9d4d3be41d5216d473d6cb8052592d78_4_ABB_REF_615_pg_756379_enk

Relion 615 series

Feeder Protection and ControlREF615Product Guide

Contents

1. Description...........................................................32. Standard configurations.......................................33. Protection functions...........................................104. Application.........................................................155. Supported ABB solutions...................................206. Control................................................................227. Measurement.....................................................228. Disturbance recorder..........................................239. Event log.............................................................2310. Recorded data...................................................2311. Condition monitoring.........................................2312. Trip-circuit supervision......................................2413. Self-supervision.................................................2414. Fuse failure supervision.....................................2415. Current circuit supervision................................2416. Access control...................................................24

17. Inputs and outputs............................................2418. Communication.................................................2619. Technical data...................................................2820. Local HMI..........................................................6821. Mounting methods............................................6922. IED case and IED plug-in unit...........................7023. Selection and ordering data..............................7024. Accessories and ordering data.........................7425. Tools..................................................................7526. Terminal diagrams.............................................7827. Certificates........................................................8428. Inspection reports.............................................8429. References........................................................8430. Functions, codes and symbols.........................8531. Document revision history.................................89

Disclaimer

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

Copyright 2010 ABB Oy.

All rights reserved.

Trademarks

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

Feeder Protection and Control 1MRS756379 KREF615Product version: 3.0 Issued: 2010-09-07

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1. DescriptionREF615 is a dedicated feeder IED (intelligentelectronic device) designed for theprotection, control, measurement andsupervision of utility substations andindustrial power systems including radial,looped and meshed distribution networkswith or without distributed power generation.

REF615 is a member of ABBs Relion

product family and part of its 615 protectionand control product series. The 615 seriesIEDs are characterized by their compactnessand withdrawable-unit design.

Re-engineered from the ground up, the 615series has been designed to unleash the fullpotential of the IEC 61850 standard forcommunication and interoperability betweensubstation automation devices.

The IED provides main protection foroverhead lines and cable feeders indistribution networks. The IED is also usedas back-up protection in applications, wherean independent and redundant protectionsystem is required.

Depending on the chosen standardconfiguration, the IED is adapted for theprotection of overhead line and cable feedersin isolated neutral, resistance earthed,

compensated and solidly earthed networks.Once the standard configuration IED hasbeen given the application-specific settings, itcan directly be put into service.

The 615 series IEDs support a range ofcommunication protocols including IEC61850 with GOOSE messaging, IEC

60870-5-103, Modbus and DNP3.

2. Standardconfigurations

REF615 is available in eight alternativestandard configurations. The standard signalconfiguration can be altered by means of thegraphical signal matrix or the optionalgraphical application functionality of theProtection and Control IED Manager PCM600.Further, the application configurationfunctionality of PCM600 supports the creationof multi-layer logic functions using variouslogical elements, including timers and flip-flops. By combining protection functions withlogic function blocks, the IED configurationcan be adapted to user-specific applicationrequirements.


Revision: K

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Table 1. Standard configurations

Description Std. conf.

Non-directional overcurrent and directional earth-fault protection A and B

Non-directional overcurrent and non-directional earth-faultprotection C and D

Non-directional overcurrent and directional earth-fault protectionwith phase-voltage based measurements E

Directional overcurrent and directional earth-fault protection withphase-voltage based measurements, undervoltage and overvoltageprotection F

Directional overcurrent and directional earth-fault protection, phase-voltage based protection and measurement functions, sensor inputs G

Non-directional overcurrent and non-directional earth-faultprotection, phase-voltage and frequency based protection andmeasurement functions, synchro-check H


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Table 2. Supported functions

Functionality A B C D E F G H

Protection1)2)

Three-phase non-directionalovercurrent protection, lowstage, instance 1

- -

Three-phase non-directionalovercurrent protection, highstage, instance 1

- -

Three-phase non-directionalovercurrent protection, highstage, instance 2

- -

Three-phase non-directionalovercurrent protection,instantaneous stage,instance 1

Three-phase directionalovercurrent protection, lowstage, instance 1

- - - - - -

Three-phase directionalovercurrent protection, lowstage, instance 2

- - - - - -

Three-phase directionalovercurrent protection, highstage

- - - - - -

Non-directional earth-faultprotection, low stage,instance 1

- - 4) 4) - - - 4)

Non-directional earth-faultprotection, low stage,instance 2

- - 4) 4) - - - 4)

Non-directional earth-faultprotection, high stage,instance 1

- - 4) 4) - - - 4)

Non-directional earth-faultprotection, instantaneousstage

- - 4) 4) - - - 4)

Directional earth-faultprotection, low stage,instance 1

3)4)6) 3)4)6) - - 3)4)5) 3)4)5) 3)4)7) -


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Table 2. Supported functions, continued


Directional earth-faultprotection, low stage,instance 2

3)4)6) 3)4)6) - - 3)4)5) 3)4)5) 3)4)7) -

Directional earth-faultprotection, high stage

3)4)6) 3)4)6) - - 3)4)5) 3)4)5) 3)4)7) -Admittance based earth-fault protection, instance 1



3)4)6) 3)4)6) - - 3)4)5) 3)4)5) 3)4)7) -Transient / intermittentearth-fault protection

6)8) 6)8) - - 6)8) 6)8) -Non-directional (cross-country) earth faultprotection, using calculatedIo

9) 9) - - 9) 9) 9) -

Negative-sequenceovercurrent protection,instance 1

Negative-sequenceovercurrent protection,instance 2

Phase discontinuityprotection

Residual overvoltageprotection, instance 1

6) 6) - - 5) 5) 7) 5)


6) 6) - - 5) 5) 7) 5)


6) 6) - - 5) 5) 7) 5)

Three-phase undervoltageprotection, instance 1

- - - - - Three-phase undervoltageprotection, instance 2

- - - - - Three-phase undervoltageprotection, instance 3

- - - - -


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Three-phase overvoltageprotection, instance 1

- - - - - Three-phase overvoltageprotection, instance 2

- - - - - Three-phase overvoltageprotection, instance 3

- - - - - Positive-sequenceundervoltage protection,instance 1

- - - - - -

Negative-sequenceovervoltage protection,instance 1

- - - - - -

Frequency protection,instance 1

- - - - - - - Frequency protection,instance 2

- - - - - - - Frequency protection,instance 3

- - - - - - - Three-phase thermalprotection for feeders,cables and distributiontransformers

-

Circuit breaker failureprotection

Three-phase inrush detector Master trip, instance 1 Master trip, instance 2 Arc protection, instance 1 o o o o o o o o

Arc protection, instance 2 o o o o o o o o

Arc protection, instance 3 o o o o o o o o

Control

Circuit-breaker control Disconnector positionindication, instance 1

- -


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Disconnector positionindication, instance 2

- - Disconnector positionindication, instance 3

- - Earthing switch indication - - Auto-reclosing o o o o o o o o

Synchronism and energizingcheck

- - - - - - - Condition monitoring

Circuit-breaker conditionmonitoring

- - Trip circuit supervision,instance 1

Trip circuit supervision,instance 2

Current circuit supervision - - - - Fuse failure supervision - - - - Measurement

Disturbance recorder Three-phase currentmeasurement, instance 1

Sequence currentmeasurement

Residual currentmeasurement, instance 1

Three-phase voltagemeasurement

- - - - Residual voltagemeasurement

- - - Sequence voltagemeasurement

- - - -


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Three-phase power andenergy measurement,including power factor

- - - -

Frequency measurement - - - - - - - = Included, = Optional at the time of the order1) Note that all directional protection functions can also be used in non-directional mode.2) The instances of a protection function represent the number of identical function blocks available in a standard

configuration. By setting the application specific parameters of an instance, a protection function stage can beestablished.

3) Admittance based E/F can be selected as an alternative to directional E/F when ordering.4) Io selectable by parameter, Io measured as default.5) Uo selectable by parameter, Uo measured as default.6) Uo measured is always used.7) Uo calculated is always used.8) Io measured is always used.9) Io selectable by parameter, Io calculated as default.


