busbar protection reb670 customized product guide

Relion® 670 series

Busbar protection REB670CustomizedProduct Guide

Contents

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

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

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

4. Zone selection..............................................................15

5. Current protection........................................................17

6. Voltage protection........................................................19

7. Frequency protection....................................................19

8. Multipurpose protection................................................20

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

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

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

12. Monitoring...................................................................22

13. Metering......................................................................24

14. Basic IED functions.....................................................24

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

16. Station communication ...............................................26

17. Remote communication..............................................27

18. Hardware description..................................................28

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

20. Technical data.............................................................36

21. Ordering......................................................................72

Disclaimer

The information in this document is subject to change without notice and should not be construed as a commitment by ABB AB. ABB AB 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 ABB Group. All other brand or product names mentioned in this document may be trademarks or registered trademarks

of their respective holders.

Busbar protection REB670 1MRK 505 273-BEN BCustomized Product version: 1.2

2 ABB

1. ApplicationREB670 is designed for the selective, reliable andfast differential protection of busbars, T-connections and meshed corners. REB670 canbe used for protection of single and doublebusbar with or without transfer bus, double circuitbreaker or one-and-half circuit breaker stations.The IED is applicable for the protection of mediumvoltage (MV), high voltage (HV) and extra highvoltage (EHV) installations at a power systemfrequency of 50Hz or 60Hz. The IED can detectall types of internal phase-to-phase and phase-to-earth faults in solidly earthed or low impedanceearthed power systems, as well as all internalmulti-phase faults in isolated or high-impedanceearthed power systems.

Ordering of VT inputs inside of the busbarprotection IED will allow integration of voltagerelated functionality like under-voltage release,residual over-voltage, power functions, meteringand voltage recording during the faults. Howeverattention shall be given to the fact that inclusionof VT inputs will reduce number of available CTinputs (in total 24 analogue inputs are the productlimit). Consequently when VT inputs are orderedthe busbar protection IED will be applicable forbuses with a fewer number of bays. Practicallythe number of available CT inputs will limit thesize of the station which can be protected.

REB670 has very low requirements on the maincurrent transformers (that is, CTs) and nointerposing current transformers are necessary.For all applications, it is possible to include andmix main CTs with 1A and 5A rated secondarycurrent within the same protection zone.Typically, CTs with up to 10:1 ratio difference canbe used within the same differential protectionzone. Adjustment for different main CT ratios isachieved numerically by a parameter setting.

The numerical, low-impedance differentialprotection function is designed for fast andselective protection for faults within protectedzone. All connected CT inputs are provided with arestraint feature. The minimum pick-up value forthe differential current is set to give a suitablesensitivity for all internal faults. For busbarprotection applications typical setting value forthe minimum differential operating current is from50% to 150% of the biggest CT. This setting ismade directly in primary amperes. The operatingslope for the differential operating characteristic isfixed to 53% in the algorithm.

The fast tripping time of the low-impedancedifferential protection function is especiallyadvantageous for power system networks withhigh fault levels or where fast fault clearance isrequired for power system stability.

The advanced open CT detection algorithmdetects instantly the open CT secondary circuitsand prevents differential protection operationwithout any need for additional check zone.

Differential protection zones in REB670 include asensitive operational level. This sensitiveoperational level is designed to be able to detectinternal busbar earth faults in low impedanceearthed power systems (that is, power systemswhere the earth-fault current is limited to a certainlevel, typically between 300A and 2000A primaryby a neutral point reactor or resistor). Alternativelythis sensitive level can be used when highsensitivity is required from busbar differentialprotection (that is, energizing of the bus via longline).

Overall operating characteristic of the differentialfunction in REB670 is shown in figure 1.

Busbar protection REB670 1MRK 505 273-BEN BCustomized Product version: 1.2 Issued: May 2012

Revision: B

ABB 3

Differential protectionoperation characteristic

Operateregion

Diff Oper Level

I d [P

rimar

y Am

ps]

Iin [Primary Amps]

s=0.53

I d=I in

Sensitivedifferentialprotection

en06000142.vsd

Sensitive Oper Level Sens Iin Block

IEC06000142 V1 EN

Figure 1. REB670 operating characteristic

Integrated overall check zone feature,independent from any disconnector position, isavailable. It can be used in double busbar stationsto secure stability of the busbar differentialprotection in case of entirely wrong statusindication of busbar disconnector in any of thefeeder bays.

Flexible, software based dynamic Zone Selectionenables easy and fast adaptation to the mostcommon substation arrangements such as singlebusbar with or without transfer bus, doublebusbar with or without transfer bus, one-and-a-half breaker stations, double busbar-doublebreaker stations, ring busbars, and so on. Thesoftware based dynamic Zone Selections ensures:

• Dynamic linking of measured CT currents tothe appropriate differential protection zoneas required by substation topology

• Efficient merging of the two differential zoneswhen required by substation topology (that isload-transfer)

• Selective operation of busbar differentialprotection ensures tripping only of circuitbreakers connected to the faulty zone

• Correct marshaling of backup-tripcommands from internally integrated or

external circuit breaker failure protections toall surrounding circuit breakers

• Easy incorporation of bus-section and/or bus-coupler bays (that is, tie-breakers) with oneor two sets of CTs into the protection scheme

• Disconnector and/or circuit breaker statussupervision

Advanced Zone Selection logic accompanied byoptionally available end-fault and/or circuitbreaker failure protections ensure minimumpossible tripping time and selectivity for faultswithin the blind spot or the end zone between bayCT and bay circuit breaker. Therefore REB670offers best possible coverage for such faults infeeder and bus-section/bus-coupler bays.

Optionally available circuit breaker failureprotection, one for every CT input into REB670,offers secure local back-up protection for thecircuit breakers in the station.

Optionally available four-stage, non-directionalovercurrent protections, one for every CT inputinto REB670, provide remote backup functionalityfor connected feeders and remote-end stations.

Optionally available voltage and frequencyprotection functions open possibility to include


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voltage release criterion for busbar protection orto integrate independent over-, under-voltageprotection for the bus in the busbar protectionIED.

Optionally available over-current, thermal overloadand capacitor bank protection functions openpossibilities to integrate protection of shuntreactors and shunt capacitor banks into thebusbar protection IED.

It is normal practice to have just one busbarprotection IED per busbar. Nevertheless someutilities do apply two independent busbarprotection IEDs per zone of protection. REB670IED fits both solutions.

A simplified bus differential protection for multi-phase faults and earth faults can be obtained byusing a single, one-phase REB670 IED withexternal auxiliary summation current transformers.

The wide application flexibility makes this productan excellent choice for both new installations andthe refurbishment of existing installations.

Optional apparatus control for up to 30 objectscan provide a facility to draw simplified single linediagram (SLD) of the station on the local HMI.Note that in such case medium-size, graphicdisplay shall be ordered.

Application examples of REB670Examples of typical station layouts, which can beprotected with REB670 are given below:

IEC11000237-1-en.vsdIEC11000237 V1 EN

Figure 2. Example of T-connection

BI1 BI1 BI1 BI1 BI1 BI1 BI1

QA1 QA1 QA1 QA1 QA1 QA1 QA1

QB1ZA ZB

IEC11000238-1-en.vsdIEC11000238 V1 EN

Figure 3. Example of single bus station


ABB 5

BI1

QA1

QB1 QB7

BI1

QB7QB1

QA1

BI1

QB7QB1

QA1

BI1

QB7QB1

QA1

BI1

QB7QB1

QA1

ZA

ZB

BI1

QB7QB1

QA1

xx06000013.vsdIEC06000013 V1 EN

Figure 4. Example of single bus station with transfer bus

BI1

QA1

QB1 QB2

BI1

QA1

QB1 QB2

BI1

QA1

QB1 QB2

BI1

QA1

QB1 QB2

BI1

QA1

QB1 QB2BI1

QA1

BI1

QB1 QB2

QA1

ZA

ZB

IEC11000239-1-en.vsdIEC11000239 V1 EN

Figure 5. Example of double bus-single breaker station

BI1

QB1 QB2 QB7

BI1

QB1 QB2 QB7

BI1

QB1 QB2 QB7

BI1

QB1 QB2 QB7

BI1

QB20QB2 QB7QB1

QA1 QA1 QA1 QA1 QA1

ZAZB

xx06000015.vsdIEC06000015 V1 EN

Figure 6. Example of double bus-single breaker station with transfer bus


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BI1

QA1

QB1 QB2

BI1

QA1

QB1 QB2

BI1

QA1

QB1 QB2

BI1

QA1

QB1 QB2

BI1

QA1

QB1 QB2

BI1

QA1

QB1 QB2

BI1

QA1

QB1 QB2

BI1

QA1

QB1 QB2BI1

QA1

BI1 QA1

BI1 QA1

BI1

QB1 QB2

QA1

BI1

QA1

ZA1

ZB1

ZA2

ZB2

xx06000016.vsd

IEC06000016 V1 EN

Figure 7. Example of double bus-single breaker station with two bus-section and two bus-coupler breakers

