9d4d3be41d5216d473d6cb8052592d78_4_ABB_REF_615_pg_756379_enk

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Relion ® 615 series Feeder Protection and Control REF615 Product Guide

description

REEF 615 By ABB

Transcript of 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.

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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.

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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

    Functionality A B C D E F G H

    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) -Admittance based earth-fault protection, instance 2

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

    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)

    Residual overvoltageprotection, instance 2

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

    Residual overvoltageprotection, instance 3

    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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  • Table 2. Supported functions, continued

    Functionality A B C D E F G H

    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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  • Table 2. Supported functions, continued

    Functionality A B C D E F G H

    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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  • Table 2. Supported functions, continued

    Functionality A B C D E F G H

    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

    Analog and binary horizontal GOOSE communication

    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

    Analog and binary horizontal GOOSE communication

    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

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  • 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

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  • 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

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  • 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

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  • 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

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  • 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

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

    Characteristic Value

    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)

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

    Reset ratio Typical 0.96

    Retardation time < 35 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 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

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

    Parameter Function Value (Range) Step

    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

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

    Characteristic Value

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

    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)

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

    Start time 1)2) Minimum Typical Maximum

    EFIPTOC:IFault = 2 x set Start

    valueIFault = 10 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

    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 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

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

    Parameter Function Value (Range) Step

    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

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

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  • Table 33. Directional earth-fault protection (DEFxPDEF)

    Characteristic Value

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

    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)

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

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

    Start time 1)2) Minimum Typical Maximum

    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

    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 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

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

    Parameter Function Value (Range) Step

    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)

    Characteristic Value

    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

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

    Parameter Function Value (Range) Step

    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)

    Characteristic Value

    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.

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  • 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

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

    Parameter Values(Range)

    Unit Step Default Description

    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)

    Characteristic Value

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

    1.5% of the set value or 0.002 x Un

    Start time1)2) Minimum Typical Maximum

    UFault = 1.1 x set Start

    value22 ms 24 ms 26 ms

    Reset time < 40 ms

    Reset ratio Depends of the set Relative hysteresis

    Retardation time < 35 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 ms3)

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

    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

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

    Parameter Function Value (Range) Step

    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

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

    Table 41. Three phase undervoltage protection (PHPTUV)

    Characteristic Value

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

    1.5% of the set value or 0.002 x Un

    Start time1)2) Minimum Typical Maximum

    UFault = 0.9 x set

    Start value62 ms 64 ms 66 ms

    Reset time < 40 ms

    Reset ratio Depends on the set Relative hysteresis

    Retardation time < 35 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 ms3)

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

    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

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

    Parameter Function Value (Range) Step

    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

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

    Table 43. Positive sequence undervoltage protection (PSPTUV)

    Characteristic Value

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

    1.5% of the set value or 0.002 x Un

    Start time1)2) Minimum Typical Maximum

    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

    Retardation time < 35 ms

    Operate time accuracy in definite time mode 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,

    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

    Parameter Function Value (Range) Step

    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

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  • Table 45. Frequency protection (FRPFRQ)

    Characteristic Value

    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

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  • Table 46. Frequency protection (FRPFRQ) main settings

    Parameter Values(Range)

    Unit Step Default Description

    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

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  • Table 47. Negative sequence overvoltage protection (NSPTOV)

    Characteristic Value

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

    1.5% of the set value or 0.002 Un

    Start time1)2) Minimum Typical Maximum

    UFault = 1.1 set

    Start valueUFault = 2.0 set

    Start value

    33 ms24 ms

    35 ms26 ms

    37 ms28 ms

    Reset time < 40 ms

    Reset ratio Typical 0.96

    Retardation time < 35 ms

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

    Parameter Function Value (Range) Step

    Start value NSPTOV 0.010...1.000 x Un 0.001

    Operate delay time NSPTOV 40...120000 ms 1

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  • Table 49. Residual overvoltage protection (ROVPTOV)

    Characteristic Value

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

    1.5% of the set value or 0.002 x Un

    Start time1)2) Minimum Typical Maximum

    UFault = 1.1 x set

    Start value55 ms 56 ms 58 ms

    Reset time < 40 ms

    Reset ratio Typical 0.96

    Retardation time < 35 ms

    Operate time accuracy in definite time mode 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,