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3. Protection functionsThe IED offers directional and non-directional overcurrent and thermal overloadprotection as well as directional and non-directional earth-fault protection. Dependingon the standard configuration, admittance-based earth-fault protection is offered as analternative to the directional earth-faultprotection. Further, the IED features sensitiveearth-fault protection, phase discontinuityprotection, transient/intermittent earth-faultprotection, overvoltage and undervoltageprotection, residual overvoltage protection,positive-sequence undervoltage and negative-sequence overvoltage protection. Frequencyprotection, including overfrequency,

underfrequency and frequency rate-of-changeprotection, is offered in IEDs with standardconfiguration H. In addition, the IED offersthree-pole multi-shot auto-reclose functionsfor overhead line feeders.

Enhanced with optional hardware andsoftware, the IED also features three lightdetection channels for arc fault protection ofthe circuit breaker, busbar and cablecompartment of metal-enclosed indoorswitchgear.

The arc-fault protection sensor interface isavailable on the optional communicationmodule. Fast tripping increases personnelsafety and limits switchgear damage, shouldan arc fault occur.

IECA070911 V4 EN

Figure 1. Protection function overview of standard configuration A and B


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IECA070912 V4 EN

Figure 2. Protection function overview of standard configuration C and D


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GUID-91451BCB-E984-4F50-AE18-732D0ED542CF V2 EN

Figure 3. Protection function overview of standard configuration E


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GUID-C5A6DAD5-BC11-4E7B-B0B4-4E9138AD63B4 V2 EN

Figure 4. Protection function overview of standard configuration F


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GUID-E84B7815-9877-4E23-994F-0B2CF2D0F220 V1 EN

Figure 5. Protection function overview of standard configuration G


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GUID-5A8E3AE6-5877-4EC8-B76A-098B5A9EF1ED V1 EN

Figure 6. Protection function overview of standard configuration H

4. ApplicationThe feeder protection IED REF615 can besupplied either with directional or non-directional earth-fault protection. Directionalearth-fault protection is mainly used inisolated neutral or compensated networks,whereas non-directional earth-fault protectionis intended for directly or low impedanceearthed neutral networks. The IED can alsobe used for protection of ring-type andmeshed distribution networks as well ofradial networks containing distributed powergeneration.

The standard configurations A and B offerdirectional earth-fault protection, if theoutgoing feeder is equipped with phasecurrent transformers, a core-balance currenttransformer and residual voltagemeasurement. The residual current calculatedfrom the phase currents can be used fordouble (cross country) earth-fault protection.The IED further features transient/intermittent earth-fault protection. Thestandard configurations C and D offer non-directional earth-fault protection for outgoingfeeders equipped with phase currenttransformers. The residual current for theearth-fault protection is derived from thephase currents. When applicable, the core-balance current transformers can be used for


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measuring the residual current, especiallywhen sensitive earth-fault protection isrequired. The standard configurations E andF offer directional earth-fault protection withphase voltage and residual voltagemeasurement. Furthermore, the two standardconfigurations E and F include current circuitsupervision and fuse failure supervision forincoming feeders provided with busbarvoltage measurement. In addition to thefunctionality of standard configuration E, thestandard configuration F offers directionalovercurrent protection, overvoltage andundervoltage protection, positive-sequenceundervoltage and negative-sequenceovervoltage protection and residual voltageprotection.

The standard configuration G includes oneconventional residual current (Io) input andthree sensor inputs for the connection ofthree combi-sensors with RJ-45 connectors.The sensor inputs enable the use of the IEDin compact medium voltage switchgear withlimited space for conventional measuringtransformers, thus requiring the use of sensortechnology. Compact medium voltageswitchgear, such as ABBs SafeRing andSafePlus, are designed for applications likecompact secondary substations, wind turbinepower plants, small industry installations andlarge buildings. As an alternative to combi-

sensors, separate current and voltage sensorscan be utilized using adapters. Further, theadapters also enable the use of sensors withTwin-BNC connectors.

The standard configuration H includes non-directional overcurrent and non-directionalearth-fault protection, phase-voltage andfrequency based protection and measurementfunctions. The provided functionalitysupports the use of the standardconfiguration in industrial power systems,where the power is generated in the plantitself and/or derived from the distributionnetwork. Completed with the synchro-checkfunction, IEDs with standard configuration Hensure a safe interconnection of two networks.

For standard configurations A, B, E, F and Gadmittance-based earth-fault protection, usingthe neutral admittance (Yo) criterion, isoffered as an option to the directional earth-fault protection. The admittance-based earth-fault protection ensures the correct operationof the earth-fault protection even if theconnection status information of the Petersencoil is missing. Furthermore, the admittancebased earth-fault protection principle offershigh independence of the fault resistance,straightforward setting principles andimproved sensitivity of the protection.


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IECA070905 V4 EN

Figure 7. Substation O/C and E/F protection using the standard configuration A or B withrelevant options. In the incoming feeder bay, the protection functions not used areuncoloured and indicated with a dashed block outline. The IEDs are equipped withoptional arc protection functions, enabling fast and selective arc protectionthroughout the switchgear.


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IECA070920 V4 EN

Figure 8. Substation O/C and E/F protection using the standard configuration C or D withrelevant options. In the incoming feeder bay the unemployed protection functions areuncoloured and indicated with a dashed block outline. The busbar protection isbased on the interlocking principle, where the start of the O/C protection of theoutgoing feeder sends a blocking signal to the instantaneous O/C stage of theincoming feeder. In the absence of the blocking signal, the O/C protection of theincoming feeder will clear the internal switchgear (busbar) fault.


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GUID-28FD0F8B-3D60-4702-A4C2-473A6D4B529B V2 EN

Figure 9. Protection and control of two incoming feeders using IEDs with standardconfiguration F. The two incoming feeders can be connected in parallel by closingthe busbar-sectionalizing breaker. To achieve selective overcurrent protection,directional overcurrent stages are needed. Busbar main and back-up protection foroutgoing feeders is implemented using residual overvoltage protection stages. Phaseundervoltage and overvoltage protection can be used for tripping or just alarmingpurposes.


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GUID-CAFB8FA9-B405-43FE-867D-8625BEBA82C2 V1 EN

Figure 10. Protection and control of a typical compact medium voltage switchgear usingREF615 IEDs with the standard configuration G. The phase currents and phasevoltages are measured using combi-sensors supporting the Rogowski current sensorand voltage divider principles. The earth-fault current is measured using aconventional cable current transformer.

5. Supported ABBsolutions

ABBs 615 series protection and control IEDstogether with the COM600 StationAutomation device constitute a genuine IEC61850 solution for reliable power distributionin utility and industrial power systems. Tofacilitate and streamline the systemengineering ABBs IEDs are supplied withConnectivity Packages containing acompilation of software and IED-specificinformation including single-line diagramtemplates, a full IED data model includingevent and parameter lists. By utilizing theConnectivity Packages the IEDs can bereadily configured via the PCM600 Protectionand Control IED Manager and integrated withthe COM600 Station Automation device or theMicroSCADA Pro network control andmanagement system.

The 615 series IEDs offer native support forthe IEC 61850 standard also including binaryand analog horizontal GOOSE messaging.Compared with traditional hard-wired inter-device signaling, peer-to-peer communicationover a switched Ethernet LAN offers anadvanced and versatile platform for powersystem protection. Fast software-basedcommunication, continuous supervision ofthe integrity of the protection andcommunication system, and inherentflexibility for reconfiguration and upgradesare among the distinctive features of theprotection system approach enabled by thefull implementation of the IEC 61850substation automation standard.

At the substation level COM600 uses the datacontent of the bay level IEDs to offerenhanced substation level functionality.COM600 features a web-browser based HMIproviding a customizable graphical displayfor visualizing single line mimic diagrams forswitchgear bay solutions. The SLD feature is


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especially useful when 615 series IEDswithout the optional single line diagramfeature are used. Further, the web HMI ofCOM600 offers an overview of the wholesubstation, including IED-specific single linediagrams, thus enabling convenientinformation accessibility. To enhancepersonnel safety, the web HMI also enablesremote access to substation devices andprocesses. Furthermore, COM600 can be usedas a local data warehouse for technicaldocumentation of the substation and fornetwork data collected by the IEDs. Thecollected network data facilitates extensivereporting and analyzing of network faultsituations using the data historian and event

handling features of COM600. The datahistorian can be used for accurate processperformance monitoring by following processand equipment performance calculations withreal-time and history values. Betterunderstanding of the process behaviour byjoining time-based process measurementswith production and maintenance eventshelps the user in understanding the processdynamics.