BI3

BI1

QA1

BI2

QA2

QA3

BI3

BI1

QA1

BI2

QA2

QA3

BI3

BI1

QA1

BI2

QA2

QA3

BI3

BI1

QA1

BI2

QA2

QA3

BI3

BI1

QA1

BI2

QA2

QA3

ZA

ZB

IEC11000240-1-en.vsdIEC11000240 V1 EN

Figure 8. Example of one-and-a-half breaker station

QA1

BI1 BI2

QA2 QA1

BI1 BI2

QA2 QA1

BI1 BI2

QA2 QA1

BI1 BI2

QA2 QA1

BI1 BI2

QA2

ZA

ZB

xx06000018.vsdIEC06000018 V1 EN

Figure 9. Example of double bus-double breaker station


ABB 7

QB32

QB12BI1

QA3BI3

BI8

QA4

BI4

QA2

BI2

BI5

BI6BI7

QB5QB8

QB6QB7

QB31

QB11

QB42 QB22

QB21QB41

QA1ZA1 ZA2

ZB1 ZB2

xx06000019.vsdIEC06000019 V1 EN

Figure 10. Example of mesh or ring bus station

Note that customized REB670 is delivered without any configuration. Thus the complete IEDengineering shall be done by the customer or its system integrator. In order to secure properoperation of the busbar protection it is strictly recommended to always start engineering work fromthe PCM600 project for the pre-configured REB670 which is the closest to the actual application.Then, necessary modifications shall be applied in order to adopt the customized IED configurationto suite the actual station layout. The PCM600 project for the pre-configured REB670 IEDs isavailable in the Connectivity Package DVD.


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2. Available functions

Main protection functions

2 = number of basic instances0-3 = option quantities

IEC 61850 ANSI Function description Busbar

REB670

Differential protection

BUTPTRC,BCZTPDIF,BZNTPDIF,BZITGGIO

87B Busbar differential protection, 2 zones, three phase/up to 8 bays 0-1

BUSPTRC,BCZSPDIF,BZNSPDIF,BZISGGIO

87B Busbar differential protection, 2 zones, single phase/up to 24 bays 0-1

SWSGGIO Status of primary switching object for busbar protection zoneselection

96


ABB 9

Back-up protection functions


REB670

Current protection

OC4PTOC 51_67 Four step phase overcurrent protection 0-8

PH4SPTOC 51 Four step single phase overcurrent protection 0-24

TRPTTR 49 Thermal overload protection, two time constant 0-2

CCRBRF 50BF Breaker failure protection 0-8

CCSRBRF 50BF Breaker failure protection, single phase version 0-24

GUPPDUP 37 Directional underpower protection 0-4

GOPPDOP 32 Directional overpower protection 0-4

CBPGAPC Capacitor bank protection 0-2

Voltage protection

UV2PTUV 27 Two step undervoltage protection 0-2

OV2PTOV 59 Two step overvoltage protection 0-2

ROV2PTOV 59N Two step residual overvoltage protection 0-2

VDCPTOV 60 Voltage differential protection 0-2

LOVPTUV 27 Loss of voltage check 0-2

Frequency protection

SAPTUF 81 Underfrequency protection 0-6

SAPTOF 81 Overfrequency protection 0-6

SAPFRC 81 Rate-of-change frequency protection 0-6

Multipurpose protection

CVGAPC General current and voltage protection 0-6


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Control and monitoring functions


REB670

Control

SMBRREC 79 Autorecloser 0-2

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

0-1

QCBAY Apparatus control 1

LocalRemote

Handling of LRswitch positions 1

LocRemControl

LHMI control of PSTO 1

SLGGIO Logic rotating switch for function selection and LHMI presentation 15

VSGGIO Selector mini switch 20

DPGGIO IEC61850 generic communication I/O functions 16

SPC8GGIO Single pole generic control 8 signals 5

AutomationBits AutomationBits, command function for DNP3.0 3

Single command, 16 signals 4

Secondary system supervision

SDDRFUF Fuse failure supervision 0-2

Logic

Configuration logic blocks 40-280

Fixed signal function blocks 1

B16I Boolean 16 to Integer conversion 16

B16IFCVI Boolean 16 to Integer conversion with Logic Node representation 16

IB16 Integer to Boolean 16 conversion 16

IB16FVCB Integer to Boolean 16 conversion with Logic Node representation 16

Monitoring

CVMMXN Measurements 6

CNTGGIO Event counter 5

Event Event function 20

DRPRDRE Disturbance report 1

SPGGIO IEC61850 generic communication I/O functions 64

SP16GGIO IEC61850 generic communication I/O functions 16 inputs 16

MVGGIO IEC61850 generic communication I/O functions 24


ABB 11


REB670

BSStartReport

Logical signal status report 3

RANGE_XP Measured value expander block 28

Metering

PCGGIO Pulse-counter logic 16

ETPMMTR Function for energy calculation and demand handling 6

Designed to communicate


REB670

Station communication

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

1

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

1

Parameter setting function forIEC61850

1

IntlReceive Horizontal communication viaGOOSE for interlocking

59

Goose binary receive 10

Multiple command and transmit 60/10

Ethernet configuration of links 1

IEC 62439-3 Edition 1 parallelredundancy protocol

0-1

IEC 62439-3 Edition 2 parallelredundancy protocol

0-1


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 protectionThe function consists of differential protectionalgorithm, sensitive differential protectionalgorithm, check zone algorithm, open CTalgorithm and two supervision algorithms.

Busbar differential protectionThis protection function is intended for fast andselective tripping of faults within protected zone.For each current input, the CT ratio can be setfrom the front HMI or via the parameter-settingtool, PCM600. In this way adaptation to differentCT ratios is provided in the simplest way. The


ABB 13

minimum pick-up value for the differential currentis then set to give a suitable sensitivity for allinternal faults. This setting is made directly inprimary amperes. For busbar protectionapplications typical setting value for the minimumdifferential operating current is from 50% to 150%of the biggest CT. The settings can be changedfrom the front HMI or via the parameter-settingtool, PCM600.

All current inputs are indirectly provided with arestraint feature. The operation is based on thewell-proven RADSS percentage restraintstabilization principle, with an extra stabilizationfeature to stabilize for very heavy CT saturation.Stability for external faults is guaranteed if a CT isnot saturated for at least two milliseconds duringeach power system cycle. It is also possible toadd external tripping criteria by binary signal.

The trip command from the differential protectionincluding sensitive differential protection andcircuit breaker failure backup-trip commands canbe set either as self-resetting or latched. Insecond case the manual reset is needed in orderto reset the individual bay trip output contacts.

Sensitive differential level BZISGGIODifferential protection zones in REB670 include asensitive operational level. This sensitiveoperational level is designed to be able to detectinternal busbar earth faults in low impedanceearthed power systems (i.e. power systems wherethe earth-fault current is limited to a certain level,typically between 300A and 2000A primary by aneutral point reactor or resistor). For increasedsecurity, the sensitive differential protection mustbe externally enabled by a binary signal (e.g. fromopen delta VT overvoltage relay or powertransformer neutral point overcurrent relay). Finallyit is as well possible to set a time delay before thetrip signal from the sensitive differential protectionis given. This sensitive level can be alternativelyused in special applications when high sensitivityis required from busbar differential protection (i.e.energizing of dead bus via a long line).

Operation and operating characteristic of thesensitive differential protection can be setindependently from the operating characteristic ofthe main differential protection. However, thesensitive differential level is blocked as soon asthe total incoming current exceeds the pre-set

level or when differential current exceed the setminimum pickup current for the usual differentialprotection. Therefore, by appropriate settings itcan be ensured that this sensitive level is blockedfor all external multi-phase faults, which cancause CT saturation. Operating characteristic ofsensitive differential characteristics is shown infigure 1.

Check zoneFor busbar protection in double busbar stationswhen dynamic zone selection is needed, it issometimes required to include the overalldifferential zone (that is, check zone). Hence, thebuilt-in, overall check zone is available in the IED.Because the built-in check zone currentmeasurement is not dependent on thedisconnector status, this feature ensures stabilityof Busbar differential protection even forcompletely wrong status indication from thebusbar disconnectors. It is to be noted that theoverall check zone, only supervise the usualdifferential protection operation. The external tripcommands, breaker failure backup-tripcommands and sensitive differential protectionoperation are not supervised by the overall checkzone.

The overall check zone has simple currentoperating algorithm, which ensures check zoneoperation for all internal faults regardless the faultcurrent distribution. To achieve this, the outgoingcurrent from the overall check zone is used asrestraint quantity. If required, the check zoneoperation can be activated externally by a binarysignal.

