Feeder Protection and Control REF630 Product · PDF fileFeeder Protection and Control REF630...

Relion® 630 series

Feeder Protection and ControlREF630Product Guide

Contents

1. Description...........................................................3

2. Application...........................................................3

3. Preconfigurations.................................................5

4. Protection functions.............................................9

5. Control................................................................13

6. Fault location......................................................13

7. Measurement.....................................................13

8. Disturbance recorder..........................................13

9. Power quality......................................................14

10. Event log............................................................14

11. Disturbance report............................................15

12. Circuit-breaker monitoring................................15

13. Trip-circuit supervision......................................15

14. Self-supervision.................................................15

15. Fuse failure supervision.....................................15

16. Current circuit supervision................................16

17. Access control...................................................16

18. Inputs and outputs............................................16

19. Communication.................................................18

20. Technical data...................................................19

21. Front panel user interface.................................67

22. Mounting methods............................................67

23. Selection and ordering data..............................69

24. Accessories.......................................................73

26. Tools..................................................................74

27. Supported ABB solutions..................................76

28. Terminal diagrams.............................................76

29. References........................................................80

30. Functions, codes and symbols.........................80

31. Document revision history.................................84

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 2011 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 1MRS756976 CREF630Product version: 1.1 Issued: 2011-02-23

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1. Description

REF630 is a comprehensive feedermanagement IED for protection, control,measuring and supervision of utility andindustrial distribution substations. REF630 is

a member of ABB’s Relion® product familyand a part of its 630 series characterized byfunctional scalability and flexibleconfigurability. REF630 also featuresnecessary control functions constituting anideal solution for feeder bay control.

The supported communication protocolsincluding IEC 61850 offer seamlessconnectivity to industrial automation systems.

2. Application

REF630 provides main protection foroverhead lines and cable feeders of

distribution networks. The IED fits bothisolated neutral networks and networks withresistance or impedance earthed neutral. Fourpre-defined configurations to match typicalfeeder protection and control requirementsare available. The pre-defined configurationscan be used as such or easily adapted orextended with freely selectable add-onfunctions, by means of which the IED can befine-tuned to exactly satisfy the specificrequirements of your present application.


Revision: C

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GUID-EBE462A5-7366-467A-BA18-583E75428EDB V2 EN

Figure 1. RET630 and REF630 IEDs applied for the incoming feeder and primary switchgearin a double busbar arrangement. The RET630 with preconfiguration A is used forprotection and control of the power transformer, the REF630 with preconfiguration Bprotects and controls the outgoing feeder and the REF630 with preconfiguration D isused for the bus sectionalizer.


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3. Preconfigurations

The 630 series IEDs are offered with optionalfactory-made preconfigurations for variousapplications. The preconfigurationscontribute to faster commissioning and lessengineering of the IED. Thepreconfigurations include defaultfunctionality typically needed for a specificapplication. Each preconfiguration isadaptable using the Protection and ControlIED Manager PCM600. By adapting thepreconfiguration the IED can be configuredto suit the particular application.

The adaptation of the preconfiguration mayinclude adding or removing of protection,control and other functions according to thespecific application, changing of the defaultparameter settings, configuration of thedefault alarms and event recorder settingsincluding the texts shown in the HMI,

configuration of the LEDs and functionbuttons, and adaptation of the default single-line diagram.

In addition, the adaptation of thepreconfiguration always includescommunication engineering to configure thecommunication according to the functionalityof the IED. The communication engineeringis done using the communicationconfiguration function of PCM600.

If none of the offeredpreconfigurations fulfill theneeds of the intended area ofapplication, 630 series IEDscan also be ordered withoutany preconfiguration. In thiscase the IED needs to beconfigured from the groundup.

Table 1. REF630 preconfiguration ordering options

Description Preconfiguration

Preconfiguration A for open/closed ring feeder A

Preconfiguration B for radial overhead/mixed line feeder B

Preconfiguration C for ring/meshed feeder C

Preconfiguration D for bus sectionalizer D

Number of instances available n


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Table 2. Functions used in preconfigurations. Column 'n' shows the total number ofavailable function instances regardless of the preconfiguration selected.

Functionality A B C D n

Protection

Three-phase non-directional overcurrent, low stage 1 1 1 1 1

Three-phase non-directional overcurrent, high stage 2 2 2 2 2

Three-phase non-directional overcurrent, instantaneous stage 1 1 1 1 1

Three-phase directional overcurrent, low stage 2 - - - 2

Three-phase directional overcurrent, high stage 1 - - - 1

Distance protection1) - - 1 - 1

Automatic switch-onto-fault logic - - 1 - 2

Fault locator1) - - - - 1

Autoreclosing 1 1 1 - 2

Non-directional earth-fault, low stage - 1 - 1 1

Non-directional earth-fault, high stage 1 1 1 1 1

Non-directional earth-fault, instantaneous stage - 1 - 1 1

Directional earth-fault, low stage 2 1 3 - 3

Directional earth-fault, high stage 1 - 1 - 1

Transient/intermittent earth-fault 1 - - - 1

Admittance-based earth-fault protection - - - - 3

Wattmetric earth-fault protection - - - - 3

Negative-sequence overcurrent 2 2 2 2 2

Three-phase thermal overload protection for feeder 1 1 1 - 1

Phase discontinuity 1 1 1 - 1

Three-phase current inrush detection 1 1 1 1 1

Three-phase overvoltage - - 3 - 3

Three-phase undervoltage - - 3 - 3

Positive-sequence overvoltage - - - - 2

Positive-sequence undervoltage - - - - 2

Negative-sequence overvoltage - - - - 2

Residual overvoltage - - 3 - 3

Frequency gradient - - - - 5


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Table 2. Functions used in preconfigurations. Column 'n' shows the total number ofavailable function instances regardless of the preconfiguration selected., continued


Overfrequency - - - - 5

Underfrequency - - - - 5

Load shedding - - - - 6

Circuit-breaker failure 1 1 1 1 2

Tripping logic 1 1 1 1 2

Multipurpose analog protection - - - - 16

Protection-related functions

Local acceleration logic - - 1 - 1

Communication logic for residual overcurrent - - 1 - 1

Scheme communication logic - - 1 - 1

Current reversal and WEI logic - - 1 - 1

Current reversal and WEI logic for residual overcurrent - - 1 - 1

Control

Bay control 1 1 1 1 1

Interlocking interface 4 4 4 1 10

Circuit breaker/disconnector control 4 4 4 1 10

Circuit breaker 1 1 1 1 2

Disconnector 3 3 3 - 8

Local/remote switch interface - - - - 1

Synchrocheck1) - - - - 1

Generic process I/O

Single point control (8 signals) - - - - 5

Double point indication - - - - 15

Single point indication - - - - 64

Generic measured value - - - - 15

Logic rotating switch for function selection and LHMIpresentation

- - - - 10

Selector mini switch - - - - 10

Pulse counter for energy metering - - - - 4

Event counter - - - - 1


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Supervision and monitoring

Circuit-breaker condition monitoring 1 1 1 1 2

Fuse failure supervision 1 1 1 - 2

Current circuit supervision 1 1 1 - 2

Trip-circuit supervision 3 3 3 3 3

Station battery supervision - - - - 1

Energy monitoring - - - - 1

Measured value limit supervision - - - - 40

Power quality

Voltage variation1) - - - - 1

Voltage unbalance1) - - - - 1

Current harmonics1) - - - - 1

Voltage harmonics (phase-to-phase)1) - - - - 1

Voltage harmonics (phase-to-earth)1) - - - - 1

Measurement

Three-phase current 1 1 1 1 1

Three-phase voltage (phase-to-earth) 1 1 1 1 1

Three-phase voltage (phase-to-phase) - - - - 1

Residual current 1 1 1 1 1

Residual voltage 1 1 1 - 1

Power monitoring with P, Q, S, power factor, frequency 1 1 1 1 1

Sequence current 1 1 1 1 1

Sequence voltage 1 1 1 1 1

Disturbance recorder function

Analog channels 1-10 (samples) 1 1 1 1 1

Analog channels 11-20 (samples) - - - - 1

Analog channels 21-30 (calc. val.) - - - - 1

Analog channels 31-40 (calc. val.) - - - - 1

Binary channels 1-16 1 1 1 1 1


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Binary channels 49-64 1 - 1 - 1

Station communication (GOOSE)

Binary receive - - - - 10

Double point receive - - - - 32

Interlock receive - - - - 59

Integer receive - - - - 32

Measured value receive - - - - 62

Single point receive - - - - 62

1) Optional function, to be specified at ordering

4. Protection functions

The IED offers selective short-circuit andovercurrent protection including three-phasenon-directional overcurrent protection withfour independent stages, and three-phasedirectional overcurrent protection with threeindependent stages. In addition, the IEDincludes three-phase current inrush detectionfor blocking selected overcurrent protectionstages or temporarily increasing the settingvalues. The included thermal overloadprotection function uses thermal models ofoverhead lines and cables. The negative-sequence overcurrent protection, with twoindependent stages, is used for phase-unbalance protection. In addition, the IEDoffers phase discontinuity.

Further, the IED features selective earth-faultand cross country fault protection for isolatedneutral, and for resistance and/or impedanceearthed neutral systems including solidlyearthed neutral systems. The earth-faultprotection includes non-directional earth-fault

protection with three independent stages anddirectional earth-fault protection with fourindependent stages. Apart from theconventional earth-fault protection, the IEDoffers wattmetric and admittance-based earth-fault protection.

The included transient/intermittent earth-faultprotection is based on detection of earth-faulttransients related to continuous orintermittent faults. Intermittent earth-fault isspecial type of earth-fault encountered incompensated networks with undergroundcables. In solidly earthed or compensatednetworks the transient earth-fault protectionfunction detects earth-faults with low faultresistance. The residual overvoltageprotection, with three independent stages, isused for earth-fault protection of thesubstation bus and the incoming feeder, andfor back-up protection of the outgoing feeders.

The IED offers distance protection includingboth circular (mho) and quadrilateral (quad)zone characteristics, three independent zoneswith separate reach settings for phase-to-phase and phase-to-earth measuring elements


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and two zones for controlling auto-reclosingof circuit breakers. Further, the IED offersautomatic switch onto fault logic with voltageand current based detection options.

The IED offers voltage protection functionsincluding three-phase undervoltage andovervoltage protection with threeindependent stages each, both with phase-to-phase or phase-to-earth measurement. TheIED offers overfrequency, underfrequency

and rate-of-change of frequency protection tobe used in load shedding and networkrestoration applications.

In addition the IED offers three-pole multi-shot autoreclose functions for overhead linefeeders.

The IED incorporates breaker failureprotection for circuit breaker re-tripping orback-up tripping for the upstream breaker.

