewith single phase tripping applications. For the three-phase


ABB 17

version of CCRBRF the current criteria can be set to operateonly if two out of four for example, two phases or one phaseplus the residual current start. This gives a higher security tothe back-up trip command.

CCRBRF function can be programmed to give a single- orthree-phase re-trip of the own breaker to avoid unnecessarytripping of surrounding breakers at an incorrect initiation dueto mistakes during testing.

Pole discordance protection CCRPLDAn open phase can cause negative and zero sequencecurrents which cause thermal stress on rotating machinesand can cause unwanted operation of zero sequence ornegative sequence current functions.

Normally the own breaker is tripped to correct such asituation. If the situation persists the surrounding breakersshould be tripped to clear the unsymmetrical load situation.

The Polediscordance protection function CCRPLD operatesbased on information from auxiliary contacts of the circuitbreaker for the three phases with additional criteria fromunsymmetrical phase currents when required.

Directional over/underpower protection GOPPDOP/GUPPDUPThe directional over-/under-power protection GOPPDOP/GUPPDUP can be used wherever a high/low active, reactiveor apparent power protection or alarming is required. Thefunctions can alternatively be used to check the direction ofactive or reactive power flow in the power system. There area number of applications where such functionality is needed.Some of them are:

• detection of reversed active power flow• detection of high reactive power flow• generator reverse power protection

Each function has two steps with definite time delay. Resettimes for both steps can be set as well.

Negative sequence time overcurrent protection for machinesNS2PTOCNegative-sequence time overcurrent protection for machinesNS2PTOC is intended primarily for the protection ofgenerators against possible overheating of the rotor causedby negative 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 earth faults• Broken conductors• Malfunction of one or more poles of a circuit breaker or a

disconnector

NS2PTOC can also be used as a backup protection, that is,to protect the generator in case line protections or circuitbreakers fail to clear unbalanced system faults.

To provide an effective protection for the generator forexternal unbalanced conditions, NS2PTOC is able to directlymeasure the negative sequence current. NS2PTOC also has atime 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 has a wide range of K settings and the sensitivityand capability of detecting and tripping for negative sequencecurrents down to the continuous capability of a generator.

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

Accidental energizing protection for synchronous generatorAEGGAPCInadvertent 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 protectthe inadvertently energized generator.

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

6. Voltage protection

Two step undervoltage protection UV2PTUVUndervoltages can occur in the power system during faults orabnormal conditions. Two step undervoltage protection(UV2PTUV) function can be used to open circuit breakers toprepare for system restoration at power outages or as long-time delayed back-up to primary protection.

UV2PTUV has two voltage steps, each with inverse or definitetime delay.


18 ABB

Two step overvoltage protection OV2PTOVOvervoltages may occur in the power system during abnormalconditions such as sudden power loss, tap changerregulating failures, open line ends on long lines etc.

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

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

OV2PTOV has an extremely high reset ratio to allow settingsclose to system service voltage.

Two step residual overvoltage protection ROV2PTOVResidual voltages may occur in the power system duringearth faults.

Two step residual overvoltage protection ROV2PTOV functioncalculates the residual voltage from the three-phase voltageinput transformers or measures it from a single voltage inputtransformer fed from an open delta or neutral point voltagetransformer.

ROV2PTOV has two voltage steps, each with inverse ordefinite time delay.

Reset delay ensures operation for intermittent earth faults.

Overexcitation protection OEXPVPHWhen the laminated core of a power transformer or generatoris subjected to a magnetic flux density beyond its designlimits, stray flux will flow into non-laminated components notdesigned to carry flux and cause eddy currents to flow. Theeddy currents can cause excessive heating and severedamage to insulation and adjacent parts in a relatively shorttime. The function has settable inverse operating curves andindependent alarm stages.

Voltage differential protection VDCPTOVA voltage differential monitoring function is available. Itcompares the voltages from two three phase sets of voltagetransformers and has one sensitive alarm step and one tripstep.

95% and 100% Stator earth fault protection based on 3rdharmonic STEFPHIZStator earth fault is a fault type having relatively high faultrate. The generator systems normally have high impedanceearthing, that is, earthing via a neutral point resistor. Thisresistor is normally dimensioned to give an earth fault currentin the range 3 – 15 A at a solid earth-fault directly at thegenerator high voltage terminal. The relatively small earth faultcurrents give much less thermal and mechanical stress on thegenerator, compared to the short circuit case, which isbetween conductors of two phases. Anyhow, the earth faultsin the generator have to be detected and the generator has tobe tripped, 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-earth fault occurs the neutral point voltage will increase andthere will be a current flow through the neutral point resistor.

To detect an earth 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 manyyears. However, at best these simple schemes protect only95% of the stator winding. They leave 5% close to the neutralend unprotected. Under unfavorable conditions the blind zonemay extend up to 20% from the neutral.

The 95% stator earth fault protection measures thefundamental frequency voltage component in the generatorstar point and it operates when it exceeds the preset value.By applying this principle approximately 95% of the statorwinding can be protected. In order to protect the last 5% ofthe stator winding close to the neutral end the 3rd harmonicvoltage measurement can be performed. In 100% Stator E/F3rd harmonic protection either the 3rd harmonic voltagedifferential principle, the neutral point 3rd harmonicundervoltage principle or the terminal side 3rd harmonicovervoltage principle can be applied. However, differentialprinciple is strongly recommended. Combination of these twomeasuring principles provides coverage for entire statorwinding against earth faults.


ABB 19

x E3

Rf

TCB 2(1-x) E3

overvoltage protection 10% – 100%

Differential0% – 30%

CB 1 may not exist

RN

NCB 1

stator winding

uTuN

x E3

Rf Transformer

TCB 2(1-x) E3

x

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

3rd harmonic differential0% - 30%

CB 1 may not exist

1 or 100 %

RN

NNCB 1

stator winding

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

fundamental and 3rd harmonic voltages are filtered out

Samples of the terminal voltage from which the 3rd harmonic

voltage is filtered out


IEC10000202 V1 EN

Figure 8. Protection principles for STEFPHIZ function

7. Frequency protection

Underfrequency protection SAPTUFUnderfrequency occurs as a result of a lack of generation inthe network.

Underfrequency protection SAPTUF is used for load sheddingsystems, remedial action schemes, gas turbine startup andso on.

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

Overfrequency protection SAPTOFOverfrequency protection function SAPTOF is applicable in allsituations, where reliable detection of high fundamental powersystem frequency is needed.

Overfrequency occurs because of sudden load drops orshunt faults in the power network. Close to the generating

plant, generator governor problems can also cause overfrequency.

SAPTOF is used mainly for generation shedding and remedialaction schemes. It is also used as a frequency stage initiatingload restoring.

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

Rate-of-change frequency protection SAPFRCRate-of-change frequency protection function (SAPFRC) givesan early indication of a main disturbance in the system.SAPFRC can be used for generation shedding, load sheddingand remedial action schemes. SAPFRC can discriminatebetween positive or negative change of frequency.

SAPFRC is provided with an undervoltage blocking. Theoperation is based on positive sequence voltagemeasurement and requires two phase-phase or three phase-


20 ABB

neutral voltages to be connected. For information about howto connect analog inputs, refer to Application manual/IEDapplication/Analog inputs/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 levels. Both of them can be used either with definitetime or inverse time characteristic. The overcurrent protectionsteps can be made directional with selectable voltagepolarizing quantity. Additionally they can be voltage and/orcurrent controlled/restrained. 2nd harmonic restraining facilityis available as well. At too low polarizing voltage theovercurrent feature can be either blocked, made nondirectional or ordered to use voltage memory in accordancewith a parameter setting.

Additionally two overvoltage and two undervoltage steps,either with definite time or inverse time characteristic, areavailable within 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.