COM600 also features gateway functionalityproviding seamless connectivity between thesubstation IEDs and network-level controland management systems such asMicroSCADA Pro and System 800xA

Table 3. Supported ABB solutions

Product Version

Station Automation COM600 3.4 or later

MicroSCADA Pro 9.2 SP2 or later

System 800xA 5.0 Service Pack 2

Analog and binary horizontal GOOSE communication

IEC 61850

IEC 60870-5-104

COM600Web HMI

ABBMicroSCADA

Ethernet switch PCM600

REF615 REU615RED615 RET615RET615REF615REU615 RED615

Binary signal transfer

COM600


IEC 61850

COM600Web HMI

PCM600Ethernet switch

COM600

Line differentialcommunication

GUID-66EB52A0-21A1-4D1F-A1EF-61060B371384 V2 EN

Figure 11. Utility power distribution network example using 615 series IEDs, StationAutomation COM600 and MicroSCADA Pro


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COM600

Ethernet switch PCM600 PCM600

REM615REF615REU615 RET615 RED615

Ethernet switch

RET615RED615 REM615 REF615 REU615Line differentialcommunication

Binary signal transfer

OPC

COM600Web HMI

COM600Web HMI

COM600

Ethernet switch

ABB System 800xA


IEC 61850Analog and binary horizontal GOOSE communication

IEC 61850

GUID-6984D893-45D5-427A-BABF-F1E1015C18E2 V2 EN

Figure 12. Industrial power system example using 615 series IEDs, Station AutomationCOM600 and System 800xA

6. ControlThe IED offers control of one circuit breakerwith dedicated push-buttons for circuitbreaker opening and closing. Further, theoptional large graphical LCD of the IEDsHMI includes a single-line diagram (SLD)with position indication for the relevantcircuit breaker. Interlocking schemesrequired by the application are configuredusing the signal matrix or the applicationconfiguration feature of PCM600.

Depending on the standard configuration, theIED also incorporates a synchro-checkfunction to ensure that the voltage, phaseangle and frequency on either side of anopen circuit breaker satisfy the conditions forsafe interconnection of two networks.

7. MeasurementThe IED continuously measures the phasecurrents, the symmetrical components of thecurrents and the residual current. If the IEDincludes voltage measurements it alsomeasures the residual voltage, the phasevoltages and the voltage sequencecomponents. Depending on the standardconfiguration the IED additionally offersfrequency measurement. In addition, the IEDcalculates the demand value of current over auser-selectable pre-set time frames, thethermal overload of the protected object, andthe phase unbalance value based on the ratiobetween the negative sequence and positivesequence current.

Further, the IED offers three-phase powerand energy measurement including powerfactor.

The values measured can be accessed locallyvia the user interface on the IED front panelor remotely via the communication interfaceof the IED. The values can also be accessed


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locally or remotely using the web-browserbased user interface.

8. Disturbance recorderThe IED is provided with a disturbancerecorder featuring up to 12 analog and 64binary signal channels. The analog channelscan be set to record either the waveform orthe trend of the currents and voltagemeasured.

The analog channels can be set to trigger therecording function when the measured valuefalls below or exceeds the set values. Thebinary signal channels can be set to start arecording on the rising or the falling edge ofthe binary signal or both.

By default, the binary channels are set torecord external or internal IED signals, forexample the start or trip signals of the IEDstages, or external blocking or controlsignals. Binary IED signals such as aprotection start or trip signal, or an externalIED control signal over a binary input can beset to trigger the recording. The recordedinformation is stored in a non-volatilememory and can be uploaded for subsequentfault analysis.

9. Event logTo collect sequence-of-events (SoE)information, the IED incorporates a non-volatile memory with a capacity of storing512 events with associated time stamps. Thenon-volatile memory retains its data also incase the IED temporarily loses its auxiliarysupply. The event log facilitates detailed pre-and post-fault analyses of feeder faults anddisturbances. The increased capacity toprocess and store data and events in the IEDoffers prerequisites to support the growing

information demand of future networkconfigurations.

The SoE information can be accessed locallyvia the user interface on the IED front panelor remotely via the communication interfaceof the IED. The information can further beaccessed, either locally or remotely, using theweb-browser based user interface.

10. Recorded dataThe IED has the capacity to store the recordsof 32 latest fault events. The records enablethe user to analyze the power system events.Each record includes current, voltage andangle values, time stamp, etc. The faultrecording can be triggered by the start signalor the trip signal of a protection block, or byboth. The available measurement modesinclude DFT, RMS and peak-to-peak. Inaddition, the maximum demand current withtime stamp is separately recorded. By default,the records are stored in a non-volatilememory.

11. Condition monitoringThe condition monitoring functions of theIED constantly monitors the performance andthe condition of the circuit breaker. Themonitoring comprises the spring chargingtime, SF6 gas pressure, the travel-time andthe inactivity time of the circuit breaker.

The monitoring functions provide operationalCB history data, which can be used forscheduling preventive CB maintenance.


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12. Trip-circuitsupervision

The trip-circuit supervision continuouslymonitors the availability and operability ofthe trip circuit. It provides open-circuitmonitoring both when the circuit breaker isin its closed and in its open position. It alsodetects loss of circuit-breaker control voltage.

13. Self-supervisionThe IEDs built-in self-supervision systemcontinuously monitors the state of the IEDhardware and the operation of the IEDsoftware. Any fault or malfunction detectedwill be used for alerting the operator.

A permanent IED fault will block theprotection functions to prevent incorrectoperation.

14. Fuse failuresupervision

Depending on the chosen standardconfiguration, the IED includes fuse failuresupervision functionality. The fuse failuresupervision detects failures between thevoltage measurement circuit and the IED. Thefailures are detected by the negative-sequence based algorithm or by the deltavoltage and delta current algorithm. Upon thedetection of a failure the fuse failuresupervision function activates an alarm andblocks voltage-dependent protectionfunctions from unintended operation.

15. Current circuitsupervision

Depending on the chosen standardconfiguration, the IED includes current circuitsupervision. Current circuit supervision isused for detecting faults in the currenttransformer secondary circuits. On detectingof a fault the current circuit supervisionfunction activates an alarm LED and blockscertain protection functions to avoidunintended operation. The current circuitsupervision function calculates the sum of thephase currents from the protection cores andcompares the sum with the measured singlereference current from a core balance currenttransformer or from separate cores in thephase current transformers.

16. Access controlTo protect the IED from unauthorized accessand to maintain information integrity, the IEDis provided with a four-level, role-basedauthentication system with administrator-programmable individual passwords for theviewer, operator, engineer and administratorlevel. The access control applies to the front-panel user interface, the web-browser baseduser interface and the PCM600 tool.

17. Inputs and outputsDepending on the standard configurationselected, the IED is equipped with three phase-current inputs and one residual-current inputfor non-directional earth-fault protection, orthree phase-current inputs, one residual-current input and one residual voltage inputfor directional earth-fault protection or threephase-current inputs, one residual-currentinput, three phase-voltage inputs and one


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residual voltage input for directional earth-fault protection and directional overcurrentprotection. The standard configuration Gincludes one conventional residual current(Io 0.2/1 A) input and three sensor inputs forthe direct connection of three combi-sensorswith RJ-45 connectors. As an alternative tocombi-sensors, separate current and voltagesensors can be utilized using adapters.Furthermore, the adapters also enable the useof sensors with Twin-BNC connectors.

The phase-current inputs are rated 1/5 A.Two optional residual-current inputs areavailable, i.e. 1/5 A or 0.2/1 A. The 0.2/1 Ainput is normally used in applicationsrequiring sensitive earth-fault protection andfeaturing core-balance current transformers.The three phase-voltage inputs and theresidual-voltage input covers the ratedvoltages 60-210 V. Both phase-to-phase

voltages and phase-to-earth voltages can beconnected.