GUID-8D94ABFF-3F94-4C26-BDF5-2F4DD4B906FB V1 EN

Figure 2. Protection function overview of preconfiguration A


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Figure 3. Protection function overview of preconfiguration B


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Figure 4. Protection function overview of preconfiguration C

GUID-CE8BEBCD-9D9B-4FE6-A9EF-AF4690339584 V1 EN

Figure 5. Protection function overview of preconfiguration D


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5. Control

The IED incorporates local and remotecontrol functions. The IED offers a number offreely assignable binary inputs/outputs andlogic circuits for establishing bay control andinterlocking functions for circuit breakers andmotor operated switch-disconnectors. TheIED supports both single and double busbarsubstation busbar layouts. The number ofcontrollable primary apparatuses depends onthe number of available inputs and outputs inthe selected configuration. Besidesconventional hardwired signaling alsoGOOSE messaging according to IEC61850-8-1 can be used for signal interchangebetween IEDs to obtain required interlockings.

Further, the IED incorporates a synchro-check function to ensure that the voltage,phase angle and frequency on either side ofan open circuit breaker satisfy the conditionsfor safe interconnection of two networks.

6. Fault location

REF630 features an impedance-measuringfault location function suitable for locatingshort-circuits in radial distribution systems.Earth faults can be located in effectively andlow-resistance earthed networks. Undercircumstances where the fault currentmagnitude is at least of the same order ofmagnitude or higher than the load current,earth faults can also be located in isolatedneutral distribution networks. The faultlocation function identifies the type of thefault and then calculates the distance to thefault point. An estimate of the fault resistancevalue is also calculated. The estimateprovides information about the possible faultcause and the accuracy of the estimateddistance to the fault point.

7. Measurement

The IED continuously measures the phasecurrents, positive and negative sequencecurrents and the residual current. The IEDalso measures phase-to earth or phase-to-phase voltages, positive and negativesequence voltages and the residual voltage.In addition, the IED monitors active, reactiveand apparent power, the power factor, powerdemand value over a user-selectable pre-settime frame as well as cumulative active andreactive energy of both directions. Linefrequency, the calculated temperature of thefeeder, and the phase unbalance value basedon the ratio between the negative sequenceand positive sequence current are alsocalculated. Cumulative and averagingcalculations utilize the non-volatile memoryavailable in the IED.

The values measured are accessed locally viathe front-panel user interface of the IED orremotely via the communication interface ofthe IED. The values are also accessed locallyor remotely using the web-browser baseduser interface.

8. Disturbance recorder

The IED is provided with a disturbancerecorder featuring up to 40 analog and 64binary signal channels. The analog channelscan be set to record the waveform of thecurrents and voltage measured. The analogchannels can be set to trigger the recordingwhen the measured value falls below orexceeds the set values. The binary signalchannels can be set to start a recording onthe rising or the falling edge of the binarysignal. The binary channels are set to recordexternal or internal IED signals, for examplethe start or operate signals of the protectionfunctions, or external blocking or controlsignals. Binary IED signals such as aprotection start or trip signal, or an external


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IED control signal over a binary input can beset to trigger the recording. In addition, thedisturbance recorder settings include pre- andpost triggering times.

The disturbance recorder can store up to 100recordings. The number of recordings mayvary depending on the length of therecording and the number of signalsincluded. The disturbance recorder controlsthe Start and Trip LEDs on the front-paneluser interface. The operation of the LEDs isfully configurable enabling activation whenone or several criteria, that is, protectionfunction starting or tripping, are fulfilled.

The recorded information is stored in a non-volatile memory and can be uploaded forsubsequent fault analysis.

9. Power quality

Power quality in standards is defined throughthe characteristics of the supply voltage.Transients, short- and long-duration voltagevariations, unbalance and waveformdistortion are the key characteristicsdescribing the power quality. The powerquality is, however, a customer-driven issue.It can be said that any power problemconcerning the voltage or current that resultsin a failure or misoperation of the customerequipment is a power quality problem.

REF630 has the following power qualitymonitoring functions.

• Voltage variation• Voltage unbalance• Current harmonics• Voltage harmonics (phase-to-phase and

phase-to-earth)

The harmonics measurement functions areused for monitoring the individual harmonic

components (up to 20th) and total harmonicdistortion (THD). The current harmonicfunction also monitors total demanddistortion (TDD).

The variation in the voltage waveform isevaluated by measuring voltage swells, dipsand interruptions. The voltage variationfunction includes a single-phase, two-phaseand three-phase voltage variationmeasurement. The voltage unbalancefunction uses five different methods forcalculating voltage unbalance.

• Negative-sequence voltage magnitude• Zero-sequence voltage magnitude• Ratio of negative-sequence to positive-

sequence voltage magnitude• Ratio of zero-sequence to positive-

sequence voltage magnitude• Ratio of maximum phase voltage

magnitude deviation from the meanvoltage magnitude to the mean of phasevoltage magnitude

10. Event log

The IED features an event log which enableslogging of event information. The event logcan be configured to log informationaccording to user pre-defined criteriaincluding IED signals. To collect sequence-of-events (SoE) information, the IEDincorporates a non-volatile memory with acapacity of storing 1000 events withassociated time stamps and user definableevent texts. The non-volatile memory retainsits data also in case the IED temporarily losesits auxiliary supply. The event log facilitatesdetailed pre- and post-fault analyses of faultsand disturbances.

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.

The logging of communication events isdetermined by the used communicationprotocol and the communication engineering.The communication events are automatically


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sent to station automation and SCADAsystems once the required communicationengineering has been done.

11. Disturbance report

The disturbance report includes informationcollected during the fault situation. Thereport includes general information such asrecording time, pre-fault time and post faulttime. Further, the report includes pre-faultmagnitude, pre-fault angle, fault magnitudeand fault angle trip values. By default, thedisturbance reports are stored in a non-volatile memory. The numerical disturbancereport can be accessed via the local frontpanel user interface. A more comprehensivedisturbance report with waveforms isavailable using PCM600.

12. Circuit-breakermonitoring

The 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,operation counter, accumulated energycalculator, circuit-breaker life estimator andthe inactivity time of the circuit breaker.

The monitoring functions provide operationalcircuit breaker history data, which can beused for scheduling preventive circuit breakermaintenance.

13. 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.

14. Self-supervision

The IED’s built-in self-supervision systemcontinuously monitors the state of the IEDhardware and the operation of the IEDsoftware. Any fault or malfunction detected isused for alerting the operator.

Self-supervision events are saved into aninternal event list which can be accessedlocally via the user interface on the IED frontpanel. The event list can also be accessedusing the web-browser based user interfaceor PCM600.

15. Fuse failuresupervision

The fuse failure supervision detects failuresbetween the voltage measurement circuit andthe IED. The failures are detected by thenegative-sequence based algorithm or by thedelta voltage and delta current algorithm.Upon the detection of a failure the fusefailure supervision function activates an alarmand blocks voltage-dependent protectionfunctions from unintended operation.


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16. Current circuitsupervision

Current circuit supervision is used fordetecting faults in the current transformersecondary circuits. On detecting of a fault thecurrent circuit supervision function can alsoactivate an alarm LED and block certainprotection functions to avoid unintendedoperation. The current circuit supervisionfunction calculates the sum of the phasecurrents and compares the sum with themeasured single reference current from acore balance current transformer or fromanother set of phase current transformers.

17. Access control

To protect the IED from unauthorized accessand to maintain information integrity, the IEDis provided with an authentication systemincluding user management. Using the IEDUser Management tool in the Protection andControl IED Manager PCM600, an individualpassword is assigned to each user by theadministrator. Further, the user name isassociated to one or more of the fouravailable user groups: System Operator,Protection Engineer, Design Engineer andUser Administrator. The user groupassociation for each individual user enablesthe use of the IED according to the profile ofthe user group.

18. Inputs and outputs

Depending on the hardware configurationselected, the IED is equipped with three phase-current inputs and one or two residual-current inputs for earth-fault protection. TheIED always includes one residual voltageinput for directional earth-fault protection or

residual voltage protection. Further, the IEDincludes three phase-voltage inputs forovervoltage, undervoltage and directionalovercurrent protection and other voltagebased protection functions. Depending on thehardware configuration, the IED also includesa dedicated voltage input for synchrocheck.

The phase-current inputs are rated 1/5 A. TheIED is equipped with one or two alternativeresidual-current inputs, that is 1/5 A or0.1/0.5 A. The 0.1/0.5 A input is normallyused in applications requiring sensitive earth-fault protection and featuring a core-balancecurrent transformer.

The three phase-voltage inputs, for eitherphase-to-phase voltages or phase-to-earthvoltages, and the residual-voltage input coverthe rated voltages 100 V, 110 V, 115 V and120 V. The rated values of the current andvoltage inputs are selected in the IED software.

In addition, the binary input thresholds areselected by adjusting the IED’s parametersettings. The threshold voltage can be setseparately for each binary input.

There is also an optional RTD/mA modulewith 8 RTD/mA inputs and 4 mA outputs.The optional RTD/mA module facilitates themeasurement of up to eight analog signalsvia the RTD/mA inputs and four scalable mAoutputs. The RTD/mA inputs can be used formeasuring the ambient air temperature orsupervising analog signals provided byexternal transducers. Any of the RTD/mAinputs can be alternatively used also asresistance input or as an input for voltagetransducer. The mA outputs can be used fortransferring freely selectable measured orcalculated analog values to other devicesprovided with mA input capabilities.

The enhanced scalability of the 6U variantIEDs are intended for optimized mediumvoltage metal-clad switchgear applicationswhere additional binary inputs and outputsare often required.

All binary input and output contacts arefreely configurable using the signal matrix of


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the application configuration function inPCM600.

Please refer to the Input/output overviewtables, the selection and ordering data and

the terminal diagrams for more detailedinformation about the inputs and outputs.

Table 3. Analog input configuration

Analog inputconfiguration

CT (1/5 A) CT sensitive(0.1/0.5 A)

VT RTD/mAinputs

mA outputs

AA 4 - 5 - -

AB 4 1 4 - -

AC 3 1 5 - -

BA 4 - 5 8 4

BB 4 1 4 8 4

BC 3 1 5 8 4

Table 4. Binary input/output options for 4U variants

Binary I/O options Binary inputconfiguration

BI BO

Default AA 14 9

With one optional binary I/Omodule

AB 23 18

With two optional binary I/O

modules1)

AC 32 27

1) Not possible if RTD/mA module is selected.

Table 5. Binary input/output options for 6U variants

Binary I/O options Binary inputconfiguration

BI BO

Default AA 14 9

With one optional binary I/Omodule

AB 2318

With two optional binary I/Omodules

AC 32 27

With three optional binary I/Omodules

AD 4136

With four optional binary I/O

modules1) AE 50 45

1) Not possible if RTD/mA module is selected.


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19. Communication

The IED supports the IEC 61850 substationautomation standard including horizontalGOOSE communication as well as the well-established DNP3 (TCP/IP) and IEC60870-5-103 protocols. All operationalinformation and controls are availablethrough these protocols.

