Capacitor Bank Protection and Control REV615 Product … · Capacitor Bank Protection and Control...

Relion® 615 series

Capacitor Bank Protection and ControlREV615Product Guide

Contents

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

2. Standard configurations................................................. 3

3. Protection functions........................................................7

4. Application..................................................................... 7

5. Supported ABB solutions............................................. 10

6. Control......................................................................... 11

7. Measurements............................................................. 12

8. Power quality................................................................12

9. Disturbance recorder....................................................12

10. Event log..................................................................... 12

11. Recorded data............................................................ 12

12. Condition monitoring .................................................. 13

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

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

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

16. Current circuit supervision........................................... 14

17. Access control............................................................ 14

18. Inputs and outputs...................................................... 14

19. Station communication................................................15

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

21. Local HMI....................................................................46

22. Mounting methods...................................................... 47

23. Relay case and plug-in unit......................................... 47

24. Selection and ordering data.........................................47

25. Accessories and ordering data.................................... 48

26. Tools...........................................................................49

27. Cyber security............................................................. 50

28. Terminal diagrams.......................................................51

29. Certificates.................................................................. 53

30. References..................................................................53

31. Functions, codes and symbols.................................... 54

32. Document revision history........................................... 57

Disclaimer

The information in this document is subject to change without notice and should not be construed as a commitment by ABB. ABB assumes no responsibility for any errors

that may appear in this document.

© Copyright 2016 ABB.

All rights reserved.

Trademarks

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

of their respective holders.

Capacitor Bank Protection and Control 1MRS757952 CREV615 Product version: 5.0 FP1

2 ABB

1. DescriptionREV615 is a dedicated capacitor bank relay designed for theprotection, control, measurement and supervision of capacitorbanks used for compensation of reactive power in utilitysubstations and industrial power systems. REV615 can also beused for protection of harmonic filter circuits, if the highestsignificant harmonic component is the 11th. REV615 is a

member of ABB’s Relion® product family and part of its 615protection and control product series. The 615 series relays arecharacterized by their compactness and withdrawable-unitdesign.

Re-engineered from the ground up, the 615 series has beendesigned to unleash the full potential of the IEC 61850 standardfor communication and interoperability between substationautomation devices.

The relay provides main protection for single star, double star,and H-bridge connected capacitor banks and harmonic filtersin distribution networks.

Depending on the chosen standard configuration, the relay isadapted for the protection of H-bridge connected or doublestar connected shunt capacitor banks. Once the standardconfiguration relay has been given the application-specificsettings, it can directly be put into service.

The 615 series relays support a range of communicationprotocols including IEC 61850 with Edition 2 support, process

bus according to IEC 61850-9-2 LE, IEC 60870-5-103,

Modbus® and DNP3. Profibus DPV1 communication protocol issupported by using the protocol converter SPA-ZC 302.

2. Standard configurationsREV615 is available in two alternative standard configurations.The standard signal configuration can be altered by means ofthe signal matrix or the graphical application functionality of theProtection and Control IED Manager PCM600. Further, theapplication configuration functionality of PCM600 supports thecreation of multi-layer logic functions using various logicalelements, including timers and flip-flops. By combiningprotection functions with logic function blocks, the relayconfiguration can be adapted to user-specific applicationrequirements.

The relay is delivered from the factory with default connectionsdescribed in the functional diagrams for binary inputs, binaryoutputs, function-to-function connections and alarm LEDs.Some of the supported functions in REV615 must be addedwith the Application Configuration tool to be available in theSignal Matrix tool and in the relay. The positive measuringdirection of directional protection functions is towards theoutgoing feeder.

Capacitor Bank Protection and Control 1MRS757952 CREV615 Product version: 5.0 FP1 Issued: 2016-05-20

Revision: C

ABB 3

3I

CONDITION MONITORING AND SUPERVISION

ORAND

CONTROL AND INDICATION 1) MEASUREMENT

CAPACITOR BANK PROTECTION AND CONTROL RELAY STANDARD CONFIGURATION

PROTECTION LOCAL HMI

Object Ctrl 2) Ind 3)

CB

DC

ES1) Check availability of binary inputs/outputs

from technical documentation2) Control and indication function for

primary object3) Status indication function for primary object

RL

ClearESCI

O

Configuration ASystemHMITimeAuthorization

RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

REMARKS

Optionalfunction

No. ofinstances

Alternative function to be defined when ordering

OR

Io/Uo

Calculatedvalue

3×

REV615 A

COMMUNICATION

Protocols: IEC 61850-8-1 Modbus®

IEC 60870-5-103 DNP3Interfaces: Ethernet: TX (RJ45), FX (LC) Serial: Serial glass fiber (ST), RS-485, RS-232Redundant protocols: HSR PRP RSTP

- I, Io- Limit value supervision- Load profile record- RTD/mA measurement (optional)- Symmetrical components

7

-

Analog interface types 1)

Current transformer

Voltage transformer1) Conventional transformer inputs

ALSO AVAILABLE

- Disturbance and fault recorders- Event log and recorded data- High-Speed Output module (optional) - Local/Remote push button on LHMI- Self-supervision- Time synchronization: IEEE 1588 v2,

SNTP, IRIG-B- User management- Web HMI 2×

I2>46

3I>>>50P/51P

3×ARC

50L/50NL

Master TripLockout relay

94/86

3I>/Io>BF51BF/51NBF

PQM3IPQM3I

2×TCSTCM

MCS 3IMCS 3I

CBCMCBCM

OPTSOPTM

18×MAPMAP

6xRTD2xmA

3I>51P-1

2×3I>>

51P-2TD>55TD

3I>3I<51C

Io>>51N-2

Io>>>50N/51N

2×Io>

51N-1

3dI>C51NC-2

dI>C51NC-1

3Ith>T/G/C49T/G/C

Io

Io

3Iunb

Io

1 -

2 3

1 2


94/86

3×2×

3×

GUID-DFC320F5-AD45-4D28-8632-C3FB2CFDCB06 V3 EN

Figure 1. Functionality overview for standard configuration A


4 ABB

CONDITION MONITORING AND SUPERVISION

ORAND

CONTROL AND INDICATION 1) MEASUREMENT

CAPACITOR BANK PROTECTION AND CONTROL RELAY STANDARD CONFIGURATION

PROTECTION LOCAL HMI

Object Ctrl 2) Ind 3)

CB

DC

ES1) Check availability of binary inputs/outputs

from technical documentation2) Control and indication function for

primary object3) Status indication function for primary object

RL

ClearESCI

O

Configuration ASystemHMITimeAuthorization

RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

REMARKS

Optionalfunction

No. ofinstances

Alternative function to be defined when ordering

OR

Io/Uo

Calculatedvalue

3×

REV615 B

COMMUNICATION

Protocols: IEC 61850-8-1/-9-2LE Modbus®

IEC 60870-5-103 DNP3Interfaces: Ethernet: TX (RJ45), FX (LC) Serial: Serial glass fiber (ST), RS-485, RS-232Redundant protocols: HSR PRP RSTP

- I, U, Io, Uo, P, Q, E, pf, f- Limit value supervision- Load profile record- RTD/mA measurement (optional)- Symmetrical components

7

5

Analog interface types 1)

Current transformer

Voltage transformer1) Conventional transformer inputs

1 -

2 3

1 2

ALSO AVAILABLE

- Disturbance and fault recorders- Event log and recorded data- High-Speed Output module (optional) - Local/Remote push button on LHMI- Self-supervision- Time synchronization: IEEE 1588 v2,

SNTP, IRIG-B- User management- Web HMI


94/86

PQM3IPQM3I

2×TCSTCM

MCS 3IMCS 3I

CBCMCBCM

OPTSOPTM

18×MAPMAP

2xRTD1xmA

Io>>51N-2

2×Io>→67N-1

Io>>→67N-2

2×3U<27

U2>47O-

U1<47U+

2×3U>59

Uo>59G

FUSEF60

2×I2>46

3I>>>50P/51P

3×ARC

50L/50NL3I>/Io>BF

51BF/51NBF

3I>51P-1

2×3I>>

51P-2TD>55TD

3I>3I<51C

3dI>C51NC-2

dI>C51NC-1

PQM3UPQM3V

PQMUPQMV

Uo>59G

3Ith>T/G/C49T/G/C

3I

3I

Io

Io

Io

Iunb

Io>IEF→67NIEF

UL1

UL2

UL3

UL1UL2UL3 UL1

UL2

UL3

Uo

Uo

3×

2×

Uo


94/86

3×2×

PQUUBPQVUB

GUID-393D9B25-06C8-42AE-A7D0-642BBCB89DBE V2 EN

Figure 2. Functionality overview for standard configuration B

Table 1. Standard configurations

Description Std. conf.