The phase-current input 1 A or 5 A, theresidual-current input 1 A or 5 A,alternatively 0.2 A or 1 A, and the ratedvoltage of the residual voltage input areselected in the IED software. In addition, thebinary input thresholds 18176 V DC areselected by adjusting the IEDs parametersettings.

All binary inputs and outputs contacts arefreely configurable with the signal matrix orapplication configuration functionality ofPCM600.

Please refer to the Input/output overviewtable and the terminal diagrams for moredetailed information about the inputs andoutputs.

Table 4. Input/output overview

Standardconfiguration

Analog inputs Binary inputs/outputs

CT VT BI BO

A 4 1 3 6

B 4 1 11 (17)1) 10 (13)1)

C 4 - 4 6

D 4 - 12 (18)1) 10 (13)1)

E 4 52) 16 10

F 4 52) 16 10

G 3+13) 33) 8 10

H 4 5 16 10

1) With optional binary I/O module ( )2) One of the five inputs is reserved for future applications3) Support for three Combi Sensors and one conventional Io input or three current sensors, three voltage sensors

and one conventional Io input


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18. CommunicationThe IED supports a range of communicationprotocols including IEC 61850, IEC

60870-5-103, Modbus and DNP3.Operational information and controls areavailable through these protocols. However,some communication functionality, forexample, horizontal communication betweenthe IEDs, is only enabled by the IEC 61850communication protocol.

The IEC 61850 communicationimplementation supports all monitoring andcontrol functions. Additionally, parametersettings, disturbance recordings and faultrecords can be accessed using the IEC 61850protocol. Disturbance recordings are availableto any Ethernet-based application in thestandard COMTRADE file format. The IEDsupports simultaneous event reporting to fivedifferent clients on the station bus.

The IED can send binary signals to otherIEDs (so called horizontal communication)using the IEC 61850-8-1 GOOSE (GenericObject Oriented Substation Event) profile.Binary GOOSE messaging can, for example,be employed for protection and interlocking-based protection schemes. The IED meets theGOOSE performance requirements fortripping applications in distributionsubstations, as defined by the IEC 61850standard. Further, the IED supports thesending and receiving of analog values usingGOOSE messaging. Analog GOOSEmessaging enables fast transfer of analogmeasurement values over the station bus,thus facilitating for example sharing of RTDinput values, such as surroundingtemperature values, to other IED applications.

The IED offers an optional second Ethernetbus to enable the creation of a self-healingEthernet ring topology. The IEDcommunication module options include bothgalvanic and fibre-optic Ethernetcombinations. The communication moduleincluding one fibre-optic LC port and twogalvanic RJ-45 ports is used when the ring

between the IEDs is built using CAT5 STPcables. The LC port can in this case be usedfor connecting the IED to communicationports outside the switchgear. Thecommunication module including three RJ-45ports is used when the whole substation busis based on CAT5 STP cabling.

The self-healing Ethernet ring solutionenables a cost efficient communication ringcontrolled by a managed switch with rapidspanning tree protocol (RSTP) support to becreated. The managed switch controls theconsistency of the loop, routes the data andcorrects the data flow in case of acommunication disturbance. The IEDs in thering topology act as unmanaged switchesforwarding unrelated data traffic. TheEthernet ring solution supports theconnection of up to thirty 615 series IEDs. Ifmore than 30 IEDs are to be connected, it isrecommended that the network is split intoseveral rings with no more than 30 IEDs perring. The self-healing Ethernet ring solutionavoids single point of failure concerns andimproves the reliability of thecommunication. The solution can be appliedfor the Ethernet-based IEC 61850, Modbusand DNP3 protocols.

All communication connectors, except for thefront port connector, are placed on integratedoptional communication modules. The IEDcan be connected to Ethernet-basedcommunication systems via the RJ-45connector (100Base-TX) or the fibre-optic LCconnector (100Base-FX). If connection to aserial bus is required, the 10-pin RS-485 screw-terminal or the fibre-optic ST connector canbe used.

Modbus implementation supports RTU, ASCIIand TCP modes. Besides standard Modbusfunctionality, the IED supports retrieval oftime-stamped events, changing the activesetting group and uploading of the latest faultrecords. If a Modbus TCP connection is used,five clients can be connected to the IEDsimultaneously. Further, Modbus serial andModbus TCP can be used in parallel, and if


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required both IEC 61850 and Modbusprotocols can be run simultaneously.

The IEC 60870-5-103 implementationsupports two parallel serial bus connectionsto two different masters. Besides basicstandard functionality, the IED supportschanging of the active setting group anduploading of disturbance recordings in IEC60870-5-103 format.

DNP3 supports both serial and TCP modesfor connection to one master. Further,changing of the active setting group issupported.

When the IED uses the RS-485 bus for theserial communication, both two- and fourwire connections are supported. Terminationand pull-up/down resistors can be configuredwith jumpers on the communication card soexternal resistors are not needed.

The IED supports the following timesynchronization methods with a time-stamping resolution of 1 ms:

Ethernet-based:

SNTP (Simple Network Time Protocol)

With special time synchronization wiring:

IRIG-B (Inter-Range Instrumentation Group- Time Code Format B)

In addition, the IED supports timesynchronization via the following serialcommunication protocols:

Modbus DNP3 IEC 60870-5-103

Managed Ethernet switchwith RSTP support

Managed Ethernet switchwith RSTP support

RED615 REF615 RET615 REU615 REM615

Client BClient A

Network

Network

GUID-AB81C355-EF5D-4658-8AE0-01DC076E519C V1 EN

Figure 13. Self-healing Ethernet ring solution


ABB 27

Table 5. Supported station communication interfaces and protocols

Interfaces/Protocols

Ethernet Serial

100BASE-TXRJ-45

100BASE-FX LC RS-232/RS-485 Fibre-optic ST

IEC 61850 - -MODBUS RTU/ASCII

- -

MODBUS TCP/IP

- -

DNP3 (serial) - - DNP3 TCP/IP - -IEC 60870-5-103 - - = Supported


28 ABB

19. Technical dataTable 6. Dimensions

Description Value

Width frame 177 mm

case 164 mm

Height frame 177 mm (4U)

case 160 mm

Depth 201 mm (153 + 48 mm)

Weight complete IED 4.1 kg

plug-in unit only 2.1 kg

Table 7. Power supply

Description Type 1 Type 2

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

24, 30, 48, 60 V DC

48, 60, 110, 125, 220, 250 V DC

Uauxvariation 38...110% of Un (38...264 V AC) 50...120% of Un (12...72 V DC)

80...120% of Un (38.4...300 V

DC)

Start-up threshold 19.2 V DC (24 V DC * 80%)

Burden of auxiliaryvoltage supply underquiescent (Pq)/operating

condition

DC < 12.0 W (nominal)/< 18.0W (max)AC< 16.0 W (nominal)/95%/5000 ms

IEC 61000-4-11

Power frequency immunitytest:

Common mode

Differential mode

Binary inputs only 300 V rms 150 V rms

IEC 61000-4-16IEC 60255-22-7, class A

Emission tests: EN 55011, class AIEC 60255-25

Conducted

0.15-0.50 MHz < 79 dB(V) quasi peak< 66 dB(V) average

0.5-30 MHz < 73 dB(V) quasi peak< 60 dB(V) average

Radiated

30-230 MHz < 40 dB(V/m) quasi peak,measured at 10 m distance

230-1000 MHz < 47 dB(V/m) quasi peak,measured at 10 m distance


36 ABB

Table 22. Insulation tests

Description Type test value Reference

Dielectric tests IEC 60255-5 andIEC 60255-27

Test voltage 2 kV, 50 Hz, 1 min500 V, 50 Hz, 1 min, communication

Impulse voltage test IEC 60255-5 andIEC 60255-27

Test voltage 5 kV, 1.2/50 s, 0.5 J1 kV, 1.2/50 s, 0.5 J,communication

Insulation resistancemeasurements

IEC 60255-5 andIEC 60255-27

Isolation resistance >100 M, 500 V DC Protective bondingresistance

IEC 60255-27

Resistance

Table 25. EMC compliance

Description Reference

EMC directive 2004/108/EC

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

Table 26. RoHS compliance

Description

Complies with RoHS directive 2002/95/EC


38 ABB

Protection functionsTable 27. Three-phase non-directional overcurrent protection (PHxPTOC)

