up_sub4_1_116_1

Relion® 630 series

Transformer Protection and ControlRET630Product Guide

Contents

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

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

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

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

5. Control................................................................11

6. Voltage regulator................................................11

7. Measurement.....................................................12

8. Disturbance recorder..........................................12

9. Event log.............................................................13

10. Disturbance report............................................13

11. Circuit-breaker monitoring................................13

12. Trip-circuit supervision......................................13

13. Self-supervision.................................................13

14. Fuse failure supervision.....................................14

15. Current circuit supervision................................14

16. Access control...................................................14

17. Inputs and outputs............................................14

18. Communication.................................................16

19. Technical data...................................................17

20. Front panel user interface.................................60

21. Mounting methods............................................60

22. Selection and ordering data..............................62

23. Accessories.......................................................66

25. Tools..................................................................67

26. Supported ABB solutions..................................69

27. Terminal diagrams.............................................70

28. References........................................................74

29. Functions, codes and symbols.........................74

30. Document revision history.................................78

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.

Transformer Protection and Control 1MRS756978 CRET630Product version: 1.1 Issued: 2011-02-23

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1. Description

RET630 is a comprehensive transformermanagement IED for protection, control,measuring and supervision of powertransformers, unit and step-up transformersincluding power generator-transformer blocksin utility and industry power distributionnetworks. RET630 is a member of ABB’s

Relion® product family and a part of its 630series characterized by functional scalabilityand flexible configurability. RET630 alsofeatures necessary control functionsconstituting an ideal solution for transformerbay control and voltage regulation.

The supported communication protocolsincluding IEC 61850 offer seamlessconnectivity to various station automationand SCADA systems.

2. Application

RET630 provides main protection for two-winding power transformers and powergenerator-transformer blocks. Two pre-defined configurations to match your typicaltransformer protection and controlspecifications are available. The pre-definedconfigurations can be used as such or easilyadapted or extended with freely selectableadd-on functions, by means of which the IEDcan be fine-tuned to exactly satisfy thespecific requirements of your presentapplication. The optional voltage regulationfunction is one example of such add-onfunctions.


Revision: C

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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. RET630 preconfiguration ordering options

Description Preconfiguration

Preconfiguration A for two-winding HV/MV transformer A

Preconfiguration B for two-winding HV/MV transformer, includingnumerical REF protection

B

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 n

Protection

Three-phase non-directional overcurrent, low stage (LV side) 1 12

Three-phase non-directional overcurrent, low stage (HV side) 1 1

Three-phase non-directional overcurrent, high stage (LV side) 1 12

Three-phase non-directional overcurrent, high stage (HV side) 1 1

Three-phase non-directional overcurrent, instantaneous stage (LVside)

1 1

2Three-phase non-directional overcurrent, instantaneous stage (HVside)

1 1

Three-phase directional overcurrent, low stage - - 2

Three-phase directional overcurrent, high stage - - 1

Non-directional earth-fault, low stage (LV side) - 12

Non-directional earth-fault, low stage (HV side) 1 1

Non-directional earth-fault, high stage (LV side) - 12

Non-directional earth-fault, high stage (HV side) 1 1

Directional earth-fault, low stage - - 2

Directional earth-fault, high stage - - 1

Stabilised restricted earth-fault (LV side) - 12

Stabilised restricted earth-fault (HV side) - 1

High-impedance-based restricted earth-fault protection - - 2

Negative-sequence overcurrent (LV side) 1 14

Negative-sequence overcurrent (HV side) 1 1

Three-phase current inrush detection - - 1

Three-phase thermal overload for transformers 1 1 1

Three-phase overvoltage (LV side) 2 2 2

Three-phase undervoltage (LV side) 2 2 2

Positive-sequence overvoltage - - 2

Positive-sequence undervoltage - - 2

Negative-sequence overvoltage - - 2

Residual overvoltage - - 3


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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

Functionality A B n

Frequency gradient - - 6

Overfrequency - - 3

Underfrequency - - 3

Overexcitation protection1) - - 2

Three-phase underimpedance protection1) - - 2

Transformer differential protection for two-winding transformers 1 1 1

Circuit-breaker failure (HV side) 1 1 2

Tripping logic (LV side) 1 12

Tripping logic (HV side) 1 1

Multipurpose analog protection - - 16

Control

Bay control 1 1 1

Interlocking interface 4 4 10

Circuit breaker/disconnector control 4 4 10

Circuit breaker 1 1 2

Disconnector 3 3 8

Local/remote switch interface - - 1

Synchrocheck - - 1

Tap changer control with voltage regulator1) - - 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 LHMI presentation - - 10