Capacitor bank overload and unbalance protection, non-directional overcurrent and earth-fault protection and circuit-breakercondition monitoring

A

Capacitor bank overload and unbalance protection, non-directional overcurrent and directional earth-fault protection, voltage andfrequency based protection and measurements, and circuit-breaker condition monitoring

B


ABB 5

Table 2. Supported functions

Function IEC 61850 A B

ProtectionThree-phase non-directional overcurrent protection, low stage PHLPTOC 1 1Three-phase non-directional overcurrent protection, high stage PHHPTOC 2 2Three-phase non-directional overcurrent protection, instantaneous stage PHIPTOC 1 1Non-directional earth-fault protection, low stage EFLPTOC 2 Non-directional earth-fault protection, high stage EFHPTOC 1 1Non-directional earth-fault protection, instantaneous stage EFIPTOC 1 Directional earth-fault protection, low stage DEFLPDEF 2Directional earth-fault protection, high stage DEFHPDEF 1Transient/intermittent earth-fault protection INTRPTEF 1 1)

Negative-sequence overcurrent protection NSPTOC 2 2Residual overvoltage protection ROVPTOV 1

22)

Three-phase undervoltage protection PHPTUV 2Three-phase overvoltage protection PHPTOV 2Positive-sequence undervoltage protection PSPTUV 1Negative-sequence overvoltage protection NSPTOV 1Three-phase thermal overload protection, two time constants T2PTTR 1 1Circuit breaker failure protection CCBRBRF 1 1Master trip TRPPTRC 2

(3) 3)2(3) 3)

Arc protection ARCSARC (3) (3)Multipurpose protection MAPGAPC 18 18Three-phase overload protection for shunt capacitor banks COLPTOC 1 1Current unbalance protection for shunt capacitor banks CUBPTOC 1 4) 1 4)

Three-phase current unbalance protection for shunt capacitor banks HCUBPTOC 1 4) 1 4)

Shunt capacitor bank switching resonance protection, current based SRCPTOC 1 1Power qualityCurrent total demand distortion CMHAI (1) 5) (1) 6)

Voltage total harmonic distortion VMHAI (1) 6)

Voltage variation PHQVVR (1) 6)

Voltage unbalance VSQVUB (1) 6)

ControlCircuit-breaker control CBXCBR 1 1Disconnector control DCXSWI 2 2Earthing switch control ESXSWI 1 1Disconnector position indication DCSXSWI 3 3Earthing switch indication ESSXSWI 2 2Condition monitoring and supervisionCircuit-breaker condition monitoring SSCBR 1 1Trip circuit supervision TCSSCBR 2 2Current circuit supervision CCSPVC 1 1Fuse failure supervision SEQSPVC 1Runtime counter for machines and devices MDSOPT 1 1MeasurementDisturbance recorder RDRE 1 1Load profile record LDPRLRC 1 1Fault record FLTRFRC 1 1Three-phase current measurement CMMXU 1 1Sequence current measurement CSMSQI 1 1Residual current measurement RESCMMXU 1 1Three-phase voltage measurement VMMXU 1Residual voltage measurement RESVMMXU 2Sequence voltage measurement VSMSQI 1Three-phase power and energy measurement PEMMXU 1


6 ABB

Table 2. Supported functions, continuedFunction IEC 61850 A B

RTD/mA measurement XRGGIO130 (1) (1)Frequency measurement FMMXU 1

IEC 61850-9-2 LE sampled value sending 7)8) SMVSENDER (1)

IEC 61850-9-2 LE sampled value receiving (voltage sharing) 7)8) SMVRCV (1)

OtherMinimum pulse timer (2 pcs) TPGAPC 4 4Minimum pulse timer (2 pcs, second resolution) TPSGAPC 1 1Minimum pulse timer (2 pcs, minute resolution) TPMGAPC 1 1Pulse timer (8 pcs) PTGAPC 2 2Time delay off (8 pcs) TOFGAPC 4 4Time delay on (8 pcs) TONGAPC 4 4Set-reset (8 pcs) SRGAPC 4 4Move (8 pcs) MVGAPC 2 2Generic control point (16 pcs) SPCGAPC 2 2Analog value scaling (4 pcs) SCA4GAPC 4 4Integer value move (4 pcs) MVI4GAPC 1 11, 2, ... = Number of included instances. The instances of a protection function represent the number of identical protection function blocks available in the standardconfiguration.() = optional

1) "Io measured" is always used.2) "Uob measured" is always used.3) Master trip is included and connected to the corresponding HSO in the configuration only when the BIO0007 module is used. If additionally the ARC option is selected, ARCSARC is

connected to the corresponding master trip input in the configuration.4) The Iunb measurement values are taken from this block and put in the Measurent view.5) Power quality option includes only current total demand distortion.6) Power quality option includes current total demand distortion, voltage total harmonic distortion, voltage variation and voltage unbalance.7) Available only with IEC 61850-9-28) Available only with COM0031-0037

3. Protection functionsThe relay offers three-phase overload protection withundercurrent and reconnection inhibit functionality forcapacitors, single or three-phase current-based unbalanceprotection for capacitors including compensation for naturalunbalance and a current-based switching resonanceprotection.

The relay features non-directional overcurrent and thermaloverload protection as well as non-directional earth-faultprotection.

Additionally, the standard configuration B includes directionalearth-fault protection, residual voltage protection, overvoltageprotection and undervoltage protection functions.

Enhanced with optional hardware and software, the relay alsofeatures three light detection channels for arc fault protection ofthe circuit breaker, busbar and cable compartment of metal-enclosed indoor switchgear.

The arc-fault protection sensor interface is available on theoptional communication module. Fast tripping increases staffsafety and security and limits material damage in an arc faultsituation. A binary input and output module can be selected asan option - having three high speed binary outputs (HSO) it

further decreases the total operate time with typically 4...6 mscompared to the normal power outputs.

4. ApplicationREV615 is intended for the protection of capacitor banks usedfor reactive power compensation in utility substations andindustrial power systems. REV615 offers protectionfunctionality especially for H-bridge, double star and single starconnected capacitor banks and the feeder cable.

The protection relay can also be used for the protection ofharmonic filter circuits, if the highest significant harmoniccomponent is the 11th.

Standard configurations A and B offer three-phase overloadprotection, unbalance protection with compensation for naturalunbalance and switching resonance protection for capacitorbanks. An integrated undercurrent function in the overloadprotection function block detects the disconnection of acapacitor bank and inhibits the closing of the circuit breaker aslong as the capacitor bank is still partially discharged. A three-phase thermal overload protection can be used for the thermalprotection of the reactors and resistors in the harmonic filtercircuits. The relay features non-directional overcurrent andearth-fault protection for the feeder cable and the capacitorbank.


ABB 7

Standard configuration A is pre-configured for H-bridgeconnected capacitor banks. Three-phase current unbalanceprotection is used for unbalance.

Standard configuration B offers directional earth-faultprotection, residual voltage protection, overvoltage protectionand undervoltage protection functions. It is pre-configured fordouble star connected capacitor banks. Single currentunbalance protection is used for unbalance.

The second and third stage of the residual voltage protection inthe standard configuration B can be used as voltage-basedunbalance protection mainly for single star connected capacitorbanks, with unearthed star point. Dedicated voltage input Uobis used for this purpose. This functionality is available instandard configuration B and needs to be configured before it istaken into use.

3I RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

REV615Std. conf.

ANSI IEC

50L/50NL

50P/51P

51C

51NC-2

51P/51N

55TD

ARC

3I>>>

3I> 3I<

3dI>C

3I>/Io>

TD>

A

Io

3Iunb

GUID-B7F0755C-006A-4806-91D3-8C290EE3ECA0 V1 EN

Figure 3. Protection of a H-bridge connected capacitor bank

Figure 3 illustrates the protection of an H-bridge connectedcapacitor bank. Standard configuration A is used with overload,three-phase connected current unbalance and undercurrent

protection for the capacitor bank. Overcurrent and earth-faultprotection functions are used for protecting the feeder cableand capacitor bank combination.

3I

REV615Std. conf.

ANSI IEC

27/59/59G

50L/50NL

50P/51P

51C

51NC-1

51P/51N

55TD

67N

3U</3U>/Uo>

ARC

3I>>>

3I> 3I<

dI>C

3I>/Io>

TD>

Io>→

B

3U Uo

RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

Io

Iunb

GUID-5F33A1B7-2B6F-4CFA-9DD6-71E633C46846 V1 EN

Figure 4. Protection of a double star connected capacitor bank in a distribution network with a compensated or isolated neutral

Protection of a double star connected capacitor bank in adistribution network with a compensated or isolated neutral isshown in Figure 4. Standard configuration B is used withoverload, single phase connected current unbalance and

undercurrent protection for the capacitor bank. Overcurrentand directional earth-fault protetion functions are used forprotecting the feeder cable and capacitor bank combination.


8 ABB

3U Uo

RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

3I

REV615Std. conf.

ANSI IEC

27/59/59G

49T

50L/50NL

50P/51P

51C

51NC-2

51P/51N

55TD

3U</3U>/Uo>

3Ith>T

ARC

3I>>>

3I> 3I<

3dI>C

3I>/Io>

TD>

BIo

3Iunb

GUID-30461537-C53B-460B-BA27-9667D6977F77 V1 EN

Figure 5. Protection of a harmonic filter circuit in an industrial network

Figure 5 illustrates the protection of a harmonic filter circuit in anindustrial network. Standard configuration B is used withoverload, three-phase connected current unbalance andundercurrent protection for the harmonic filter and with an

additional thermal protection mainly for the coil. Overcurrentand earth-fault protection functions are used for protecting thefeeder cable and harmonic filter circuit combination.

3U Uo

RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

3I

REV615Std. conf.

ANSI IEC

27/59/59G

50L/50NL

50P/51P

51C

51P

55TD

67N

3U</3U>/Uo>

ARC

3I>>>

3I> 3I<

3I>

TD>

Io>→

B

Uob

Io

GUID-9C6F9938-FB13-4615-842A-9606411B47FC V1 EN

Figure 6. Protection of a single star connected capacitor bank

The protection of a single star connected capacitor bank isshown in Figure 6. Standard configuration B is used withoverload, voltage-based unbalance (Uob) and undercurrent

protection for the capacitor bank. Overcurrent and earth-faultprotection functions are used for protecting the feeder cableand the capacitor bank combination.


ABB 9

5. Supported ABB solutionsThe 615 series protection relays together with the SubstationManagement Unit COM600S constitute a genuine IEC 61850solution for reliable power distribution in utility and industrialpower systems. To facilitate the system engineering, ABB'srelays are supplied with connectivity packages. Theconnectivity packages include a compilation of software andrelay-specific information, including single-line diagramtemplates and a full relay data model. The data model includesevent and parameter lists. With the connectivity packages, therelays can be readily configured using PCM600 and integratedwith COM600S or the network control and managementsystem MicroSCADA Pro.