Open CT detectionThe innovative measuring algorithm providesstability for open or short-circuited main CTsecondary circuits, which means that no separatecheck zone is actually necessary. Start currentlevel for open CT detection can usually be set todetect the open circuit condition for the smallestCT. This built-in feature allows the protectionterminal to be set very sensitive, even to a lowervalue than the maximum CT primary rating in thestation. At detection of problems in CT secondarycircuits, the differential protection can be instantlyblocked and an alarm is given. Alternatively, thedifferential protection can be automaticallydesensitized in order to ensure busbar differentialprotection stability during normal through-load


14 ABB

condition. When problems in CT secondarycircuits have been found and associated error hasbeen corrected a manual reset must be given tothe IED. This can be done locally from the localHMI, or remotely via binary input orcommunication link.

However, it is to be noted that this feature canonly be partly utilized when the summationprinciple is in use.

Differential protection supervisionDual monitoring of differential protection status isavailable. The first monitoring feature operatesafter settable time delay when differential currentis higher than the user settable level. This featurecan be, for example, used to design automaticreset logic for previously described open CTdetection feature. The second monitoring featureoperates immediately when the busbar through-going current is bigger than the user settablelevel. Both of these monitoring features are phasesegregated and they give out binary signals,which can be either used to trigger disturbancerecorder or for alarming purposes.

4. Zone selectionTypically CT secondary circuits from every bay inthe station are connected to the busbarprotection. The built-in software feature called“Zone Selection” gives a simple but efficientcontrol over the connected CTs to busbarprotection IED in order to provide fully operationaldifferential protection scheme for multi-zoneapplications on both small and large buses.

The function consists of dedicated disconnector/circuit breaker status monitoring algorithm, baydedicated CT-connection control algorithm andzone interconnection algorithm.

Switch status monitoringFor stations with complex primary layout (that is,double busbar single breaker station with orwithout transfer bus) the information about busbardisconnector position in every bay is crucialinformation for busbar protection. The positions ofthese disconnectors then actually determinewhich CT input (that is, bay) is connected towhich differential protection zone. For some moreadvanced features like end-fault or blind-spotprotection the actual status of the circuit breakerin some or even all bays can be vital information

for busbar protection as well. The switch functionblock is used to take the status of two auxiliarycontacts from the primary device, evaluate themand then to deliver the device primary contactposition to the rest of the zone selection logic.

For such applications typically two auxiliarycontacts (that is, normally open and normallyclosed auxiliary contacts) from each relevantprimary switching object shall be connected tothe IED. Then the status for every individualprimary switching object will be determined. Thededicated function block for each primaryswitching object is available in order to determinethe status of the object primary contacts. By aparameter setting one of the following two logicalschemes can be selected for each primary objectindividually by the end user:

• If not open then closed (that is, as in RADSSschemes)

• Open or closed only when clearly indicatedby aux contact status (that is, as in INXschemes)

Table 1 gives quick overview about both schemes.

Note that the first scheme only requires fastbreaking normally closed auxiliary contact (that is,b contact) for proper operation. The timing ofnormally open auxiliary contact is not criticalbecause it is only used for supervision of theprimary object status. The second scheme inaddition requires properly timed-adjusted, early-making normally open auxiliary contact (that is,early making a contact) for proper operation.

Regardless which scheme is used the time-delayed disconnector/circuit breaker statussupervision alarm is available (that is, 00 or 11auxiliary contact status). How two integrateddifferential protection zones behave whendisconnector alarm appears is freely configurableby the end user.

It is possible by a parameter setting to overridethe primary object status as either permanentlyopen or permanently closed. This feature can beuseful during testing, installation andcommissioning of the busbar protection scheme.At the same time, separate alarm is given toindicate that the actual object status isoverwritten by a setting parameter.


ABB 15

It is to be noted that it is as well possible to useonly normally closed auxiliary contacts for Zone

Selection logic. In that case the Switch functionblocks are not used.

Table 1. Treatment of primary object auxiliary contact status

Primary equipment Status in busbar protection Alarm facility

Normally Openauxiliarycontact status(that is,“closed” or“a” contact)

NormallyClosedauxiliarycontact status(that is,“open” or “b”contact)

when“Scheme 1RADSS”is selected

when“Scheme 2INX”is selected

Alarm aftersettable timedelay

Information visible on localHMI

open open closed Last positionsaved

yes intermediate_00

open

closed open open no open

closed

open closed closed no closed

closed closed closed closed yes badState_11

BayEach CT input is allocated to one dedicated bayfunction block. This function block is used toprovide complete user interface for all signalsfrom and towards this bay. It is also used toinfluence bay measured current.

It is possible by a parameter settingCTConnection to connect or disconnect the CTinput to the bay function block. Once the CT inputis connected to the bay function block thisassociated current input can be included to orexcluded from the two internally availabledifferential functions in software. This can bedone by a parameter setting for simple stationlayouts (that is, one-and-a-half breaker stations)or alternatively via dedicated logical scheme (thatis, double busbar stations). For each bay the enduser have to select one of the following fivealternatives:

• Permanently connect this bay current tozone A (that is, ZA)

• Permanently connect this bay current tozone B (that is, ZB)

• Permanently connect this bay current tozone A and inverted bay current to ZB (thatis, ZA and ZB)

• Connect this bay current to ZA or ZBdepending on the logical status of the two

input binary signals available on this bayfunction block. These two input signals willinclude measured current to the respectivezone when their logical value is one (that is,CntrlIncludes). This option is used togetherwith above described Switch function blocksin order to provide complete Zone Selectionlogic

• Connect the bay current to ZA or ZBdepending on the logical status of the twoinput binary signals available on this bayfunction block. These two signals will includemeasured current to the respective zonewhen their logical value is zero (that is,CntrlExcludes). This option is typically usedwhen only normally closed auxiliary contactsfrom the busbar disconnector are availableto the Zone Selection logic

At the same time, an additional feature forinstantaneous or time delayed disconnection oreven inversion of the connected bay current viaseparate logical signals is also available. Thisfeature is provided in order to facilitate for bus-section or bus-coupler CT disconnection for tie-breakers with a CT only on one side of the circuitbreaker. This ensures correct and fast faultclearance of faults between the CT and the circuitbreaker within these bays. The same feature canbe individually used in any feeder bay to optimizeBusbar differential protection performance, when


16 ABB

feeder circuit breaker is open. Thus, the end-faultprotection for faults between circuit breaker andthe CT is available. However, to use this featurecircuit breaker auxiliary contacts and closingcommand to the circuit breaker shall be wired tothe binary inputs of the IED. Therefore, he IEDoffers best possible coverage for these specialfaults between CT and circuit breaker in feederand bus-section/bus-coupler bays.

Within the Bay function block it is decided by aparameter setting how this bay should behaveduring zone interconnection (that is, loadtransfer). For each bay individually one of thefollowing three options can be selected:

• Bay current is forced out from both zonesduring zone interconnection (used for bus-coupler bays)

• Bay current is unconditionally forced intoboth zones during zone interconnection(used in special applications)

• Bay current is connected to both zonesduring zone interconnection if the bay waspreviously connected to one of the twozones (typically used for feeder bays)

The third option ensures that the feeder, which isout of service, is not connected to any of the twozones during zone interconnection.

Within the Bay function block it is decided by aparameter setting whether this bay should beconnected to the check zone or not. In this waythe end user has simple control over the bays,which shall be connected to the overall checkzone.

By appropriate configuration logic it is possible totake any bay (that is, CT input) out of service. Thiscan be done from the local HMI or externally viabinary signal. In that case all internal currentmeasuring functions (that is, differentialprotection, sensitive differential protection, check

zone, breaker failure protection and overcurrentprotection) are disabled. At the same time, anytrip command to this bay circuit breaker can beinhibited.

Via two dedicated binary input signals it ispossible to:

• Trip only the bay circuit breaker (used forintegrated OC protection tripping)

• Trip the whole differential zone to which thisbay is presently connected (used for backup-trip command from either integrated orexternal bay circuit breaker failure protection)

Finally dedicated trip binary output from the Bayfunction block is available in order to providecommon trip signal to the bay circuit breaker frombusbar differential protection, breaker failureprotection, backup overcurrent protection and soon.

In this way the interface to the user is kept assimple as possible and IED engineering work isquite straight forward.

Zone interconnection (Load transfer)When this feature is activated the two integrateddifferential protection zones are merged into onecommon, overall differential zone. This feature isrequired in double busbar stations when in any ofthe feeder bays both busbar disconnectors areclosed at the same time (that is, load transfer). Asexplained in above section Bay each CT input willthen behave in the pre-set way in order to ensureproper current balancing during this specialcondition. This feature can be startedautomatically (when Zone Selection logicdetermines that both busbar disconnectors in onefeeder bay are closed at the same time) orexternally via dedicated binary signal. If thisfeature is active for longer time than the pre-setvale the alarm signal is given.

5. Current protection

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

All IEC and ANSI inverse time characteristics areavailable together with an optional user definedtime characteristic.

The directional function is voltage polarized withmemory. The function can be set to be directional


ABB 17

or non-directional independently for each of thesteps.