Selector mini switch - - 10

Pulse counter for energy metering - - 4

Event counter - - 1

Supervision and monitoring


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Functionality A B n

Circuit breaker condition monitoring (HV side) 1 1 2

Fuse failure supervision 1 - 1

Current circuit supervision (LV side) - -2

Current circuit supervision (HV side) - -

Trip-circuit supervision 2 2 3

Tap position indication - - 1

Energy monitoring 1 1 1

Station battery supervision - - 1

Measured value limit supervision - - 40

Measurement

Three-phase current (LV side) 1 12

Three-phase current (HV side) 1 1

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

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

Residual current measurement 2 2 2

Residual voltage measurement - - 1

Sequence current measurement - - 1

Sequence voltage measurement - - 1

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

Disturbance recorder function

Analog channels 1-10 (samples) 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




Station communication (GOOSE)


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Functionality A B n

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

RET630 features transformer differentialprotection with instantaneous and stabilizedstages to provide fast and selective protectionfor phase-to-phase, winding interturn andbushing short-circuits including most phase-to-earth faults. Besides second harmonicrestraint an advanced waveform-basedblocking algorithm ensures stability attransformer energization and fifth harmonicrestraint ensures stability at moderateoverexcitation.

Sensitive restricted earth-fault protection(REF) completes the overall differentialprotection to detect even single phase-to-earth faults close to the earthing point of thetransformer. Either the conventional high-impedance scheme or a numerical low-impedance scheme can be selected forprotection of the windings. If the low-impedance REF protection is used neitherstabilizing resistors nor varistors are neededand as a further benefit the transforming ratioof the earthing point current transformers candiffer from those of the phase currenttransformers. Due to its unit protection

character the REF protection does not needany time grading, and therefore a fastprotection operating time can be achieved.The overexcitation protection is used toprotect generators and power transformersagainst an excessive flux density andsaturation of the magnetic core.

The IED also incorporates thermal overloadprotection to prevent an accelerated aging ofthe transformer isolation. Multiple stages ofshort-circuit, phase-overcurrent, negative-phase-sequence and earth-fault back-upprotection are separately available for bothwindings. The three-phase underimpedanceprotection, based on impedance values fromvoltage and current phasors, provides backupprotection against short-circuit faults. Earth-fault protection based on the measured orcalculated residual overvoltage is alsoavailable.

To detect reversed power flow or circulatingcurrents at parallel power transformersRET630 also offers directional overcurrentprotection. Further, overfrequency andunderfrequency protection, overvoltage andundervoltage protection and circuit-breakerfailure protection are provided.


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Figure 2. Protection function overview of preconfiguration A


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Figure 3. Protection function overview of preconfiguration B

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. Voltage regulator

The voltage regulator function (on-load tapchanger controller) is designed for regulatingthe voltage of power transformers with on-load tap changers in distribution substations.The voltage regulation function provides amanual or automatic voltage control of the


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power transformer using the raise and lowersignals to the on-load tap changer.

The automatic voltage regulation can be usedin single or parallel transformer applications.Parallel operation can be based on master/follower (M/F), negative-reactance principle(NRP) or minimizing circulating current(MCC).

The voltage regulator includes the line dropcompensation (LDC) functionality, and theload decrease is possible with a dynamicvoltage reduction.

Either definite time (DT) characteristic orinverse definitive time (IDMT) characteristiccan be selected for delays between the raiseand lower operations.

The function contains a blockingfunctionality. It is possible to block thevoltage control operations with an externalsignal or with the supervision functionality ofthe function, if wanted.

7. Measurement

The IED continuously measures the highvoltage (HV) side and the low-voltage (LV)side phase currents and the neutral current(s)of the protected transformer. Further, itmeasures the positive and negative sequencecurrents on both sides. The IED alsomeasures phase-to earth or phase-to-phasevoltages, positive and negative sequencevoltages and the residual voltage. In addition,the IED monitors active, reactive andapparent power, the power factor, powerdemand value over a user-selectable pre-settime frame as well as cumulative active andreactive energy of both directions.