The 615 series relays offer native support for IEC 61850 Edition2 also including binary and analog horizontal GOOSEmessaging. In addition, process bus with the sending ofsampled values of analog currents and voltages and thereceiving of sampled values of voltages is supported.Compared to traditional hard-wired, inter-device signaling,peer-to-peer communication over a switched Ethernet LANoffers an advanced and versatile platform for power systemprotection. Among the distinctive features of the protectionsystem approach, enabled by the full implementation of the IEC61850 substation automation standard, are fastcommunication capability, continuous supervision of theprotection and communication system's integrity, and aninherent flexibility regarding reconfiguration and upgrades.Thisprotection relay series is able to optimally utilize interoperabilityprovided by the IEC 61850 Edition 2 features.

At substation level, COM600S uses the data content of the bay-level devices to enhance substation level functionality.

COM600S features a Web browser-based HMI, which providesa customizable graphical display for visualizing single-linemimic diagrams for switchgear bay solutions. The SLD featureis especially useful when 615 series relays without the optionalsingle-line diagram feature are used. The Web HMI ofCOM600S also provides an overview of the whole substation,including relay-specific single-line diagrams, which makesinformation easily accessible. Substation devices andprocesses can also be remotely accessed through the WebHMI, which improves personnel safety.

In addition, COM600S can be used as a local data warehousefor the substation's technical documentation and for thenetwork data collected by the devices. The collected networkdata facilitates extensive reporting and analyzing of networkfault situations by using the data historian and event handlingfeatures of COM600S. The historical data can be used foraccurate monitoring of process and equipment performance,using calculations based on both real-time and historicalvalues. A better understanding of the process dynamics isachieved by combining time-based process measurementswith production and maintenance events.

COM600S can also function as a gateway and provideseamless connectivity between the substation devices andnetwork-level control and management systems, such asMicroSCADA Pro and System 800xA.

GOOSE Analyzer interface in COM600S enables the followingand analyzing the horizontal IEC 61850 application duringcommissioning and operation at station level. It logs all GOOSEevents during substation operation to enable improved systemsupervision.

Table 3. Supported ABB solutions

Product Version

Substation Management Unit COM600S 4.0 SP1 or later

4.1 or later (Edition 2)

MicroSCADA Pro SYS 600 9.3 FP2 or later

9.4 or later (Edition 2)

System 800xA 5.1 or later


10 ABB

PCM600Ethernet switch

Utility: IEC 60870-5-104Industry: OPC

COM600SWeb HMI

ABBMicroSCADA Pro/

System 800xA

Analog and binary horizontal GOOSE communication IEC 61850

PCM600Ethernet switch

COM600SWeb HMI

Analog and binary horizontal GOOSE communication IEC 61850

GUID-4D002AA0-E35D-4D3F-A157-01F1A3044DDB V4 EN

Figure 7. ABB power system example using Relion relays, COM600S and MicroSCADA Pro/System 800xA

6. ControlREV615 integrates functionality for the control of a circuitbreaker via the front panel HMI or by means of remote controls.In addition to the circuit breaker control the relay features twocontrol blocks intended for motor-operated control ofdisconnectors or circuit breaker truck and their positionindications.

The relay has one control block intended for motor-operatedcontrol of one earthing switch control and its positionindication. Two physical binary inputs and two physical binaryoutputs are needed in the relay for each controllable primarydevice taken into use. The number of unused binary inputs andbinary outputs varies, depending on the chosen standardconfiguration of the relay. Further, some standardconfigurations offer optional hardware modules that increasethe number of available binary inputs and outputs.

If the amount of available binary inputs or outputs of the chosenstandard configuration is not sufficient, the standardconfiguration can be modified to release some binary inputs or

outputs which have originally been configured for otherpurposes, when applicable, or an external input or outputmodule, for example, RIO600 can be integrated to the relay.The binary inputs and outputs of the external I/O module can beused for the less time critical binary signals of the application.The integration enables releasing of some initially reservedbinary inputs and outputs of the relay in the standardconfiguration.

The suitability of the binary outputs of the relay which have beenselected for controlling of primary devices should be carefullyverified, for example the make and carry as well as the breakingcapacity. If the requirements for the control-circuit of theprimary device are not met, the use of external auxiliary relaysshould be considered.

The optional large graphical LCD of the relay's HMI includes asingle-line diagram (SLD) with position indication for therelevant primary devices. Interlocking schemes required by theapplication are configured using the signal matrix or theapplication configuration functionality of PCM600.


ABB 11

7. MeasurementsThe relay continuously measures the phase currents, the singleor three-phase unbalance currents (with the natural unbalancecurrent compensated), the symmetrical components of thephase currents and the residual current.

The standard configuration B includes voltage measurements.It measures the residual voltage, the phase voltages, thevoltage sequence components and frequency. It also measuresthe capacitor bank unbalance voltage if the Uob is connectedand the relay is configured accordingly. This voltagemeasurement is called residual voltage measurement, instance2. The relay offers three-phase power and energy measurementincluding power factor.

In addition, the relay calculates the demand value of currentover a user-selectable preset time frames, the thermal overloadof the protected object, and the phase unbalance value basedon the ratio between the negative-sequence and positive-sequence current.

The measured values can be accessed via the local HMI orremotely via the communication interface of the relay. Thevalues can also be accessed locally or remotely using the WebHMI.

The relay is provided with a load profile recorder. The loadprofile feature stores the historical load data captured at aperiodical time interval (demand interval). The records are inCOMTRADE format.

8. Power qualityIn the EN standards, power quality is defined through thecharacteristics of the supply voltage. Transients, short-durationand long-duration voltage variations and unbalance andwaveform distortions are the key characteristics describingpower quality. The distortion monitoring functions are used formonitoring the current total demand distortion and the voltagetotal harmonic distortion.

Power quality monitoring is an essential service that utilities canprovide for their industrial and key customers. A monitoringsystem can provide information about system disturbances andtheir possible causes. It can also detect problem conditionsthroughout the system before they cause customer complaints,equipment malfunctions and even equipment damage orfailure. Power quality problems are not limited to the utility sideof the system. In fact, the majority of power quality problemsare localized within customer facilities. Thus, power qualitymonitoring is not only an effective customer service strategy butalso a way to protect a utility's reputation for quality power andservice.

The protection relay has the following power quality monitoringfunctions.

• Voltage variation• Voltage unbalance• Current harmonics• Voltage harmonics

The voltage unbalance and voltage variation functions are usedfor measuring short-duration voltage variations and monitoringvoltage unbalance conditions in power transmission anddistribution networks.

The voltage and current harmonics functions provide a methodfor monitoring the power quality by means of the currentwaveform distortion and voltage waveform distortion. Thefunctions provides a short-term three-second average and along-term demand for total demand distortion TDD and totalharmonic distortion THD.

9. Disturbance recorderThe relay is provided with a disturbance recorder featuring up to12 analog and 64 binary signal channels. The analog channelscan be set to record either the waveform or the trend of thecurrents and voltages measured.

The analog channels can be set to trigger the recording functionwhen the measured value falls below or exceeds the set values.The binary signal channels can be set to start a recording eitheron the rising or the falling edge of the binary signal or on both.

By default, the binary channels are set to record external orinternal relay signals, for example, the start or trip signals of therelay stages, or external blocking or control signals. Binary relaysignals, such as protection start and trip signals, or an externalrelay control signal via a binary input, can be set to trigger therecording. Recorded information is stored in a non-volatilememory and can be uploaded for subsequent fault analysis.

10. Event logTo collect sequence-of-events information, the relay has a non-volatile memory capable of storing 1024 events with theassociated time stamps. The non-volatile memory retains itsdata even if the relay temporarily loses its auxiliary supply. Theevent log facilitates detailed pre- and post-fault analyses offeeder faults and disturbances. The considerable capacity toprocess and store data and events in the relay facilitatesmeeting the growing information demand of future networkconfigurations.

The sequence-of-events information can be accessed either vialocal HMI or remotely via the communication interface of therelay. The information can also be accessed locally or remotelyusing the Web HMI.

11. Recorded dataThe relay has the capacity to store the records of the 128 latestfault events. The records can be used to analyze the powersystem events. Each record includes, for example, current,


12 ABB

voltage and angle values and a time stamp. The fault recordingcan be triggered by the start or the trip signal of a protectionblock, or by both. The available measurement modes includeDFT, RMS and peak-to-peak. Fault records store relay

measurement values at the moment when any protectionfunction starts. In addition, the maximum demand current withtime stamp is separately recorded. The records are stored inthe non-volatile memory.

1024

PROCESS LEVELUSER LEVEL

Fault summary; Trip timestamp, Function, Currents, Voltages, etc.

BASI

C F

UN

CTI

ON

S

IEC

618

50-8

-1M

odbu

sIE

C 1

03D

NP3

LHM

IW

HM

IPC

M60

0 Process events (FIFO)

128

Fault records (FIFO)

System and security-related events;Configuration changes, Control, Login, etc.

2048

Audittrailevents(FIFO)

n…100

Disturbance records

...7 yrs

Load profile record

Historical load data captured at a periodical time interval (Demand interval 1 ...180min)

Function specific data

Min/max demand currents, Operation counters, etc. History view

GUID-CDF1DC16-AF90-406F-B21B-EF6C7F60BCCA V1 EN

Figure 8. Recording and event capabilities overview

12. Condition monitoringThe condition monitoring functions of the relay constantlymonitor the performance and the condition of the circuitbreaker. The monitoring comprises the spring charging time,SF6 gas pressure, the travel time and the inactivity time of thecircuit breaker.

The monitoring functions provide operational circuit breakerhistory data, which can be used for scheduling preventivecircuit breaker maintenance.

In addition, the relay includes a runtime counter for monitoringof how many hours a protected device has been in operation

thus enabling scheduling of time-based preventivemaintenance of the device.