Rotor earth fault protectionThe 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 ifthe rotor is cooled by air or by hydrogen. The insulationresistance is much lower if the rotor winding is cooled bywater. This is true even if the insulation is intact. A fault in theinsulation of the field circuit will result in a conducting pathfrom the field winding to earth. This means that the fault hascaused a field earth fault.

The field circuit of a synchronous generator is normallyunearthed. Therefore, a single earth fault on the field windingwill cause only a very small fault current. Thus the earth faultdoes not produce any damage in the generator. Furthermore,it will not affect the operation of a generating unit in any way.However, the existence of a single earth fault increases theelectric stress at other points in the field circuit. This meansthat the risk for a second earth fault at another point on thefield winding has increased considerably. A second earth faultwill cause a field short-circuit with severe consequences.

The rotor earth 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 earth fault occurs, this condition will bedetected by the rotor earth fault protection. Depending on thegenerator owner philosophy this operational state will bealarmed and/or the generator will be tripped. An injection unitis required for rotor earth fault protection (RXTTE4) and aprotective resistor on plate for correct operation.

9. Secondary system supervision

Current circuit supervision CCSRDIFOpen or short circuited current transformer cores can causeunwanted operation of many protection functions such asdifferential, earth-fault current and negative-sequence currentfunctions.

It must be remembered that a blocking of protectionfunctions at an occurrence of open CT circuit will mean thatthe situation will remain and extremely high voltages willstress the secondary circuit.

Current circuit supervision (CCSRDIF) compares the residualcurrent from a three phase set of current transformer coreswith the neutral point current on a separate input taken fromanother set of cores on the current transformer.

A detection of a difference indicates a fault in the circuit andis used as alarm or to block protection functions expected togive unwanted tripping.

Fuse failure supervision SDDRFUFThe aim of the fuse failure supervision function (SDDRFUF) isto block voltage measuring functions at failures in thesecondary circuits between the voltage transformer and theIED in order to avoid unwanted operations that otherwisemight occur.

The fuse failure supervision function basically has threedifferent algorithms, negative sequence and zero sequencebased algorithms and an additional delta voltage and deltacurrent algorithm.

The negative sequence detection algorithm is recommendedfor IEDs used in isolated or high-impedance earthednetworks. It is based on the negative-sequence measuringquantities, a high value of voltage 3U2 without the presence

of the negative-sequence current 3I2.

The zero sequence detection algorithm is recommended forIEDs used in directly or low impedance earthed networks. It isbased on the zero sequence measuring quantities, a highvalue of voltage 3U0 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 andzero sequence based function. The selection of different


ABB 21

operation modes makes it possible to choose differentinteraction possibilities between the negative sequence andzero sequence based 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 transformerswitching during station operations.

10. Control

Synchrocheck, energizing check, and synchronizing SESRSYNThe 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) function checks that the voltages on both sides ofthe circuit breaker are in synchronism, or with at least oneside dead to ensure that closing can be done safely.

SESRSYN function includes a built-in voltage selectionscheme for double bus and 1½ breaker or ring busbararrangements.

Manual closing as well as automatic reclosing can bechecked by 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 breakerswhen two asynchronous systems are going to be connected.It is used for slip frequencies that are larger than those forsynchrocheck 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 earthingswitches within a bay. Permission to operate is given afterevaluation of conditions from other functions such asinterlocking, synchrocheck, 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 theresulting position is not supervised. However with enhancedsecurity, the command is processed and the resultingposition is supervised.

Normal security means that only the command is evaluatedand the resulting position is not supervised. Enhancedsecurity means that the command is evaluated with anadditional supervision of the status value of the controlobject. The command security with enhanced security isalways terminated by a CommandTermination serviceprimitive.

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 signalsor alternatively via an mA input signal. The actual tap-positioncan be used by the transformer or overall differentialprotection function in order to enable more sensitive pickupsetting. This will in turn make differential protection moresensitive for low level 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)is used 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. Thelogic selector 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 symbolon the 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


22 ABB

other systems or equipment in the substation. It is especiallyused in the interlocking and reservation station-wide logics.

Single point generic control 8 signals SPC8GGIOThe Single point generic control 8 signals (SPC8GGIO)function block is a collection of 8 single point commands,designed to bring in commands from REMOTE (SCADA) tothose parts of the logic configuration that do not needextensive command receiving functionality (for example,SCSWI). In this way, simple commands can be sent directlyto the IED outputs, without confirmation. Confirmation (status)of the result of the commands is supposed to be achieved byother means, such as binary inputs and SPGGIO functionblocks. The commands can 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 commandscoming through the DNP3 protocol. The AUTOBITS functionplays the same role as functions GOOSEBINRCV (for IEC61850) and MULTICMDRCV (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 SMPPTRCA function block for protection tripping is provided for eachcircuit breaker involved in the tripping of the fault. It providesa settable pulse prolongation to ensure a trip pulse ofsufficient length, as well as all functionality necessary forcorrect 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 tripsignals and other logical output signals to different outputcontacts on the IED.

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

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-lineinformation from the IED. These service values make itpossible to display on-line information on the local HMI andon the Substation automation 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 mAinput module.

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 of40 analog and 96 binary signals.

The Disturbance report functionality is a common name forseveral functions:

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

The Disturbance report function is characterized by greatflexibility regarding configuration, starting conditions,recording times, and large storage capacity.


ABB 23

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-faulttime to the end of post-fault time will be included in therecording.

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. Thedisturbance report files may be uploaded to PCM600 forfurther analysis using the disturbance handling tool.

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

The event list logs all binary input signals connected to theDisturbance report function. The list may contain up to 1000time-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 itis important to know, for example binary signals that havechanged status during a disturbance. This information is usedin the short perspective to get information via the local HMI ina straightforward way.

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

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

Event recorder DRPRDREQuick, complete and reliable information about disturbancesin the primary and/or in the secondary system is vital, forexample, time-tagged events logged during disturbances.This information is used for different purposes in the shortterm (for example corrective actions) and in the long term (forexample functional 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 thedisturbances locally 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 currentsand voltages 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, completeand reliable information about disturbances in the powersystem. It facilitates understanding system behavior andrelated primary and secondary equipment during and after adisturbance. Recorded information is used for differentpurposes in the short perspective (for example correctiveactions) and long perspective (for example functional analysis).

The Disturbance recorder acquires sampled data fromselected analog- and binary signals connected to theDisturbance report function (maximum 40 analog and 96binary signals). The binary signals available are the same asfor 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. Upto ten seconds of data before the trigger instant can be savedin the disturbance file.

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

Event functionWhen using a Substation Automation system with LON orSPA communication, time-tagged events can be sent atchange or cyclically from the IED to the station level. Theseevents are created from any available signal in the IED that isconnected to the Event function (EVENT). The event functionblock is used for LON and SPA 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 analog


24 ABB

signal to other systems or equipment in the substation. It canalso be used inside the same IED, to attach a RANGE aspectto an analog value and to permit measurement supervision onthat value.

Measured value expander block RANGE_XPThe current and voltage measurements functions (CVMMXN,CMMXU, VMMXU and VNMMXU), current and voltagesequence measurement functions (CMSQI and VMSQI) andIEC 61850 generic communication I/O functions (MVGGIO)are provided with measurement supervision functionality. Allmeasured values can be supervised with four settable limits:low-low limit, low limit, high limit and high-high limit. Themeasure value expander block (RANGE_XP) has beenintroduced to enable translating the integer output signal fromthe measuring functions to 5 binary signals: below low-lowlimit, below low limit, normal, above high-high limit or abovehigh limit. The output signals can be used as conditions in theconfigurable logic or for alarming purpose.

13. Metering

Pulse counter logic PCGGIOPulse counter (PCGGIO) function counts externally generatedbinary pulses, for instance pulses coming from an externalenergy meter, for calculation of energy consumption values.The pulses are captured by the binary input module and thenread by the function. A scaled service value is available overthe station bus. The special Binary input module withenhanced pulse counting capabilities must be ordered toachieve this functionality.