Characteristic Value

Operation accuracy Depending on the frequency of the currentmeasured: fn 2 Hz

PHLPTOC 1.5% of the set value or 0.002 x In

PHHPTOCandPHIPTOC

1.5% of set value or 0.002 x In(at currents in the range of 0.110 x In)

5.0% of the set value(at currents in the range of 1040 x In)

Start time 1)2) Minimum Typical Maximum

PHIPTOC:IFault = 2 x set Start

valueIFault = 10 x set Start

value

16 ms 11 ms

19 ms 12 ms

23 ms 14 ms

PHHPTOC andPHLPTOC:IFault = 2 x set Start

value

22 ms

24 ms

25 ms

Reset time < 40 ms

Reset ratio Typical 0.96

Retardation time < 30 ms

Operate time accuracy in definite time mode 1.0% of the set value or 20 ms

Operate time accuracy in inverse time mode 5.0% of the theoretical value or 20 ms 3)

Suppression of harmonics RMS: No suppressionDFT: -50 dB at f = n x fn, where n = 2, 3, 4, 5,

Peak-to-Peak: No suppressionP-to-P+backup: No suppression

1) Set Operate delay time = 0,02 s, Operate curve type = IEC definite time, Measurement mode = default (depends onstage), current before fault = 0.0 x In, fn = 50 Hz, fault current in one phase with nominal frequency injectedfrom random phase angle, results based on statistical distribution of 1000 measurements

2) Includes the delay of the signal output contact3) Includes the delay of the heavy-duty output contact


ABB 39

Table 28. Three-phase non-directional overcurrent protection (PHxPTOC) main settings

Parameter Function Value (Range) Step

Start Value PHLPTOC 0.05...5.00 x In 0.01

PHHPTOC 0.10...40.00 x In 0.01

PHIPTOC 1.00...40.00 x In 0.01

Time multiplier PHLPTOC 0.05...15.00 0.05

PHHPTOC 0.05...15.00 0.05

Operate delay time PHLPTOC 40...200000 ms 10

PHHPTOC 40...200000 ms 10

PHIPTOC 20...200000 ms 10

Operating curve

type1)PHLPTOC Definite or inverse time

Curve type: 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12,13, 14, 15, 17, 18, 19

PHHPTOC Definite or inverse timeCurve type: 1, 3, 5, 9, 10, 12, 15, 17

PHIPTOC Definite time

1) For further reference please refer to the Operating characteristics table


40 ABB

Table 29. Three-phase directional overcurrent protection (DPHxPDOC)


Operation accuracy Depending on the frequency of the current/voltage measured: fn 2 Hz

DPHLPDOC Current:1.5% of the set value or 0.002 x InVoltage:1.5% of the set value or 0.002 x UnPhase angle: 2

DPHHPDOC Current:1.5% of the set value or 0.002 x In(at currents in the range of 0.110 x In)


Voltage:1.5% of the set value or 0.002 x UnPhase angle: 2

Start time1)2) Minimum Typical Maximum

IFault = 2.0 x set Start

value37 ms 40 ms 42 ms

Reset time < 40 ms




Operate time accuracy in inverse time mode 5.0% of the theoretical value or 20 ms3)

Suppression of harmonics DFT: -50 dB at f = n x fn, where n = 2, 3, 4, 5,

1) Measurement mode and Pol quantity = default, current before fault = 0.0 x In, voltage before fault = 1.0 x Un, fn= 50 Hz, fault current in one phase with nominal frequency injected from random phase angle, results based onstatistical distribution of 1000 measurements

2) Includes the delay of the signal output contact3) Maximum Start value = 2.5 x In, Start value multiples in range of 1.5 to 20


ABB 41

Table 30. Three-phase directional overcurrent protection (DPHxPDOC) main settings


Start value DPHLPDOC 0.05...5.00 x In 0.01

DPHHPDOC 0.10...40.00 x In 0.01

Time multiplier DPHxPDOC 0.05...15.00 0.05

Operate delay time DPHxPDOC 40...200000 ms 10

Directional mode DPHxPDOC 1 = Non-directional2 = Forward3 = Reverse

Characteristic angle DPHxPDOC -179...180 deg 1

Operating curve

type1)DPHLPDOC Definite or inverse time

Curve type: 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12,13, 14, 15, 17, 18, 19

DPHHPDOC Definite or inverse timeCurve type: 1, 3, 5, 9, 10, 12, 15, 17

1) For further reference, refer to the Operating characteristics table


42 ABB

Table 31. Non-directional earth-fault protection (EFxPTOC)



EFLPTOC 1.5% of the set value or 0.002 x In

EFHPTOCandEFIPTOC

1.5% of set value or 0.002 x In(at currents in the range of 0.110 x In)



EFIPTOC:IFault = 2 x set Start


value

16 ms11 ms

19 ms12 ms

23 ms14 ms

EFHPTOC andEFLPTOC:IFault = 2 x set Start

value

22 ms

24 ms

25 ms

Reset time < 40 ms






Peak-to-Peak: No suppression

1) Measurement mode = default (depends on stage), current before fault = 0.0 x In, fn = 50 Hz, earth-fault current

with nominal frequency injected from random phase angle, results based on statistical distribution of 1000measurements

2) Includes the delay of the signal output contact3) Maximum Start value = 2.5 x In, Start value multiples in range of 1.5 to 20


ABB 43

Table 32. Non-directional earth-fault protection (EFxPTOC) main settings


Start value EFLPTOC 0.010...5.000 x In 0.005

EFHPTOC 0.10...40.00 x In 0.01

EFIPTOC 1.00...40.00 x In 0.01

Time multiplier EFLPTOC 0.05...15.00 0.05

EFHPTOC 0.05...15.00 0.05

Operate delay time EFLPTOC 40...200000 ms 10

EFHPTOC 40...200000 ms 10

EFIPTOC 20...200000 ms 10

Operating curve

type1)EFLPTOC Definite or inverse time

Curve type: 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12,13, 14, 15, 17, 18, 19

EFHPTOC Definite or inverse timeCurve type: 1, 3, 5, 9, 10, 12, 15, 17

EFIPTOC Definite time



44 ABB

Table 33. Directional earth-fault protection (DEFxPDEF)



DEFLPDEF Current:1.5% of the set value or 0.002 x InVoltage1.5% of the set value or 0.002 x UnPhase angle:2

DEFHPDEF Current:1.5% of the set value or 0.002 x In(at currents in the range of 0.110 x In)


Voltage:1.5% of the set value or 0.002 x UnPhase angle:2


DEFHPDEFIFault = 2 x set Start

value

42 ms

44 ms

46 ms

DEFLPDEFIFault = 2 x set Start

value

61ms 64 ms 66 ms

Reset time < 40 ms






Peak-to-Peak: No suppression

1) Set Operate delay time = 0.06 s,Operate curve type = IEC definite time, Measurement mode = default (depends onstage), current before fault = 0.0 x In, fn = 50 Hz, earth-fault current with nominal frequency injected from

random phase angle, results based on statistical distribution of 1000 measurements2) Includes the delay of the signal output contact3) Maximum Start value = 2.5 x In, Start value multiples in range of 1.5 to 20


ABB 45

Table 34. Directional earth-fault protection (DEFxPDEF) main settings


Start Value DEFLPDEF 0.010...5.000 x In 0.005

DEFHPDEF 0.10...40.00 x In 0.01

Directional mode DEFLPDEF andDEFHPDEF

1=Non-directional2=Forward3=Reverse

Time multiplier DEFLPDEF 0.05...15.00 0.05

DEFHPDEF 0.05...15.00 0.05

Operate delay time DEFLPDEF 60...200000 ms 10

DEFHPDEF 40...200000 ms 10

Operating curve

type1)DEFLPDEF Definite or inverse time

Curve type: 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12,13, 14, 15, 17, 18, 19