13. Trip-circuit supervisionThe trip-circuit supervision continuously monitors theavailability and operability of the trip circuit. It provides open-circuit monitoring both when the circuit breaker is in its closedand in its open position. It also detects loss of circuit-breakercontrol voltage.


ABB 13

14. Self-supervisionThe relay’s built-in self-supervision system continuouslymonitors the state of the relay hardware and the operation ofthe relay software. Any fault or malfunction detected is used foralerting the operator.

A permanent relay fault blocks the protection functions toprevent incorrect operation.

15. Fuse failure supervisionIn the standard configuration B, the relay includes fuse failuresupervision functionality. The fuse failure supervision detectsfailures between the voltage measurement circuit and the relay.The failures are detected either by the negative sequence-based algorithm or by the delta voltage and delta currentalgorithm. Upon the detection of a failure, the fuse failuresupervision function activates an alarm and blocks voltage-dependent protection functions from unintended operation.

16. Current circuit supervisionThe relay includes current circuit supervision. Current circuitsupervision is used for detecting faults in the currenttransformer secondary circuits. On detecting of a fault thecurrent circuit supervision function activates an alarm LED andblocks certain protection functions to avoid unintendedoperation. The current circuit supervision function calculatesthe sum of the phase currents from the protection cores andcompares the sum with the measured single reference currentfrom a core balance current transformer or from separate coresin the phase current transformers.

17. Access controlTo protect the relay from unauthorized access and to maintaininformation integrity, the relay is provided with a four-level, role-

based authentication system with administrator-programmableindividual passwords for the viewer, operator, engineer andadministrator levels. The access control applies to the localHMI, the Web HMI and PCM600.

18. Inputs and outputsThe relay is equipped with three phase-current inputs, threeunbalance-current inputs and one residual-current input fornon-directional earth-fault protection.

In the standard configuration B, the relay is additionallyequipped with three phase-voltage inputs, one residual voltageinput for directional earth-fault protection and one voltage input(Uob) that can be used for voltage based unbalance protection.

The rated level of the current inputs is 1/5 A and selectable inthe relay software. The three phase-voltage inputs and theresidual-voltage inputs cover the rated voltages 60-210 V. Bothphase-to-phase voltages and phase-to-earth voltages can beconnected. The binary input thresholds 16…176 V DC areselected by adjusting the relay’s parameter settings.

All binary inputs and outputs contacts are freely configurablewith the signal matrix or application configuration functionalityof PCM600.

See the Input/output overview table and the terminal diagramsfor more information about the inputs and outputs.

Optionally, a binary input and output module can be selected. Ithas three high speed binary outputs (HSO) and it decreases thetotal operate time with typically 4...6 ms compared to thenormal power outputs.


14 ABB

Table 4. Input/output overview

Std. conf. Order code digit Analog channels Binary channels

5-6 7-8 CT VT BI BO RTD mA

A

BA

BA 7 - 8 4 PO + 6 SO - -

BB 7 - 14 4 PO + 9 SO - -

FD 7 - 8 4 PO + 2 SO+ 3 HSO

- -

FF 7 - 14 4 PO + 5 SO+ 3 HSO

- -

BG

BA 7 - 8 4 PO + 6 SO 6 2

FD 7 - 8 4 PO + 2 SO+ 3 HSO

6 2

B

BC

AD 7 5 12 4 PO + 6 SO - -

FE 7 5 12 4 PO + 2 SO+ 3 HSO

- -

BE

BA 7 5 8 4 PO + 6 SO 2 1

FD 7 5 8 4 PO + 2 SO+ 3 HSO

2 1

As an option for standard configuration B, the relay has twoRTD inputs and 1 mA input. The relay measures signals such astemperature via the two RTD inputs and mA inputs using atransducer. The values can, apart from measuring and

monitoring purposes, be used for tripping and alarm purposesusing the multipurpose protection functions. The temperaturesignal can also be used for ambient temperature information forthe thermal protection function.

19. Station communicationThe relay supports a range of communication protocolsincluding IEC 61850 Edition 2, IEC 61850-9-2 LE, IEC

60870-5-103, Modbus® and DNP3. Profibus DPV1communication protocol is supported with using the protocolconverter SPA-ZC 302. Operational information and controlsare available through these protocols. However, somecommunication functionality, for example, horizontalcommunication between the relays, is only enabled by the IEC61850 communication protocol.

The IEC 61850 protocol is a core part of the relay as theprotection and control application is fully based on standardmodelling. The relay supports Edition 2 and Edition 1 versionsof the standard. With Edition 2 support, the relay has the latestfunctionality modelling for substation applications and the bestinteroperability for modern substations. It incorporates also thefull support of standard device mode functionality supportingdifferent test applications. Control applications can utilize thenew safe and advanced station control authority feature.

The IEC 61850 communication implementation supportsmonitoring and control functions. Additionally, parametersettings, disturbance recordings and fault records can beaccessed using the IEC 61850 protocol. Disturbancerecordings are available to any Ethernet-based application in

the standard COMTRADE file format. The relay supportssimultaneous event reporting to five different clients on thestation bus. The relay can exchange data with other devicesusing the IEC 61850 protocol.

The relay can send binary and analog signals to other devicesusing the IEC 61850-8-1 GOOSE (Generic Object OrientedSubstation Event) profile. Binary GOOSE messaging can, forexample, be employed for protection and interlocking-basedprotection schemes. The relay meets the GOOSE performancerequirements for tripping applications in distributionsubstations, as defined by the IEC 61850 standard (<10 msdata exchange between the devices). The relay also supportsthe sending and receiving of analog values using GOOSEmessaging. Analog GOOSE messaging enables easy transfer ofanalog measurement values over the station bus, thusfacilitating for example the sending of measurement valuesbetween the relays when controlling parallel runningtransformers.

The relay also supports IEC 61850 process bus by sendingsampled values of analog currents and voltages and byreceiving sampled values of voltages. With this functionality thegalvanic interpanel wiring can be replaced with Ethernetcommunication. The measured values are transferred assampled values using IEC 61850-9-2 LE protocol. The intended


ABB 15

application for sampled values shares the voltages to other 615series relays, having voltage based functions and 9-2 support.615 relays with process bus based applications use IEEE 1588for high accuracy time synchronization.

For redundant Ethernet communication, the relay offers eithertwo optical or two galvanic Ethernet network interfaces. A thirdport with galvanic Ethernet network interface is also available.The third Ethernet interface provides connectivity for any otherEthernet device to an IEC 61850 station bus inside a switchgearbay, for example connection of a Remote I/O. Ethernet networkredundancy can be achieved using the high-availabilityseamless redundancy (HSR) protocol or the parallelredundancy protocol (PRP) or a with self-healing ring usingRSTP in managed switches. Ethernet redundancy can beapplied to Ethernet-based IEC 61850, Modbus and DNP3protocols.

The IEC 61850 standard specifies network redundancy whichimproves the system availability for the substation

communication. The network redundancy is based on twocomplementary protocols defined in the IEC 62439-3 standard:PRP and HSR protocols. Both the protocols are able toovercome a failure of a link or switch with a zero switch-overtime. In both the protocols, each network node has twoidentical Ethernet ports dedicated for one network connection.The protocols rely on the duplication of all transmittedinformation and provide a zero switch-over time if the links orswitches fail, thus fulfilling all the stringent real-timerequirements of substation automation.

In PRP, each network node is attached to two independentnetworks operated in parallel. The networks are completelyseparated to ensure failure independence and can havedifferent topologies. The networks operate in parallel, thusproviding zero-time recovery and continuous checking ofredundancy to avoid failures.

Ethernet switchIEC 61850 PRPEthernet switch

REF615 REF620 RET620 REM620 REF615

SCADACOM600

GUID-334D26B1-C3BD-47B6-BD9D-2301190A5E9D V1 EN

Figure 9. Parallel redundancy protocol (PRP) solution

HSR applies the PRP principle of parallel operation to a singlering. For each message sent, the node sends two frames, onethrough each port. Both the frames circulate in oppositedirections over the ring. Every node forwards the frames itreceives from one port to another to reach the next node. Whenthe originating sender node receives the frame it sent, the

sender node discards the frame to avoid loops. The HSR ringwith 615 series relays supports the connection of up to 30relays. If more than 30 relays are to be connected, it isrecommended to split the network into several rings toguarantee the performance for real-time applications.


16 ABB

Ethernet switch

RedundancyBox

IEC 61850 HSR

RedundancyBox

RedundancyBox

REF615 REF620 RET620 REM620 REF615

SCADA Devices not supporting HSRCOM600

GUID-7996332D-7FC8-49F3-A4FE-FB4ABB730405 V1 EN

Figure 10. High availability seamless redundancy (HSR) solution

The choice between the HSR and PRP redundancy protocolsdepends on the required functionality, cost and complexity.

The self-healing Ethernet ring solution enables a cost-efficientcommunication ring controlled by a managed switch withstandard Rapid Spanning Tree Protocol (RSTP) support. Themanaged switch controls the consistency of the loop, routesthe data and corrects the data flow in case of a communication

switch-over. The relays in the ring topology act as unmanagedswitches forwarding unrelated data traffic. The Ethernet ringsolution supports the connection of up to 30 615 series relays.If more than 30 relays are to be connected, it is recommendedto split the network into several rings. The self-healing Ethernetring solution avoids single point of failure concerns andimproves the reliability of the communication.


ABB 17

Managed Ethernet switchwith RSTP support

Managed Ethernet switchwith RSTP support

Client BClient A

Network ANetwork B

GUID-AB81C355-EF5D-4658-8AE0-01DC076E519C V4 EN

Figure 11. Self-healing Ethernet ring solution

All communication connectors, except for the front portconnector, are placed on integrated optional communicationmodules. The relay can be connected to Ethernet-basedcommunication systems via the RJ-45 connector (100Base-TX)or the fiber optic LC connector (100Base-FX). If connection toserial bus is required, the 9-pin RS-485 screw-terminal can beused. An optional serial interface is available for RS-232communication.