Function for energy calculation and demand handlingETPMMTROutputs 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. Maximumdemand power 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 partof a protection system. This makes it possible to compareevent and disturbance data between all IEDs in a stationautomation system.

15. Human machine interface

Human machine interfaceThe 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.

IEC05000056-LITEN V1 EN

Figure 9. Example of medium graphic HMI

16. Station communication

OverviewEach IED is provided with a communication interface,enabling it to connect to one or many substation levelsystems or equipment, either on the Substation Automation(SA) bus or Substation 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 Ethernetrear ports (order dependent) for IEC 61850-8-1 station buscommunication. The IEC 61850-8-1 communication is alsopossible from the optical Ethernet front port. IEC 61850-8-1


ABB 25

protocol allows intelligent electrical devices (IEDs) fromdifferent vendors to exchange information and simplifiessystem engineering. Peer-to-peer communication accordingto GOOSE is part of the standard. Disturbance files uploadingis 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 andcooperation between existing ABB IED's and the new IED670.

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 availablefor the DNP3.0 communication. DNP3.0 Level 2communication with unsolicited events, time synchronizingand disturbance reporting is provided for communication toRTUs, Gateways or HMI 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 atthe time of ordering when an existingredundant station bus DuoDriver installationis extended.Select IEC 62439-3 Edition 2 protocol atthe time of ordering for new installationswith redundant 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 theline differential protection. However it can be used in otherproducts as well. An IED can communicate with up to 4remote 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 beused to send information such as status of primaryswitchgear apparatus or intertripping signals to the remoteIED. An IED can communicate 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 <60km or from the IED to optical to electrical converter with G.703 or G.703E1 interface located on a distances <3 kmaway. The LDCM module sends and receives data, to andfrom another LDCM module. The IEEE/ANSI C37.94 standardformat is 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 powerplants

18. Hardware description

Hardware modulesPower supply module PSMThe power supply module is used to provide the correctinternal voltages and full isolation between the terminal andthe battery system. An internal fail alarm output is available.

Binary input module BIMThe binary input module has 16 optically isolated inputs andis available in two versions, one standard and one withenhanced pulse counting capabilities on the inputs to beused with the pulse counter function. The binary inputs arefreely programmable and can be used for the input of logicalsignals to any of the functions. They can also be included inthe disturbance recording and event-recording functions. Thisenables extensive monitoring and evaluation of operation ofthe IED and for all associated electrical circuits.


26 ABB

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 outputsand six change over output relays for use in applications withhigh speed 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.The two high speed signal output channels are used forapplications where short operating time is essential. Eightoptically isolated binary inputs cater for required binary inputinformation.

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 modulehas six 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 theIEC 61850-8-1 protocol (port A, B). The module has one ortwo optical 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 endto which the IED communicates.

Alternative cards for Medium range (1310 nm single mode)and Short 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 RXand TX multidrop communication with a dedicated Masterand the rest are slaves. No special control signal is needed inthis case.

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

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

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 inputsin different combinations of currents and voltage inputs.Either protection class or metering class CT inputs areavailable.

Alternative connectors of Ring lug or Compression type canbe ordered.

High impedance resistor unitThe high impedance resistor unit, with resistors for pick-upvalue setting and a voltage dependent resistor, is available ina single phase unit and a three phase unit. Both are mountedon a 1/1 19 inch apparatus plate with compression typeterminals.

Layout and dimensionsDimensions


ABB 27

xx05000003.vsd

CB

E

F

A

D

IEC05000003 V1 EN

Figure 10. 1/2 x 19” case with rear cover

xx05000004.vsdIEC05000004 V1 EN

Figure 11. Side-by-side mounting

Case size A B C D E F

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

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

(mm)

Mounting alternatives• 19” rack mounting kit• Flush mounting kit with cut-out dimensions:

– 1/2 case size (h) 254.3 mm (w) 210.1 mm– 1/1 case size (h) 254.3 mm (w) 434.7 mm

• Wall mounting kit

See ordering for details about available mounting alternatives.


28 ABB

Injection equipment hardwareInjection unit REX060The injection unit REX060 is used to inject voltage andcurrent signals to the generator or motor stator and rotorcircuits. REX060 generates two square wave signals withdifferent frequencies for injection into the stator and rotorcircuits respectively. The response from the injected voltageand currents are then measured by the REX060 unit andamplified to a level suitable for the analog voltage inputs ofIED.

Stator injection module SIMThe SIM module is installed into the REX060 enclosure. TheSIM module generates a square wave voltage signal forinjection into the stator circuit via the neutral point resistor orVT/DT. The SIM module measures the voltage and currentfrom the injected signal and the IED consecutively calculatesthe stator to earth impedance. If the calculated impedance islower than the preset value an ALARM and/or TRIP output isset.

Rotor injection module RIMThe RIM module is installed into the REX060 enclosure. TheRIM module generates a square wave voltage signal for

injection into the rotor circuit via a capacitor unit REX061 forisolation. The RIM module measures the voltage and currentfrom the injected signal and the IED consecutively calculatesthe rotor to earth impedance. If the calculated impedance islower than the preset value an ALARM and/or TRIP output isset.

Coupling capacitor unit REX061REX061 isolates the injection circuit from the rotor excitervoltage.

The REX061 coupling capacitor unit grounding point andgrounding brush of the rotor shaft should be properlyinterconnected.

Shunt resistor unit REX062REX062 is typically used when injection is done via agrounding transformer.


ABB 29

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

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

1MRK002801-AC-6-670-1.2-PG V1 EN

Module Rear Positions

PSM X11

BIM, BOM, SOM,IOM or MIM

X31 and X32 etc. to X131and X132

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


30 ABB

1MRK002801-AC-10-670-1.2-PG V1 EN

Figure 12. Transformer input module (TRM)

￭ Indicates high polarity

CT/VT-input designation according to figure 12

Cur

rent

/vol

tage

conf

igur

atio

n(5

0/60

Hz)

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+3U, 1A 1A 1A 1A 1A 1A 1A 1A 1A 1A 110-220V 110-220V 110-220V9I+3U, 5A 5A 5A 5A 5A 5A 5A 5A 5A 5A 110-220V 110-220V 110-220V5I, 1A+4I, 5A+3U 1A 1A 1A 1A 1A 5A 5A 5A 5A 110-220V 110-220V 110-220V7I+5U, 1A 1A 1A 1A 1A 1A 1A 1A 110-220V 110-220V 110-220V 110-220V 110-220V7I+5U, 5A 5A 5A 5A 5A 5A 5A 5A 110-220V 110-220V 110-220V 110-220V 110-220V6I+6U, 1A 1A 1A 1A 1A 1A 1A 110-220V 110-220V 110-220V 110-220V 110-220V 110-220V6I+6U, 5A 5A 5A 5A 5A 5A 5A 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

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


ABB 31

1MRK002801-AC-11-670-1.2-PG V1 EN

Figure 13. Binary input module (BIM). Input contactsnamed XA corresponds to rear positionX31, X41, and so on, and input contactsnamed XB to rear position X32, X42, andso on.

1MRK002801-AC-15-670-1.2-PG V1 EN

Figure 14. mA input module (MIM)

1MRK002801-AC-8-670-1.2-PG V1 EN

Figure 15. IED with basic functionality and communication interfaces


32 ABB

1MRK002801-AC-7-670-1.2-PG V1 EN

Figure 16. Power supply module (PSM)

1MRK002801-AC-12-670-1.2-PG V1 EN

Figure 17. Binary output module (BOM). Output contacts named XA corresponds to rear position X31, X41, and so on, and outputcontacts named XB to rear position X32, X42, and so on.


ABB 33

1MRK002801-AC-13-670-1.2-PG V1 EN

Figure 18. Static output module (SOM)

1MRK002801-AC-14-670-1.2-PG V1 EN

Figure 19. Binary in/out module (IOM). Input contacts named XA corresponds to rear position X31, X41, and so on, and output contactsnamed XB to rear position X32, X42, and so on.