Disturbance files are accessed using the IEC61850 or IEC 60870-5-103 protocols.Disturbance files are also available to anyEthernet based application in the standardCOMTRADE format. The IED can send binarysignals to other IEDs (so called horizontalcommunication) using the IEC 61850-8-1GOOSE (Generic Object Oriented SubstationEvent) profile. Binary GOOSE messaging can,for example, be employed for protection andinterlocking-based protection schemes. TheIED meets the GOOSE performancerequirements for tripping applications indistribution substations, as defined by theIEC 61850 standard. Further, the IEDsupports the sending and receiving of analogvalues using GOOSE messaging. AnalogGOOSE messaging enables fast transfer ofanalog measurement values over the stationbus, thus facilitating for example sharing ofRTD input values, such as surroundingtemperature values, to other IEDapplications. Analog GOOSE messages canalso be used in load shedding applications.The IED interoperates with other IEC 61850compliant IEDs, tools and systems andsimultaneously reports events to five different

clients on the IEC 61850 station bus. For asystem using DNP3 over TCP/IP, events canbe sent to four different masters. For systemsusing IEC 60870-5-103 IED can be connectedto one master in a station bus with star-topology.

All communication connectors, except for thefront port connector, are placed on integratedcommunication modules. The IED isconnected to Ethernet-based communicationsystems via the RJ-45 connector (10/100BASE-TX) or the fibre-optic multimode LCconnector (100BASE-FX).

IEC 60870-5-103 is available from opticalserial port where it is possible to use serialglass fibre (ST connector) or serial plasticfibre (snap-in connector).

The IED supports SNTP, DNP3 and IRIG-Btime synchronization methods with a time-stamping resolution of 1 ms.

The IED supports the following timesynchronization methods with atimestamping resolution of 1 ms:

Ethernet communication based:

• SNTP (simple network time protocol)• DNP3

With special time synchronization wiring:

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

IEC 60870-5-103 serial communication has atime-stamping resolution of 10 ms.


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Table 6. Supported communication interface and protocol alternatives

Interfaces/

protocols1)

Ethernet100BASE-TX

RJ-45

Ethernet100BASE-FX LC

Serial snap-in Serial ST

IEC 61850

DNP3

IEC 60870-5-103 = Supported

1) Please refer to the Selection and ordering data chapter for more information


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20. Technical data

Table 7. Dimensions

Description Value

Width 220 mm

Height 177 mm (4U)265.9 mm (6U)

Depth 249.5 mm

Weight box 6.2 kg (4U)

5.5 kg (6U)1)

Weight LHMI 1.0 kg (4U)

1) Without LHMI

Table 8. Power supply

Description Type 1 Type 2

Uauxnominal 100, 110, 120, 220, 240 VAC, 50 and 60 Hz

48, 60, 110, 125 V DC

110, 125, 220, 250 V DC

Uauxvariation 85...110% of Un (85...264 V

AC)

80...120% of Un (38.4...150 V

DC)

80...120% of Un (88...300 V

DC)

Maximum load of auxiliaryvoltage supply

35 W

Ripple in the DC auxiliaryvoltage

Max 15% of the DC value (at frequency of 100 Hz)

Maximum interruption time inthe auxiliary DC voltagewithout resetting the IED

50 ms at Uaux

Power supply input must beprotected by an externalminiature circuit breaker

For example, type S282 UC-K.The rated maximum load of aux voltage which is given as35 watts. Depending on the voltage used, select a suitableMCB based on the respective current. Type S282 UC-K hasa rated current of 0.75 A at 400 V AC.


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Table 9. Energizing inputs

Description Value

Rated frequency 50/60 Hz

Operating range Rated frequency ± 5 Hz

Current inputs Rated current, In 0.1/0.5 A1) 1/5 A2)

Thermal withstandcapability:

• Continuously 4 A 20 A

• For 1 s 100 A 500 A

• For 10 s 25 A 100 A

Dynamic currentwithstand:

• Half-wave value 250 A 1250 A

Input impedance <100 mΩ <20 mΩ

Voltage inputs Rated voltage, Un 100 V AC/ 110 V AC/ 115 V AC/ 120 V AC

Voltage withstand:

• Continuous 425 V AC

• For 10 s 450 V AC

Burden at rated voltage <0.05 VA

1) Residual current2) Phase currents or residual current

Table 10. Binary inputs

Description Value

Operating range Maximum input voltage 300 V DC

Rated voltage 24...250 V DC

Current drain 1.6...1.8 mA

Power consumption/input <0.3 W

Threshold voltage 15...221 V DC (parametrizable in the range insteps of 1% of the rated voltage)


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Table 11. RTD inputs

Description Value

RTDinputs

Supported RTD sensor 100 Ω platinum TCR 0.00385(DIN 43760)

250 Ω platinum TCR 0.00385

100 Ω nickel TCR 0.00618(DIN 43760)

120 Ω nickel TCR 0.00618

10 Ω copper TCR 0.00427

Supported resistance range 0…10 kΩ

Maximum leadresistance(three-wire measurement)

100 Ω platinum 25 Ω per lead

250 Ω platinum 25 Ω per lead

100 Ω nickel 25 Ω per lead

120 Ω nickel 25 Ω per lead

10 Ω copper 2.5 Ω per lead

Resistance 25 Ω per lead

Isolation 4 kV Inputs to alloutputs andprotective earth

RTD / resistance sensingcurrent

Maximum 0.275 mA rms

Operation accuracy /temperature

• ±1°C Pt and Ni sensorsfor measuringrange -40°C to200°C and -40°Cto 70°C ambienttemperature

• ±2°C CU sensor formeasuring range-40°C to 200°C inroom temperature

• ±4°C CU sensors -40°Cto 70°C ambienttemperature

• ±5°C From -40°C to-100 ºC ofmeasurementrange

Operation accuracy /Resistance

±2.5 Ω 0-400 Ω range

±1.25% 400 Ω -10K Ωohms range

Response time < Filter time +350 ms


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Table 11. RTD inputs, continued

Description Value

mA inputs Supported current range -20 mA … +20 mA

Current input impedance 100 Ω ± 0.1%

Operation accuracy ± 0.01% ± 20 ppm per °C offull-scale

Ambienttemperature-40°C to 70°C

Voltageinputs

Supported current range -10 Vdc….+10 Vdc

Operation accuracy ±0.01% ± 40 ppm per °C of full-scale

Ambienttemperature-40°C to 70°C

Table 12. Signal output and IRF output

IRF relay change over - type signal output relay

Description Value

Rated voltage 250 V AC/DC

Continuous contact carry 5 A

Make and carry for 3.0 s 10 A

Make and carry 0.5 s 15 A

Breaking capacity when the control-circuittime constant L/R<40 ms, at U< 48/110/220V DC

≤0.5 A/≤0.1 A/≤0.04 A

Minimum contact load 100 mA at 24 V AC/DC

Table 13. Power output relays without TCS function

Description Value

Rated voltage 250 V AC/DC





≤1 A/≤0.3 A/≤0.1 A

Minimum contact load 100 mA at 24 V AC/DC


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Table 14. Power output relays with TCS function

Description Value

Rated voltage 250 V DC





≤1 A/≤0.3 A/≤0.1 A

Minimum contact load 100 mA at 24 V DC

Control voltage range 20...250 V DC

Current drain through the supervision circuit ~1.0 mA

Minimum voltage over the TCS contact 20 V DC

Table 15. mA outputs

Description Value

mA outputs Output range -20 mA … +20 mA

Operation accuracy ±0.2 mA

Maximum (including wiring resistance) 700 Ω

Response time ~20 ms

Isolation 4 kV

Table 16. Ethernet interfaces

Ethernet interface Protocol Cable Data transfer rate

LAN1 (X1) TCP/IP protocol Fibre-optic cablewith LC connector orshielded twisted pairCAT 5e cable or better

100 MBits/s

Table 17. Fibre-optic communication link

Wave length Fibre type Connector Permitted path

attenuation1)

Distance

1300 nm MM 62.5/125μm glassfibre core

LC <8 dB 2 km

1) Maximum allowed attenuation caused by connectors and cable together


24 ABB

Table 18. X4/IRIG-B interface

Type Protocol Cable

Screw terminal, pinrow header

IRIG-B Shielded twisted pair cableRecommended: CAT 5, Belden RS-485 (9841-9844) or Alpha Wire (Alpha 6222-6230)

Table 19. Serial rear interface

Type Counter connector

Serial port (X9) Optical ST connector or optical snap-inconnector

Table 20. Degree of protection of flush-mounted IED

Description Value

Front side IP 40

Rear side, connection terminals IP 20

Table 21. Degree of protection of the LHMI

Description Value

Front and side IP 42

Table 22. Environmental conditions

Description Value

Operating temperature range -25...+55ºC (continuous)

Short-time service temperature range -40...+85ºC (<16h)Note: Degradation in MTBF and HMIperformance outside the temperature rangeof -25...+55ºC

Relative humidity <93%, non-condensing

Atmospheric pressure 86...106 kPa

Altitude up to 2000 m

Transport and storage temperature range -40...+85ºC


ABB 25

Table 23. Environmental tests

Description Type test value Reference

Dry heat test (humidity <50%) • 96 h at +55ºC• 16 h at +85ºC

IEC 60068-2-2

Cold test • 96 h at -25ºC• 16 h at -40ºC

IEC 60068-2-1

Damp heat test, cyclic • 6 cycles at +25…55°C, Rh>93%

IEC 60068-2-30

Storage test • 96 h at -40ºC• 96 h at +85ºC

IEC 60068-2-48


26 ABB

Table 24. Electromagnetic compatibility tests


100 kHz and 1 MHz burstdisturbance test

IEC 61000-4-18IEC 60255-22-1, level 3

• Common mode 2.5 kV

• Differential mode 1.0 kV

Electrostatic discharge test IEC 61000-4-2IEC 60255-22-2IEEE C37.90.3.2001

• Contact discharge 8 kV

• Air discharge 15 kV

Radio frequency interferencetests

• Conducted, common mode 10 V (rms), f=150 kHz...80MHz

IEC 61000-4-6IEC 60255-22-6, level 3

• Radiated, pulse-modulated 10 V/m (rms), f=900 MHz ENV 50204IEC 60255-22-3

• Radiated, amplitude-modulated

10 V/m (rms), f=80...2700MHz

IEC 61000-4-3IEC 60255-22-3, level 3

Fast transient disturbancetests

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

• All ports 4 kV

Surge immunity test IEC 61000-4-5IEC 60255-22-5

• Communication 1 kV line-to-earth

• Binary inputs, voltageinputs

2 kV line-to-earth1 kV line-to-line

• Other ports 4 kV line-to-earth, 2 kV line-to-line

Power frequency (50 Hz)magnetic field

IEC 61000-4-8

• 1...3 s 1000 A/m

• Continuous 300 A/m


ABB 27

Table 24. Electromagnetic compatibility tests, continued


Power frequency immunitytest

• Common mode

• Differential mode

Binary inputs only 300 V rms 150 V rms

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

Voltage dips and shortinterruptions

30%/10 ms60%/100 ms60%/1000 ms>95%/5000 ms

IEC 61000-4-11

Electromagnetic emissiontests

EN 55011, class AIEC 60255-25

• Conducted, RF-emission(mains terminal)