Modbus implementation supports RTU, ASCII and TCP modes.Besides standard Modbus functionality, the relay supportsretrieval of time-stamped events, changing the active settinggroup and uploading of the latest fault records. If a ModbusTCP connection is used, five clients can be connected to therelay simultaneously. Further, Modbus serial and Modbus TCPcan be used in parallel, and if required both IEC 61850 andModbus protocols can be run simultaneously.

The IEC 60870-5-103 implementation supports two parallelserial bus connections to two different masters. Besides basicstandard functionality, the relay supports changing of the activesetting group and uploading of disturbance recordings in IEC60870-5-103 format. Further, IEC 60870-5-103 can be used atthe same time with the IEC 61850 protocol.

DNP3 supports both serial and TCP modes for connection upto five masters. Changing of the active setting and reading fault

records are supported. DNP serial and DNP TCP can be used inparallel. If required, both IEC 61850 and DNP protocols can berun simultaneously.

615 series supports Profibus DPV1 with support of SPA-ZC302 Profibus adapter. If Profibus is required the relay must beordered with Modbus serial options. Modbus implementationincludes SPA-protocol emulation functionality. Thisfunctionality enables connection to SPA-ZC 302.

When the relay uses the RS-485 bus for the serialcommunication, both two- and four wire connections aresupported. Termination and pull-up/down resistors can beconfigured with jumpers on the communication card so externalresistors are not needed.

The relay supports the following time synchronization methodswith a time-stamping resolution of 1 ms.

Ethernet-based• SNTP (Simple Network Time Protocol)

With special time synchronization wiring• IRIG-B (Inter-Range Instrumentation Group - Time Code

Format B)


18 ABB

The relay supports the following high accuracy timesynchronization method with a time-stamping resolution of 4 µsrequired especially in process bus applications.• PTP (IEEE 1588) v2 with Power Profile

The IEEE 1588 support is included in all variants having aredundant Ethernet communication module.

IEEE 1588 v2 features• Ordinary Clock with Best Master Clock algorithm• One-step Transparent Clock for Ethernet ring topology• 1588 v2 Power Profile• Receive (slave): 1-step/2-step• Transmit (master): 1-step

• Layer 2 mapping• Peer to peer delay calculation• Multicast operation

Required accuracy of grandmaster clock is +/-1 µs. The relaycan work as a master clock per BMC algorithm if the externalgrandmaster clock is not available for short term.

The IEEE 1588 support is included in all variants having aredundant Ethernet communication module.

In addition, the relay supports time synchronization viaModbus, DNP3 and IEC 60870-5-103 serial communicationprotocols.

Table 5. Supported station communication interfaces and protocols

Interfaces/Protocols Ethernet Serial

100BASE-TX RJ-45 100BASE-FX LC RS-232/RS-485 Fiber optic ST

IEC 61850-8-1 - -

IEC 61850-9-2 LE - -

MODBUS RTU/ASCII - -

MODBUS TCP/IP - -

DNP3 (serial) - -

DNP3 TCP/IP - -

IEC 60870-5-103 - - = Supported


ABB 19

20. Technical data

Table 6. Dimensions

Description Value

Width Frame 177 mm

Case 164 mm

Height Frame 177 mm (4U)

Case 160 mm

Depth 201 mm (153 + 48 mm)

Weight Complete protection relay 4.1 kg

Plug-in unit only 2.1 kg

Table 7. Power supply

Description Type 1 Type 2

Nominal auxiliary voltage Un 100, 110, 120, 220, 240 V AC, 50 and 60 Hz 24, 30, 48, 60 V DC

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

Maximum interruption time in the auxiliaryDC voltage without resetting the relay

50 ms at Un

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

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

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

Burden of auxiliary voltage supply underquiescent (Pq)/operating condition

DC <13.0 W (nominal)/<18.0 W (max.)AC <16.0 W (nominal)/<21.0 W (max.)

DC <13.0 W (nominal)/<18.0 W (max.)

Ripple in the DC auxiliary voltage Max 15% of the DC value (at frequency of 100 Hz)

Fuse type T4A/250 V

Table 8. Energizing inputs

Description Value

Rated frequency 50/60 Hz

Current inputs Rated current, In 0.2/1 A1) 1/5 A2)

Thermal withstand capability:

• Continuously 4 A 20 A

• For 1 s 100 A 500 A

Dynamic current withstand:

• Half-wave value 250 A 1250 A

Input impedance <100 mΩ <20 mΩ

Voltage inputs Rated voltage 60...210 V AC

Voltage withstand:

• Continuous 240 V AC

• For 10 s 360 V AC

Burden at rated voltage <0.05 VA

1) Ordering option for residual current input2) Residual current and/or phase current


20 ABB

Table 9. Binary inputs

Description Value

Operating range ±20% of the rated voltage

Rated voltage 24...250 V DC

Current drain 1.6...1.9 mA

Power consumption 31.0...570.0 mW

Threshold voltage 16...176 V DC

Reaction time <3 ms

Table 10. RTD/mA measurement (XRGGIO130)

Description Value

RTD inputs Supported RTD sensors 100 Ω platinum250 Ω platinum100 Ω nickel120 Ω nickel250 Ω nickel10 Ω copper

TCR 0.00385 (DIN 43760)TCR 0.00385TCR 0.00618 (DIN 43760)TCR 0.00618TCR 0.00618TCR 0.00427

Supported resistance range 0...2 kΩ

Maximum lead resistance (three-wire measurement) 25 Ω per lead

Isolation 2 kV (inputs to protective earth)

Response time <4 s

RTD/resistance sensing current Maximum 0.33 mA rms

Operation accuracy Resistance Temperature

± 2.0% or ±1 Ω ±1°C10 Ω copper: ±2°C

mA inputs Supported current range 0…20 mA

Current input impedance 44 Ω ± 0.1%

Operation accuracy ±0.5% or ±0.01 mA

Table 11. Signal output X100: SO1

Description Value

Rated voltage 250 V AC/DC

Continuous contact carry 5 A

Make and carry for 3.0 s 15 A


Breaking capacity when the control-circuit time constant L/R<40 ms 1 A/0.25 A/0.15 A

Minimum contact load 100 mA at 24 V AC/DC


ABB 21

Table 12. Signal outputs and IRF output

Description Value




Make and carry 0.5 s 15 A

Breaking capacity when the control-circuit time constant L/R<40 ms, at48/110/220 V DC

1 A/0.25 A/0.15 A


Table 13. Double-pole power output relays with TCS function

Description Value





Breaking capacity when the control-circuit time constant L/R<40 ms, at48/110/220 V DC (two contacts connected in series)

5 A/3 A/1 A


Trip-circuit supervision (TCS):

• Control voltage range 20...250 V AC/DC

• Current drain through the supervision circuit ~1.5 mA

• Minimum voltage over the TCS contact 20 V AC/DC (15...20 V)

Table 14. Single-pole power output relays

Description Value





Breaking capacity when the control-circuit time constant L/R<40 ms, at48/110/220 V DC

5 A/3 A/1 A



22 ABB

Table 15. High-speed output HSO with BIO0007

Description Value





Breaking capacity when the control-circuit time constant L/R <40 ms, at48/110/220 V DC

5 A/3 A/1 A

Operate time <1 ms

Reset <20 ms, resistive load

Table 16. Front port Ethernet interfaces

Ethernet interface Protocol Cable Data transfer rate

Front TCP/IP protocol Standard Ethernet CAT 5 cable with RJ-45 connector 10 MBits/s

Table 17. IRIG-B

Description Value

IRIG time code format B004, B0051)

Isolation 500V 1 min

Modulation Unmodulated

Logic level 5 V TTL

Current consumption <4 mA

Power consumption <20 mW

1) According to the 200-04 IRIG standard

Table 18. Degree of protection of flush-mounted protection relay

Description Value

Front side IP 54

Rear side, connection terminals IP 20

Table 19. Environmental conditions

Description Value

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

Short-time service temperature range -40...+85ºC (<16h)1)2)

Relative humidity <93%, non-condensing

Atmospheric pressure 86...106 kPa

Altitude Up to 2000 m

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

1) Degradation in MTBF and HMI performance outside the temperature range of -25...+55 ºC2) For relays with an LC communication interface the maximum operating temperature is +70 ºC


ABB 23

Table 20. Electromagnetic compatibility tests

Description Type test value Reference

1 MHz/100 kHz burst disturbance test IEC 61000-4-18IEC 60255-26, class IIIIEEE C37.90.1-2002

• Common mode 2.5 kV

• Differential mode 2.5 kV

3 MHz, 10 MHz and 30 MHz burst disturbancetest

IEC 61000-4-18IEC 60255-26, class III

• Common mode 2.5 kV

Electrostatic discharge test IEC 61000-4-2IEC 60255-26IEEE C37.90.3-2001

• Contact discharge 8 kV

• Air discharge 15 kV

Radio frequency interference test

10 V (rms)f = 150 kHz...80 MHz

IEC 61000-4-6IEC 60255-26, class III

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

IEC 61000-4-3IEC 60255-26, class III

10 V/mf = 900 MHz

ENV 50204IEC 60255-26, class III

20 V/m (rms)f = 80...1000 MHz

IEEE C37.90.2-2004

Fast transient disturbance test IEC 61000-4-4IEC 60255-26IEEE C37.90.1-2002

• All ports 4 kV

Surge immunity test IEC 61000-4-5IEC 60255-26

• Communication 1 kV, line-to-earth

• Other ports 4 kV, line-to-earth2 kV, line-to-line

Power frequency (50 Hz) magnetic fieldimmunity test

IEC 61000-4-8

• Continuous• 1...3 s

300 A/m1000 A/m

Pulse magnetic field immunity test 1000 A/m6.4/16 µs

IEC 61000-4-9

Damped oscillatory magnetic field immunity test IEC 61000-4-10

• 2 s 100 A/m

• 1 MHz 400 transients/s

Voltage dips and short interruptions 30%/10 ms60%/100 ms60%/1000 ms>95%/5000 ms

IEC 61000-4-11


24 ABB

Table 20. Electromagnetic compatibility tests, continued


Power frequency immunity test Binary inputs only IEC 61000-4-16IEC 60255-26, class A