34 ABB

Injection unit REX060

1MRK002501-BA-2-PG V1 EN

Figure 20. Designation for REX060 unit casing


Figure 21. Power supply module


ABB 35


Figure 22. Stator injection module


Figure 23. Rotor injection module


36 ABB

Coupling capacitor unit REX061


Figure 24. Designation for capacitor unit casing


Figure 25. Coupling capacitor module


ABB 37

Shunt resistor unit REX062


Figure 26. Designation for shunt resistor unit casing


Figure 27. Shunt resistor module


38 ABB

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 thespecified requirements

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

Quantity Rated value Nominal range

Current Ir = 1 or 5 A (0.2-40) × Ir

Operative range (0-100) x Ir

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

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

Ac voltage Ur = 110 V 0.5–288 V

Operative range (0–340) V

Permissive overload 420 V cont.450 V 10 s

Burden < 20 mVA at 110 V

Frequency fr = 50/60 Hz ± 5%

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

Table 4. 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

-


ABB 39

Table 5. 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

Auxiliary DC voltage

Table 6. 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 7. BIM - Binary input module


Binary inputs 16 -

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

RL ± 20%RL ± 20%RL ± 20%RL ± 20%

Power consumption24/30 V, 50mA48/60 V, 50mA110/125 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 maybe activated simultaneously with influencingfactors within nominal range.


40 ABB

Table 8. 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 V110/125 V220/250 V

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

-

Counter input frequency 10 pulses/s max -

Balanced counter input frequency 40 pulses/s max -

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


Table 9. 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 mA110/125 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 41

Table 10. 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


42 ABB

Table 11. 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

Table 12. 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


ABB 43

Table 13. 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 of0.2 μF:

0.2s 30A

1.0s 10A

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

110V / 0.4A

125V / 0.35A

220V / 0.2A

250V / 0.15A

Table 14. 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 15. Temperature and humidity influence

Parameter Reference value Nominal range Influence

Ambient temperature, operatevalue

+20 °C -10 °C to +55 °C 0.02% /°C

Relative humidityOperative range

10%-90%0%-95%

10%-90% -

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


44 ABB

Table 16. 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

Table 17. Frequency influence (reference standard: IEC 60255–1)

Dependence on Within nominal range Influence

Frequency dependence, operate value fr ± 2.5 Hz for 50 Hzfr ± 3.0 Hz for 60 Hz

± 1.0% / Hz

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

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

2nd, 3rd and 5th harmonic of fr ±5.0%


ABB 45

Type tests according to standards

Table 18. Electromagnetic compatibility

Test Type test values Reference standards

1 MHz 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



IEEE/ANSI C37.90.1

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

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

IEC 60255-22-5

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

Conducted common 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

Table 19. Insulation

Test Type test values Reference standard

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

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

Insulation resistance >100 MW at 500 VDC


46 ABB

Table 20. 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 =24 hours)

IEC 60068-2-30

Table 21. CE compliance

Test According to

Immunity EN 50263

Emissivity EN 50263

Low voltage directive EN 50178

Table 22. Mechanical tests


Vibration response test Class II IEC 60255-21-1

Vibration endurance test Class I IEC 60255-21-1

Shock response test Class II IEC 60255-21-2

Shock withstand test Class I IEC 60255-21-2

Bump test Class I IEC 60255-21-2

Seismic test Class II IEC 60255-21-3


ABB 47

Injection equipment

Table 23. Electromagnetic compatibility tests


1 MHz 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

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

IEEE/ANSI C37.90.1



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



IEEE/ANSI C37.90.3

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

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

IEC 60255-22-5

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

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

IEC 61000-4-8

Radiated electromagnetic field disturbance test 20 V/m, 80-1000 MHz1.4-2.7 GHz

IEC 60255-22-3

Radiated electromagnetic field disturbance test 20 V/m, 80-1000 MHz IEEE/ANSI C37.90.2

Conducted electromagnetic field disturbance test 10 V, 0.15-80 MHz IEC 60255-22-6

Voltage dips and short interruptions Dips:40% /200 ms70% /500 msInterruptions:0-50 ms: No restart0… ∞ s: Correct behaviour atpower down

IEC 60255-11

Radiated emission 30-1000 MHz IEC 60255-25

Conducted emission 0.15-30 MHz IEC 60255-25

Table 24. Insulation tests, REX060, REX062 and REG670


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

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

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


48 ABB

Table 25. Insulation tests, REX061


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

IEEE 421.3 IEC 60255-5

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

IEC 60664-1 IEC 60255-5

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

Table 26. Mechanical tests

Test Reference standards Requirements

Vibration response test IEC 60255-21-1 Class 2

Vibration endurance testREG670 and REX060REX061 and REX062

IEC 60255-21-1 Class 1Class 2

Shock response test IEC 60255-21-2 Class 2

Shock withstand testREG670 and REX060REX061 and REX062


Bump testREG670 and REX060REX061 and REX062


Seismic testREG670 and REX060REX061 and REX062

IEC 60255-21-3 Class 2Class 2 extended

Table 27. Environmental tests

Test Type test value Reference standard

Cold testoperationstorage

16 h at -25°C16 h at -40°C

IEC 60068-2-1

Dry heat testoperationstorage

16 h at +70°C16 h at +85°C

IEC 60068-2-2

Damp heat teststeady state cyclic

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

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

Table 28. Auxiliary DC supply voltage influence

Test Type test values Influence

Auxiliary voltage dependence, operate value ±20% of EL 0.01% /°C

Ripple in DC auxiliary voltage, operate value 15% of EL 0.01% /°C


ABB 49

Table 29. Temperature influence

Test Type test values Influence

Ambient temperature, operate value -25° C to +55°C 0.01% /°C

Storage temperature -40° C to +85°C -

Table 30. Degree of protection

Description Values

REX060Front sidePanel mounted, frontRear side, connection terminals

IP40IP54IP20

REX061 and REX062Front and sideBottom side

IP41IP20


50 ABB

Differential protection

Table 31. Generator differential protection GENPDIF

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 Ir

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

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

-


ABB 51

Table 32. Transformer differential protection T2WPDIF, T3WPDIF


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

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 Ir

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 Y or D -

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

0–11 -

Operate time, restrained function 25 ms typically at 0 to 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 33. Restricted earth fault protection, low impedance REFPDIF


Operate characteristic Adaptable ± 1% of IBase2% of theoretical operate value (Idiff) if Ibias >= 1.25 IBase (i.e. sections2 and 3)(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 IrBase


52 ABB

Table 34. 1Ph High impedance differential protection HZPDIF


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

± 1.0% of Ir

Reset ratio >95% -

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

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

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

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


ABB 53

Impedance protection

Table 35. Full-scheme distance protection, Mho characteristic ZMHPDIS


Number of zones with selectabledirections

3 with selectable direction -

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

Positive sequence impedance,phase-to-earth loop

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

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

Positive sequence impedanceangle, phase-to-earth loop

(10–90) degrees

Reverse reach, phase-to-earthloop (Magnitude)

(0.005–3000.000) Ω/phase

Magnitude of earth returncompensation factor KN

(0.00–3.00)

Angle for earth 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 36. Pole slip protection PSPPPAM


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

Characteristic angle (72.00–90.00) degrees ± 5.0 degrees

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

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

Table 37. Loss of excitation LEXPDIS


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

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

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


54 ABB

Table 38. ROTIPHIZ technical data


Fault resistance sensitivity Can be reached 500 kΩ

Typically 50 kΩ

Injection frequency (75.000 - 250.000) Hz ±0.1 Hz

Trip limit of fault resistance (100 - 100000)Ω 5% of 1 kΩ at Rf ≤ 1 kΩ5% of set value at 1 kΩ < Rf ≤ 20 kΩ10% of set value at Rf > 20 kΩ