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

This function can be used as a backup bayprotection (e.g. for transformers, reactors, shuntcapacitors and tie-breakers). A special applicationis to use this phase overcurrent protection todetect short-circuits between the feeder circuitbreaker and feeder CT in a feeder bay when thecircuit breaker is open. This functionality is calledend-fault protection. In such case unnecessarilyoperation of the busbar differential protection canbe prevented and only fast overcurrent trip signalcan be sent to the remote line end. In order toutilize this functionality the circuit breaker statusand CB closing command must be connected tothe REB670. One of the overcurrent steps can beset and configured to act as end-fault protectionin REB670.

Four step single phase overcurrent protectionPH4SPTOCFour step single phase overcurrent protection(PH4SPTOC)has an inverse or definite time delayindependent for each step separately.

All IEC and ANSI time delayed characteristics areavailable together with an optional user definedtime characteristic.

The function is normally used as end faultprotection to clear faults between currenttransformer and circuit breaker.

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

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

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

Breaker failure protection CCRBRFBreaker failure protection (CCRBRF) ensures fastback-up tripping of surrounding breakers in casethe own breaker fails to open. CCRBRF can becurrent based, contact based, or an adaptivecombination of these two conditions.

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

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

CCRBRF can be single- or three-phase initiatedto allow use with single phase trippingapplications. For the three-phase version ofCCRBRF the current criteria can be set to operateonly if two out of four for example, two phases orone phase plus the residual current start. Thisgives a higher security to the back-up tripcommand.

CCRBRF function can be programmed to give asingle- or three-phase re-trip of the own breakerto avoid unnecessary tripping of surroundingbreakers at an incorrect initiation due to mistakesduring testing.

Breaker failure protection, single phase versionCCSRBRFBreaker failure protection, single phase version(CCSRBRF) function ensures fast back-uptripping of surrounding breakers.

A current check with extremely short reset time isused as check criteria to achieve a high securityagainst unnecessary operation.

CCSRBRF can be programmed to give a re-trip ofthe own breaker to avoid unnecessary tripping ofsurrounding breakers at an incorrect starting dueto mistakes during testing.

Directional over/underpower protectionGOPPDOP/GUPPDUPThe directional over-/under-power protectionGOPPDOP/GUPPDUP can be used wherever a


18 ABB

high/low active, reactive or apparent powerprotection or alarming is required. The functionscan alternatively be used to check the direction ofactive or reactive power flow in the power system.There are a number of applications where suchfunctionality is needed. Some of them are:

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

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

Capacitor bank protection (CBPGAPC)Shunt Capacitor Banks (SCB) are used in a powersystem to provide reactive power compensationand power factor correction. They are as wellused as integral parts of Static Var Compensators(SVC) or Harmonic Filters installations. Capacitorbank protection (CBPGAPC) function is speciallydesigned to provide protection and supervisionfeatures for SCBs.

6. Voltage protection

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

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

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

Two step overvoltage protection (OV2PTOV)function can be used to detect open line ends,normally then combined with a directional reactiveover-power function to supervise the systemvoltage. When triggered, the function will causean alarm, switch in reactors, or switch outcapacitor banks.

OV2PTOV has two voltage steps, each of themwith inverse or definite time delayed.

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

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

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

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

Reset delay ensures operation for intermittentearth faults.

Voltage differential protection VDCPTOVA voltage differential monitoring function isavailable. It compares the voltages from two threephase sets of voltage transformers and has onesensitive alarm step and one trip step.

Loss of voltage check LOVPTUVLoss of voltage check (LOVPTUV) is suitable foruse in networks with an automatic systemrestoration function. LOVPTUV issues a three-pole trip command to the circuit breaker, if allthree phase voltages fall below the set value for atime longer than the set time and the circuitbreaker remains closed.

7. Frequency protection

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

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

SAPTUF is provided with an undervoltageblocking.

The operation is based on positive sequencevoltage measurement and requires two phase-phase or three phase-neutral voltages to beconnected. For information about how to connect


ABB 19

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

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

Overfrequency occurs at sudden load drops orshunt faults in the power network. Close to thegenerating plant, generator governor problemscan also cause over frequency.

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

SAPTOF is provided with an undervoltageblocking.

The operation is based on positive sequencevoltage measurement and requires two phase-phase or three phase-neutral voltages to beconnected. For information about how to connectanalog inputs, refer to Application manual/IEDapplication/Analog inputs/Setting guidelines

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

SAPFRC is provided with an undervoltageblocking. The operation is based on positivesequence voltage measurement and requires twophase-phase or three phase-neutral voltages tobe connected. For information about how toconnect analog inputs, refer to Applicationmanual/IED application/Analog inputs/Settingguidelines.

8. Multipurpose protection

General current and voltage protection CVGAPCThe General current and voltage protection(CVGAPC) can be utilized as a negative or zerosequence current and/or voltage protection

detecting unsymmetrical conditions such as openphase or unsymmetrical faults.

9. Secondary system supervision

Fuse failure supervision SDDRFUFThe aim of the fuse failure supervision function(SDDRFUF) is to block voltage measuringfunctions at failures in the secondary circuitsbetween the voltage transformer and the IED inorder to avoid unwanted operations thatotherwise might occur.

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

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

negative-sequence current 3I2.

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

residual current 3I0.

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

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


20 ABB

10. Control

Autorecloser SMBRRECThe autoreclosing function provides high-speedand/or delayed three pole autoreclosing. Theautoreclosing can be used for delayed busbarrestoration. One Autorecloser (SMBRREC) perzone can be made available.

Apparatus control APCThe apparatus control functions are used forcontrol and supervision of circuit breakers,disconnectors and earthing switches within a bay.Permission to operate is given after evaluation ofconditions from other functions such asinterlocking, synchrocheck, operator placeselection and external 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 processedand the resulting position is not supervised.However with enhanced security, the command isprocessed and the resulting position is supervised.

Normal security means that only the command isevaluated and the resulting position is notsupervised. Enhanced security means that thecommand is evaluated with an additionalsupervision of the status value of the controlobject. The command security with enhancedsecurity is always terminated by aCommandTermination service primitive.

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

Logic rotating switch for function selection andLHMI presentation SLGGIOThe logic rotating switch for function selectionand LHMI presentation function (SLGGIO) (or theselector switch function block) is used to get aselector switch functionality similar to the oneprovided by a hardware selector switch.Hardware selector switches are used extensivelyby utilities, in order to have different functionsoperating on pre-set values. Hardware switchesare however sources for maintenance issues,lower system reliability and an extended purchaseportfolio. The logic selector switches eliminate allthese problems.

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

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

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

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

AutomationBits, command function for DNP3.0AUTOBITSAutomationBits function for DNP3 (AUTOBITS) isused within PCM600 to get into the configurationof the commands coming through the DNP3


ABB 21

protocol. The AUTOBITS function plays the samerole as functions GOOSEBINRCV (for IEC 61850)and MULTICMDRCV (for LON).

Single command, 16 signalsThe IEDs can receive commands either from asubstation automation system or from the localHMI. The command function block has outputsthat can be used, for example, to control highvoltage apparatuses or for other user definedfunctionality.

11. Logic

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

• OR function block.

• INVERTER function blocks that inverts the inputsignal.

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

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

• XOR function block.

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

• TIMERSET function has pick-up and drop-outdelayed outputs related to the input signal. Thetimer has a settable time delay.

• AND function block.

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

• RSMEMORY function block is a flip-flop thatcan reset or set an output from two inputsrespectively. Each block has two outputs whereone is inverted. The memory setting controls if

the block's output should reset or return to thestate it was, after a power interruption. RESETinput has priority.

Fixed signal function blockThe Fixed signals function (FXDSIGN) generates anumber of pre-set (fixed) signals that can be usedin the configuration of an IED, either for forcingthe unused inputs in other function blocks to acertain level/value, or for creating certain logic.

12. Monitoring

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

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

• measured currents• 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 measureand process signals from different measuringtransducers. Many devices used in processcontrol represent various parameters such asfrequency, temperature and DC battery voltage aslow current values, usually in the range 4-20 mAor 0-20 mA.

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

The function requires that the IED is equippedwith the mA input module.

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


22 ABB

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

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

The Disturbance report functionality is a commonname for several functions:

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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


ABB 23

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

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

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

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

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

Event functionWhen using a Substation Automation system withLON or SPA communication, time-tagged eventscan be sent at change or cyclically from the IEDto the station level. These events are created fromany available signal in the IED that is connectedto the Event function (EVENT). The event functionblock is used for LON and SPA communication.

Analog and double indication values are alsotransferred through EVENT function.

IEC61850 generic communication I/O functionsMVGGIOIEC61850 generic communication I/O functions(MVGGIO) function is used to send theinstantaneous value of an analog output to othersystems or equipment in the substation. It canalso be used inside the same IED, to attach aRANGE aspect to an analog value and to permitmeasurement supervision on that value.