• Common mode 300 V rms

• Differential mode 150 V rms

Conducted common mode disturbances 15 Hz...150 kHzTest level 3 (10/1/10 V rms)

IEC 61000-4-16

Emission tests EN 55011, class AIEC 60255-26CISPR 11CISPR 12

• Conducted

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

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

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

1…3 GHz <76 dB (µV/m) peak<56 dB (µV/m) average, measured at 3 mdistance

3…6 GHz <80 dB (µV/m) peak<60 dB (µV/m) average, measured at 3 mdistance

Table 21. Insulation tests


Dielectric tests 2 kV, 50 Hz, 1 min500 V, 50 Hz, 1 min, communication

IEC 60255-27

Impulse voltage test 5 kV, 1.2/50 μs, 0.5 J1 kV, 1.2/50 μs, 0.5 J, communication

IEC 60255-27

Insulation resistance measurements >100 MΩ, 500 V DC IEC 60255-27

Protective bonding resistance <0.1 Ω, 4 A, 60 s IEC 60255-27

Table 22. Mechanical tests

Description Reference Requirement

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

Class 2

Shock and bump test IEC 60068-2-27 (test Ea shock)IEC 60068-2-29 (test Eb bump)IEC 60255-21-2

Class 2

Seismic test IEC 60255-21-3 Class 2


ABB 25

Table 23. Environmental tests


Dry heat test • 96 h at +55ºC IEC 60068-2-2

Dry cold test • 96 h at -25ºC• 16 h at -40ºC

IEC 60068-2-1

Damp heat test • 6 cycles (12 h + 12 h) at +25°C…+55°C,humidity >93%

IEC 60068-2-30

Change of temperature test • 5 cycles (3 h + 3 h)at -25°C...+55°C

IEC60068-2-14

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

IEC 60068-2-1IEC 60068-2-2

Table 24. Product safety

Description Reference

LV directive 2006/95/EC

Standard EN 60255-27 (2013)EN 60255-1 (2009)

Table 25. EMC compliance

Description Reference

EMC directive 2004/108/EC

Standard EN 60255-26 (2013)

Table 26. RoHS compliance

Description

Complies with RoHS directive 2002/95/EC


26 ABB

Protection functions

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

Characteristic Value

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

PHLPTOC ±1.5% of the set value or ±0.002 × In

PHHPTOCandPHIPTOC

±1.5% of set value or ±0.002 × In(at currents in the range of 0.1…10 × In)±5.0% of the set value(at currents in the range of 10…40 × In)

Start time 1)2) Minimum Typical Maximum

PHIPTOC:IFault = 2 × set Start valueIFault = 10 × set Start value

16 ms 11 ms

19 ms 12 ms

23 ms 14 ms

PHHPTOC and PHLPTOC:IFault = 2 × set Start value

23 ms

26 ms

29 ms

Reset time Typically 40 ms

Reset ratio Typically 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 × 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 on stage), current before fault = 0.0 × In, fn = 50 Hz, fault current in one phasewith nominal frequency injected from 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

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

Parameter Function Value (Range) Step

Start value PHLPTOC 0.05...5.00 × In 0.01

PHHPTOC 0.10...40.00 × In 0.01

PHIPTOC 1.00...40.00 × In 0.01

Time multiplier PHLPTOC and PHHPTOC 0.05...15.00 0.01

Operate delay time PHLPTOC and PHHPTOC 40...200000 ms 10

PHIPTOC 20...200000 ms 10

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, see the Operation characteristics table


ABB 27

Table 29. Non-directional earth-fault protection (EFxPTOC)



EFLPTOC ±1.5% of the set value or ±0.002 × In

EFHPTOCandEFIPTOC

±1.5% of set value or ±0.002 × In(at currents in the range of 0.1…10 × In)±5.0% of the set value(at currents in the range of 10…40 × In)


EFIPTOC:IFault = 2 × set Start valueIFault = 10 × set Start value

16 ms11 ms

19 ms12 ms

23 ms14 ms

EFHPTOC and EFLPTOC:IFault = 2 × set Start value

23 ms

26 ms

29 ms






Suppression of harmonics RMS: No suppressionDFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,…Peak-to-Peak: No suppression

1) Measurement mode = default (depends on stage), current before fault = 0.0 × 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 × In, Start value multiples in range of 1.5...20

Table 30. Non-directional earth-fault protection (EFxPTOC) main settings


Start value EFLPTOC 0.010...5.000 × In 0.005

EFHPTOC 0.10...40.00 × In 0.01

EFIPTOC 1.00...40.00 × In 0.01

Time multiplier EFLPTOC and EFHPTOC 0.05...15.00 0.01

Operate delay time EFLPTOC and EFHPTOC 40...200000 ms 10

EFIPTOC 20...200000 ms 10

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



28 ABB

Table 31. Directional earth-fault protection (DEFxPDEF)



DEFLPDEF Current:±1.5% of the set value or ±0.002 × InVoltage±1.5% of the set value or ±0.002 × UnPhase angle:±2°

DEFHPDEF Current:±1.5% of the set value or ±0.002 × In(at currents in the range of 0.1…10 × In)±5.0% of the set value(at currents in the range of 10…40 × In)Voltage:±1.5% of the set value or ±0.002 × UnPhase angle:±2°


DEFHPDEFIFault = 2 × set Start value

42 ms

46 ms

49 ms

DEFLPDEFIFault = 2 × set Start value

58 ms 62 ms 66 ms






Suppression of harmonics RMS: No suppressionDFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,…Peak-to-Peak: No suppression

1) Set Operate delay time = 0.06 s,Operate curve type = IEC definite time, Measurement mode = default (depends on stage), current before fault = 0.0 × 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 × In, Start value multiples in range of 1.5...20


ABB 29

Table 32. Directional earth-fault protection (DEFxPDEF) main settings


Start value DEFLPDEF 0.010...5.000 × In 0.005

DEFHPDEF 0.10...40.00 × In 0.01

Directional mode DEFLPDEF and DEFHPDEF 1 = Non-directional2 = Forward3 = Reverse

-

Time multiplier DEFLPDEF 0.05...15.00 0.01

DEFHPDEF 0.05...15.00 0.01

Operate delay time DEFLPDEF 50...200000 ms 10

DEFHPDEF 40...200000 ms 10

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

-

1) For further reference, see the Operating characteristics table

Table 33. Transient/intermittent earth-fault protection (INTRPTEF)


Operation accuracy (Uo criteria with transient protection) Depending on the frequency of the measured current: fn ±2 Hz

±1.5% of the set value or ±0.002 × Uo

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

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

Table 34. Transient/intermittent earth-fault protection (INTRPTEF) main settings


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

-

Operate delay time INTRPTEF 40...1200000 ms 10

Voltage start value INTRPTEF 0.05...0.50 × Un 0.01

Operation mode INTRPTEF 1 = Intermittent EF2 = Transient EF

-

Peak counter limit INTRPTEF 2...20 1

Min operate current INTRPTEF 0.01...1.00 × In 0.01


30 ABB

Table 35. Negative-sequence overcurrent protection (NSPTOC)


Operation accuracy Depending on the frequency of the measured current: fn

±1.5% of the set value or ±0.002 × In


IFault = 2 × set Start valueIFault = 10 × set Start value

23 ms15 ms

26 ms18 ms

28 ms20 ms






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

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

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

Table 36. Negative-sequence overcurrent protection (NSPTOC) main settings


Start value NSPTOC 0.01...5.00 × In 0.01

Time multiplier NSPTOC 0.05...15.00 0.01

Operate delay time NSPTOC 40...200000 ms 10

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


Table 37. Residual overvoltage protection (ROVPTOV)


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

±1.5% of the set value or ±0.002 × Un

Start time1)2) Minimum Typical Maximum

UFault = 2 × set Start value 48 ms 51 ms 54 ms






1) Residual voltage before fault = 0.0 × Un, fn = 50 Hz, residual voltage with nominal frequency injected from random phase angle, results based on statistical distribution of 1000

measurements2) Includes the delay of the signal output contact


ABB 31

Table 38. Residual overvoltage protection (ROVPTOV) main settings


Start value ROVPTOV 0.010...1.000 × Un 0.001

Operate delay time ROVPTOV 40...300000 ms 1

Table 39. Three-phase undervoltage protection (PHPTUV)


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



UFault = 0.9 × set Start value 62 ms 66 ms 70 ms


Reset ratio Depends on the set Relative hysteresis



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


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 angle, results based on statistical

distribution of 1000 measurements2) Includes the delay of the signal output contact3) Minimum Start value = 0.50, Start value multiples in range of 0.90...0.20

Table 40. Three-phase undervoltage protection (PHPTUV) main settings


Start value PHPTUV 0.05...1.20 × Un 0.01

Time multiplier PHPTUV 0.05...15.00 0.01

Operate delay time PHPTUV 60...300000 ms 10

Operating curve type1) PHPTUV Definite or inverse timeCurve type: 5, 15, 21, 22, 23



32 ABB

Table 41. Three-phase overvoltage protection (PHPTOV)





UFault = 1.1 × set Start value 23 ms 27 ms 31 ms





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


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 angle, results based on statistical

distribution of 1000 measurements2) Includes the delay of the signal output contact3) Maximum Start value = 1.20 × Un, Start value multiples in range of 1.10...2.00

Table 42. Three-phase overvoltage protection (PHPTOV) main settings


Start value PHPTOV 0.05...1.60 × Un 0.01

Time multiplier PHPTOV 0.05...15.00 0.01

Operate delay time PHPTOV 40...300000 ms 10

Operating curve type1) PHPTOV Definite or inverse timeCurve type: 5, 15, 17, 18, 19, 20