Alarm limit of fault resistance (100 - 1000000)Ω 5% of 1 kΩ at Rf ≤ 1 kΩ5% of 10 kΩ at 1 kΩ < Rf ≤ 20 kΩ10% of set value at 20 kΩ < Rf ≤ 200 kΩ

Operate time, start 1.00 s typically -

Operate time, trip 2.00 s typically -

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

Table 39. STTIPHIZ technical data


Fault resistance sensitivity Can be reached at steady stateoperating condition of the machine

50 kΩ

Typically 10 kΩ

Injection frequency (50.000 - 250.000) Hz ±0.1 Hz

Trip limit of fault resistance (100 - 10000)Ω ±5% of 1 kΩ at Rf ≤ 1 kΩ±10% of set value at Rf > 1 kΩ

Alarm limit of fault resistance (100 - 100000)Ω ±5% of 1 kΩ at Rf ≤ 1 kΩ±10% of 10 kΩ at 1 kΩ < Rf ≤ 10 kΩ±50% of set value at Rf > 10 kΩ

Operate time, start 1.00 s typically -

Operate time, trip 2.00 s typically -

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


ABB 55

Current protection

Table 40. Instantaneous phase overcurrent protection PHPIOC


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

Reset ratio > 95% -

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

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

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




Dynamic overreach < 5% at t = 100 ms -

Table 41. Four step phase overcurrent protection OC4PTOC

Function Setting range Accuracy

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

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

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

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 Ir

Independent time delay at 0 to 2 xIset

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

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

Inverse characteristics, seetable 107, table 108 and table 109

16 curve types See table 107, table 108 and table 109

Operate time, start non-directionalat 0 to 2 x Iset

Min. = 15 ms

Max. = 30 ms

Reset time, start non-directional at2 to 0 x Iset

Min. = 15 ms

Max. = 30 ms


Impulse margin time 15 ms typically -


56 ABB

Table 42. Instantaneous residual overcurrent protection EFPIOC


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

Reset ratio > 95% -







Dynamic overreach < 5% at t = 100 ms -

Table 43. Four step residual overcurrent protection EF4PTOC


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

Reset ratio > 95% -

Operate current for directionalcomparison

(1–100)% of lBase ± 1.0% of Ir

Timers (0.000-60.000) s ± 0.5% ±10 ms

Inverse characteristics, see table107, table 108 and table 109

18 curve types See table 107, table 108 andtable 109

Second harmonic restrainoperation

(5–100)% of fundamental ± 2.0% of Ir

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

Minimum polarizing voltage (1–100)% of UBase ± 0.5% of Ur

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

Real part of source Z used forcurrent polarization

(0.50-1000.00) W/phase -

Imaginary part of source Z usedfor current polarization

(0.50–3000.00) W/phase -

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

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




ABB 57

Table 44. Four step negative sequence overcurrent protection NS4PTOC


Operate value, negativesequence current, step 1-4

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

Reset ratio > 95% -

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

Inverse characteristics, see table107, table 108 and table 109

18 curve types See table 107, table 108 andtable 109

Minimum operate current for step1 - 4

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

Operate value, negative currentfor directional release

(1–100)% of IBase ± 1.0% of Ir

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

Minimum polarizing voltage (1–100)% of UBase ± 0.5% of Ur

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

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

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

Critical impulse time, startfunction

10 ms typically at 0 to 2 x Iset -

Impulse margin time, startfunction

15 ms typically -

Transient overreach <10% at τ = 100 ms -


58 ABB

Table 45. Sensitive directional residual overcurrent and power protection SDEPSDE


Operate level for 3I0·cosj

directional residualovercurrent

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

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

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

± 1.0% of S at S > Sr

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

Operate level for non-directional overcurrent

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

Operate level for non-directional residualovervoltage

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

± 0.5% of U at U > Ur

Residual release current forall directional modes

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

Residual release voltage forall directional modes

(0.01-200.00)% of UBase ± 0.5% of Ur at U£Ur

± 0.5% of U at U > Ur

Reset ratio > 95% -

Timers (0.000-60.000) s ± 0.5% ±10 ms

Inverse characteristics, seetable 107, table 108 andtable 109

19 curve types See table 107, table 108 and table 109

Relay characteristic angleRCA

(-179 to 180) degrees ± 2.0 degrees

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

Operate time, non-directionalresidual over current



ABB 59

Table 45. Sensitive directional residual overcurrent and power protection SDEPSDE, continued


Reset time, non-directionalresidual over current


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

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

Table 46. Thermal overload protection, two time constants TRPTTR


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

Operate time:

2 2

2 2ln p

b

I It

I It

æ ö-ç ÷= ×ç ÷-è ø

EQUATION1356 V1 EN (Equation 1)

I = Imeasured

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

IEC 60255–8, ±5% + 200 ms

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

± 2.0% of heat content trip

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

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

Table 47. Breaker failure protection CCRBRF


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

Reset ratio, phase current > 95% -

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

Reset ratio, residual current > 95% -

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

Reset ratio > 95% -

Timers (0.000-60.000) s ± 0.5% ±10 ms

Operate time for current detection 10 ms typically -

Reset time for current detection 15 ms maximum -

Table 48. Pole discordance protection CCRPLD


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

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


60 ABB

Table 49. Directional underpower protection GUPPDUP


Power level (0.0–500.0)% of SBase

± 1.0% of Sr at S < Sr

± 1.0% of S at S > Sr

Characteristic angle (-180.0–180.0) degrees 2 degrees

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

Table 50. Directional overpower protection GOPPDOP


Power level (0.0–500.0)% of Sbase

± 1.0% of Sr at S < Sr

± 1.0% of S at S > Sr

Characteristic angle (-180.0–180.0) degrees 2 degrees

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

Table 51. Negative sequence time overcurrent protection for machines NS2PTOC


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

Reset ratio, step 1 and 2 >95% -

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

15 ms typically at 0 to 10 x Iset

-

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

Time characteristics Definite or Inverse -

Inverse time characteristic step 1, 2

2I t K=K=1.0-99.0 ± 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


ABB 61

Table 52. Accidental energizing protection for synchronous generator AEGGAPC


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

Reset ratio, overcurrent >95% -

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

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

Impulse margin time, overcurrent 10 ms typically -

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

± 0.5% of U at U>Ur

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

Impulse margin time, undervoltage 15 ms typically -

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

± 0.5% of U at U>Ur

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


62 ABB

Voltage protection

Table 53. Two step undervoltage protection UV2PTUV


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

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

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

Inverse time characteristics for step 1 and step 2, see table 111 - See table 111

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

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

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


Table 54. Two step overvoltage protection OV2PTOV


Operate voltage, step 1 and 2 (1-200)% of UBase ± 0.5% of Ur at U < Ur

± 0.5% of U at U > Ur

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

± 0.5% of U at U > Ur

Inverse time characteristics for steps 1 and 2, see table 110 - See table 110

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


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



ABB 63

Table 55. Two step residual overvoltage protection ROV2PTOV


Operate voltage, step 1 and step 2 (1-200)% of UBase ± 0.5% of Ur at U < Ur

± 1.0% of U at U > Ur

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

± 1.0% of U at U > Ur

Inverse time characteristics for low and high step, see table 112 - See table 112

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




Table 56. Overexcitation protection OEXPVPH


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

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

± 0.5% of U at U > Ur

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

Curve type IEEE or customer defined

2

(0.18 ):

( 1)k

IEEE tM

×=

-


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

± 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 57. Voltage differential protection VDCPTOV


Voltage difference for alarm andtrip

(0.0–100.0) % of UBase ± 0.5 % of Ur

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

Timers (0.000–60.000)s ± 0.5% ± 10 ms


64 ABB

Table 58. 100% Stator E/F 3rd harmonic STEFPHIZ


Fundamental frequency level UN(95% Stator EF)