0.15...0.50 MHz < 79 dB(µV) quasi peak< 66 dB(µV) average

0.5...30 MHz < 73 dB(µV) quasi peak< 60 dB(µV) average

• Radiated RF-emission

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

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


28 ABB

Table 25. Insulation tests


Dielectric tests: IEC 60255-5IEC 60255-27

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

Impulse voltage test: IEC 60255-5IEC 60255-27

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

Insulation resistancemeasurements

IEC 60255-5IEC 60255-27

• Isolation resistance >100 MΏ, 500 V DC

Protective bonding resistance IEC 60255-27

• Resistance <0.1 Ώ, 4 A, 60 s

Table 26. Mechanical tests

Description Reference Requirement

Vibration tests (sinusoidal) IEC 60068-2-6 (test Fc)IEC 60255-21-1

Class 1

Shock and bump test IEC 60068-2-27 (test Eashock)IEC 60068-2-29 (test Ebbump)IEC 60255-21-2

Class 1

Seismic test IEC 60255-21-3 (method A) Class 1

Table 27. Product safety

Description Reference

LV directive 2006/95/EC

Standard EN 60255-27 (2005)EN 60255-1 (2009)


ABB 29

Table 28. EMC compliance

Description Reference

EMC directive 2004/108/EC

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

Table 29. RoHS compliance

Description

Complies with RoHS directive 2002/95/EC


30 ABB

Protection functions

Table 30. Three-phase non-directional overcurrent protection (PHxPTOC)

Characteristic Value

Operation accuracy At the frequency f = fn

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 0.1…10 x In)

±5.0% of the set value(at currents in the range of 10…40 x In)

Start time 1)2) PHIPTOC:IFault = 2 x set Start

valueIFault = 10 x set Start

value

Typical: 17 ms (±5 ms) Typical: 10 ms (±5 ms)

PHHPTOC:IFault = 2 x set Start

value

Typical: 19 ms (±5 ms)

PHLPTOC:IFault = 2 x set Start

value


Reset time < 45 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 31

Table 31. Three-phase non-directional overcurrent protection (PHxPTOC) main settings

Parameter Function Value (Range) Step

Start Value PHLPTOC 0.05...5.00 pu 0.01

PHHPTOC 0.10...40.00 pu 0.01

PHIPTOC 0.10...40.00 pu 0.01

Time multiplier PHLPTOC 0.05...15.00 0.05

PHHPTOC 0.05...15.00 0.05

Operate delay time PHLPTOC 0.04…200.00 s 0.01

PHHPTOC 0.02…200.00 s 0.01

PHIPTOC 0.02…200.00 s 0.01

Operating curve

type1)

PHLPTOC Definite or inverse timeCurve 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


32 ABB

Table 32. Three-phase directional overcurrent protection (DPHxPDOC)



DPHLPDOC Current:±1.5% of the set value or ±0.002 x InVoltage:±1.5% of the set value or ±0.002 x Un

Phase angle:±2°

DPHHPDOC Current:±1.5% of the set value or ±0.002 x In (at

currents in the range of 0.1…10 x In)

±5.0% of the set value (at currents in therange of 10…40 x In)

Voltage:±1.5% of the set value or ±0.002 x Un

Phase angle:±2°

Start time1)2) IFault = 2.0 x set Start

value


Reset time < 40 ms




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


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

1) Measurement mode = default (depends of stage), current before fault = 0.0 x In, fn = 50 Hz, fault current in one

phase 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 33

Table 33. Three-phase directional overcurrent protection (DPHxPDOC) main settings


Start value DPHLPDOC 0.05...5.00 pu 0.01

DPHHPDOC 0.05...5.00 pu 0.01

Time multiplier DPHxPDOC 0.05...15.00 0.05

Operate delay time DPHxPDOC 0.04...200.00 s 0.01

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

Characteristic angle DPHxPDOC -179...180 deg 1

Operating curve

type1)

DPHLPDOC Definite or inverse timeCurve 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

Table 34. Distance protection (DSTPDIS)



Current:±1.5% of the set value or ±0.002 x InVoltage:±1.5% of the set value or ±0.002 x Un

Impedance:±2.0% static accuracyPhase angle: ±2°

Start time 1)2) SIR3): 0.1–60 Typical 50 ms (±15 ms)

Transient overreach SIR = 0.1 – 60 < 6%

Reset time < 50 ms



1) Includes the delay of the signal output contact2) Relates to start signals of the Zone Z1–Zone ZAR23) SIR = Source impedance ratio


34 ABB

Table 35. Distance protection (DSTPDIS) main settings

Parameter Function Value (Range) Steps

Phase voltage Meas DSTPDIS AccuratePP without Uo

-

System groundingGFC

DSTPDIS High impedanceLow impedanceFrom input

-

Phase Sel mode GFC DSTPDIS OvercurrentVoltdep overcurUnder impedanceOvercur/underZ

-

EF detection ModGFC

DSTPDIS IoIo OR UoIo AND UoIo AND Ioref

-

Operate delay GFC DSTPDIS 0.100 - 60.000 s 0.001

Ph Str A Ph Sel GFC DSTPDIS 0.10 - 10.00 pu 0.01

Ph Lo A Ph Sel GFC DSTPDIS 0.10 - 10.00 pu 0.01

Ph V Ph Sel GFC DSTPDIS 0.10 - 1.00 pu 0.01

PP V Ph Sel GFC DSTPDIS 0.10 - 1.00 pu 0.01

Z Chr Mod Ph Sel GFC DSTPDIS QuadrilateralMho (circular)

-

Load Dsr mode GFC DSTPDIS OffOn

-

X Gnd Fwd reachGFC

DSTPDIS 0.01 - 3000.00 ohm 0.01

X Gnd Rv reach GFC DSTPDIS 0.01 - 3000.00 ohm 0.01

Ris Gnd Rch GFC DSTPDIS 0.01 - 500.00 ohm 0.01

X PP Fwd reach GFC DSTPDIS 0.01 - 3000.00 ohm 0.01

X PP Rv reach GFC DSTPDIS 0.01 - 3000.00 ohm 0.01

Resistive PP Rch GFC DSTPDIS 0.01 - 100.00 ohm 0.01

Ris reach load GFC DSTPDIS 1.00 - 3000.00 ohm 0.01

Angle load area GFC DSTPDIS 5 - 45 deg 1

Z Max Ph load GFC DSTPDIS 1.00 - 10000.00 ohm 0.01

Gnd Op current GFC DSTPDIS 0.01 - 10.00 pu 0.01

Gnd Op A Ref GFC DSTPDIS 0.01 - 10.00 pu 0.01


ABB 35

Table 35. Distance protection (DSTPDIS) main settings, continued


Gnd Str voltage GFC DSTPDIS 0.02 - 1.00 pu 0.01

Ph Prf mode Hi Z GFC DSTPDIS No filterNo preferenceCyc A-B-C-ACyc A-C-B-AAcyc A-B-CAcyc A-C-BAcyc B-A-CAcyc B-C-AAcyc C-A-BAcyc C-B-A

-

Ph Prf mode Lo Z GFC DSTPDIS All loopsPE onlyPP onlyBLK leading PEBLK lagging PE

-

Gnd Op A XC GFC DSTPDIS 0.10 - 10.00 pu 0.01

PP voltage XCF GFC DSTPDIS 0.10 - 1.00 pu 0.01

Cross-country Dl GFC DSTPDIS 0.00 - 10.00 s 0.01

Impedance mode Zn DSTPDIS RectangularPolar

-

Impedance Chr GndZn

DSTPDIS QuadrilateralMho (circular)Mho dir lineOffset dir lineBullet (combi)

-

Impedance Chr PP Zn DSTPDIS QuadrilateralMho (circular)Mho dir lineOffset dir lineBullet (combi)

-

Max phase angle zone DSTPDIS 0 - 45 deg 1

Min phase angle zone DSTPDIS 90 - 135 deg 1

Pol quantity zone DSTPDIS Pos. seq. volt.Self polCross Pol

-

Directional mode Zn1 DSTPDIS Non-directionalForwardReverse

-


36 ABB

Table 35. Distance protection (DSTPDIS) main settings, continued


Op Mod PP loops Zn1 DSTPDIS DisabledEnabled

-

PP Op delay Mod Zn1 DSTPDIS DisabledEnabled

-

R1 zone 1 DSTPDIS 0.01 - 3000.00 ohm 0.01

X1 zone 1 DSTPDIS 0.01 - 3000.00 ohm 0.01

X1 reverse zone 1 DSTPDIS 0.01 - 3000.00 ohm 0.01

Z1 zone 1 DSTPDIS 0.01 - 3000.00 ohm 0.01

Z1 angle zone 1 DSTPDIS 15 - 90 deg 1

Z1 reverse zone 1 DSTPDIS 0.01 - 3000.00 ohm 0.01

Min Ris PP Rch Zn1 DSTPDIS 0.01 - 100.00 ohm 0.01

Max Ris PP Rch Zn1 DSTPDIS 0.01 - 100.00 ohm 0.01

R0 zone 1 DSTPDIS 0.01 - 3000.00 ohm 0.01

X0 zone 1 DSTPDIS 0.01 - 3000.00 ohm 0.01

Factor K0 zone 1 DSTPDIS 0.0 - 4.0 0.1

Factor K0 angle Zn1 DSTPDIS -135 - 135 deg 1

Min Ris Gnd Rch Zn1 DSTPDIS 0.01 - 500.00 ohm 0.01

Max Ris Gnd Rch Zn1 DSTPDIS 0.01 - 500.00 ohm 0.01

Gnd operate Dl Zn1 DSTPDIS 0.030 - 60.000 s 0.001

Table 36. Automatic switch-onto-fault function (CVRSOF)


Operation accuracies At the frequency f = fn

Current: ±1.5% of the set value or ±0.002 × InVoltage: ±1.5% of the set value or ±0.002 × Un

Operate time accuracy ±1.0% of the set value or ±35 ms

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

…


ABB 37

Table 37. Fault locator (SCEFRFLO)


Operation accuracies At the frequency f = fn


Fault location accuracy: ±2.5% of the linelengthActual fault location accuracy depends onthe fault and the power system characteristics.