Measured value expander block RANGE_XPThe current and voltage measurements functions(CVMMXN, CMMXU, VMMXU and VNMMXU),current and voltage sequence measurementfunctions (CMSQI and VMSQI) and IEC 61850generic communication I/O functions (MVGGIO)are provided with measurement supervisionfunctionality. All measured values can besupervised with four settable limits: low-low limit,low limit, high limit and high-high limit. Themeasure value expander block (RANGE_XP) hasbeen introduced to enable translating the integeroutput signal from the measuring functions to 5binary signals: below low-low limit, below lowlimit, normal, above high-high limit or above highlimit. The output signals can be used asconditions in the configurable logic or for alarmingpurpose.

13. Metering

Pulse counter logic PCGGIOPulse counter (PCGGIO) function countsexternally generated binary pulses, for instancepulses coming from an external energy meter, forcalculation of energy consumption values. Thepulses are captured by the binary input moduleand then read by the function. A scaled servicevalue is available over the station bus. The specialBinary input module with enhanced pulsecounting capabilities must be ordered to achievethis functionality.

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

14. Basic IED functions

Time synchronizationThe time synchronization source selector is usedto select a common source of absolute time forthe IED when it is a part of a protection system.This makes it possible to compare event and


24 ABB

disturbance data between all IEDs in a stationautomation system.

15. Human machine interface

Human machine interfaceThe local HMI is equipped with a LCD that is usedamong other things to locally display the followingcrucial information:

• Connection of each bay, respecting the twodifferential protection zones and the checkzone. In the Parameter Setting Tool the usersets individual bay names to facilitate theidentification of each primary bay for stationpersonnel.

• Status of each individual primary switchgeardevice, for example, open, closed, 00 asintermediate state and 11 as bad state. InPCM600 the user sets the individual primaryswitchgear object names to facilitate theidentification of each switchgear device forthe station personnel.

The local HMI is divided into zones with differentfunctionality.

• Status indication LEDs.• Alarm indication LEDs, which consist of 15

LEDs (6 red and 9 yellow) with user printablelabel. All LEDs are configurable fromPCM600.

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

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

• Isolated RJ45 communication port.

IEC06000143 V1 EN

Figure 11. Example of medium graphic HMI


ABB 25

IEC06000191 V1 EN

Figure 12. Bay to zone connection example

1 User settable bay name

2 Internally used bay FB

3 Connections to internal zones

IEC06000192 V1 EN

Figure 13. Example of status of primary switchgearobjects

1 User settable switchgear names

2 Switchgear object status

16. Station communication

OverviewEach IED is provided with a communicationinterface, enabling it to connect to one or manysubstation level systems or equipment, either onthe Substation Automation (SA) bus or SubstationMonitoring (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 combinedin the same IED.


26 ABB

IEC 61850-8-1 communication protocolThe IED is equipped with single or double opticalEthernet rear ports (order dependent) for IEC61850-8-1 station bus communication. The IEC61850-8-1 communication is also possible fromthe optical Ethernet front port. IEC 61850-8-1protocol allows intelligent electrical devices (IEDs)from different vendors to exchange informationand simplifies system engineering. Peer-to-peercommunication according to GOOSE is part ofthe standard. Disturbance files uploading isprovided.

Serial communication, LONExisting stations with ABB station bus LON canbe extended with use of the optical LONinterface. This allows full SA functionality includingpeer-to-peer messaging and cooperationbetween existing ABB IED's and the new IED 670.

SPA communication protocolA single glass or plastic port is provided for theABB SPA protocol. This allows extensions ofsimple substation automation systems but themain use is for Substation Monitoring SystemsSMS.

IEC 60870-5-103 communication protocolA single glass or plastic port is provided for theIEC60870-5-103 standard. This allows design ofsimple substation automation systems includingequipment from different vendors. Disturbancefiles uploading is provided.

DNP3.0 communication protocolAn electrical RS485 and an optical Ethernet portis available for the DNP3.0 communication. DNP3.0 Level 2 communication with unsolicited events,time synchronizing and disturbance reporting isprovided for communication to RTUs, Gatewaysor HMI systems.

Multiple command and transmitWhen 670 IED's are used in SubstationAutomation systems with LON, SPA orIEC60870-5-103 communication protocols theEvent and Multiple Command function blocks areused as the communication interface for verticalcommunication to station HMI and gateway andas interface for horizontal peer-to-peercommunication (over LON only).

IEC 62439-3 Parallel Redundant ProtocolRedundant station bus communication accordingto IEC 62439-3 Edition 1 and IEC 62439-3 Edition2 are available as options in 670 series IEDs. IEC62439-3 parallel redundant protocol is an optionalquantity and the selection is made at ordering.Redundant station bus communication accordingto IEC 62439-3 uses both port AB and port CDon the OEM module.

Select IEC 62439-3 Edition 1protocol at the time of orderingwhen an existing redundantstation bus DuoDriverinstallation is extended.Select IEC 62439-3 Edition 2protocol at the time of orderingfor new installations withredundant station bus.IEC 62439-3 Edition 1 is NOTcompatible with IEC 62439-3Edition 2.

17. Remote communication

Analog and binary signal transfer to remote endThree analog and eight binary signals can beexchanged between two IEDs. This functionality ismainly used for the line differential protection.However it can be used in other products as well.An IED can communicate with up to 4 remoteIEDs.

Binary signal transfer to remote end, 192 signalsIf the communication channel is used for transferof binary signals only, up to 192 binary signalscan be exchanged between two IEDs. Forexample, this functionality can be used to sendinformation such as status of primary switchgearapparatus or intertripping signals to the remoteIED. An IED can communicate with up to 4remote IEDs.

For REB670 primary apparatus position indicationcan be exchanged between the single phase IEDs.

Line data communication module, short rangeLDCMThe line data communication module (LDCM) isused for communication between the IEDssituated at distances <110 km or from the IED to


ABB 27

optical to electrical converter with G.703 or G.703E1 interface located on a distances <3 kmaway. The LDCM module sends and receivesdata, to and from another LDCM module. TheIEEE/ANSI C37.94 standard format is used.

18. Hardware description

Hardware modulesPower supply module PSMThe power supply module is used to provide thecorrect internal voltages and full isolation betweenthe terminal and the battery system. An internalfail alarm output is available.

Binary input module BIMThe binary input module has 16 optically isolatedinputs and is available in two versions, onestandard and one with enhanced pulse countingcapabilities on the inputs to be used with thepulse counter function. The binary inputs arefreely programmable and can be used for theinput of logical signals to any of the functions.They can also be included in the disturbancerecording and event-recording functions. Thisenables extensive monitoring and evaluation ofoperation of the IED and for all associatedelectrical circuits.

Binary output module BOMThe binary output module has 24 independentoutput relays and is used for trip output or anysignaling purpose.

Static binary output module SOMThe static binary output module has six fast staticoutputs and six change over output relays for usein applications with high speed requirements.

Binary input/output module IOMThe binary input/output module is used when onlya few input and output channels are needed. Theten standard output channels are used for tripoutput or any signaling purpose. The two highspeed signal output channels are used forapplications where short operating time isessential. Eight optically isolated binary inputscater for required binary input information.

mA input module MIMThe milli-ampere input module is used to interfacetransducer signals in the –20 to +20 mA rangefrom for example OLTC position, temperature or

pressure transducers. The module has sixindependent, galvanically separated channels.

Optical ethernet module OEMThe optical fast-ethernet module is used toconnect an IED to the communication buses (likethe station bus) that use the IEC 61850-8-1protocol (port A, B). The module has one or twooptical ports with ST connectors.

Serial and LON communication module SLM,supports SPA/IEC 60870-5-103, LON and DNP 3.0The serial and LON communication module (SLM)is used for SPA, IEC 60870-5-103, DNP3 andLON communication. The module has two opticalcommunication ports for plastic/plastic, plastic/glass or glass/glass. One port is used for serialcommunication (SPA, IEC 60870-5-103 andDNP3 port or dedicated IEC 60870-5-103 portdepending on ordered SLM module) and one portis dedicated for LON communication.

Line data communication module LDCMEach module has one optical port, one for eachremote end to which the IED communicates.

Alternative cards for Short range (850 nm multimode) are available.

Galvanic RS485 serial communication moduleThe Galvanic RS485 communication module(RS485) is used for DNP3.0 communication. Themodule has one RS485 communication port. TheRS485 is a balanced serial communication thatcan be used either in 2-wire or 4-wireconnections. A 2-wire connection uses the samesignal for RX and TX and is a multidropcommunication with no dedicated Master orslave. This variant requires however a control ofthe output. The 4-wire connection has separatedsignals for RX and TX multidrop communicationwith a dedicated Master and the rest are slaves.No special control signal is needed in this case.

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


28 ABB

IRIG-B Time synchronizing moduleThe IRIG-B time synchronizing module is used foraccurate time synchronizing of the IED from astation clock.

Electrical (BNC) and optical connection (ST) for0XX and 12X IRIG-B support.

Transformer input module TRMThe transformer input module is used togalvanically separate and transform the secondary

currents and voltages generated by themeasuring transformers. The module has twelveinputs in different combinations of currents andvoltage inputs.