(1.0–50.0)% of UBase ± 0.5% of Ur

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

Third harmonic differential blocklevel

(0.1–10.0)% of UBase ± 0.5% of Ur

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

Filter characteristic:FundamentalThird harmonic

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

-


ABB 65

Frequency protection

Table 59. Underfrequency protection SAPTUF


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

Operate time, start function 100 ms typically -

Reset time, start function 100 ms typically -

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

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

Voltage dependent time delay

( )ExponentU UMin

t tMax tMin tMinUNom UMin

-= × - +

-é ùê úë û


U=Umeasured

Settings:UNom=(50-150)% of Ubase

UMin=(50-150)% of Ubase

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

5% + 200 ms

Table 60. Overfrequency protection SAPTOF


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

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

Reset time, start function 100 ms typically -

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

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

Table 61. Rate-of-change frequency protection SAPFRC


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

Operate value, internal blocking level (0-100)% of UBase ± 0.5% of Ur

Operate time, start function 100 ms typically -


66 ABB

Multipurpose protection

Table 62. General current and voltage protection CVGAPC


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

-

Base current (1 - 99999) A -

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

-

Base voltage (0.05 - 2000.00) kV -

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

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

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

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

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

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

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

See table 107 and table 108 Parameter ranges for customer definedcharacteristic no 17:k: 0.05 - 999.00A: 0.0000 - 999.0000B: 0.0000 - 99.0000C: 0.0000 - 1.0000P: 0.0001 - 10.0000PR: 0.005 - 3.000TR: 0.005 - 600.000CR: 0.1 - 10.0

See table 107 and table 108

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

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

± 0.5% of U for U>Ur

Start undervoltage, step 1 and 2 (2.0 - 150.0)% of UBase ± 0.5% of Ur for U<Ur


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

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

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

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

High and low voltage limit, voltage dependent operation (1.0 - 200.0)% of UBase ± 1.0% of Ur for U<Ur


Directional function Settable: NonDir, forward and reverse -


ABB 67

Table 62. General current and voltage protection CVGAPC , continued


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:



Table 63. Rotor earth fault protection based on General current and voltage protection (CVGAPC) and RXTTE4


For machines with:

• rated field voltage up to 350 V DC -

• static exciter with rated supplyvoltage up to

700 V 50/60 Hz -

Supply voltage 120 or 230 V 50/60 Hz -

Operate earth 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 earthingresistance

Maximum 200 Ω -

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

-


68 ABB

Secondary system supervision

Table 64. Current circuit supervision CCSRDIF


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

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

Table 65. Fuse failure supervision SDDRFUF


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

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

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

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

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

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

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

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

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

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

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

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


ABB 69

Control

Table 66. Synchronizing, synchrocheck and energizing check SESRSYN


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

Voltage ratio, Ubus/Uline 0.500 - 2.000 -

Voltage high limit for synchronizing and synchrocheck (50.0-120.0)% of UBaseBus andUBaseLIne

± 0.5% of Ur at U ≤ Ur

± 0.5% of U at U >Ur

Reset ratio, synchrocheck > 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 Ur

Time delay output for synchrocheck (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 beenmade before 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 UBaseBus andUBaseLIne



Reset ratio, voltage high limit > 95% -

Voltage low limit for energizing check (10.0-80.0)% of UBaseBus andUBaseLine

± 0.5% of Ur

Reset ratio, voltage low limit < 105% -

Maximum voltage for energizing (50.0-180.0)% of UBaseBus and/or UBaseLIne



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

Operate time for synchrocheck function 160 ms typically -

Operate time for energizing function 80 ms typically -


70 ABB

Logic

Table 67. Tripping logic SMPPTRC


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

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

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

Table 68. 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 69. Measurements CVMMXN


Frequency (0.95-1.05) × fr ± 2.0 mHz

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

± 0.5% of U at U > Ur

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

Active power, P 0.1 x Ur Sr

Conditions:0.8 x Ur < U < 1.2 Ur

0.2 x Ir < I < 1.2 Ir

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

0.2 x Ir < I < 4.0 x Ir

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

0.2 x Ir 0.5 × Ir

Phase angle (0.1–4.0) x Ir ± 0.5° at 0.2 × Ir 50 V

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

Table 72. Phase-neutral voltage measurement VNMMXU


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



72 ABB

Table 73. Current sequence component measurement CMSQI


Current positive sequence, I1Three phase settings

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

Current zero sequence, 3I0Three phase settings


Current negative sequence, I2Three phase settings


Phase angle (0.1–4.0) × Ir ± 0.5° at 0.2 × Ir 50 V

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

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


Table 75. 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 level for input (-20.00 to +20.00) mA

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

Alarm hysteresis for input (0.0-20.0) mA

Table 76. Event counter CNTGGIO


Counter value 0-100000 -

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


ABB 73

Table 77. 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 103

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 Event list 1000, first in - first out -

Maximum total recording time (3.4 s recording time and maximum number ofchannels, 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 78. Event list

Function Value

Buffer capacity Maximum number of events in the list 1000

Resolution 1 ms

Accuracy Depending on time synchronizing

Table 79. Indications

Function Value

Buffer capacity Maximum number of indications presented for single disturbance 96

Maximum number of recorded disturbances 100

Table 80. 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 81. Trip value recorder

Function Value

Buffer capacity

Maximum number of analog inputs 30


Table 82. 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 83. Pulse counter PCGGIO

Function Setting range Accuracy

Input frequency See Binary Input Module (BIM) -

Cycle time for report of countervalue

(1–3600) s -

Table 84. Energy metering ETPMMTR


Energy metering kWh Export/Import, kvarh Export/Import

Input from MMXU. No extra error at steady load


76 ABB

Station communication

Table 85. 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 86. LON communication protocol

Function Value

Protocol LON

Communication speed 1.25 Mbit/s

Table 87. SPA communication protocol

Function Value

Protocol SPA

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

Slave number 1 to 899

Table 88. IEC60870-5-103 communication protocol

Function Value


Communication speed 9600, 19200 Bd

Table 89. SLM – LON port

Quantity Range or value

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

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

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

*) depending on optical budget calculation


ABB 77

Table 90. SLM – SPA/IEC 60870-5-103/DNP3 port


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

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

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

*) depending on optical budget calculation

Table 91. Galvanic RS485 communication module


Communication speed 2400–19200 bauds

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

Table 92. IEC 62439-3 Edition 1 and Edition 2 parallel redundancy protocol

Function Value


Communication speed 100 Base-FX


78 ABB

Remote communication

Table 93. Line data communication module

Characteristic Range or value

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

Type of fibre Graded-indexmultimode62.5/125 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 3km *)9 dB (typicaldistance about 2km *)

22 dB (typicaldistance 80 km *)

26 dB (typical distance 110 km *)

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

Protocol C37.94 C37.94implementation **)

C37.94 implementation **)

Data transmission Synchronous Synchronous Synchronous

Transmission rate / Data rate 2 Mb/s / 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 94. 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 95. 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 96. Weight

Case size Weight

6U, 1/2 x 19” £ 10 kg

6U, 1/1 x 19” £ 18 kg

Connection system

Table 97. 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 98. 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

Injection equipment hardware

Table 99. Injection unit REX060

Specifications Values

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

Weight 8.0 kg

Firmware 1p0r00, loaded in the HMI & Logic module

Table 100. Coupling capacitor unit REX061

Function Range or values Accuracy

For machines with:

• rated field voltage up to 800 V DC -

• static exciter with rated supply voltageup to

1600 V 50/60 Hz -


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

Weight 4.8 kg

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

Table 101. Shunt resistor unit REX062


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

Weight 4.5 kg

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


ABB 81

Basic IED functions

Table 102. Self supervision with internal event list

Data Value

Recording manner Continuous, event controlled

List size 40 events, first in-first out

Table 103. 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 sampledmeasurement values

± 1.0 ms typically

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

Table 104. 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 105. 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


82 ABB

Table 106. 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


ABB 83

Inverse characteristic

Table 107. ANSI Inverse time characteristics


Operating characteristic:

( )1= + ×

-

æ öç ÷ç ÷è ø

P

At B k

I

EQUATION1249-SMALL V1 EN

Reset characteristic:

( )2 1= ×

-

trt kI


I = Imeasured/Iset

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

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


84 ABB

Table 108. IEC Inverse time characteristics


Operating characteristic:

( )1= ×

-


P

At k

I


I = Imeasured/Iset

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

Time delay to reset, IEC 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:

( )= + ×

-


P

At B k

I C


Reset characteristic:

( )= ×

-PR

TRt k

I CR


I = Imeasured/Iset

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

Table 109. RI and RD type inverse time characteristics


RI type inverse characteristic

1

0.2360.339

= ×

-

t k

IEQUATION1137-SMALL V1 EN

I = Imeasured/Iset

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

RD type logarithmic inverse characteristic

5.8 1.35= - ×æ öç ÷è ø

tI

Ink


I = Imeasured/Iset

k = (0.05-999) in steps of 0.01


ABB 85

Table 110. Inverse time characteristics for overvoltage protection


Type A curve:

=- >

>

æ öç ÷è ø

tk

U U

U


U> = Uset

U = Umeasured

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

Type B curve:

2.0

480

32 0.5 0.035

=×

- >× - -

>

æ öç ÷è ø

tk

U U

U


k = (0.05-1.10) in steps of 0.01

Type C curve:

3.0

480

32 0.5 0.035

=×

- >× - -

>

æ öç ÷è ø

tk

U U

U


k = (0.05-1.10) in steps of 0.01

Programmable curve:

×= +

- >× -

>

æ öç ÷è ø

P

k At D

U UB C

U


k = (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 111. Inverse time characteristics for undervoltage protection


Type A curve:

=< -

<

æ öç ÷è ø

kt

U U

UEQUATION1431-SMALL V1 EN

U< = Uset

U = UVmeasured

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

Type B curve:

2.0

4800.055

32 0.5

×= +

< -× -

<

æ öç ÷è ø

kt

U U

U


U< = Uset

U = Umeasured

k = (0.05-1.10) in steps of 0.01

Programmable curve:

×= +

< -× -

<

é ùê úê úê úæ öê úç ÷ë è ø û

P

k At D

U UB C

U


U< = Uset

U = Umeasured

k = (0.05-1.10) in steps 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 87

Table 112. Inverse time characteristics for residual overvoltage protection


Type A curve:

=- >

>

æ öç ÷è ø

tk

U U

U


U> = Uset

U = Umeasured

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

5% +40 ms

Type B curve:

2.0

480

32 0.5 0.035

=×

- >× - -

>

æ öç ÷è ø

tk

U U

U


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

Type C curve:

3.0

480

32 0.5 0.035

=×

- >× - -

>

æ öç ÷è ø

tk

U U

U


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

Programmable curve:

×= +

- >× -

>

æ öç ÷è ø

P

k At D

U UB C

U


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


88 ABB

21. Ordering

GuidelinesCarefully read and follow the set of rules to ensure problem-free order management.Please refer to the available functions table for included application functions.PCM600 can be used to make changes and/or additions to the delivered factory configuration of the pre-configured.

To obtain the complete ordering code, please combine code from the tables, as given in the example below.Example code: REG670*1.1-A20X00-X00-X0-A-B-A6-X0-CA-XD. Using the code of each position #1-12 specified as REG670*1-2 2-3 3 3 3 3-4 4-5-6-7 7-8-9 9 9-1010 10 10 10 10 10 10 10 10 10-11 11 11 11 11 11-12 12

# 1 - 2 - 3 - 4 - 5 6 - 7 - 8 - 9 -REG670* - - - - - . - -

- 10 - 11 - 12- . -

Po

sitio

n

SOFTWARE #1 Notes and Rules

Version number Version no 1.2

Selection for position #1.

Configuration alternatives #2 Notes and Rules

Gen diff + backup 12 AI A20 Gen diff + backup 24 AI B30 Gen and block transformer protection 24 AI C30 ACT configuration ABB standard configuration X00 Selection for position #2.

Software options #3 Notes and Rules

No option X00 All fields in the ordering form donot need to be filled in

Restricted earth fault protection, low impedance A01 Note: A01 only for B30 High impedance differential protection - 3 blocks A02 Note: A02 only for A20 Transformer differential protection, 2 winding A31 Note: A31 only for A20 Transformer differential protection, 2 and 3 winding A33 Note: A33 only for B30 Pole slip detection B21 Sensitive rotor earth fault protection, injection based B31 100% stator earth fault protection, injection based B32 Sensitive directional residual overcurrent and power protection C16 Four step directional negative phase sequence overcurrent protection - 1 block C41 Note: C41 only for A20 Four step directional negative phase sequence overcurrent protection - 2

blocksC42 Note: C42 only for B30/C30

100% Stator E/F 3rd harmonic D21 Note: D21 only for A20 Apparatus control 30 objects H09 IEC 62439-3 Edition 1 parallel redundancy protocol P01 Note:Require 2-channel OEM IEC 62439-3 Edition 2 parallel redundancy protocol P02 Selection for position #3


ABB 89

First local HMI user dialogue language #4 Notes and Rules

HMI language, English IEC B1 HMI language, English US B2 Additional local HMI user dialogue language HMI language, German A1 HMI language, Russian A2 HMI language, French A3 HMI language, Spanish A4 HMI language, Polish A6 HMI language, Hungarian A7 HMI language, Czech A8 HMI language, Swedish A9 Selection for position #4.

Casing #5 Notes and Rules

1/2 x 19" case A Note: Only for A20 1/1 x 19" case 2 TRM slots E Note: Only for B20 and C30 Selection for position #5.

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

No mounting kit included X 19" rack mounting kit for 1/2 x 19" case of 2xRHGS6 or RHGS12 A Note: Only for A20 19" rack mounting kit for 1/1 x 19" case C Note: Only for B30 and C30 Wall mounting kit D Note: Wall mounting not

recommended withcommunication modules withfibre connection (SLM, OEM,LDCM)

Flush mounting kit E Flush mounting kit + IP54 mounting seal F Selection for position #6.

Connection type for Power supply, Input/output and Communication modules #7 Notes and Rules

Compression terminals K Auxiliary power supply 24-60 VDC A 90-250 VDC B Selection for position #7.

Human machine hardware interface #8 Notes and Rules

Small size - text only, IEC keypad symbols A Medium size - graphic display, IEC keypad symbols B Medium size - graphic display, ANSI keypad symbols C Selection for position #8.


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Connection type for Analog modules #9 Notes and Rules

Compression terminals A Ringlug terminals B Analog system First TRM, 9I+3U 1A, 110/220V 3 Note: Only for B30/C30 First TRM, 9I+3U 5A, 110/220V 4 Note: Only for B30/C30 First TRM, 5I, 1A+4I, 5A+3U, 110/220V 5 Note: Only for B30/C30 First TRM, 7I+5U 1A, 110/220V 12 Note: Only for A20 First TRM, 7I+5U 5A, 110/220V 13 Note: Only for A20 First TRM, 6I, 5A+1I, 1A+5U, 50/60 Hz, 100/220V 14 Note: Only for A20 First TRM, 3I, 5A + 4I, 1A + 5U, 50/60 Hz, 100/220V 15 Note: Only for A20 No second TRM included X0 Note: B30/C30 must include a

second TRM Second TRM, 9I+3U 1A, 110/220V 3 Note: Only for B30 Second TRM, 9I+3U 5A, 110/220V 4 Note: Only for B30 Second TRM, 5I, 1A+4I, 5A+3U, 110/220V 5 Note: Only for B30 Second TRM, 6I+6U 1A, 100/220V 6 Note: Only for C30 Second TRM, 6I+6U 5A, 100/220V 7 Note: Only for C30 Selection for position #9.


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Binary input/output module, mA and time synchronization boards.Note: 1BIM and 1 BOM included.