DEFHPDEF Definite or inverse timeCurve type: 1, 3, 5, 15, 17

Operation mode DEFLPDEF andDEFHPDEF

1=Phase angle2=IoSin3=IoCos4=Phase angle 805=Phase angle 88

1) For further reference, refer to the Operating characteristics table

Table 35. Transient/intermittent earth-fault protection (INTRPTEF)


Operation accuracy (Uo criteria withtransient protection)

Depending on the frequency of the currentmeasured: fn 2 Hz

1.5% of the set value or 0.002 x Uo

Operate time accuracy 1.0% of the set value or 20 ms

Suppression of harmonics DFT: -50 dB at f = n x fn, where n = 2, 3, 4, 5


46 ABB

Table 36. Transient/intermittent earth-fault protection (INTRPTEF) main settings


Directional mode INTRPTEF 1=Non-directional2=Forward3=Reverse

-

Operate delay time INTRPTEF 40...1200000 ms 10

Voltage start value(voltage start valuefor transient EF)

INTRPTEF 0.01...0.50 x Un 0.01

Operation mode INTRPTEF 1=Intermittent EF2=Transient EF

-

Peak counter limit(Min requirement forpeak counter beforestart in IEF mode)

INTRPTEF 2...20 -

Table 37. Admittance-based earth-fault protection (EFPADM)


Operation accuracy1) At the frequency f = fn

1.0% or 0.01 mS(In range of 0.5 - 100 mS)

Start time2) Minimum Typical Maximum

56 ms 60 ms 64 ms

Reset time 40 ms

Operate timeaccuracy

1.0% of the set value of 20 ms

Suppression ofharmonics

-50 dB at f = n x fn, where n = 2, 3, 4, 5,

1) Uo = 1.0 x Un2) Includes the delay of the signal output contact. Results based on statistical distribution of 1000 measurements.


ABB 47

Table 38. Admittance-based earth-fault protection (EFPADM) main settings

Parameter Values(Range)

Unit Step Default Description

Voltage start value 0.05...5.00 xUn 0.01 0.05 Voltage startvalue

Directional mode 1=Non-directional2=Forward3=Reverse

2=Forward Directionalmode

Operation mode 1=Yo2=Go3=Bo4=Yo, Go5=Yo, Bo6=Go, Bo7=Yo, Go, Bo

1=Yo Operationcriteria

Operate delay time 60...200000 ms 10 60 Operate delaytime

Circle radius 0.05...500.00 mS 0.01 1.00 Admittancecircle radius

Circle conductance -500.00...500.00 mS 0.01 0.00 Admittancecircle midpoint,conductance

Circle susceptance -500.00...500.00 mS 0.01 0.00 Admittancecircle midpoint,susceptance

Conductanceforward

-500.00...500.00 mS 0.01 1.00 Conductancethreshold inforwarddirection

Conductancereverse

-500.00...500.00 mS 0.01 -1.00 Conductancethreshold inreverse direction

Conductance tiltAng

-30...30 deg 1 0 Tilt angle ofconductanceboundary line


48 ABB

Table 38. Admittance-based earth-fault protection (EFPADM) main settings, continued



Susceptanceforward

-500.00...500.00 mS 0.01 1.00 Susceptancethreshold inforwarddirection

Susceptance reverse -500.00...500.00 mS 0.01 -1.00 Susceptancethreshold inreverse direction

Susceptance tilt Ang -30...30 deg 1 0 Tilt angle ofsusceptanceboundary line

Table 39. Three-phase overvoltage protection (PHPTOV)


Operation accuracy Depending on the frequency of the voltagemeasured: fn 2 Hz

1.5% of the set value or 0.002 x Un


UFault = 1.1 x set Start

value22 ms 24 ms 26 ms

Reset time < 40 ms

Reset ratio Depends of the set Relative hysteresis





1) Start value = 1.0 x Un, Voltage before fault = 0.9 x Un, fn = 50 Hz, overvoltage in one phase-to-phase with

nominal frequency injected from random phase angle, results based on statistical distribution of 1000 measurements2) Includes the delay of the signal output contact3) Maximum Start value = 1.20 x Un, Start value multiples in range of 1.10 to 2.00


ABB 49

Table 40. Three-phase overvoltage protection (PHPTOV) main settings


Start value PHPTOV 0.05...1.60 x Un 0.01

Time multiplier PHPTOV 0.05...15.00 0.05

Operate delay time PHPTOV 40...300000 ms 10

Operating curve

type1)PHPTOV Definite or inverse time

Curve type: 5, 15, 17, 18, 19, 20


Table 41. Three phase undervoltage protection (PHPTUV)





UFault = 0.9 x set

Start value62 ms 64 ms 66 ms

Reset time < 40 ms

Reset ratio Depends on the set Relative hysteresis





1) Start value = 1.0 x Un, Voltage before fault = 1.1 x Un, fn = 50 Hz, undervoltage in one phase-to-phase with

nominal frequency injected from random phase angle, results based on statistical distribution of 1000 measurements2) Includes the delay of the signal output contact3) Minimum Start value = 0.50, Start value multiples in range of 0.90 to 0.20


50 ABB

Table 42. Three-phase undervoltage protection (PHPTUV) main settings


Start value PHPTUV 0.05...1.20 x Un 0.01

Time multiplier PHPTUV 0.05...15.00 0.05

Operate delay time PHPTUV 60...300000 ms 10

Operating curve

type1)PHPTUV Definite or inverse time

Curve type: 5, 15, 21, 22, 23


Table 43. Positive sequence undervoltage protection (PSPTUV)





UFault = 0.99 x set

Start valueUFault = 0.9 x set Start

value

51 ms43 ms

53 ms45 ms

54 ms46 ms

Reset time < 40 ms

Reset ratio Depends of the set Relative hysteresis




1) Start value = 1.0 x Un, Positive sequence voltage before fault = 1.1 x Un, fn = 50 Hz, positive sequence

undervoltage with nominal frequency injected from random phase angle, results based on statistical distributionof 1000 measurements

2) Includes the delay of the signal output contact

Table 44. Positive sequence undervoltage protection (PSPTUV) main settings


Start value PSPTUV 0.010...1.200 x Un 0.001

Operate delay time PSPTUV 40...120000 ms 10

Voltage block value PSPTUV 0.01...1.0 x Un 0.01


ABB 51

Table 45. Frequency protection (FRPFRQ)


Operation accuracy f>/f< 10 mHz

df/dt 100 mHz/s (in range |df/dt| < 5 Hz/s) 2.0% of the set value (inrange 5 Hz/s < |df/dt| < 15Hz/s)

Start time f>/f< < 80 ms

df/dt < 120 ms

Reset time < 150 ms

Operate time accuracy 1.0% of the set value or 30ms


52 ABB

Table 46. Frequency protection (FRPFRQ) main settings



Operation mode 1=Freq3=df/dt4=Freq< + df/dt5=Freq> + df/dt6=Freq< OR df/dt7=Freq> OR df/dt

1=Freq< Frequencyprotectionoperation modeselection

Start value Freq> 0.900...1.200 xFn 0.001 1.050 Frequency startvalueoverfrequency

Start value Freq< 0.800...1.100 xFn 0.001 0.950 Frequency startvalueunderfrequency

Start value df/dt -0.200...0.200 xFn /s 0.005 0.010 Frequency startvalue rate ofchange

Operate Tm Freq 80...200000 ms 10 200 Operate delaytime forfrequency

Operate Tm df/dt 120...200000 ms 10 400 Operate delaytime forfrequency rateof change


ABB 53

Table 47. Negative sequence overvoltage protection (NSPTOV)



1.5% of the set value or 0.002 Un


UFault = 1.1 set

Start valueUFault = 2.0 set

Start value

33 ms24 ms

35 ms26 ms

37 ms28 ms

Reset time < 40 ms




Suppression of harmonics DFT: -50 dB at f = n fn, where n = 2, 3, 4, 5,

1) Negative-sequence voltage before fault = 0.0 Un, fn = 50 Hz, negative-sequence overvoltage with nominal

frequency injected from random phase angle, results based on statistical distribution of 1000 measurements2) Includes the delay of the signal output contact