Table 43. Positive-sequence undervoltage protection (PSPTUV)





UFault = 0.99 × set Start valueUFault = 0.9 × set Start value

52 ms44 ms

55 ms47 ms

58 ms50 ms






1) Start value = 1.0 × Un, positive-sequence voltage before fault = 1.1 × Un, fn = 50 Hz, positive sequence undervoltage with nominal frequency injected from random phase angle, results based

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


ABB 33

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


Start value PSPTUV 0.010...1.200 × Un 0.001

Operate delay time PSPTUV 40...120000 ms 10

Voltage block value PSPTUV 0.01...1.00 × Un 0.01

Table 45. Negative-sequence overvoltage protection (NSPTOV)


Operation accuracy Depending on the frequency of the voltage measured: fn



UFault = 1.1 × set Start valueUFault = 2.0 × set Start value

33 ms24 ms

35 ms26 ms

37 ms28 ms






1) Negative-sequence voltage before fault = 0.0 × Un, fn = 50 Hz, negative-sequence overvoltage with nominal frequency injected from random phase angle, results based on statistical

distribution of 1000 measurements2) Includes the delay of the signal output contact

Table 46. Negative-sequence overvoltage protection (NSPTOV) main settings


Start value NSPTOV 0.010...1.000 × Un 0.001

Operate delay time NSPTOV 40...120000 ms 1

Table 47. Three-phase thermal overload protection, two time constants (T2PTTR)



Current measurement: ±1.5% of the set value or ±0.002 x In (at currentsin the range of 0.01...4.00 x In)

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

1) Overload current > 1.2 x Operate level temperature


34 ABB

Table 48. Three-phase thermal overload protection, two time constants (T2PTTR) main settings


Temperature rise T2PTTR 0.0...200.0°C 0.1

Max temperature T2PTTR 0.0...200.0°C 0.1

Operate temperature T2PTTR 80.0...120.0% 0.1

Short time constant T2PTTR 6...60000 s 1

Weighting factor p T2PTTR 0.00...1.00 0.01

Current reference T2PTTR 0.05...4.00 × In 0.01

Operation T2PTTR 1 = on5 = off

-

Table 49. Circuit breaker failure protection (CCBRBRF)



±1.5% of the set value or ±0.002 × In




Table 50. Circuit breaker failure protection (CCBRBRF) main settings


Current value CCBRBRF 0.05...2.00 × In 0.05

Current value Res CCBRBRF 0.05...2.00 × In 0.05

CB failure mode CCBRBRF 1 = Current2 = Breaker status3 = Both

-

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

-

Retrip time CCBRBRF 0...60000 ms 10

CB failure delay CCBRBRF 0...60000 ms 10

CB fault delay CCBRBRF 0...60000 ms 10


ABB 35

Table 51. Arc protection (ARCSARC)


Operation accuracy ±3% of the set value or ±0.01 × In

Operate time Minimum Typical Maximum

Operation mode = "Light+current"1)2)

9 ms3)

4 ms4)12 ms3)

6 ms4)15 ms 3)

9 ms4)

Operation mode = "Light only"2) 9 ms3)

4 ms4)10 ms3)

6 ms4)12 ms3)

7 ms4)



1) Phase start value = 1.0 × In, current before fault = 2.0 × set Phase start value, fn = 50 Hz, fault with nominal frequency, results based on statistical distribution of 200 measurements

2) Includes the delay of the heavy-duty output contact3) Normal power output4) High-speed output

Table 52. Arc protection (ARCSARC) main settings


Phase start value ARCSARC 0.50...40.00 × In 0.01

Ground start value ARCSARC 0.05...8.00 × In 0.01

Operation mode ARCSARC 2 = Light only3 = BI controlled

-

Table 53. Multipurpose protection (MAPGAPC)


Operation accuracy ±1.0% of the set value or ±20 ms

Table 54. Multipurpose protection (MAPGAPC) main settings


Start value MAPGAPC -10000.0...10000.0 0.1

Operate delay time MAPGAPC 0...200000 ms 100

Operation mode MAPGAPC 1 = Over2 = Under

-


36 ABB

Table 55. Three-phase overload protection for shunt capacitor banks (COLPTOC)


Operation accuracy Depending on the frequency of the measured current: fn ±2 Hz, and noharmonics

5% of the set value or 0.002 × In

Start time for overload stage1)2) Typically 75 ms

Start time for under current stage2)3) Typically 26 ms

Reset time for overload and alarm stage Typically 60 ms


Operate time accuracy in definite time mode 1% of the set value or ±20 ms

Operate time accuracy in inverse time mode 10% of the theoretical value or ±20 ms

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

1) Harmonics current before fault = 0.5 × In, harmonics fault current 1.5 × Start value, results based on statistical distribution of 1000 measurements

2) Includes the delay of the signal output contact3) Harmonics current before fault = 1.2 × In, harmonics fault current 0.8 × Start value, results based on statistical distribution of 1000 measurements

Table 56. Three-phase overload protection for shunt capacitor banks (COLPTOC) main settings


Start value overload COLPTOC 0.30...1.50 × In 0.01

Alarm start value COLPTOC 80...120% 1

Start value Un Cur COLPTOC 0.10...0.70 × In 0.01

Time multiplier COLPTOC 0.05...2.00 0.01

Alarm delay time COLPTOC 500...6000000 ms 100

Un Cur delay time COLPTOC 100...120000 ms 100

Table 57. Current unbalance protection for shunt capacitor banks (CUBPTOC)



1.5% of the set value or 0.002 × In

Start time1)2) Typically 26 ms



Operate time accuracy in definite time mode 1% of the theoretical value or ±20 ms

Operate time accuracy in inverse definite minimum time mode 5% of the theoretical value or ±20 ms

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

1) Fundamental frequency current = 1.0 × In, current before fault = 0.0 × In, fault current = 2.0 × Start value, results based on statistical distribution of 1000 measurements

2) Includes the delay of the signal output contact


ABB 37

Table 58. Current unbalance protection for shunt capacitor banks (CUBPTOC) main settings


Alarm mode CUBPTOC 1 = Normal2 = Element counter

-

Start value CUBPTOC 0.01...1.00 × In 0.01

Alarm start value CUBPTOC 0.01...1.00 × In 0.01

Time multiplier CUBPTOC 0.05...15.00 0.01

Operating curve type1) CUBPTOC Definite or inverse timeCurve type: 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 17, 18, 19

Operate delay time CUBPTOC 50...200000 ms 10

Alarm delay time CUBPTOC 50...200000 ms 10

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

Table 59. Three-phase current unbalance protection for shunt capacitor banks (HCUBPTOC)



1.5% of the set value or 0.002 × In

Start time1)2) Typically 26 ms



Operate time accuracy in definite time mode 1% of the theoretical value or ±20 ms

Operate time accuracy in IDMT mode 5% of the theoretical value or ±20 ms

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

1) Fundamental frequency current = 1.0 × In, current before fault = 0.0 × In, fault current = 2.0 × Start value, results based on statistical distribution of 1000 measurements

2) Includes the delay of the signal output contact

Table 60. Three-phase current unbalance protection for shunt capacitor banks (HCUBPTOC) main settings


Start value HCUBPTOC 0.01...1.00 × In 0.01

Alarm start value HCUBPTOC 0.01...1.00 × In 0.01

Time multiplier HCUBPTOC 0.05...15.00 0.01

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

Operate delay time HCUBPTOC 40...200000 ms 10

Alarm delay time HCUBPTOC 40...200000 ms 10

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


38 ABB

Table 61. Shunt capacitor bank switching resonance protection, current based (SRCPTOC)



Operate value accuracy:±3% of the set value or ±0.002 × In (for 2nd order Harmonics)±1.5% of the set value or ±0.002 × In (for 3rd order < Harmonics < 10thorder)±6% of the set value or ±0.004 × In (for Harmonics >= 10th order)

Reset time Typically 45 ms or maximum 50 ms

Retardation time Typically 0.96



Suppression of harmonics -50 dB at f = fn

Table 62. Shunt capacitor bank switching resonance protection, current based (SRCPTOC) main settings


Alarm start value SRCPTOC 0.03...0.50 × In 0.01

Start value SRCPTOC 0.03...0.50 × In 0.01

Tuning harmonic Num SRCPTOC 1...11 1

Operate delay time SRCPTOC 120...360000 ms 1

Alarm delay time SRCPTOC 120...360000 ms 1


ABB 39

Table 63. Operation characteristics

Parameter Value (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


40 ABB

Power quality functions

Table 64. Voltage variation (PHQVVR)


Operation accuracy ±1.5% of the set value or ±0.2% of reference voltage

Reset ratio Typically 0.96 (Swell), 1.04 (Dip, Interruption)

Table 65. Voltage unbalance (VSQVUB)


Operation accuracy ±1.5% of the set value or ±0.002 × Un



ABB 41

Condition and supervision functions

Table 66. Circuit-breaker condition monitoring (SSCBR)


Current measuring accuracy ±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)


Travelling time measurement +10 ms / -0 ms

Table 67. Current circuit supervision (CCSPVC)


Operate time 1) <30 ms

1) Including the delay of the output contact

Table 68. Current circuit supervision (CCSPVC) main settings


Start value CCSPVC 0.05...0.20 × In 0.01

Max operate current CCSPVC 1.00...5.00 × In 0.01

Table 69. Fuse failure supervision (SEQSPVC)


Operate time1) NPS function UFault = 1.1 × set Neg Seq voltageLev

<33 ms

UFault = 5.0 × set Neg Seq voltageLev

<18 ms

Delta function ΔU = 1.1 × set Voltage change rate <30 ms

ΔU = 2.0 × set Voltage change rate <24 ms

1) Includes the delay of the signal output contact, fn = 50 Hz, fault voltage with nominal frequency injected from random phase angle, results based on statistical distribution of 1000

measurements

Table 70. Runtime counter for machines and devices (MDSOPT)