…

Table 38. Fault locator (SCEFRFLO) main settings

Parameter Function Values (Range) Step

Phase voltage Meas SCEFRFLO Accurate PP withoutUo

-

Calculation Trg mode SCEFRFLO External InternalContinuous

-

Pre fault time SCEFRFLO 0.100...300.000 s 0.001

Z Max phase load SCEFRFLO 1.00...10000.00 ohm 0.01

Ph leakage Ris SCEFRFLO 1...1000000 ohm 1

Ph capacitive React SCEFRFLO 1...1000000 ohm 1

R1 line section A SCEFRFLO 0.001...1000.000ohm/pu

0.001

X1 line section A SCEFRFLO 0.001...1000.000ohm/pu

0.001

R0 line section A SCEFRFLO 0.001...1000.000ohm/pu

0.001

X0 line section A SCEFRFLO 0.001...1000.000ohm/pu

0.001

Line Len section A SCEFRFLO 0.001...1000.000 pu 0.001

Table 39. Autoreclosing (DARREC)




38 ABB

Table 40. Non-directional earth-fault protection (EFxPTOC)



EFLPTOC ±1.5% of the set value or ±0.001 x In

EFHPTOCandEFIPTOC

±1.5% of set value or ±0.002 x In(at currents in the range of 0.1…10 x In)


Start time 1)2) EFIPTOC:IFault = 2 x set Start

value

Typical 12 ms (±5 ms)

EFHPTOC:IFault = 2 x set Start

value


EFLPTOC:IFault = 2 x set Start

value


Reset time < 45 ms






…Peak-to-Peak: No suppression

1) Operate curve type = IEC definite time, 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 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 39

Table 41. Non-directional earth-fault protection (EFxPTOC) main settings


Start value EFLPTOC 0.010...5.000 pu 0.005

EFHPTOC 0.10...40.00 pu 0.01

EFIPTOC 0.10...40.00 pu 0.01

Time multiplier EFLPTOC 0.05...15.00 0.05

EFHPTOC 0.05...15.00 0.05

Operate delay time EFLPTOC 0.04...200.00 s 0.01

EFHPTOC 0.02...200.00 s 0.01

EFIPTOC 0.02...200.00 s 0.01

Operating curve

type1)

EFLPTOC Definite or inverse timeCurve 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



40 ABB

Table 42. Directional earth-fault protection (DEFxPDEF)



DEFLPDEF Current:±1.5% of the set value or ±0.002 x InVoltage±1.5% of the set value or ±0.002 x Un

Phase angle: ±2°

DEFHPDEF Current:±1.5% of the set value or ±0.002 x In(at currents in the range of 0.1…10 x In)


Voltage:±1.5% of the set value or ±0.002 x Un

Phase angle: ±2°

Start time 1)2) DEFHPDEF andDEFLPTDEF:IFault = 2 x set Start

value


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 41

Table 43. Directional earth-fault protection (DEFxPDEF) main settings


Start Value DEFLPDEF 0.010...5.000 pu 0.005

DEFHPDEF 0.10...40.00 pu 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 0.06...200.00 s 0.01

DEFHPDEF 0.06...200.00 s 0.01

Operating curve

type1)

DEFLPDEF Definite or inverse timeCurve 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 44. Transient/intermittent earth-fault protection (INTRPTEF)


Operation accuracy (Uo criteria withtransient protection)

At the frequency f = fn

±1.5% of the set value or ±0.002 × Uo


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


42 ABB

Table 45. Transient/intermittent earth-fault protection (INTRPTEF) main settings


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

-

Operate delay time INTRPTEF 0.04...1200.00 s 0.01

Voltage start value(voltage start valuefor transient EF)

INTRPTEF 0.005...0.500 pu 0.001

Operation mode INTRPTEF 1=Intermittent EF2=Transient EF

-

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

INTRPTEF 2...20 -

Table 46. Admittance-based earth-fault protection (EFPADM)


Operation accuracy1) At the frequency f=fn

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

Start time2) Typical 65 ms (±15 ms)

Reset time < 50 ms

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

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

1) Io varied during the test. Uo = 1.0 x Un = phase to earth voltage during earth-fault in compensated or un-earthednetwork..

2) Includes the delay of the signal output contact. Results based on statistical distribution of 1000 measurements


ABB 43

Table 47. Admittance-based earth-fault protection (EFPADM) main settings


Operation mode EFPADM YoGoBoYo, GoYo, BoGo, BoYo, Go, Bo

-

Directional mode EFPADM Non-directionalForwardReverse

-

Voltage start value EFPADM 0.01 - 2.00 0.01

Circle conductance EFPADM -500.00 - 500.00 0.01

Circle susceptance EFPADM -500.00 - 500.00 0.01

Circle radius EFPADM 0.05 - 500.00 0.01

Conductance forward EFPADM -500.00 - 500.00 0.01

Conductance reverse EFPADM -500.00 - 500.00 0.01

Susceptance forward EFPADM -500.00 - 500.00 0.01

Susceptance reverse EFPADM -500.00 - 500.00 0.01

Operate delay time EFPADM 0.06 - 200.00 0.01

Table 48. Wattmetric earth-fault protection (WPWDE)


Operation accuracy Depending on the frequency of the residualcurrent and voltage measured, f=fn ±2 Hz

±3.0% of the set value or ±0.002 x Sn

Start time1)2) Typical 65 ms (±15ms)

Reset time < 45 ms


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

Operate time accuracy in inverse time mode ±5.0% of the set value of ±20 ms

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

1) Io varied during the test. Uo = 1.0 x Un = phase to earth voltage during earth-fault in compensated or un-earthednetwork. The residual power value before fault = 0.0 p.u., fn = 50 Hz, results based on statistical distribution of1000 measurements.

2) Includes the delay of the signal output contact.


44 ABB

Table 49. Wattmetric earth-fault protection (WPWDE) main settings


Directional mode WPWDE ForwardReverse

-

Current start value WPWDE 0.01 - 5.00 0.01

Voltage start value WPWDE 0.010 - 1.000 0.001

Power start value WPWDE 0.003 - 1.000 0.001

Reference power WPWDE 0.050 - 1.000 0.001

Characteristic angle WPWDE -179 - 180 1

Time multiplier WPWDE 0.05 - 2.00 0.01

Operating curve type WPWDE ANSI Def. TimeIEC Def. TimeWattMetric IDMT

-

Operate delay time WPWDE 0.06 - 200.00 0.01

Table 50. Phase discontinuity protection (PDNSPTOC)



±2% of the set value

Start time Typical 15 ms

Reset time < 40 ms





…

Table 51. Phase discontinuity protection (PDNSPTOC) main settings


Start value (Currentratio setting I2/I1)

PDNSPTOC 10...100 % 1

Operate delay time PDNSPTOC 0.100...30.000 s 0.001

Min phase current PDNSPTOC 0.05...0.30 pu 0.01


ABB 45

Table 52. Negative-sequence overcurrent protection (NSPTOC)



±1.5% of the set value or ±0.002 × In

Start time 1)2) IFault = 2 × set Start

valueIFault = 10 × set Start

value

Typical 23 ms (±15 ms)Typical 16 ms (±15 ms)

Reset time < 40 ms





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

…

1) Operate curve type = IEC definite time, negative sequence current before fault = 0.0, fn = 50 Hz

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

Table 53. Negative-sequence overcurrent protection (NSPTOC) main settings


Start value NSPTOC 0.01...5.00 pu 0.01

Time multiplier NSPTOC 0.05...15.00 0.05

Operate delay time NSPTOC 0.04...200.00 s 0.01

Operating curve

type1)

NSPTOC Definite or inverse timeCurve type: 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12,13, 14, 15, 17, 18, 19



46 ABB

Table 54. Three-phase thermal overload (T1PTTR)



Current measurement: ±0.5% 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% or ±0.50 s

1) Overload current > 1.2 x Operate level temperature, Current reference > 0.50 p.u.


ABB 47

Table 55. Three-phase thermal overload (T1PTTR) main settings


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

T1PTTR -50...100 deg 1

Current multiplier(Current multiplierwhen function isused for parallellines)

T1PTTR 1...5 1

Current reference T1PTTR 0.05...4.00 pu 0.01

Temperature rise(End temperaturerise above ambient)

T1PTTR 0.0...200.0 deg 0.1

Time constant (Timeconstant of the linein seconds)

T1PTTR 1...1000 min 1

Maximumtemperature(temperature levelfor operate)

T1PTTR 20.0...200.0 deg 0.1

Alarm value(Temperature levelfor start (alarm)

T1PTTR 20.0...150.0 deg 0.1

Reclose temperature(Temperature forreset of block recloseafter operate)

T1PTTR 20.0...150.0 deg 0.1

Initial temperature(Temperature raiseabove ambienttemperature atstartup)

T1PTTR -50.0...100.0 deg 0.1


48 ABB

Table 56. Three-phase current inrush detection (INRPHAR)



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 +30 ms / -0 ms

Table 57. Three-phase current inrush detection (INRPHAR) main settings


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

INRPHAR 5...100 % 1

Operate delay time INRPHAR 0.02...60.00 s 0.001

Table 58. Three-phase overvoltage protection (PHPTOV)



±1.5% of the set value or ±0.002 × Un

Start time1)2) UFault = 2.0 x set Start

value


Reset time < 40 ms

Reset ratio Depends of the set Relative hysteresis





…

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

nominal frequency injected from random phase angle2) Includes the delay of the signal output contact3) Maximum Start value = 1.20 × Un, Start value multiples in range of 1.10 to 2.00


ABB 49

Table 59. Three-phase overvoltage protection (PHPTOV) main settings


Start value PHPTOV 0.05...1.60 pu 0.01

Time multiplier PHPTOV 0.05...15.00 0.05

Operate delay time PHPTOV 0.40...300.000 s 0.10

Operating curve

type1)

PHPTOV Definite or inverse timeCurve type: 5, 15, 17, 18, 19, 20


Table 60. Three-phase undervoltage protection (PHPTUV)




Start time1)2) UFault = 0.9 x set

Start value


Reset time < 40 ms

Reset ratio Depends of the set Relative hysteresis





…

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

nominal frequency injected from random phase angle2) Includes the delay of the signal output contact3) Minimum Start value = 0.50 × Un, Start value multiples in range of 0.90 to 0.20

Table 61. Three-phase undervoltage protection (PHPTUV) main settings


Start value PHPTUV 0.05...1.20 pu 0.01

Time multiplier PHPTUV 0.05...15.00 0.05

Operate delay time PHPTUV 0.040...300.000 s 0.010

Operating curve

type1)

PHPTUV Definite or inverse timeCurve type: 5, 15, 21, 22, 23



50 ABB

Table 62. Positive-sequence overvoltage protection (PSPTOV)



±1.5% of the set value or ±0.002 x Un


Start valueUFault = 2.0 x set

Start value

Typical: 29 ms (±15 ms) Typical: 24 ms (±15 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 angle2) Includes the delay of the signal output contact

Table 63. Positive-sequence overvoltage protection (PSPTOV) main settings


Start value PSPTOV 0.800...1.600 pu 0.001

Operate delay time PSPTOV 0.040...120.000 s 0.001


ABB 51

Table 64. Positive-sequence undervoltage protection (PSPTUV)