System frequency and the temperature of thetransformer are also calculated. Cumulativeand averaging calculations utilize the non-volatile memory available in the IED.Calculated values are also obtained from theprotection and condition monitoringfunctions of 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 externalIED 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.


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

10. 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.

11. 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.

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-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.


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14. 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.

15. 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.

16. 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 and

User Administrator. The user groupassociation for each individual user enablesthe use of the IED according to the profile ofthe user group.

17. Inputs and outputs

Depending on the hardware configurationselected, the IED is equipped with six phase-current inputs (three inputs for the HV sideand three inputs for the LV side) and one ortwo neutral-current inputs for earth-faultprotection.

Depending on the selected hardwareconfiguration the IED includes two or threevoltage inputs. One of the voltage inputs canbe used as a residual voltage input fordirectional earth-fault protection or residualvoltage protection. The voltage inputs canalso be used as phase-voltage inputs forovervoltage, undervoltage and directionalovercurrent protection and other voltagebased protection functions.

The phase-current inputs are rated 1/5 A.Depending on the selected hardwareconfiguration the IED is equipped with oneor two alternative residual-current inputs, thatis 1/5 A or 0.1/0.5 A. The 0.1/0.5 A input isnormally used in applications requiringsensitive earth-fault protection and featuringa core-balance current transformer.

The voltage inputs, for either phase-to-phasevoltages or phase-to-earth voltages, and theresidual-voltage input cover the ratedvoltages 100 V, 110 V, 115 V and 120 V. Therated values of the current and voltage inputsare 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 signals


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via the RTD or mA inputs and provides fourmA outputs. The RTD and mA inputs can forinstance be used for measuring oiltemperature at the bottom and top of thetransformer tank and the ambient airtemperature or supervision of analog signalsprovided by external transducers. An RTDinput can also be used as a direct resistancemeasuring input for position tracking of an on-load tap changer. Alternatively, tap changerposition can be obtained via a mA transducer.The RTD/mA inputs can also be used as aninput for DC voltage transducer. The RTD/mA module enables the use of themultipurpose protection functions. Theseprotection functions can be used for trippingand alarm purposes based on RTD/mAmeasuring data, or analog valuescommunicated via GOOSE messaging. The

mA outputs can be used for transferringfreely selectable measured or calculatedanalog values to devices provided with mAinput 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 ofthe application configuration function inPCM600. Please refer to the Input/outputoverview tables, the selection and orderingdata, and the terminal diagrams for moredetailed information about the inputs andoutputs.

Table 3. Analog input configuration

Analog inputconfiguration

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

VT RTD/mAinputs

mA outputs

AA 7 - 4 - -

AB 8 - 3 - -

AC 7 1 2 - -

BA 7 - 4 8 4

BB 8 - 3 8 4

BC 7 1 2 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.


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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.

18. 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 of

analog measurement values over the stationbus, thus facilitating for example sharing ofRTD input values, such as surroundingtemperature values, to other IEDapplications. The IED interoperates withother IEC 61850 compliant IEDs, tools andsystems and simultaneously reports events tofive different clients on the IEC 61850 stationbus. For a system using DNP3 over TCP/IP,events can be sent to four different masters.For systems using IEC 60870-5-103 IED canbe connected to one master in a station buswith 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.


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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.

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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19. 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


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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 23

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


24 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 25

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


26 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 27

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


28 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 29

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


30 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 31

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


32 ABB

Table 34. 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 33

Table 35. 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



34 ABB

Table 36. 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 35

Table 37. 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


36 ABB

Table 38. Stabilized restricted earth-fault protection (LREFPNDF)



±1.5% of the set value or ±0.002 × In

Start time1)2) IFault = 2.0 × set

Operate valueIFault =

10.0 × set Operatevalue

Typical 18 ms (±5 ms)Typical 12 ms (±5 ms)

Reset time < 50 ms




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

5, …

1) Current before fault = 0.0 × In, fn = 50 Hz

2) Includes the delay of the signal output contact

Table 39. Stabilized restricted earth-fault protection (LREFPNDF) main settings


Operate value LREFPNDF 5...50 % 1

Restraint mode LREFPNDF None2nd harmonic

-

Start value 2.H LREFPNDF 10...50 % 1

Minimum operatetime

LREFPNDF 0.040...300.000 s 0.001


ABB 37

Table 40. High-impedance based restricted earth-fault protection (HREFPDIF)