Table 48. Negative sequence overvoltage protection (NSPTOV) main settings


Start value NSPTOV 0.010...1.000 x Un 0.001

Operate delay time NSPTOV 40...120000 ms 1


54 ABB

Table 49. Residual overvoltage protection (ROVPTOV)





UFault = 1.1 x set

Start value55 ms 56 ms 58 ms

Reset time < 40 ms





1) Residual voltage before fault = 0.0 x Un, fn = 50 Hz, residual voltage with nominal frequency injected from

random phase angle, results based on statistical distribution of 1000 measurements2) Includes the delay of the signal output contact

Table 50. Residual overvoltage protection (ROVPTOV) main settings


Start value ROVPTOV 0.010...1.000 x Un 0.001

Operate delay time ROVPTOV 40...300000 ms 1


ABB 55

Table 51. Negative phase-sequence overcurrent protection (NSPTOC)



1.5% of the set value or 0.002 x In


IFault = 2 x set Start


value

22 ms14 ms

24 ms16 ms

25 ms17 ms

Reset time < 40 ms






1) Negative sequence current before fault = 0.0, fn = 50 Hz, results based on statistical distribution of 1000

measurements2) Includes the delay of the signal output contact3) Maximum Start value = 2.5 x In, Start value multiples in range of 1.5 to 20

Table 52. Negative phase-sequence overcurrent protection (NSPTOC) main settings


Start value NSPTOC 0.01...5.00 x In 0.01

Time multiplier NSPTOC 0.05...15.00 0.05

Operate delay time NSPTOC 40...200000 ms 10

Operating curve

type1)NSPTOC Definite or inverse time

Curve type: 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12,13, 14, 15, 17, 18, 19



56 ABB

Table 53. Phase discontinuity protection (PDNSPTOC)



2% of the set value

Start time < 70 ms

Reset time < 40 ms





Table 54. Phase discontinuity protection (PDNSPTOC) main settings


Start value (Currentratio setting I2/I1)

PDNSPTOC 10...100 % 1

Operate delay time PDNSPTOC 100...30000 ms 1

Min phase current PDNSPTOC 0.05...0.30 x In 0.01

Table 55. Circuit breaker failure protection (CCBRBRF)



1.5% of the set value or 0.002 x In



ABB 57

Table 56. Circuit breaker failure protection (CCBRBRF) main settings


Current value(Operating phasecurrent)

CCBRBRF 0.05...1.00 x In 0.05

Current value Res(Operating residualcurrent)

CCBRBRF 0.05...1.00 x In 0.05

CB failure mode(Operating mode offunction)

CCBRBRF 1=Current2=Breaker status3=Both

-

CB fail trip mode CCBRBRF 1=Off2=Without check3=Current check

-

Retrip time CCBRBRF 0...60000 ms 10

CB failure delay CCBRBRF 0...60000 ms 10

CB fault delay CCBRBRF 0...60000 ms 10

Table 57. Three-phase thermal overload protection for feeders (T1PTTR)



Current measurement: 1.5% of the set valueor 0.002 x In (at currents in the range of

0.01...4.00 x In)

Operate time accuracy1) 2.0% of the theoretical value or 0.50 s

1) Overload current > 1.2 x Operate level temperature


58 ABB

Table 58. Three-phase thermal overload (T1PTTR) main settings


Env temperature Set(Ambienttemperature usedwhen the AmbSens isset to Off)

T1PTTR -50...100C 1

Current multiplier(Current multiplierwhen function isused for parallellines)

T1PTTR 1...5 1

Current reference T1PTTR 0.05...4.00 x In 0.01

Temperature rise(End temperaturerise above ambient)

T1PTTR 0.0...200.0C 0.1

Time constant (Timeconstant of the linein seconds)

T1PTTR 60...60000 s 1

Maximumtemperature(temperature levelfor operate)

T1PTTR 20.0...200.0C 0.1

Alarm value(Temperature levelfor start (alarm)

T1PTTR 20.0...150.0C 0.1

Reclose temperature(Temperature forreset of block recloseafter operate)

T1PTTR 20.0...150.0C 0.1

Initial temperature(Temperature raiseabove ambienttemperature atstartup)

T1PTTR -50.0...100.0C 0.1


ABB 59

Table 59. Three-phase inrush current detection (INRPHAR)


Operation accuracy At the frequency f = fn

Current measurement:1.5% of the set value or 0.002 x InRatio I2f/I1f measurement:5.0% of the set value

Reset time +35 ms / -0 ms


Operate time accuracy +35 ms / -0 ms

Table 60. Three-phase inrush detection (INRPHAR) main settings


Start value (Ratio ofthe 2nd to the 1stharmonic leading torestraint)

INRPHAR 5...100 % 1

Operate delay time INRPHAR 20...60000 ms 1

Table 61. Arc protection (ARCSARC)


Operation accuracy 3% of the set value or 0.01 x In

Operate time Minimum Typical Maximum

Operation mode =

"Light+current"1)2)9 ms 12 ms 15 ms

Operation mode =

"Light only"2)9 ms 10 ms 12 ms

Reset time < 40 ms


1) Phase start value = 1.0 x In, current before fault = 2.0 x set Phase start value, fn = 50 Hz, fault with nominal

frequency, results based on statistical distribution of 200 measurements2) Includes the delay of the heavy-duty output contact


60 ABB

Table 62. Arc protection (ARCSARC) main settings


Phase start value(Operating phasecurrent)

ARCSARC 0.50...40.00 x In 0.01

Ground start value(Operating residualcurrent)

ARCSARC 0.05...8.00 x In 0.01

Operation mode ARCSARC 1=Light+current2=Light only3=BI controlled

Table 63. Operation characteristics

Parameter Values (Range)

Operating curve type 1=ANSI Ext. inv.2=ANSI Very. inv.3=ANSI Norm. inv.4=ANSI Mod inv.5=ANSI Def. Time6=L.T.E. inv.7=L.T.V. inv.8=L.T. inv.9=IEC Norm. inv.10=IEC Very inv.11=IEC inv.12=IEC Ext. inv.13=IEC S.T. inv.14=IEC L.T. inv15=IEC Def. Time17=Programmable18=RI type19=RD type

Operating curve type (voltage protection) 5=ANSI Def. Time15=IEC Def. Time17=Inv. Curve A18=Inv. Curve B19=Inv. Curve C20=Programmable21=Inv. Curve A22=Inv. Curve B23=Programmable


ABB 61

Control functionsTable 64. Autoreclosure (DARREC)



Table 65. Synchrocheck (SECRSYN)



Voltage: 3.0% of the set value or 0.01 x UnFrequency: 10 mHzPhase angle: 3

Reset time < 50 ms




62 ABB

Table 66. Synchronism and energizing check (SECRSYN) main settings

Parameter Values (Range) Unit Step Default Description

Live deadmode

-1=Off1=Both Dead2=Live L, Dead B3=Dead L, Live B4=Dead Bus, LAny5=Dead L, BusAny6=One Live,Dead7=Not Both Live

1=Both Dead Energizingcheck mode

Differencevoltage

0.01...0.50 xUn 0.01 0.05 Maximumvoltagedifferencelimit

Differencefrequency

0.001...0.100 xFn 0.001 0.001 Maximumfrequencydifferencelimit

Differenceangle

5...90 deg 1 5 Maximumangledifferencelimit

Synchrocheckmode

1=Off2=Synchronous3=Asynchronous

2=Synchronous Synchrocheckoperationmode

Control mode 1=Continuous2=Command

1=Continuous Selection ofthesynchrocheckcommand orcontinuouscontrol mode

Dead linevalue

0.1...0.8 xUn 0.1 0.2 Voltage low-limit line forenergizingcheck

Live line value 0.2...1.0 xUn 0.1 0.5 Voltage high-limit line forenergizingcheck


ABB 63

Table 66. Synchronism and energizing check (SECRSYN) main settings, continued

Parameter Values (Range) Unit Step Default Description

Close pulse 200...60000 ms 10 200 Breaker-closing pulseduration

Maxenergizing V

0.50...1.15 xUn 0.01 1.05 Maximumvoltage forenergizing

Phase shift -180...180 deg 1 180 Correction ofphasedifferencebetweenmeasuredU_BUS andU_LINE