Start time1)2) UFault = 0.9 x set Start

value


Reset time < 40 ms





…

1) Residual voltage before fault = 1.1 × Un, fn = 50 Hz, residual voltage with nominal frequency injected from


Table 65. Positive-sequence undervoltage protection (PSPTUV) main settings


Start value PSPTUV 0.010...1.200 pu 0.001

Operate delay time PSPTUV 0.040...120.000 s 0.001

Voltage block value PSPTUV 0.01...1.0 pu 0.01


52 ABB

Table 66. Negative-sequence overvoltage protection (NSPTOV)





Start valueUFault = 2.0 x set

Start value

Typical 29 ms (± 15ms)Typical 24 ms (± 15ms)

Reset time < 40 ms





…

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


Table 67. Negative-sequence overvoltage protection (NSPTOV) main settings


Start value NSPTOV 0.010...1.000 pu 0.001

Operate delay time NSPTOV 0.040...120.000 s 0.001


ABB 53

Table 68. Residual overvoltage protection (ROVPTOV)





Start value

Typical 27 ms (± 15 ms)

Reset time < 40 ms





…

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


Table 69. Residual overvoltage protection (ROVPTOV) main settings


Start value ROVPTOV 0.010...1.000 pu 0.001

Operate delay time ROVPTOV 0.040...300.000 s 0.001

Table 70. Frequency gradient protection (DAPFRC)


Operation accuracy df/dt < ± 10 Hz/s: ±10 mHz/sUndervoltage blocking: ±1.5% of the setvalue or ±0.002 × Un

Start time1)2) Start value = 0.05 Hz/sdf/dtFAULT = ±1.0 Hz/s


Reset time < 150 ms



…

1) Frequency before fault = 1.0 × fn, fn = 50 Hz

2) Includes the delay of the signal output contact


54 ABB

Table 71. Frequency gradient protection (DAPFRC) main settings


Start value DAPFRC -10.00...10.00 Hz/s 0.01

Operate delay time DAPFRC 0.120...60.000 s 0.001

Table 72. Overfrequency protection (DAPTOF)


Operation accuracy At the frequency f = 35 to 66 Hz

± 0.003 Hz

Start time1)2) fFault = 1.01 × set

Start value

Typical < 190 ms

Reset time < 190 ms



…



Table 73. Overfrequency protection (DAPTOF) main settings


Start value DAPTOF 35.0...64.0 Hz 0.1

Operate delay time DAPTOF 0.170...60.000 s 0.001

Table 74. Underfrequency protection (DAPTUF)



± 0.003 Hz

Start time1)2) fFault = 0.99 × set

Start value

Typical < 190 ms

Reset time < 190 ms



…




ABB 55

Table 75. Underfrequency protection (DAPTUF) main settings


Start value DAPTUF 35.0...64.0 Hz 0.1

Operate delay time DAPTUF 0.170...60.000 s 0.001

Table 76. Load shedding (LSHDPFRQ)



± 0.003 Hz

Start time1)2) Load shed mode Typical 175 ms (±15ms)Typical 250 ms (±15ms)

Freq<: fFault = 0.80 ×

set Start valuefreq< AND dfdt>: df/dt = 0.3 Hz/s

Reset time < 190 ms



…



Table 77. Load shedding (LSHDPFRQ) main settings


Load shed mode LSHDPFRQ Freq<Freq< AND df/dtFreq< OR df/dt

-

Restore mode LSHDPFRQ DisabledAutoManual

-

Start value Freq LSHDPFRQ 0.800...1.200 x Fn 0.001

Start value df/dt LSHDPFRQ -0.200...-0.005 x Fn 0.005

Operate Tm Freq LSHDPFRQ 80...200000 ms 10

Operate Tm df/dt LSHDPFRQ 120...200000 ms 10

Restore start Val LSHDPFRQ 0.800...1.200 x Fn 0.001

Restore delay time LSHDPFRQ 80...200000 ms 10


56 ABB

Table 78. Circuit breaker failure protection (CCBRBRF)





Table 79. Circuit breaker failure protection (CCBRBRF) main settings


Current value(Operating phasecurrent)

CCBRBRF 0.05...1.00 pu 0.05

Current value Res(Operating residualcurrent)

CCBRBRF 0.05...1.00 pu 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 0.00...60.00 s 0.01

CB failure delay CCBRBRF 0.00...60.00 s 0.01

CB fault delay CCBRBRF 0.00...60.00 s 0.01

Table 80. Multipurpose analog protection (MAPGAPC)



Table 81. Multipurpose analog protection (MAPGAPC) main settings


Operation mode MAPGAPC 1-2 1

Start value MAPGAPC -10000.0 - 10000.0 0.1

Start value Add MAPGAPC -100.0 - 100.0 0.1

Operate delay time MAPGAPC 0.00 - 200.00 0.01


ABB 57

Table 82. 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


Table 83. Local acceleration logic (DSTPLAL)






…


58 ABB

Table 84. Local acceleration logic (DSTPLAL) main settings


Load current value DSTPLAL 0.01...1.00 pu 0.01

Minimum current DSTPLAL 0.01...1.00 pu 0.01

Minimum currenttime

DSTPLAL 0.000...60.000 s 0.001

Load release on time DSTPLAL 0.000...60.000 s 0.001

Load release off Tm DSTPLAL 0.000...60.000 s 0.001

Loss of load Op DSTPLAL DisabledEnabled

-

Zone extension DSTPLAL DisabledEnabled

-

Table 85. Communication logic for residual overcurrent (RESCPSCH)



Table 86. Communication logic for residual overcurrent (RESCPSCH) main settings


Scheme type RESCPSCH OffIntertripPermissive URPermissive ORBlocking

-

Coordination time RESCPSCH 0.000...60.000 s 0.001

Carrier Min Dur RESCPSCH 0.000...60.000 s 0.001

Table 87. Scheme communication logic (DSOCPSCH)




ABB 59

Table 88. Scheme communication logic (DSOCPSCH) main settings


Scheme type DSOCPSCH OffIntertripPermissive URPermissive ORBlocking

-

Coordination time DSOCPSCH 0.000...60.000 s 0.001

Carrier dur time DSOCPSCH 0.000...60.000 s 0.001

Table 89. Current reversal and WEI logic (CRWPSCH)






…

Table 90. Current reversal and WEI logic (CRWPSCH) main settings


Reversal mode CRWPSCH OffOn

-

Wei mode CRWPSCH OffEchoEcho & Trip

-

PhV level for Wei CRWPSCH 0.10...0.90 pu 0.01

PPV level for Wei CRWPSCH 0.10...0.90 pu 0.01

Reversal time CRWPSCH 0.000...60.000 s 0.001

Reversal reset time CRWPSCH 0.000...60.000 s 0.001

Wei Crd time CRWPSCH 0.000...60.000 s 0.001

Table 91. Current reversal and WEI logic for residual overcurrent (RCRWPSCH)






60 ABB

Table 92. Current reversal and WEI logic for residual overcurrent (RCRWPSCH) mainsettings


Reversal mode RCRWPSCH OffOn

-

Wei mode RCRWPSCH OffEchoEcho & Trip

-

Residual voltage Val RCRWPSCH 0.05...0.70 pu 0.01

Reversal time RCRWPSCH 0.000...60.000 s 0.001

Reversal reset time RCRWPSCH 0.000...60.000 s 0.001

Wei Crd time RCRWPSCH 0.000...60.000 s 0.001

Control functions

Table 93. Synchrocheck (SYNCRSYN)



Voltage: ±1.0% or ±0.002 x Un

Frequency: ±10 mHzPhase angle ±2°

Reset time < 50 ms



Supervision and monitoring functions

Table 94. Circuit-breaker condition monitoring (SSCBR)


Current measuring accuracy At the frequency f = fn

±1.5% or ±0.002 × In (at currents in the

range of 0.1…10 × In)

±5.0% (at currents in the range of 10…40 ×In)


Traveling time measurement ±10 ms


ABB 61

Table 95. Fuse failure supervision (SEQRFUF)




Operate time1)

• NPS function UFault = 1.1 x set Neg

Seq voltage LevUFault = 5.0 x set Neg

Seq voltage Lev

Typical 35 ms (±15ms)Typical 25 ms (±15ms)

• Delta function ΔU = 1.1 x setVoltage change rate

ΔU = 2.0 x setVoltage change rate

Typical 35 ms (±15ms)Typical 28 ms (±15ms)

1) Includes the delay of the signal output contact, fn = 50 Hz, fault voltage with nominal frequency injected from

random phase angle

Table 96. Current circuit supervision (CCRDIF)


Operate time1) < 30 ms

1) Including the delay of the output contact.

Table 97. Current circuit supervision (CCRDIF) main settings


Start value CCRDIF 0.05...2.00 pu 0.01

Maximum operatecurrent

CCRDIF 0.05...5.00 pu 0.01

Table 98. Trip circuit supervision (TCSSCBR)


Time accuracy ±1.0% of the set value or ±40 ms

Table 99. Station battery supervision (SPVNZBAT)


Operation accuracy ±1.0% of the set value



62 ABB

Table 100. Energy monitoring (EPDMMTR)


Operation accuracy At all three currents in range 0.10…1.20 x Inn

At all three voltages in range 0.50…1.15 x Un

At the frequency f = fnActive power and energy in range |PF| > 0.71Reactive power and energy in range |PF| <0.71

±1.5% for energy

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

…

Power quality functions

Table 101. Voltage variation measurement function (PHQVVR)


Operation accuracy ±1.5% of the set value or ±0.2% of referencevoltage

Reset ratio Typical: 0.96 (Swell), 1.04 (Dip, Interruption)

Table 102. Voltage variation measurement function (PHQVVR) main settings


Voltage swell set PHQVVR 100.0 - 200.0 0.1

Voltage dip set PHQVVR 0.0 - 100.0 0.1

Voltage Int set PHQVVR 0.0 - 100.0 0.1

V Var Dur point 1 PHQVVR 0.000 - 60.000 0.001

V Var Dur point 2 PHQVVR 0.000 - 60.000 0.001


ABB 63

Table 103. Voltage unbalance power quality function (VSQVUB) main settings


Operation VSQVUB OffOn

-

Unb detectionmethod

VSQVUB Negative SeqZero sequenceNeg to Pos SeqZero to Pos SeqPh vectors Comp

-

Obs period Str date VSQVUB 19700101 - 20380101 1

Obs period Str hour VSQVUB 0 - 23 1

Table 104. Current harmonics (CMHAI) main settings


Measuring mode CMHAI 1-4 1

Trigger mode CMHAI 1-3 1

Low limit CMHAI 1.0-50 0.1

Obs period Str date CMHAI 19700101-20380101 1

Obs period Str hour CMHAI 0-23 1

Table 105. Voltage harmonics (phase-to-phase) (VPPMHAI) main settings


Measuring mode VPPMHAI 1-4 1

Trigger mode VPPMHAI 1-3 1

Low limit VPPMHAI 1.0-50 0.1

Obs period Str date VPPMHAI 19700101-20380101 1

Obs period Str hour VPPMHAI 0-23 1

Table 106. Voltage harmonics (phase-to-earth) (VPHMHAI) main settings


Measuring mode VPHMHAI 1-4 1

Trigger mode VPHMHAI 1-3 1

Low limit VPHMHAI 1.0-50 0.1

Obs period Str date VPHMHAI 19700101-20380101 1

Obs period Str hour VPHMHAI 0-23 1


64 ABB

Measurement functions

Table 107. 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

Table 108. Three-phase voltage measurement (VPHMMXU )