Start time1)2) IFault = 2.0 × set

Operate valueIFault = 10.0 × set

Operate value


Reset time < 40 ms




1) Current before fault = 0.0 × In, fn = 50 Hz


Table 41. High-impedance based restricted earth-fault protection (HREFPDIF) mainsettings


Operate value HREFPDIF 0.5...50.0 % 0.1

Minimum operatetime

HREFPDIF 0.020...300.000 s 0.001


38 ABB

Table 42. Negative-sequence overcurrent protection (NSPTOC)




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

valueIFault = 10 × set Start

value


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 43. 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



ABB 39

Table 44. Three-phase thermal overload protection for transformers (T2PTTR)



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% or ±1000 ms

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

Table 45. Three-phase thermal overload protection for transformers (T2PTTR) mainsettings


Temperature rise T2PTTR 0.0...200.0 deg 0.1

Max temperature T2PTTR 0.0...200.0 deg 0.1

Operate temperature T2PTTR 80.0...120.0 % 0.1

Weighting factor p T2PTTR 0.00...1.00 0.01

Short time constant T2PTTR 60...60000 s 1

Current reference T2PTTR 0.05...4.00 pu 0.01

Table 46. 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


40 ABB

Table 47. 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 48. Transformer differential protection for two-winding transformers (TR2PTDF)




Operate time1)2) Biased low stageInstantaneous highstage


Reset time < 30 ms



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

…

1) Differential current before fault = 0.0 × In, fn = 50 Hz. Injected differential current = 2.0 × set operate value

2) Includes the delay of the output contact value and fn = 50 Hz


ABB 41

Table 49. Transformer differential protection for two-winding transformers (TR2PTDF)main settings


Restraint mode TR2PTDF 2.h & 5.h & wavWaveform2.h & waveform5.h & waveform

-

High operate value TR2PTDF 500...3000 % 10

Low operate value TR2PTDF 5...50 % 1

Slope section 2 TR2PTDF 10...50 % 1

End section 2 TR2PTDF 100...500 % 1

Start value 2.H TR2PTDF 7...20 % 1

Start value 5.H TR2PTDF 10...50 % 1

Winding 1 type TR2PTDF YYNDZZN

-

Winding 2 type TR2PTDF YYNDZZN

-

Zro A elimination TR2PTDF Not eliminatedWinding 1Winding 2Winding 1 and 2

-

Clock number TR2PTDF Clk Num 0Clk Num 1Clk Num 2Clk Num 4Clk Num 5Clk Num 6Clk Num 7Clk Num 8Clk Num 10Clk Num 11

-


42 ABB

Table 50. 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

Table 51. 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



ABB 43

Table 52. 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 53. 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



44 ABB

Table 54. 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 55. 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 45

Table 56. 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 57. 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


46 ABB

Table 58. 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 59. 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 47

Table 60. 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 61. 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 62. 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



48 ABB

Table 63. 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 64. 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 65. 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 66. Underfrequency protection (DAPTUF)


Operation accuracy At the frequency f = 35 to 66 Hz

± 0.003 Hz

Start time1)2) fFault = 0.99 × set

Start value

Typical < 190 ms

Reset time < 190 ms



…




ABB 49

Table 67. 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 68. Overexcitation protection (OEPVPH)


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

±2.5% of the set value or 0.01 x Ub/f

Start time 1)2) Frequency change Typical 200 ms (±20 ms)

Voltage change Typical 100 ms (±20 ms)

Reset time < 60 ms



Operate time accuracy indefinite-time mode

±1.0% of the set value or ±20 ms

Operate time accuracy ininverse-time mode

±5.0% of the theoretical value or ±50 ms

1) Results based on statistical distribution of 1000 measurements2) Includes the delay of the signal output contact

Table 69. Overexcitation protection (OEPVPH) main settings

Parameter Function Values (Range) Step

Leakage React OEPVPH 0.0 - 50.0 0.1

Start value OEPVPH 100 - 200 1

Time multiplier OEPVPH 0.1 - 100.0 0.1

Operating curve type OEPVPH ANSI Def. TimeIEC Def. TimeOvExt IDMT Crv1OvExt IDMT Crv2OvExt IDMT Crv3OvExt IDMT Crv4

-

Operate delay time OEPVPH 0.10 - 200.00 0.01


50 ABB

Table 70. Three-phase underimpedance protection (UZPDIS)