Minimum Syntime

0...60000 ms 10 0 Minimumtime to acceptsynchronizing

Maximum Syntime

100...6000000 ms 10 2000 Maximumtime to acceptsynchronizing

Energizingtime

100...60000 ms 10 100 Time delayfor energizingcheck

Closing timeof CB

40...250 ms 10 60 Closing timeof the breaker

Measurement functionsTable 67. Three-phase current measurement (CMMXU)



0.5% or 0.002 x In(at currents in the range of 0.01...4.00 x In)


RMS: No suppression


64 ABB

Table 68. Current sequence components (CSMSQI)


Operation accuracy Depending on the frequency of the currentmeasured: f/fn = 2 Hz

1.0% or 0.002 x Inat currents in the range of 0.01...4.00 x In


Table 69. Three-phase voltage measurement (VMMXU)



At voltages in range 0.011.15 x Un

0.5% or 0.002 x Un


RMS: No suppression

Table 70. Voltage sequence components (VSMSQI)



At voltages in range 0.011.15 x Un

1.0% or 0.002 x Un


Table 71. Residual current measurement (RESCMMXU)



0.5% or 0.002 x Inat currents in the range of 0.01...4.00 x In


RMS: No suppression


ABB 65

Table 72. Residual voltage measurement (RESVMMXU)



0.5% or 0.002 x Un


RMS: No suppression

Table 73. Three-phase power and energy (PEMMXU)


Operation accuracy At all three currents in range 0.101.20 x InAt all three voltages in range 0.501.15 x UnAt the frequency fn 1 Hz

Active power and energy in range |PF| > 0.71Reactive power and energy in range |PF| (1) 51P-1 (1)

Three-phase non-directionalovercurrent protection, high stage,instance 1

PHHPTOC1 3I>> (1) 51P-2 (1)

Three-phase non-directionalovercurrent protection, high stage,instance 2

PHHPTOC2 3I>> (2) 51P-2 (2)

Three-phase non-directionalovercurrent protection,instantaneous stage, instance 1

PHIPTOC1 3I>>> (1) 50P/51P (1)

Three-phase directionalovercurrent protection, low stage,instance 1

DPHLPDOC1 3I> -> (1) 67-1 (1)

Three-phase directionalovercurrent protection, low stage,instance 2

DPHLPDOC2 3I> -> (2) 67-1 (2)

Three-phase directionalovercurrent protection, high stage

DPHHPDOC1 3I>> -> 67-2

Non-directional earth-faultprotection, low stage, instance 1

EFLPTOC1 Io> (1) 51N-1 (1)

Non-directional earth-faultprotection, low stage, instance 2

EFLPTOC2 Io> (2) 51N-1 (2)

Non-directional earth-faultprotection, high stage, instance 1

EFHPTOC1 Io>> (1) 51N-2 (1)

Non-directional earth-faultprotection, instantaneous stage

EFIPTOC1 Io>>> 50N/51N

Directional earth-fault protection,low stage, instance 1

DEFLPDEF1 Io> -> (1) 67N-1 (1)

Directional earth-fault protection,low stage, instance 2

DEFLPDEF2 Io> -> (2) 67N-1 (2)

Directional earth-fault protection,high stage

DEFHPDEF1 Io>> -> 67N-2


86 ABB

Table 84. REF615 Functions, codes and symbols, continued

Function IEC 61850 IEC 60617 IEC-ANSI

Admittance based earth-faultprotection, instance 1

EFPADM1 Yo> -> (1) 21YN (1)


EFPADM2 Yo> -> (2) 21YN (2)


EFPADM3 Yo> -> (3) 21YN (3)

Transient / intermittent earth-faultprotection

INTRPTEF1 Io> -> IEF 67NIEF

Non-directional (cross-country)earth fault protection, usingcalculated Io

EFHPTOC1 Io>> (1) 51N-2 (1)

Negative-sequence overcurrentprotection, instance 1

NSPTOC1 I2> (1) 46 (1)

Negative-sequence overcurrentprotection, instance 2

NSPTOC2 I2> (2) 46 (2)

Phase discontinuity protection PDNSPTOC1 I2/I1> 46PD

Residual overvoltage protection,instance 1

ROVPTOV1 Uo> (1) 59G (1)






PHPTUV1 3U< (1) 27 (1)


PHPTUV2 3U< (2) 27 (2)


PHPTUV3 3U< (3) 27 (3)


PHPTOV1 3U> (1) 59 (1)


PHPTOV2 3U> (2) 59 (2)


PHPTOV3 3U> (3) 59 (3)

Positive-sequence undervoltageprotection, instance 1

PSPTUV1 U1< (1) 47U+ (1)


ABB 87



Negative-sequence overvoltageprotection, instance 1

NSPTOV1 U2> (1) 47O- (1)

Frequency protection, instance 1 FRPFRQ1 f>/f/f/fF 49F

Circuit breaker failure protection CCBRBRF1 3I>/Io>BF 51BF/51NBF

Three-phase inrush detector INRPHAR1 3I2f> 68

Master trip, instance 1 TRPPTRC1 Master Trip (1) 94/86 (1)

Master trip, instance 2 TRPPTRC2 Master Trip (2) 94/86 (2)

Arc protection, instance 1 ARCSARC1 ARC (1) 50L/50NL (1)



Control

Circuit-breaker control CBXCBR1 I O CB I O CB

Disconnector position indication,instance 1

DCSXSWI1 I O DC (1) I O DC (1)





Earthing switch indication ESSXSWI1 I O ES I O ES

Auto-reclosing DARREC1 O -> I 79

Synchronism and energizing check SECRSYN1 SYNC 25

Condition monitoring

Circuit-breaker conditionmonitoring

SSCBR1 CBCM CBCM

Trip circuit supervision, instance 1 TCSSCBR1 TCS (1) TCM (1)

Trip circuit supervision, instance 2 TCSSCBR2 TCS (2) TCM (2)

Current circuit supervision CCRDIF1 MCS 3I MCS 3I


88 ABB



Fuse failure supervision SEQRFUF1 FUSEF 60

Measurement

Disturbance recorder RDRE1 - -

Three-phase current measurement,instance 1

CMMXU1 3I 3I

Sequence current measurement CSMSQI1 I1, I2, I0 I1, I2, I0

Residual current measurement,instance 1

RESCMMXU1 Io In

Three-phase voltage measurement VMMXU1 3U 3U

Residual voltage measurement RESVMMXU1 Uo Vn

Sequence voltage measurement VSMSQI1 U1, U2, U0 U1, U2, U0

Three-phase power and energymeasurement, including powerfactor

PEMMXU1 P, E P, E

Frequency measurement FMMXU1 f f


ABB 89

31. Document revision historyDocument revision/date

Product version History

A/2007-12-20 1.0 First release

B/2008-02-22 1.0 Content updated

C/2008-06-20 1.1 Content updated to correspond to theproduct version

D/2009-03-03 2.0 Content updated to correspond to theproduct version. New layout on frontand back page

E/2009-07-03 2.0 Content updated

F/2009-10-01 2.0 Content updated

G/2010-06-11 3.0 Content updated to correspond to theproduct version

H/2010-06-29 3.0 Terminology corrected

K/2010-09-07 3.0 Content corrected


90 ABB

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ContentsDescriptionStandard configurationsProtection functionsApplicationSupported ABB solutionsControlMeasurementDisturbance recorderEvent logRecorded dataCondition monitoringTrip-circuit supervisionSelf-supervisionFuse failure supervisionCurrent circuit supervisionAccess controlInputs and outputsCommunicationTechnical dataLocal HMIMounting methodsIED case and IED plug-in unitSelection and ordering dataAccessories and ordering dataToolsTerminal diagramsCertificatesInspection reportsReferencesFunctions, codes and symbolsDocument revision history

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