±0.5% or ±0.002 x Un

(at voltages in the range of 0.01...1.15 × Un)

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


Table 109. Three-phase voltage measurement (VPPMMXU )



±0.5% or ±0.002 x Un

(at voltages in the range of 0.01...1.15 × Un)

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


Table 110. Residual current measurement (RESCMMXU)



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




ABB 65

Table 111. Residual voltage measurement (RESVMMXU)



±0.5% or ±0.002 × Un



Table 112. Power monitoring with P, Q, S, power factor, frequency (PWRMMXU)


Operation accuracy At all three currents in range 0.10…1.20 x Inn

At all three voltages in range 0.50…1.15 x Un

At the frequency f = fnActive power and energy in range |PF| > 0.71Reactive power and energy in range |PF| <0.71

±1.5% for power (S, P and Q)±0.015 for power factor

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

…

Table 113. Sequence current (CSMSQI)



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


…

Table 114. Sequence voltage (VSMSQI)



±1.0% or ±0.002 x Un

At voltages in range of 0.01…1.15 x Un


…


66 ABB

21. Front panel userinterface

The 630 series IEDs can be ordered with andetached front-panel user interface (HMI). Anintegrated HMI is available for 4U highhousing. The local HMI includes a largegraphical monochrome LCD with a resolutionof 320 x 240 pixels (width x height). Theamount of characters and rows fitting theview depends on the character size as thecharacters' width and height may vary.

In addition, the local HMI includes dedicatedopen/close operating buttons and five

programmable function buttons with LEDindicators. The 15 programmable alarm LEDscan indicate a total of 45 alarms. The localHMI offers full front-panel user-interfacefunctionality with menu navigation, menuviews and operational data. In addition, thelocal HMI can, using PCM600, be configuredto show a single-line diagram (SLD). The SLDview displays the status of the primaryapparatus such as circuit breakers anddisconnectors, selected measurement valuesand busbar arrangements.

GUID-5CFD3446-A92F-4A5F-B60D-90025DCFDC61 V2 EN

Figure 6. Local user interface

22. Mounting methods

By means of appropriate mountingaccessories the standard IED case for the 630series IEDs can be flush mounted, semi-flushmounted or wall mounted. Detachable HMI isintended for optimized mounting in mediumvoltage metal-clad switchgear, thus reducingwiring between the low-voltage compartmentand the panel door. Further, the IEDs can bemounted in any standard 19” instrumentcabinet by means of 19” rack mountingaccessories.

For the routine testing purposes, the IEDcases can be installed with RTXP test

switches (RTXP8, RTXP18 or RTXP24) whichcan be mounted side by side with the IEDcase in a 19” rack.

Mounting methods:

• Flush mounting• Semi-flush mounting• Overhead/ceiling mounting• 19” rack mounting• Wall mounting• Mounting with a RTXP8, RTXP18 or

RTXP24 test switch to a 19”rack• Door mounting of the local HMI, IED case

mounted in the low-voltage compartment ofthe switchgear


ABB 67

For further information regarding cut-outsand templates for different mounting options

please refer to the 630 series InstallationManual 1MRS755958.

GUID-8E2EDADD-D709-423D-8677-E3CF75DB256F V1 EN

Figure 7. Flush mounting GUID-AF1BEC0B-A9DC-4E9B-9C89-98F28B1C81DB V1 EN

Figure 8. Semi-flushmounting

GUID-945D3C86-A432-4C1F-927A-A208E0C1F5F6 V1 EN

Figure 9. Wall mounting

224

265,9

22025,5

177 258,6

13

GUID-A368C5C3-D4A9-40B7-BD0E-181A6BB7ECA6 V1 EN

Figure 10. 6U half 19" unit wall mountedwith two mounting brackets anddetached LHMI


68 ABB

23. Selection andordering data

The IED type and serial number labelidentifies the protection and control IED. Thelabel placed is on the side of the IED case.The IED labels include a set of smaller size

labels, one label for each module in the IED.The module labels state the type and serialnumber of each module.

The order number consists of a string ofcodes generated from the hardware andsoftware modules of the IED. Use theordering key information in tables togenerate the order number when orderingprotection and control IEDs.

S B F B A B A C B B B Z A Z N A X B

# DESCRIPTION1 IED

630 series IED, 4U half 19” housing S

630 series IED, 6U half 19” housing T

630 series IED, 4U half 19” housing with connector set U630 series IED, 6U half 19” housing with connector set V

2 StandardIEC B

3 Main application

Feeder protection and control FGUID-3D6E8ED5-075A-4229-82C7-80A7D126FEC2 V1 EN


ABB 69


# DESCRIPTION4-8

1)

N = NonePre- conf.# 4

Available analog inputs options

# 5-6

Available binary in-puts/output options

# 7-8

A AB = 4 I (I0 1/5 A) + 1 I (I0 0.1/0.5 A) + 4 U

AB = 23 BI + 18 BOAC = 32 BI + 27 BOAD 2) = 41 BI + 36 BOAE 2) = 50 BI + 45 BO

B AB = 4 I (I0 1/5 A) + 1 I (I0 0.1/0.5 A) + 4U

AB = 23 BI + 18 BOAC = 32 BI + 27 BO

AD 2) = 41 BI + 36 BO

AE 2) = 50 BI + 45 BO

C 1) AB = 4 I (I0 1/5 A) + 1 I (I0 0.1/0.5 A) + 4 U


D AB = 4 I (I0 1/5 A) + 1 I (I0 0.1/0.5 A) + 4 U


N

AA = 4 I (I0 1/5 A) + 5 U AA = 14 BI + 9 BO

AB = 4 I (I0 1/5 A) + 1 I (I0 0.1/0.5 A) + 4 U AB = 23 BI + 18 BO

AC = 3 I (I0 1/5 A) + 1 I (I0 0.1/0.5 A) + 5 U AC 3) = 32 BI + 27 BO

BA = 4 I (I0 1/5 A) + 5 U + 8 mA in/RTD + 4 mA out AD 2) = 41 BI + 36 BO

BB = 4 I (I0 1/5 A) + 1 I (I0 0.1/0.5 A) + 4 U + 8 mA in/RTD + 4 mA out

AE 2,4) = 50 BI + 45 BO

BC = 3 I (I0 1/5 A) + 1 I (I0 0.1/0.5 A) + 5 U + 8 mA in/RTD + 4 mA out

1) en for digit #14 or digit #15 2) Binary input/output options AD and AE require 6U half 19” IED housing (digit #1 = T or V)3) Binary input/output option AC is not available for 4U high variant (digit #1 = S or U) with RTD input options (digit #5-6 = BA, BB or BC)4) Binary input/output option AE is not available for 6U high variant (digit #1 = T or V) with RTD input options (digit #5-6 = BA, BB or BC)

GUID-D8AAE9B9-CABD-41D3-BBC1-F9377202A589 V1 EN


70 ABB


# DESCRIPTION 9 Communication serial

A

B10 Communication Ethernet

Ethernet 100BaseFX (LC) A

Ethernet 100BaseTX (RJ-45) B11 Communication protocol

IEC 61850 A

IEC 61850 and DNP3 TCP/IP B

IEC 61850 and IEC 60870-103 CGUID-28800219-99DA-45EB-919C-C7CBE7B7C69D V1 EN


ABB 71


# DESCRIPTION12 Language

English and Chinese Z13 Front panel

Integrated local HMI 1) ADetached local HMI, 1 m cable BDetached local HMI, 2 m cable CDetached local HMI, 3 m cable DDetached local HMI, 4 m cable EDetached local HMI, 5 m cable FNo local HMI N

14 Option 1 2)

Fault locator and synchro-check A

Fault locator and distance protection 3) B

Fault locator and power quality C

Synchro-check and distance protection 3) D

Synchro-check and power quality E

Distance protection and power quality 3) FAll options ZNone N

15 Option 2 2)

Fault locator ASynchro-check BDistance protection 3) DPower quality ENone N

16 Power supply48...125 V DC A110...250 V DC, 100...240 V AC B

17 Vacant digitVacant X

18 VersionVersion 1.1 B

1) Integrated HMI is not available for 6 U high variant (digit #1 = T or V)2) Any optional function can be chosen only once. Due to this, the option 2 (digit 15) has limitations based on the selection in option 1 (digit 14).)

GUID-140E3596-81E7-43EF-A18C-680093ADA9CC V1 EN


72 ABB

Example code: S B F B A B A C B B B Z A Z N A X B

Your ordering code:

Digit (#) 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18

Code GUID-05BC330A-4237-4597-B5B0-9FD1B4414DC0 V1 EN

Figure 11. Ordering key for complete IEDs

24. Accessories

Table 115. Mounting accessories

Item Order number

Flush mounting kit for one 4U half 19” housing IED 1KHL400040R0001

Semi-flush mounting kit for one 4U half 19” housing IED 1KHL400041R0001

Wall-mounting kit (cabling towards the mounting wall) for one 4Uhalf 19” housing IED

1KHL400067R0001

Wall-mounting kit (cabling to the front) for one 4U half 19” housingIED

1KHL400039R0001

19" rack mounting kit for one 4U half 19” housing IED 1KHL400236R0001

19" rack mounting kit for two 4U half 19” housing IEDs 1KHL400237R0001

Overhead/ceiling mounting kit (with cable space) for one 4U half19” housing IED

1KHL400038P0001

Wall-mounting kit for direct rear wall mounting (with cabling to thefront) of one 6U half 19" housing IED

1KHL400079R0001

Wall-mounting kit (with cabling towards the mounting wall) for one6U half 19" housing IED

1KHL400200R0001

Overhead/ceiling mounting kit (with cable space) for one 6U half19" housing IED

1KHL400175R0001


ABB 73

Table 116. Test switch mounting accessories

Item Order number

19" rack mounting kit for one RTXP8 test switch (the test switch isnot included in the delivery)

1KHL400176R0001


1KHL400177R0001


1KHL400178R0001

Table 117. Connector sets

Item Order number

Connector set for one 4U half 19" housing IED including analoginput variant 4I + 5U (Io 1/5A), 5I + 4U (Io 0.1/0.5A) or 4I + 5U (Io0.1/0.5A)

2RCA021735

Connector set for one 6U half 19" housing IED including analoginput variant 4I + 5U (Io 1/5A), 5I + 4U (Io 0.1/0.5A) or 4I + 5U (Io0.1/0.5A)

2RCA021736

Table 118. Optional cables for external display module

Items Order number

LHMI cable (1m) 2RCA025073P0001





26. Tools

The IED is delivered either with or withoutan optional factory made preconfiguration.The default parameter setting values can bechanged from the front-panel user interface,the web-browser based user interface(WebHMI) or the PCM600 tool incombination with the IED specificconnectivity package.