#10 Notes and Rules

Make BIM with 50 mA inrush current the primary choice. BIM with 50 mA inrush current fulfill additional standards. As a consequence the EMC withstandcapability is further increased.BIM with 30 mA inrush current is still available.For pulse counting, for example kWh metering, the BIM with enhanced pulse counting capabilities must be used.

Slot position (rear view)

X31

X41

X51

X61

X71

X81

X91

X101

X111

X121

X131 Note: Max 3 positions in 1/2 rack

and 11 in 1/1 rack with 2 TRM1/2 Case with 1 TRM █ █ █ Note: Only for A201/1 Case with 2 TRM █ █ █ █ █ █ █ █ █ █ █ Note: Only for B30/C30 No board in slot X X X X X X X X X Binary output module 24 output relays (BOM) A A A A A A A A A A Note: Maximum 4 (BOM+SOM

+MIM) boards. BIM 16 inputs, RL24-30 VDC, 30 mA B B B B B B B B B B BIM 16 inputs, RL48-60 VDC, 30 mA C C C C C C C C C C BIM 16 inputs, RL110-125 VDC, 30 mA D D D D D D D D D D BIM 16 inputs, RL220-250 VDC, 30 mA E E E E E E E E E E BIM 16 inputs, RL24-30 VDC, 50 mA B

1 B

1B1

B1

B1

B1

B1

B1

B1

B1

BIM 16 inputs, RL48-60 VDC, 50 mA C1

C1

C1

C1

C1

C1

C1

C1

C1

C1

BIM 16 inputs, RL110-125 VDC, 50 mA D1

D1

D1

D1

D1

D1

D1

D1

D1

D1

BIM 16 inputs, RL220-250 VDC, 50 mA E1

E1

E1

E1

E1

E1

E1

E1

E1

E1

BIMp 16 inputs, RL24-30 VDC for pulse counting F F F F F F F F F BIMp 16 inputs, RL48-60 VDC for pulse counting G G G G G G G G G BIMp 16 inputs, RL110-125 VDC for pulse counting H H H H H H H H H BIMp 16 inputs, RL220-250 VDC for pulse counting K K K K K K K K K IOM 8 inputs, 10+2 output, RL24-30 VDC, 30 mA L L L L L L L L L IOM 8 inputs, 10+2 output, RL48-60 VDC, 30 mA M M M M M M M M M IOM 8 inputs, 10+2 output, RL110-125 VDC, 30 mA N N N N N N N N N IOM 8 inputs, 10+2 output, RL220-250 VDC, 30 mA P P P P P P P P P IOM 8 inputs, 10+2 output, RL24-30 VDC, 50 mA L1 L1 L1 L1 L1 L1 L1 L1 L1 IOM 8 inputs, 10+2 output, RL48-60 VDC, 50 mA M

1M1

M1

M1

M1

M1

M1

M1

M1

IOM 8 inputs, 10+2 output, RL110-125 VDC, 50 mA N1

N1

N1

N1

N1

N1

N1

N1

N1

IOM 8 inputs, 10+2 output, RL220-250 VDC, 50 mA P1

P1

P1

P1

P1

P1

P1

P1

P1

IOM with MOV 8 inputs, 10-2 output, 24-30 VDC U U U U U U U U U IOM with MOV 8 inputs, 10-2 output, 48-60 VDC V V V V V V V V V IOM with MOV 8 inputs, 10-2 output, 110-125 VDC W W W W W W W W W IOM with MOV 8 inputs, 10-2 output, 220-250 VDC Y Y Y Y Y Y Y Y Y mA input module MIM 6 channels R R R R R R R R R No MIM board in 1/2 case SOM Static outputs module, 12 outputs, 48-60 VDC T1 T1 T1 T1 T1 T1 T1 T1 T1 SOM static outputs module, 12 outputs, 110-250 VDC T2 T2 T2 T2 T2 T2 T2 T2 T2

Selection for position #10.

Remote end communication, DNP serial comm. and time synchronization modules #11 Notes and Rules


X312

X313

X302

X303

X322

X323

Available slots in 1/2 case with 1TRM Note: Max 1 LDCM Available slots in 1/1 case with 2 TRM slots Note: Max 2 LDCM No remote communication board included X X X X X X Optical short range LDCM A A A A A A Note: Max 2 LDCM (same or

different type) can be selected Optical medium range, LDCM 1310 nm B B B B B B IRIG-B Time synchronization module, with PPS F Galvanic RS485 communication module G G G G Selection for position #11.


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Serial communication unit for station communication #12 Notes and Rules


X301

X311

No first communication board included X No second communication board included X Serial and LON communication module (plastic) A Note: Optical ethernet module, 2

channel glass is not allowedtogether with SLM. Serial (plastic) and LON (glass) communication module B

Serial and LON communication module (glass) C Serial IEC 60870-5-103 plastic interface F Serial IEC 60870-5-103 plastic/glass interface G Serial IEC 60870-5-103 glass interface H Optical ethernet module, 1 channel glass D Optical ethernet module, 2 channel glass E Selection for position #12.

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.

AccessoriesGPS antenna and mounting details

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

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

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

Interface converter (for remote end data communication)

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

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

Test switchThe test system COMBITEST intended for use with the IED670 products 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 varietyof applications possible the test switches needs to beselected for each specific application.

Select your suitable test switch based on the availablecontacts arrangements shown in the referencedocumentation.

However our proposals for suitable variants are:

Two winding transformer with internal neutral on currentcircuits. Two pcs can be used in applications for threewinding transformers in single or multi-breaker arrangement(ordering number RK926 315-BD)

Two winding transformer with external neutral on currentcircuits. Two pcs can be used in applications for threewinding transformers in single or multi-breaker arrangement(ordering number 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 test


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function block to allow activation of functions individuallyduring testing.

Test switches type RTXP 24 is ordered separately. Pleaserefer to Section "Related documents" for reference tocorresponding documents.

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.

Protection cover

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, 1/1 x 19” Quantity: 1MRK 002 420-AA

External resistor unit

High impedance resistor unit 1-ph with resistor and voltage dependent resistor for20-100V operating voltage

Quantity:

1 2 3 RK795101-MA


Quantity: RK795101-MB


Quantity:

1 2 3 RK795101-CB


Quantity: RK795101-DC


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Injection equipment

Rule: If Sensitive rotor earth fault protection, injection based (option B31) or 100% stator earth fault protection,injection based (option B32) 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,injection based (option B32) 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,injection based (option B31) 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 REX060and that Sensitive rotor earth fault protection, injection based (option B31) is selected/active inREG670.

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

Rule: REX062 requires REX060 and that Stator injection module (SIM) is selected in REX060and that 100% stator earth fault protection, injection based (option B32) is selected/active inREG670

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

Combiflex

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.


ABB 95

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


96 ABB

User documentation

Rule: Specify the number of printed manuals requested

Operator’s manual IEC Quantity: 1MRK 502 028-UEN

ANSI Quantity: 1MRK 502 028-UUS

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


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


Application manual IEC Quantity: 1MRK 502 030-UEN


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

Reference information

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

Country: End user:

Station name: Voltage level: kV

Generator manufacturer: Rated power: MVA

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

Related documents

Documents related to REG670 Identity number

Operator’s manual 1MRK 502 028-UEN

Installation and commissioning manual 1MRK 502 029-UEN

Technical reference manual 1MRK 502 027-UEN

Application manual 1MRK 502 030-UEN

Product guide customized 1MRK 502 031-BEN

Product guide pre-configured 1MRK 502 032-BEN

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


ABB 97

Connection and Installation components 1MRK 513 003-BEN

Test system, COMBITEST 1MRK 512 001-BEN

Accessories for 670 series IEDs 1MRK 514 012-BEN

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

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

Engineering manual 670 series 1MRK 511 240-UEN

Buyer’s guide REG 216 1MRB520004-BEN

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

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


98 ABB

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Contact us

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

www.abb.com/substationautomation

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