    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

    Parameter Function Value (Range) Step

    Start value ROVPTOV 0.010...1.000 x Un 0.001

    Operate delay time ROVPTOV 40...300000 ms 1

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

    Characteristic Value

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

    1.5% of the set value or 0.002 x In

    Start time 1)2) Minimum Typical Maximum

    IFault = 2 x set Start

    valueIFault = 10 x set Start

    value

    22 ms14 ms

    24 ms16 ms

    25 ms17 ms

    Reset time < 40 ms

    Reset ratio Typical 0.96

    Retardation time < 35 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 DFT: -50 dB at f = n x fn, where n = 2, 3, 4, 5,

    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

    Parameter Function Value (Range) Step

    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

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

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  • Table 53. Phase discontinuity protection (PDNSPTOC)

    Characteristic Value

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

    2% of the set value

    Start time < 70 ms

    Reset time < 40 ms

    Reset ratio Typical 0.96

    Retardation time < 35 ms

    Operate time accuracy in definite time mode 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,

    Table 54. Phase discontinuity protection (PDNSPTOC) main settings

    Parameter Function Value (Range) Step

    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)

    Characteristic Value

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

    1.5% of the set value or 0.002 x In

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

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

    Parameter Function Value (Range) Step

    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)

    Characteristic Value

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

    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

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

    Parameter Function Value (Range) Step

    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

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

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

    Characteristic Value

    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

    Reset ratio Typical 0.96

    Operate time accuracy +35 ms / -0 ms

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

    Parameter Function Value (Range) Step

    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)

    Characteristic Value

    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

    Reset ratio Typical 0.96

    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

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  • Table 62. Arc protection (ARCSARC) main settings

    Parameter Function Value (Range) Step

    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

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

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  • Control functionsTable 64. Autoreclosure (DARREC)

    Characteristic Value

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

    Table 65. Synchrocheck (SECRSYN)

    Characteristic Value

    Operation accuracy Depending on the frequency of the voltagemeasured: fn 1 Hz

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

    Reset time < 50 ms

    Reset ratio Typical 0.96

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

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  • 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

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  • 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)

    Characteristic Value

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

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

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

    RMS: No suppression

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  • Table 68. Current sequence components (CSMSQI)

    Characteristic Value

    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

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

    Table 69. Three-phase voltage measurement (VMMXU)

    Characteristic Value

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

    At voltages in range 0.011.15 x Un

    0.5% or 0.002 x Un

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

    RMS: No suppression

    Table 70. Voltage sequence components (VSMSQI)

    Characteristic Value

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

    At voltages in range 0.011.15 x Un

    1.0% or 0.002 x Un

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

    Table 71. Residual current measurement (RESCMMXU)

    Characteristic Value

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

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

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

    RMS: No suppression

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  • Table 72. Residual voltage measurement (RESVMMXU)

    Characteristic Value

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

    0.5% or 0.002 x Un

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

    RMS: No suppression

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

    Characteristic Value

    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

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  • 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)

    Admittance based earth-faultprotection, instance 2

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

    Admittance based earth-faultprotection, instance 3

    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)

    Residual overvoltage protection,instance 2

    ROVPTOV2 Uo> (2) 59G (2)

    Residual overvoltage protection,instance 3

    ROVPTOV3 Uo> (3) 59G (3)

    Three-phase undervoltageprotection, instance 1

    PHPTUV1 3U< (1) 27 (1)

    Three-phase undervoltageprotection, instance 2

    PHPTUV2 3U< (2) 27 (2)

    Three-phase undervoltageprotection, instance 3

    PHPTUV3 3U< (3) 27 (3)

    Three-phase overvoltageprotection, instance 1

    PHPTOV1 3U> (1) 59 (1)

    Three-phase overvoltageprotection, instance 2

    PHPTOV2 3U> (2) 59 (2)

    Three-phase overvoltageprotection, instance 3

    PHPTOV3 3U> (3) 59 (3)

    Positive-sequence undervoltageprotection, instance 1

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

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  • Table 84. REF615 Functions, codes and symbols, continued

    Function IEC 61850 IEC 60617 IEC-ANSI

    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)

    Arc protection, instance 2 ARCSARC2 ARC (2) 50L/50NL (2)

    Arc protection, instance 3 ARCSARC3 ARC (3) 50L/50NL (3)

    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)

    Disconnector position indication,instance 2

    DCSXSWI2 I O DC (2) I O DC (2)

    Disconnector position indication,instance 3

    DCSXSWI3 I O DC (3) I O DC (3)

    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

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  • Table 84. REF615 Functions, codes and symbols, continued

    Function IEC 61850 IEC 60617 IEC-ANSI

    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

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

    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

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

    90 ABB

  • 91

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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