PCM600 offers extensive IED configurationfunctions such as IED applicationconfiguration, signal configuration, DNP3communication configuration and IEC 61850communication configuration includinghorizontal communication, GOOSE.

When the web-browser based user interfaceis used, the IED can be accessed eitherlocally or remotely using a web browser (IE7.0 or later). For security reasons, the web-browser based user interface is disabled bydefault. The interface can be enabled withthe PCM600 tool or from the front panel user


74 ABB

interface. The functionality of the interface isby default limited to read-only, but can beconfigured to enable read and write access bymeans of PCM600 or the local HMI.

The IED connectivity package is a collectionof software and specific IED information,

which enable system products and tools toconnect and interact with the IED. Theconnectivity packages reduce the risk oferrors in system integration, minimizingdevice configuration and set-up times.

Table 119. Tools

Configuration and setting tools Version

PCM600 2.3 or later

Web-browser based user interface IE 7.0 or later

REF630 Connectivity Package 1.1 or later

Table 120. Supported functions

Function WebHMI PCM600 PCM600Engineering

PCM600Engineering

Pro

Parameter setting

Disturbance handling

Signal monitoring

Event viewer

Alarm LED viewing

Hardware configuration -

Signal matrix -

Graphical display editor -

IED configuration templates -

Communication management -

Disturbance record analysis -

IED user management -

User management -

Creating/handling projects -

Graphical applicationconfiguration

- -

IEC 61850 communicationconfiguration, incl. GOOSE

- - -


ABB 75

27. Supported ABBsolutions

ABB’s 630 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 ABB’s IEDs are supplied withConnectivity Packages containing acompilation of software and IED-specificinformation including single-line diagramtemplates, manuals, a full IED data modelincluding event and parameter lists. Byutilizing the Connectivity Packages the IEDscan be readily configured via the PCM600Protection and Control IED Manager andintegrated with the COM600 StationAutomation device or the MicroSCADA Pronetwork control and management system.

The 630 series IEDs offer support for the IEC61850 standard also including horizontalGOOSE messaging. Compared withtraditional hard-wired inter-device signaling,peer-to-peer communication over a switchedEthernet LAN offers an advanced andversatile platform for power systemprotection. Fast software-based

communication, 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 theimplementation of the IEC 61850 substationautomation standard.

At the substation level COM600 utilizes thelogic processor and data content of the baylevel IEDs to offer enhanced substation levelfunctionality. COM600 features a web-browser based HMI providing a customizablegraphical display for visualizing single linemimic diagrams for switchgear bay solutions.To enhance personnel safety, the web HMIalso enables remote access to substationdevices and processes. Furthermore, COM600can be used as a local data warehouse fortechnical documentation of the substationand for network data collected by the IEDs.The collected network data facilitatesextensive reporting and analyzing of networkfault situations using the data historian andevent handling features of COM600.

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

Table 121. Supported ABB solutions

Product Version

Station Automation COM600 3.3 or later

MicroSCADA Pro 9.2 SP1 or later

RTU 560 9.5.1 or later

System 800xA 5.0 Service Pack 2


76 ABB

28. Terminal diagrams

GUID-88CD16F3-27E5-4657-BDAF-46D27B4970D8 V1 EN

Figure 12. Terminal diagram for REF630


ABB 77

GUID-5E27DD50-FD15-4824-BDFB-DD52E29730EA V1 EN

Figure 13. 630 series BIO module option


78 ABB

GUID-CB7B1CF8-A0E4-42F5-998C-701641515127 V1 EN

Figure 14. 630 series RTD module option


ABB 79

29. References

The www.abb.com/substationautomationportal offers you information about thedistribution automation product and servicerange.

You will find the latest relevant informationon the REF630 protection IED on the productpage.

The download area on the right hand side ofthe web page contains the latest productdocumentation, such as technical referencemanual, installation manual, operatorsmanual, etc. The selection tool on the webpage helps you find the documents by thedocument category and language.

The Features and Application tabs containproduct related information in a compactformat.

GUID-BC8A0DF1-E732-4C9A-BFB9-E3744F17A616 V1 EN

Figure 15. Product page


80 ABB

HTTP://WWW.ABB.COM/SUBSTATIONAUTOMATION

HTTP://WWW.ABB.COM/PRODUCT/DB0003DB004281/7FEF57FAF232B7B4C12575F5002162CB.ASPX

HTTP://WWW.ABB.COM/PRODUCT/DB0003DB004281/7FEF57FAF232B7B4C12575F5002162CB.ASPX

30. Functions, codes and symbols

Table 122. Functions included in REF630

Functionality IEC 61850 IEC 60617 ANSI

Protection

Three-phase non-directionalovercurrent, low stage

PHLPTOC 3I> 51P-1

Three-phase non-directionalovercurrent, high stage

PHHPTOC 3I>> 51P-2

Three-phase non-directionalovercurrent, instantaneous stage

PHIPTOC 3I>>> 50P/51P

Three-phase directionalovercurrent, low stage

DPHLPDOC 3I> → 67-1

Three-phase directionalovercurrent, high stage

DPHHPDOC 3I>> → 67-2

Distance protection DSTPDIS Z< 21, 21P, 21N

Automatic switch-onto-fault logic CVRSOF SOTF SOTF

Fault locator SCEFRFLO FLOC 21FL

Autoreclosing DARREC O → I 79

Non-directional earth-fault, lowstage

EFLPTOC I0> 51N-1

Non-directional earth-fault, highstage

EFHPTOC I0>> 51N-2

Non-directional earth-fault,instantaneous stage

EFIPTOC I0>>> 50N/51N

Directional earth-fault, low stage DEFLPDEF I0> → 67N-1

Directional earth-fault, high stage DEFHPDEF I0>> → 67N-2

Transient/intermittent earth-fault INTRPTEF I0> → IEF 67NIEF

Admittance-based earth-faultprotection

EFPADM Yo>-> 21YN

Wattmetric earth-fault protection WPWDE Po>-> 32N

Phase discontinuity PDNSPTOC I2/I1> 46PD

Negative-sequence overcurrent NSPTOC I2> 46

Three-phase thermal overload forfeeder

T1PTTR 3Ith>F 49F


ABB 81

Table 122. Functions included in REF630, continued


Three-phase current inrushdetection

INRPHAR 3I2f> 68

Three-phase overvoltage PHPTOV 3U> 59

Three-phase undervoltage PHPTUV 3U< 27

Positive-sequence overvoltage PSPTOV U1> 47O+

Positive-sequence undervoltage PSPTUV U1< 47U+

Negative-sequence overvoltage NSPTOV U2> 47O-

Residual overvoltage ROVPTOV U0> 59G

Frequency gradient DAPFRC df/dt> 81R

Overfrequency DAPTOF f> 81O

Underfrequency DAPTUF f< 81U

Load shedding LSHDPFRQ UFLS/R 81LSH

Circuit-breaker failure CCBRBRF 3I>/I0>BF 51BF/51NBF

Tripping logic TRPPTRC I → O 94

Multipurpose analog protection MAPGAPC MAP MAP


Local acceleration logic DSTPLAL LAL LAL

Communication logic for residualovercurrent

RESCPSCH CLN 85N

Scheme communication logic DSOCPSCH CL 85

Current reversal and WEI logic CRWPSCH CLCRW 85CRW

Current reversal and WEI logic forresidual overcurrent

RCRWPSCH CLCRWN 85NCRW

Control

Bay control QCCBAY CBAY CBAY

Interlocking interface SCILO 3 3

Circuit breaker/disconnector control GNRLCSWI I ↔ O CB/DC I ↔ O CB/DC

Circuit breaker DAXCBR I ↔ O CB I ↔ O CB

Disconnector DAXSWI I ↔ O DC I ↔ O DC

Local/remote switch interface LOCREM R/L R/L

Synchrocheck SYNCRSYN SYNC 25


82 ABB



Generic process I/O

Single point control (8 signals) SPC8GGIO

Double point indication DPGGIO

Single point indication SPGGIO

Generic measured value MVGGIO

Logic rotating switch for functionselection and LHMI presentation

SLGGIO

Selector mini switch VSGGIO

Pulse counter for energy metering PCGGIO

Event counter CNTGGIO

Supervision and monitoring

Circuit-breaker condition monitoring SSCBR CBCM CBCM

Fuse failure supervision SEQRFUF FUSEF 60

Current circuit supervision CCRDIF MCS 3I MCS 3I

Trip-circuit supervision TCSSCBR TCS TCM

Station battery supervision SPVNZBAT U<> U<>

Energy monitoring EPDMMTR E E

Measured value limit supervision MVEXP

Power quality

Voltage variation PHQVVR PQMU PQMV

Voltage unbalance VSQVUB PQMUBU PQMUBV

Current harmonics CMHAI PQM3I PQM3I

Voltage harmonics (phase-to-phase) VPPMHAI PQM3Upp PQM3Vpp

Voltage harmonics (phase-to-earth) VPHMHAI PQM3Upe PQM3Vpg

Measurement

Three-phase current CMMXU 3I 3I

Three-phase voltage (phase-to-earth)

VPHMMXU 3Upe 3Upe

Three-phase voltage (phase-to-phase)

VPPMMXU 3Upp 3Upp

Residual current RESCMMXU I0 I0


ABB 83



Residual voltage RESVMMXU U0 Vn

Power monitoring with P, Q, S,power factor, frequency

PWRMMXU PQf PQf

Sequence current CSMSQI I1, I2 I1, I2

Sequence voltage VSMSQI U1, U2 V1, V2

Disturbance recorder function

Analog channels 1-10 (samples) A1RADR ACH1 ACH1

Analog channels 11-20 (samples) A2RADR ACH2 ACH2

Analog channels 21-30 (calc. val.) A3RADR ACH3 ACH3

Analog channels 31-40 (calc. val.) A4RADR ACH4 ACH4

Binary channels 1-16 B1RBDR BCH1 BCH1




Station communication (GOOSE)

Binary receive GOOSEBINRCV

Double point receive GOOSEDPRCV

Interlock receive GOOSEINTLKRCV

Integer receive GOOSEINTRCV

Measured value receive GOOSEMVRCV

Single point receive GOOSESPRCV

31. Document revision history

Document revision/date

Product version History

A/2009-10-26 1.0 First release

B/2009-12-23 1.0 Content updated

C/2011-02-23 1.1 Content updated to correspond to theproduct version


84 ABB

Contact us

ABB OyDistribution AutomationP.O. Box 699FI-65101 VAASA, FinlandPhone +358 10 22 11Fax +358 10 22 41094

www.abb.com/substationautomation

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