Operation accuracy Depending on the frequency of the currentand voltage measured f = fn ±2 Hz

±3.0% of the set value or ±0.2% x Zb

Start time Typical 25 ms (±15 ms)

Reset time < 50 ms



Operate time accuracy in definite-time mode1)2)

±1.0% of the set value or ±20 ms

1) Fn = 50 Hz, results based on statistical distribution of 1000 measurements2) Includes the delay of the signal output contact

Table 71. Three-phase underimpedance protection (UZPDIS) main settings


Polar reach UZPDIS 1 - 6000 1

Operate delay time UZPDIS 0.04 - 200.00 0.01

Table 72. Circuit breaker failure protection (CCBRBRF)




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


ABB 51

Table 73. 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 74. Multipurpose analog protection (MAPGAPC)



Table 75. 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


52 ABB

Table 76. 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

Control functions

Table 77. Synchrocheck (SYNCRSYN)



Voltage: ±1.0% or ±0.002 x Un

Frequency: ±10 mHzPhase angle ±2°

Reset time < 50 ms




ABB 53

Table 78. Tap changer control with voltage regulator (OLATCC)


Operation accuracy 1) Depending on the frequency of the current measured: fn ±2Hz

Differential voltage Ud ± 1.0% of the measured valueor ± 0.004 x Un (in measuredvoltages < 2.0 x Un)

Operation value ± 1.0% of the Ud or ±0.004 xUn for Us = 1.0 x Un

Operate time accuracy in definite time mode 2) ± 1.0% of the set value or0.11 seconds

Operate time accuracy in inverse time mode 3) ± 15.0% of the set value or0.15 s(at theoretical B in range of1.1…5.0) Also note fixedminimum operate time(IDMT) 1 s

Reset ratio for control operation Typical 0.80 (1.20)

Reset ratio for analogue based blockings (except run backraise voltage blocking)

Typical 0.96 (1.04)

1) Default setting values used2) Default setting values used3) Default setting values used


54 ABB

Table 79. Voltage regulator (OLATCC) main settings


Operation mode OLATCC 1 - 4 1

Custom Man blocking OLATCC 1 - 8 1

Delay characteristic OLATCC 1 - 1 1

Band width voltage OLATCC 0.01

Load current limit OLATCC 0.10 - 5.00 0.01

Block lower voltage OLATCC 0.10 - 0.01

Runback raise V OLATCC 0.80 - 0.01

Cir current limit OLATCC 0.10 - 5.00 0.01

LDC limit OLATCC 0.00 - 2.00 0.01

Lower block tap OLATCC -36 - 36 1

Raise block tap OLATCC -36 - 36 1

LDC enable OLATCC 0 - 1 1

Auto parallel mode OLATCC MasterFollowerNRPMCC

1

Band center voltage OLATCC 0.000 - 2.000 0.001

Line drop V Ris OLATCC 0.0 - 25.0 0.1

Line drop V React OLATCC 0.0 - 25.0 0.1

Band reduction OLATCC 0.0 - 9.0 0.1

Stability factor OLATCC 0.0 - 70.0 0.1

Load phase angle OLATCC -89 - 89 1

Control delay time 1 OLATCC 1.0 - 300.0 0.1

Control delay time 2 OLATCC 1.0 - 300.0 0.1


ABB 55

Supervision and monitoring functions

Table 80. 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

Table 81. Fuse failure supervision (SEQRFUF)



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

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 82. Current circuit supervision (CCRDIF)


Operate time1) < 30 ms

1) Including the delay of the output contact.


56 ABB

Table 83. 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 84. Trip circuit supervision (TCSSCBR)


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

Table 85. Tap position indication (TPOSSLTC)

Descrpition Value

Response time for binary inputs Typical 100 ms

Table 86. 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,

…

Table 87. Station battery supervision (SPVNZBAT)


Operation accuracy ±1.0% of the set value



ABB 57

Measurement functions

Table 88. 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 89. 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 90. 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 91. Residual current measurement (RESCMMXU)



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




58 ABB

Table 92. Residual voltage measurement (RESVMMXU)



±0.5% or ±0.002 × Un



Table 93. 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 94. Sequence current (CSMSQI)



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


…

Table 95. Sequence voltage (VSMSQI)



±1.0% or ±0.002 x Un

At voltages in range of 0.01…1.15 x Un


…


ABB 59

20. 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 4. Local user interface

21. 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


60 ABB

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

Figure 6. Semi-flushmounting

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

Figure 7. Wall mounting

224

265,9

22025,5

177 258,6

13

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

Figure 8. 6U half 19" unit wall mounted withtwo mounting brackets anddetached LHMI


ABB 61

22. 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.