Alternative connectors of Ring lug orCompression type can be ordered.

Layout and dimensionsDimensions

xx05000059.vsd

EA

BC

F

D

IEC05000059 V1 EN

Figure 14. 1/1 x 19” case with rear cover

Case size A B C D E F

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

(mm)

Mounting alternativesThe following mounting alternatives are available(IP40 protection from the front):

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

See ordering for details about available mountingalternatives.


ABB 29

19. Connection diagrams

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

SLM and LDCM ports shallnot be used in RES670.


30 ABB

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

Figure 15. Transformer input module (TRM)

￭ Indicates high polarity

CT/VT-input designation according to figure 15

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 110-220V

9I+3U,5A

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

6I+6U,1A

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

6I+6U,5A

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

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 16. 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 17. mA input module (MIM)


32 ABB

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

Figure 18. IED with basic functionality and communication interfaces

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

Figure 19. Power supply module (PSM)


ABB 33

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

Figure 20. Binary output module (BOM). Output contacts named XA corresponds to rear position X31, X41, andso on, and output contacts named XB to rear position X32, X42, and so on.

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

Figure 21. Static output module (SOM)


34 ABB

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

Figure 22. Binary in/out module (IOM). Input contacts named XA corresponds to rear position X31, X41, and soon, and output contacts named XB to rear position X32, X42, and so on.


ABB 35

20. Technical data

General

Definitions

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

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

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

Energizing quantities, rated values and limitsAnalog inputs

Table 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

-


36 ABB

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 V48/60 V110/125 V220/250 V

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

-

Counter input frequency 10 pulses/s max -

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


ABB 37

Table 8. BIM - Binary input module with enhanced pulse counting capabilities


Binary inputs 16 -


RL ± 20%RL ± 20%RL ± 20%RL ± 20%



-

Counter input frequency 10 pulses/s max -

Balanced counter input frequency 40 pulses/s max -

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

Table 9. IOM - Binary input/output module


Binary inputs 8 -


RL ± 20%RL ± 20%RL ± 20%RL ± 20%



-


38 ABB

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 AC, DC

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

Current carrying capacityContinuous1 s

8 A10 A

8 A10 A

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

30 A10 A

0.4 A0.4 A

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

Breaking capacity for DC with L/R < 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

Table 11. 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 withthe maximum 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 39

Table 12. 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 maximumcapacitance of 0.2 μF:

0.2s 30A

1.0s 10A

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

110V / 0.4A

125V / 0,35A

220V / 0,2A

250V / 0.15A

Table 13. BOM - Binary output module contact data (reference standard: IEC 61810-2)

Function or quantity Trip and Signal relays

Binary outputs 24

Max system voltage 250 V AC, DC

Test voltage across open contact, 1 min 1000 V rms

Current carrying capacityContinuous1 s

8 A10 A

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

30 A10 A

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

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


40 ABB

Influencing factors

Table 14. Temperature and humidity influence

Parameter Reference value Nominal range Influence

Ambient temperature,operate value

+20 °C -10 °C to +55 °C 0.02% /°C

Relative humidityOperative range

10%-90%0%-95%

10%-90% -

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

Table 15. 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 powerdown

Restart time <180 s

Table 16. 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

Frequency dependence for differentialprotection

fr ± 2.5 Hz for 50 Hzfr ± 3.0 Hz for 50 Hz

± 2.0% / Hz

Harmonic frequency dependence (20%content)

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

Harmonic frequency dependence fordifferential protection (10% content)

2nd, 3rd and 5th harmonic of fr ± 6.0%


ABB 41

Type tests according to standards

Table 17. Electromagnetic compatibility

Test Type test values Reference standards

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

100 kHz slow damped oscillatory waveimmunity test

2.5 kV IEC 61000-4-18, Class III

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

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

IEEE/ANSI C37.90.1

Electrostatic dischargeDirect applicationIndirect application

15 kV air discharge8 kV contact discharge8 kV contact discharge

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

Electrostatic dischargeDirect applicationIndirect application

15 kV air discharge8 kV contact discharge8 kV contact discharge

IEEE/ANSI C37.90.1

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

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

IEC 60255-22-5

Power frequency immunity test 150-300 V, 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 18. 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


42 ABB

Table 19. 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 andhumidity 93 to 95% (1 cycle = 24 hours)

IEC 60068-2-30

Table 20. CE compliance

Test According to

Immunity EN 50263

Emissivity EN 50263

Low voltage directive EN 50178

Table 21. Mechanical tests

Test Type test values Reference standards

Vibration response test Class II IEC 60255-21-1

Vibration endurance test Class I IEC 60255-21-1

Shock response test Class II IEC 60255-21-2

Shock withstand test Class I IEC 60255-21-2

Bump test Class I IEC 60255-21-2

Seismic test Class II IEC 60255-21-3


ABB 43


Table 22. Busbar differential protection

Function Range or value Accuracy

Operating characteristic S=0.53 fixed ± 2.0% of Ir for I < Ir± 2.0% of I for I > Ir

Reset ratio > 95% -

Differential current operating level (1-100000) A ± 2.0% of Ir for I < Ir± 2.0% of I for I > Ir

Sensitive differential operationlevel

(1-100000) A ± 2.0% of Ir for I < Ir± 2.0% of I for I < Ir

Check zone operation level (0-100000) A ± 2.0% of Ir for I < Ir± 2.0% of I for I > Ir

Check zone slope (0.0-0.9) -

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

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

Operate time 19 ms typically at 0 to 2 x Id12 ms typically at 0 to 10 x Id

-

Reset time 21 ms typically at 2 to 0 x Id29 ms typically at 10 to 0 x Id

-

Critical impulse time 8 ms typically at 0 to 2 x Id -


44 ABB

Current protection

Table 23. Four step phase overcurrent protection OC4PTOC

Function Setting range Accuracy

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

Reset ratio > 95% -

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

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

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

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

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

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

Inverse characteristics, seetable 73, table 74 and table 75

19 curve types See table 73, table 74 and table75

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 -

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

Impulse margin time 15 ms typically -

Table 24. Four step single phase overcurrent protection PH4SPTOC


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

Reset ratio > 95% -

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

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

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

Inverse characteristics, seetable 73 and table 74

19 curve types See table 73 and table 74

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 45

Table 25. 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, class 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 26. 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 ofcontact function

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

Reset ratio > 95% -

Timers (0.000-60.000) s ± 0.5% ±10 ms

Operate time for current detection 10 ms typically -

Reset time for current detection 15 ms maximum -


46 ABB

Table 27. Breaker failure protection, single phase version CCSRBRF


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% -

Phase current level for blocking ofcontact function

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

Reset ratio > 95% -

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

Operate time for current detection 10 ms typically -

Reset time for current detection 15 ms maximum -

Table 28. Directional underpower protection GUPPDUP


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

± 1.0% of Sr at S < Sr

± 1.0% of S at S > Sr

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

Characteristic angle (-180.0–180.0) degrees 2 degrees

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

Table 29. Directional overpower protection GOPPDOP


Power level (0.0–500.0)% of Sbase

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

(2.0-10)% of Sbase

± 1.0% of Sr at S < Sr

± 1.0% of S at S > Sr

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

Characteristic angle (-180.0–180.0) degrees 2 degrees

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


ABB 47

Table 30. Capacitor bank protection CBPGAPC


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

Reset ratio, overcurrent >95% -

Operate time, start 10 ms typically -

Reset time, start 30 ms typically -

Critical impulse time, overcurrent protectionstart

2 ms typically at 0.5 to.2xIset1 ms typically at 0.5 to 10xIset

-

Impulse margin time, overcurrent protectionstart

15 ms typically

Operate value, undercurrent (5-100)% of IBase ± 1.0% of Ir at I < Ir± 1.0% of I at I > Ir

Reset ratio, undercurrent <105% -

Operate value, reconnection inhibit function (4-1000)% of IBase ± 1.0% of Ir at I < Ir± 1.0% of I at I > Ir

Operate value, reactive power overloadfunction

(5-900)% ± 1.0% of Sr at S < Sr

± 1.0% of S at S > Sr

Operate value, voltage protection functionfor harmonic overload (Definite time)

(5-500)% ± 0.5% of Ur at U<Ur

± 0.5% of U at U>Ur

Operate value, voltage protection functionfor harmonic overload (Inverse time)

(80-200)% ± 0.5% of Ur at U<Ur

± 0.5% of U at U>Ur

Inverse time characteristic According to IEC60871-1 (2005) andIEEE/ANSI C37.99 (2000)

Class 10 + 50 ms

Maximum trip delay, harmonic overloadIDMT

(0.05-6000.00) s ± 0.5% ± 10 ms

Minimum trip delay, harmonic overload IDMT (0.05-60.00) s ± 0.5% ± 10 ms

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


48 ABB

Voltage protection

Table 31. 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, low and highstep