T B T B A B A E B B B Z E A N A X B

# DESCRIPTION1 IED

630 series IED, 4U half 19” housing S630 series IED, 6U half 19” housing T630 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

Transformer protection and control T

GUID-66432CA7-529D-47D1-BE0E-11281EEF90A7 V1 EN


62 ABB

-

T B T B A B A E B B B Z EA N A X B

# DESCRIPTION4-8

numerical REF protectionN = None

Pre- conf.# 4

Available analog inputs options

# 5-6

Available binary inputs/output options

# 7-8

A AA = 7 I (I0 1/5A) + 3U

AA = 14 BI + 9 BOAB = 23 BI + 18 BOAC = 32 BI + 27 BOAD 1) = 41 BI + 36 BOAE 1) = 50 BI + 45 BO

B AB = 8 I (I0 1/5A) + 2U

AA = 14 BI + 9 BOAB = 23 BI + 18 BOAC = 32 BI + 27 BOAD 1) = 41 BI + 36 BOAE 1) = 50 BI + 45 BO

N

AA = 7 I (I0 1/5A) + 3U AA = 14 BI + 9 BO

AB = 8 I (I0 1/5A) + 2U AB = 23 BI + 18 BO

AC = 7 I (I0 1/5A) + 1 I (I0 0.1/0.5A) + 2U AC 2) = 32 BI + 27 BO

BA = 7 I (I0 1/5A) + 3U + 8 mA in/RTD + 4 mA out AD 1) = 41 BI + 36 BO

BB = 8 I (I0 1/5A) + 2U + 8 mA in/RTD + 4 mA out AE 1,3) = 50 BI + 45 BO

BC = 7 I (I0 1/5A) + 1 I (I0 0.1/0.5A) + 2U + 8 mA in/RTD + 4 mA out

1) Binary input/output options AD and AE require 6U half 19” IED housing (digit #1 = T or V)2) 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)3) 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-64E6FE1A-8BB4-4C63-B850-03A3D11FA84F V1 EN


ABB 63

T B T B A B A E B B B Z E A N A X B

# DESCRIPTION 9 Communication serial

A

B10 Communication Ethernet

Ethernet 100BaseFX (LC) AEthernet 100BaseTX (RJ-45) B

11 Communication protocol

IEC 61850 A

IEC 61850 and DNP3 TCP/IP B

IEC 61850 and IEC 60870-103 C

GUID-D74AEC37-E74D-4DE6-B586-008C9A763DDA V1 EN


64 ABB

T B T B A B A E B B B Z E A D A X B

# 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)

Automatic voltage regulator and under impedance protection A

Automatic voltage regulator and over-excitation protection B

Under impedance and over-excitation protections CAll options ZNone N

15 Option 2 2)

Automatic voltage regulator BUnder impedance protection COver-excitation protection DNone 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-846C73DA-505B-472C-B4AB-B37748BEBCD1 V1 EN


ABB 65

Example code: T B T B A B A E B B B Z E A 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-67914A30-7CA3-4BCE-B154-BE1325867621 V1 EN

Figure 9. Ordering key for complete IEDs

23. Accessories

Table 96. 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


66 ABB

Table 97. 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 98. Connector sets

Item Order number

Connector set for one 4U half 19" housing IED including analoginput variant 7I (I0 1/5A) + 3U

2RCA023041

Connector set for one 6U half 19" housing IED including analoginput variant 7I (I0 1/5A) + 3U

2RCA023042

Connector set for one 4U half 19" housing IED including analoginput variant 8I (I0 1/5A) + 2U or 7I (I0 1/5A) + 1I (I0 0.1/0.5A) + 2U

2RCA023039

Connector set for one 6U half 19" housing IED including analoginput variant 8I (I0 1/5A) + 2U or 7I (I0 1/5A) + 1I (I0 0.1/0.5A) + 2U

2RCA023040

Table 99. Optional cables for external display module

Items Order number

LHMI cable (1m) 2RCA025073P0001





25. 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 in

combination 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.


ABB 67

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 userinterface. 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 100. Tools

Configuration and setting tools Version

PCM600 2.3 or later

Web-browser based user interface IE 7.0 or later

RET630 Connectivity Package 1.1 or later


68 ABB

Table 101. 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

- - -

26. 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-specific

information 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 switched


ABB 69

Ethernet LAN offers an advanced andversatile platform for power systemprotection. 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 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 line

mimic 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 102. 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


70 ABB

27. Terminal diagrams

GUID-3901C29E-BCA6-44AE-B6BC-B2FA10958F19 V1 EN

Figure 10. Terminal diagram for RET630


ABB 71

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

Figure 11. 630 series BIO module option


72 ABB

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

Figure 12. 630 series RTD module option


ABB 73

28. References

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

You will find the latest relevant informationon the RET630 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-08D3B177-E4DA-4CCF-81A0-017F639B9C5C V1 EN

Figure 13. Product page


74 ABB

HTTP://WWW.ABB.COM/SUBSTATIONAUTOMATION

HTTP://WWW.ABB.COM/PRODUCT/DB0003DB004281/87A4DD831433ABBFC12575F50021D71F.ASPX

HTTP://WWW.ABB.COM/PRODUCT/DB0003DB004281/87A4DD831433ABBFC12575F50021D71F.ASPX

29. Functions, codes and symbols

Table 103. Functions included in RET630

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

Non-directional earth-fault, lowstage

EFLPTOC I0> 51N-1

Non-directional earth-fault, highstage

EFHPTOC I0>> 51N-2

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

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

Stabilised restricted earth-fault LREFPNDF dI0Lo> 87NL

High-impedance-based restrictedearth-fault protection

HREFPDIF dI0Hi> 87NH

Negative-sequence overcurrent NSPTOC I2> 46

Three-phase thermal overload fortransformers

T2PTTR 3Ith>T 49T

Three-phase current inrushdetection

INRPHAR 3I2f> 68

Transformer differential protectionfor two-winding transformers

TR2PTDF 3dI>T 87T

Three-phase overvoltage (LV side) PHPTOV 3U> 59

Three-phase undervoltage (LV side) PHPTUV 3U< 27

Positive-sequence overvoltage PSPTOV U1> 47O+

Positive-sequence undervoltage PSPTUV U1< 47U+

Negative-sequence overvoltage NSPTOV U2> 47O-


ABB 75

Table 103. Functions included in RET630, continued


Residual overvoltage ROVPTOV U0> 59G

Frequency gradient DAPFRC df/dt> 81R

Overfrequency DAPTOF f> 81O

Underfrequency DAPTUF f< 81U

Overexcitation protection OEPVPH U/f> 24

Three-phase underimpedanceprotection

UZPDIS Z< GT 21GT

Circuit-breaker failure (HV side) CCBRBRF 3I>/I0>BF 51BF/51NBF

Tripping logic TRPPTRC I → O 94

Multipurpose analog protection MAPGAPC MAP MAP

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

Tap changer control with voltageregulator

OLATCC COLTC 90V

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


76 ABB



Circuit-breaker conditionmonitoring (HV side)

SSCBR CBCM CBCM

Fuse failure supervision SEQRFUF FUSEF 60

Current circuit supervision CCRDIF MCS 3I MCS 3I

Trip-circuit supervision TCSSCBR TCS TCM

Tap position indication TPOSSLTC TPOSM 84M

Energy monitoring EPDMMTR E E

Station battery supervision SPVNZBAT U<> U<>

Measured value limit supervision MVEXP

Measurement

Three-phase current CMMXU 3I 3I

Three-phase voltage (phase-to-phase)

VPPMMXU 3Upp 3Vpp

Three-phase voltage (phase-to-earth) VPHMMXU 3Upe 3Vpe

Residual current measurement RESCMMXU I0 I0

Residual voltage measurement RESVMMXU U0 Vn

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

PWRMMXU PQf PQf

Sequence current measurement CSMSQI I1, I2 I1, I2

Sequence voltage measurement 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


ABB 77



Double point receive GOOSEDPRCV

Interlock receive GOOSEINTLKRCV

Integer receive GOOSEINTRCV

Measured value receive GOOSEMVRCV

Single point receive GOOSESPRCV

30. 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


78 ABB

79

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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