(1–100)% of UBase ± 0.5% of Ur

Inverse time characteristics for lowand high step, see table 77

- See table 77

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

Minimum operate time, inversecharacteristics

(0.000–60.000) s ± 0.5% ± 10 ms

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

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

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


Table 32. Two step overvoltage protection OV2PTOV


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

± 0.5% of U at U > Ur

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

± 0.5% of U at U > Ur


- See table 76

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

Minimum operate time, Inversecharacteristics

(0.000-60.000) s ± 0.5% ± 10 ms



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



ABB 49

Table 33. Two step residual overvoltage protection ROV2PTOV


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

± 1.0% of U at U > Ur

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

± 1.0% of U at U > Ur


- See table 78

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

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





Table 34. 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

Table 35. Loss of voltage check LOVPTUV


Operate voltage (0–100)% of UBase ± 0.5% of Ur

Pulse timer (0.050–60.000) s ± 0.5% ± 10 ms

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


50 ABB


Table 36. 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

EQUATION1182 V1 EN (Equation 2)

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

Class 5 + 200 ms

Table 37. 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 38. 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 -


ABB 51


Table 39. 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 73 and table 74 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 73 and table 74

Voltage level where voltage memorytakes 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 -


52 ABB

Table 39. General current and voltage protection CVGAPC , continued


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

High and low voltage limit, voltagedependent operation

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


Directional function Settable: NonDir, forward and reverse -

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

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

Reset ratio, overcurrent > 95% -

Reset ratio, undercurrent < 105% -

Reset ratio, overvoltage > 95% -

Reset ratio, undervoltage < 105% -

Overcurrent:



Undercurrent:



Overvoltage:



Undervoltage:




ABB 53


Table 40. 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, start function 25 ms typically at 1 to 0 Ubase -

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


54 ABB

Control

Table 41. Autorecloser SMBRREC


Number of autoreclosing shots 1 - 5 -

Autoreclosing open time:shot 1 - t1 1Phshot 1 - t1 2Phshot 1 - t1 3PhHSshot 1 - t1 3PhDld

(0.000-60.000) s

± 0.5% ± 10 ms

shot 2 - t2shot 3 - t3shot 4 - t4shot 5 - t5

(0.00-6000.00) s

Extended autorecloser open time (0.000-60.000) s

Autorecloser maximum wait time for sync (0.00-6000.00) s

Maximum trip pulse duration (0.000-60.000) s

Inhibit reset time (0.000-60.000) s

Reclaim time (0.00-6000.00) s

Minimum time CB must be closed before AR becomes readyfor autoreclosing cycle

(0.00-6000.00) s

Circuit breaker closing pulse length (0.000-60.000) s

CB check time before unsuccessful (0.00-6000.00) s

Wait for master release (0.00-6000.00) s

Wait time after close command before proceeding to next shot (0.000-60.000) s


ABB 55

Logic

Table 42. Configurable logic blocks

Logic block Quantity with update rate Range or value Accuracy

fast medium normal

LogicAND 90 90 100 - -

LogicOR 90 90 100 - -

LogicXOR 15 15 10 - -

LogicInverter 45 45 50 - -

LogicSRMemory 15 15 10 - -

LogicRSMemory 15 15 10 - -

LogicGate 15 15 10 - -

LogicTimer 15 15 10 (0.000–90000.000) s ± 0.5% ± 10 ms

LogicPulseTimer 15 15 10 (0.000–90000.000) s ± 0.5% ± 10 ms

LogicTimerSet 15 15 10 (0.000–90000.000) s ± 0.5% ± 10 ms

LogicLoopDelay 15 15 10 (0.000–90000.000) s ± 0.5% ± 10 ms

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 - -


56 ABB

Monitoring

Table 43. Measurements CVMMXN


Frequency (0.95-1.05) × fr ± 2.0 mHz

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

± 0.5% of U at U > Ur

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

Active power, P 0.1 x Ur< U < 1.5 x Ur

0.2 x Ir < I < 4.0 x Ir± 1.0% of Sr at S ≤ Sr

± 1.0% of S at S > Sr

Conditions:0.8 x Ur < U < 1.2 Ur

0.2 x Ir < I < 1.2 Ir

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

0.2 x Ir < I < 4.0 x Ir

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

0.2 x Ir< I < 4.0 x Ir

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

0.2 x Ir< I < 4.0 x Ir± 0.02

Table 44. 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 45. Event counter CNTGGIO


Counter value 0-10000 -

Max. count up speed 10 pulses/s -


ABB 57

Table 46. 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 69

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

-

Maximum number of binary inputs 96 -

Maximum number of phasors in the Trip Valuerecorder per recording

30 -

Maximum number of indications in a disturbance report 96 -

Maximum number of events in the Event recording perrecording

150 -

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

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

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

-

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

-

Recording bandwidth (5-300) Hz -

Table 47. Event list

Function Value

Buffer capacity Maximum number of events in the list 1000

Resolution 1 ms

Accuracy Depending on time synchronizing

Table 48. Indications

Function Value

Buffer capacity Maximum number of indications presented for singledisturbance

96

Maximum number of recorded disturbances 100


58 ABB

Table 49. 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

Table 50. Trip value recorder

Function Value

Buffer capacity

Maximum number of analog inputs 30


Table 51. 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 59

Metering

Table 52. Pulse counter PCGGIO


Input frequency See Binary Input Module (BIM) -

Cycle time for report of countervalue

(1–3600) s -

Table 53. Energy metering ETPMMTR


Energy metering kWh Export/Import, kvarh Export/Import

Input from MMXU. No extra error at steady load


60 ABB


Table 54. IEC 61850-8-1 communication protocol

Function Value

Protocol IEC 61850-8-1

Communication speed for the IEDs 100BASE-FX

Table 55. LON communication protocol

Function Value

Protocol LON

Communication speed 1.25 Mbit/s

Table 56. SPA communication protocol

Function Value

Protocol SPA

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

Slave number 1 to 899

Table 57. IEC60870-5-103 communication protocol

Function Value


Communication speed 9600, 19200 Bd

Table 58. 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 61

Table 59. 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 60. Galvanic RS485 communication module


Communication speed 2400–19200 bauds

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

Table 61. IEC 62439-3 Edition 1 and Edition 2 parallel redundancy protocol

Function Value


Communication speed 100 Base-FX


62 ABB

Remote communication

Table 62. 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 62.5/125mm, 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 63

HardwareIED

Table 63. 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 64. Water and dust protection level according to IEC 60529

Front IP40 (IP54 with sealing strip)

Rear, sides, top andbottom

IP20

Table 65. Weight

Case size Weight

6U, 1/1 x 19” £ 18 kg

Connection system

Table 66. 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 67. 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)


64 ABB

Basic IED functions

Table 68. Self supervision with internal event list

Data Value

Recording manner Continuous, event controlled

List size 1000 events, first in-first out

Table 69. Time synchronization, time tagging

Function Value

Time tagging resolution, events and sampled measurement values 1 ms

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

± 1.0 ms typically

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

Table 70. 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 71. GPS – Antenna and cable

Function Value

Max antenna cable attenuation 26 db @ 1.6 GHz

Antenna cable impedance 50 ohm

Lightning protection Must be provided externally

Antenna cable connector SMA in receiver endTNC in antenna end

Accuracy +/-2μs


ABB 65

Table 72. 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


66 ABB

Inverse characteristic

Table 73. 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 unlessotherwise stated

-

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

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

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

ANSI Moderately Inverse A=0.0515, B=0.1140, P=0.02, tr=4.85

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


ABB 67

Table 74. 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 60255-3, class 5 +40 ms

IEC Very inverse A=13.5, P=1.0

IEC Inverse A=0.14, P=0.02

IEC Extremely inverse A=80.0, P=2.0

IEC Short time inverse A=0.05, P=0.04

IEC Long time inverse A=120, P=1.0

Programmable characteristicOperate characteristic:

( )= + ×

-


P

At B k

I C


Reset characteristic:

( )= ×

-PR

TRt k

I CR


I = Imeasured/Iset

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

IEC 60255, class 5 + 40ms


68 ABB

Table 75. 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 60255-3, class 5 +40 ms

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 IEC 60255-3, class 5 +40 ms

Table 76. 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 0.01unless otherwise stated

Class 5 +40 ms

Type B curve:

2.0

480

32 0.5 0.035

=×

- >× - -

>

æ öç ÷è ø

tk

U U

U



Type C curve:

3.0

480

32 0.5 0.035

=×

- >× - -

>

æ öç ÷è ø

tk

U U

U



Programmable curve:

×= +

- >× -

>

æ öç ÷è ø

P

k At D

U UB C

U


k = (0.05-1.10) in steps of 0.01unless otherwise statedA = (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 69

Table 77. Inverse time characteristics for undervoltage protection


Type A curve:

=< -

<

æ öç ÷è ø

kt

U U

UEQUATION1431-SMALL V1 EN

U< = Uset

U = UVmeasured


Class 5 +40 ms

Type B curve:

2.0

4800.055

32 0.5

×= +

< -× -

<

æ öç ÷è ø

kt

U U

U


U< = Uset

U = Umeasured


Programmable curve:

×= +

< -× -

<

é ùê úê úê úæ öê úç ÷ë è ø û

P

k At D

U UB C

U


U< = Uset

U = Umeasured

k = (0.05-1.10) in steps of 0.01unless otherwise statedA = (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


70 ABB

Table 78. 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

Class 5 +40 ms

Type B curve:

2.0

480

32 0.5 0.035

=×

- >× - -

>

æ öç ÷è ø

tk

U U

U


k = (0.05-1.10) 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


ABB 71

21. Ordering

Guidelines

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

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

Product specification

Default:

Option:

Customer specific configuration On request

Connection type for Power supply modules and I/O modules

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

Compression terminals 1MRK 002 960-AA

Ring lug terminals 1MRK 002 960-BA

Power supply module

Rule: One Power supply module must be specified

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

90-250 VDC 1MRK 002 239-BB


Rule: Only one, Busbar differential protection must be ordered

Busbar differential protection, 2 zones, three phase/up to 8 bays (BUTPTRC,BCZTPDIF, BZNTPDIF, BZITGGIO)

1MRK 002 901-LB

Busbar differential protection, 2 zones, single phase/up to 24 bays (BUSPTRC,BCZSPDIF, BZNSPDIF, BZISGGIO)

1MRK 002 901-NB

Optional functions


72 ABB

Current protection

Rule: Only one of OC4PTOC and PH4SPTOC can beordered

Four step phase overcurrent protection (OC4PTOC)

Qty:

1 2 3 4

5 6 7 8

1MRK 002 906-BD

Four step single phase overcurrent protection(PH4SPTOC)

Qty:

1 2 3 4 5 6

7 8 9 10 11 12

13

22 23 24

14 15 16 17 18

19 20 21

1MRK 002 907-BB

Thermal overload protection, two time constants(TRPTTR)

Qty:

1 2 1MRK 002 906-NC

Rule: Only one type of Breaker failure protection can beordered

Breaker failure protection (CCRBRF)

Qty

1 2 3 4

5 6 7 8

1MRK 002 906-RC

Breaker failure protection, single phase version(CCSRBRF)

Qty

1 2 3 4 5 6

7 8 9 10 11 12

13

22 23 24

14 15 16 17 18

19 20 21

1MRK 002 907-CB

Directional underpower protection (GUPPDUP)

Qty:

1 2 3 4 1MRK 002 902-FB

Directional overpower protection (GOPPDUP)

Qty:

1 2 3 4 1MRK 002 902-GB

Capacitor bank protection (CBPGAPC)

Qty:

1 2 1MRK 002 902-MA


ABB 73

Voltage protection

Two step undervoltage protection (UV2PTUV)

Qty:

1 2 1MRK 002 908-AC

Two step overvoltage protection (OV2PTOV)

Qty:

1 2 1MRK 002 908-DC

Two step residual overvoltage protection (ROV2PTOV)

Qty:

1 2 1MRK 002 908-GC

Voltage differential protection (VDCPTOV)

Qty:

1 2 1MRK 002 924-TB

Loss of voltage check (LOVPTUV)

Qty:

1 2 1MRK 002 902-EB


Underfrequency protection (SAPTUF)

Qty:

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

Overfrequency protection (SAPTOF)

Qty:

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

Rate-of-change frequency protection (SAPFRC)

Qty:

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


General current and voltage protection (CVGAPC)

Qty:

1 2 3 4 5 6 1MRK 002 902-AB


Fuse failure supervision (SDDRFUF)

Qty:

1 2 1MRK 002 914-GC

Control

Autorecloser (SMBRREC)

Qty:

1 2 1MRK 002 916-TB

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

1MRK 002 916-RD


Note: Require 2-channel OEM

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

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


74 ABB

First local HMI user dialogue language

Rule: One must be ordered

HMI language, English IEC 1MRK 002 930-AA

HMI language, English US 1MRK 002 930-BA

Additional local HMI user dialogue language

Rule: Maximum one alternative

HMI language, German 1MRK 002 920-AB

HMI language, Russian 1MRK 002 920-BB

HMI language, French 1MRK 002 920-DB

HMI language, Spanish 1MRK 002 920-DB

HMI language, Polish 1MRK 002 920-GB

HMI language, Hungarian 1MRK 002 920-FB

HMI language, Czech 1MRK 002 920-HB

HMI language, Swedish 1MRK 002 920-KB

Optional hardwareHuman machine hardware interface

Rule: One must be ordered.

Display type Keypad symbol Case size

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

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

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


ABB 75

Analog system

Note: The same type of connection terminals has to be ordered for both TRMs

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

Qty:

1 2 1MRK 002 247-CG

Transformer input module, compression terminals 12I, 5A, 50/60 Hz

Qty:

1 2 1MRK 002 247-CH

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

Qty:

1 2 1MRK 002 247-BG


Qty:

1 2 1MRK 002 247-BH


Qty:

1 2 1MRK 002 247-AG


Qty:

1 2 1MRK 002 247-AH

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

Qty:

1 2 1MRK 002 247-CC

Transformer input module, ring lug terminals 12I, 5A, 50/60 Hz

Qty:

1 2 1MRK 002 247-CD

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

Qty:

1 2 1MRK 002 247-BC

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

1 2 1MRK 002 247-BD


Qty:

1 2 1MRK 002 247-AC


Qty:

1 2 1MRK 002 247-AD

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

Case size

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

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

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


76 ABB

Maximum quantity of I/O modules

Case sizes BIM IOM BOM/SOM

MIM Maximum in case

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

1MRK 000 151-ND

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

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

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


ABB 77

Binary input/output modules

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

Binary input module (BIM) 16 inputs

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

7 8 9 10 11

1MRK 000 508-DB

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

7 8 9 10 11

1MRK 000 508-AB

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

7 8 9 10 11

1MRK 000 508-BB

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

7 8 9 10 11

1MRK 000 508-CB

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

7 8 9 10 11

1MRK 000 508-DD

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

7 8 9 10 11

1MRK 000 508-AD

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

7 8 9 10 11

1MRK 000 508-BD

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

7 8 9 10 11

1MRK 000 508-CD


78 ABB

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

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

7 8 9 10 11

1MRK 000 508-HA

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

7 8 9 10 11

1MRK 000 508-EA

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

7 8 9 10 11

1MRK 000 508-FA

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

7 8 9 10 11

1MRK 000 508-GA

Binary output module 24 output relays (BOM) Qty: 1 2 3 4 5 6

7 8 9 10 11

1MRK 000 614-AB

Static binary output module (SOM)

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

7 8 9 10 11

1MRK 002 614-BA

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

7 8 9 10 11

1MRK 002 614-CA


ABB 79

Make IOM with 50 mA inrush current the primary choice. IOM with 50 mA inrush current fulfilladditional standards. As a consequence the EMC withstand capability is further increased.IOM with 30 mA inrush current is still available.

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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


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Station communication ports

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

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

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

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

Serial/LON plastic interface 1MRK 001 608-AA

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

Serial/LON glass interface 1MRK 001 608-CA

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

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

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

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

Remote end serial communication for C37.94

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

Qty:

1 2 1MRK 002 122-AB

Time synchronization

Rule: Only one Time synchronization can be ordered.

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

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

Engineering facilities

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

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

Quantity: 1MRK 002 420-DA

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

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

Quantity: 1MRK 002 420-EA

Accessories


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External current transformer unit

3 pcs SLCE 8–1 summation transformers on apparatus plate (2Uhigh), 1/1 A

Quantity: 1MRK 000 643-EA


Quantity: 1MRK 000 643-FA


Quantity: 1MRK 000 643-GA

GPS antenna and mounting details

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

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

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

Interface converter (for remote end data communication)

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

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

Test switchThe test system COMBITEST intended for usewith the IED 670 products is described in 1MRK512 001-BEN and 1MRK 001024-CA. Pleaserefer to the website:www.abb.com/substationautomation for detailedinformation.

Test switches type RTXP 24 is orderedseparately. Please refer to Section "Related

documents" for reference to correspondingdocuments.

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

Protection cover

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

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

Combiflex


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Key switch for settings

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

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

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

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


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User documentation

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

IEC Quantity: 1MRK 505 209-UEN

ANSI Quantity: 1MRK 505 209-UUS

Technical reference manual IEC Quantity: 1MRK 505 208-UEN


Installation and commissioning manual IEC Quantity: 1MRK 505 210-UEN


Application manual IEC Quantity: 1MRK 505 211-UEN


Engineering guide IED 670 products Quantity: 1MRK 511 256-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

Related documentsRelated documents

Documents related to REB670 Identity number

Operator’s manual 1MRK 505 209-UEN

Installation and commissioning manual 1MRK 505 210-UEN

Technical reference manual 1MRK 505 208-UEN

Application manual 1MRK 505 211-UEN

Product guide pre-configured 1MRK 505 212-BEN


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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 511 256-UEN

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

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


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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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