Description Value

Motor runtime measurement accuracy1) ±0.5%

1) Of the reading, for a stand-alone relay, without time synchronization


42 ABB

Measurement functions

Table 71. Three-phase current measurement (CMMXU)



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

Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,…RMS: No suppression

Table 72. Sequence current measurement (CSMSQI)


Operation accuracy Depending on the frequency of the measured current: f/fn = ±2 Hz

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


Table 73. Residual current measurement (RESCMMXU)


Operation accuracy Depending on the frequency of the current measured: f/fn = ±2 Hz

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


Table 74. Three-phase voltage measurement (VMMXU)


Operation accuracy Depending on the frequency of the voltage measured: fn ±2 HzAt voltages in range 0.01…1.15 × Un

±0.5% or ±0.002 × Un


Table 75. Residual voltage measurement (RESVMMXU)


Operation accuracy Depending on the frequency of the measured current: f/fn = ±2 Hz

±0.5% or ±0.002 × Un



ABB 43

Table 76. Sequence voltage measurement (VSMSQI)


Operation accuracy Depending on the frequency of the voltage measured: fn ±2 HzAt voltages in range 0.01…1.15 × Un

±1.0% or ±0.002 × Un


Table 77. Three-phase power and energy measurement (PEMMXU)


Operation accuracy At all three currents in range 0.10…1.20 × InAt all three voltages in range 0.50…1.15 × UnAt the frequency fn ±1 Hz

±1.5% for apparent power S±1.5% for active power P and active energy1)

±1.5% for reactive power Q and reactive energy2)

±0.015 for power factor


1) |PF| >0.5 which equals |cosφ| >0.52) |PF| <0.86 which equals |sinφ| >0.5

Table 78. RTD/mA measurement (XRGGIO130)

Description Value

RTD inputs Supported RTD sensors 100 Ω platinum250 Ω platinum100 Ω nickel120 Ω nickel250 Ω nickel10 Ω copper

TCR 0.00385 (DIN 43760)TCR 0.00385TCR 0.00618 (DIN 43760)TCR 0.00618TCR 0.00618TCR 0.00427

Supported resistance range 0...2 kΩ

Maximum lead resistance (three-wire measurement) 25 Ω per lead

Isolation 2 kV (inputs to protective earth)

Response time <4 s

RTD/resistance sensing current Maximum 0.33 mA rms

Operation accuracy Resistance Temperature

± 2.0% or ±1 Ω ±1°C10 Ω copper: ±2°C

mA inputs Supported current range 0…20 mA

Current input impedance 44 Ω ± 0.1%

Operation accuracy ±0.5% or ±0.01 mA

Table 79. Frequency measurement (FMMXU)


Operation accuracy ±5 mHz(in measurement range 35...75 Hz)


44 ABB

Other functions

Table 80. Pulse timer (PTGAPC)



Table 81. Time delay off (8 pcs) (TOFPAGC)



Table 82. Time delay on (8 pcs) (TONGAPC)




ABB 45

21. Local HMIThe relay is available with two optional displays, a large one anda small one. The large display is suited for relay installationswhere the front panel user interface is frequently used and asingle line diagram is required. The small display is suited forremotely controlled substations where the relay is onlyoccasionally accessed locally via the front panel user interface.

Both LCD displays offer front-panel user interface functionalitywith menu navigation and menu views. However, the largedisplay offers increased front-panel usability with less menuscrolling and improved information overview. In addition, thelarge display includes a user-configurable single line diagram(SLD) with position indication for the associated primaryequipment. Depending on the chosen standard configuration,the relay displays the related measuring values, apart from the

default single line diagram. The SLD view can also be accessedusing the Web browser-based user interface. The default SLDcan be modified according to user requirements by using theGraphical Display Editor in PCM600. The user can create up to10 SLD pages.

The local HMI includes a push button (L/R) for local/remoteoperation of the relay. When the relay is in the local mode, it canbe operated only by using the local front panel user interface.When the relay is in the remote mode, it can executecommands sent from a remote location. The relay supports theremote selection of local/remote mode via a binary input. Thisfeature facilitates, for example, the use of an external switch atthe substation to ensure that all relays are in the local modeduring maintenance work and that the circuit breakers cannotbe operated remotely from the network control center.

IECA070904 V3 EN

Figure 12. Small display

IECA070901 V3 EN

Figure 13. Large display

Table 83. Small display

Character size1) Rows in the view Characters per row

Small, mono-spaced (6 × 12 pixels) 5 20

Large, variable width (13 × 14 pixels) 3 8 or more

1) Depending on the selected language

Table 84. Large display

Character size1) Rows in the view Characters per row

Small, mono-spaced (6 × 12 pixels) 10 20

Large, variable width (13 × 14 pixels) 7 8 or more

1) Depending on the selected language


46 ABB

22. Mounting methodsBy means of appropriate mounting accessories, the standardrelay case can be flush mounted, semi-flush mounted or wallmounted. The flush mounted and wall mounted relay cases canalso be mounted in a tilted position (25°) using specialaccessories.

Further, the relays can be mounted in any standard 19”instrument cabinet by means of 19” mounting panels availablewith cut-outs for one or two relays.Alternatively, the relays canbe mounted in 19” instrument cabinets by means of 4UCombiflex equipment frames.

For routine testing purposes, the relay cases can be equippedwith test switches, type RTXP 18, which can be mounted sideby side with the relay cases.

Mounting methods• Flush mounting• Semi-flush mounting• Semi-flush mounting in a 25° tilt• Rack mounting• Wall mounting• Mounting to a 19" equipment frame• Mounting with an RTXP 18 test switch to a 19" rack

Panel cut-out for flush mounting• Height: 161.5 ±1 mm• Width: 165.5 ±1 mm

48

177

160

177

153

164

IECA070900 V4 EN

Figure 14. Flush mounting

98

177

160

186

103

IECA070903 V4 EN

Figure 15. Semi-flush mounting

230

107

25°

133

190

IECA070902 V4 EN

Figure 16. Semi-flush mounting in a 25º tilt

23. Relay case and plug-in unitThe relay cases are assigned to a certain type of plug-in unit.For safety reasons, the relay cases for current measuring relaysare provided with automatically operating contacts for short-circuiting the CT secondary circuits when a relay unit iswithdrawn from its case. The relay case is further provided witha mechanical coding system preventing the current measuringrelay units from being inserted into relay cases intended forvoltage measuring relay units.

24. Selection and ordering dataUse ABB Library to access the selection and orderinginformation and to generate the order number.

Product Selection Tool (PST), a Next-Generation Order NumberTool, supports order code creation for ABB DistributionAutomation IEC products with emphasis on but not exclusivelyfor the Relion product family. PST is an easy to use, online toolalways containing the latest product information. The completeorder code can be created with detailed specification and theresult can be printed and mailed. Registration is required.


ABB 47

http://search.abb.com/library/Download.aspx?DocumentID=1MRS758396&LanguageCode=en&DocumentPartId=&Action=Launch

https://abbtm.fi.abb.com/PST/#/

25. Accessories and ordering data

Table 85. Cables

Item Order number

Optical sensor for arc protection, cable length 1.5 m 1MRS120534-1.5

Optical sensor for arc protection, cable length 3.0 m 1MRS120534-3








Table 86. Mounting accessories

Item Order number

Semi-flush mounting kit 1MRS050696

Wall mounting kit 1MRS050697

Inclined semi-flush mounting kit 1MRS050831

19” rack mounting kit with cut-out for one relay 1MRS050694

19” rack mounting kit with cut-out for two relays 1MRS050695

Mounting bracket for one relay with test switch RTXP in 4U Combiflex (RHGT 19” variant C) 2RCA022642P0001

Mounting bracket for one relay in 4U Combiflex (RHGT 19” variant C) 2RCA022643P0001

19” rack mounting kit for one relay and one RTXP18 test switch (the test switch is not included in the delivery) 2RCA021952A0003

19” rack mounting kit for one relay and one RTXP24 test switch (the test switch is not included in the delivery) 2RCA022561A0003

Functional earthing flange for RTD modules1) 2RCA036978A0001

Replacement kit for a Strömberg SP_J40 series relay (cut-out in the center of the installation plate) 2RCA027871A0001

Replacement kit for a Strömberg SP_J40 series relay (cut-out on the left or the right of the installation plate) 2RCA027874A0001

Replacement kit for two Strömberg SP_J3 series relays 2RCA027880A0001

19” rack replacement kit for Strömberg SP_J3/J6 series relays (one cut-out) 2RCA027894A0001

19” rack replacement kit for Strömberg SP_J3/J6 series relays (two cut-outs) 2RCA027897A0001

Replacement kit for a Strömberg SP_J6 series relay 2RCA027881A0001

Replacement kit for three BBC S_ series relays 2RCA027882A0001

Replacement kit for a SPA 300 series relay 2RCA027885A0001

1) Cannot be used when the protection relay is mounted with the Combiflex 19" equipment frame (2RCA032826A0001)


48 ABB

26. ToolsThe protection relay is delivered as a preconfigured unit. Thedefault parameter setting values can be changed from the front-panel user interface (local HMI), the Web browser-based userinterface (Web HMI) or Protection and Control IED ManagerPCM600 in combination with the relay-specific connectivitypackage.

PCM600 offers extensive relay configuration functions. Forexample, depending on the protection relay, the relay signals,application, graphical display and single-line diagram, and IEC61850 communication, including horizontal GOOSEcommunication, can be modified with PCM600.

When the Web HMI is used, the protection relay can beaccessed either locally or remotely using a Web browser

(Internet Explorer). For security reasons, the Web HMI isdisabled by default but it can be enabled via the local HMI. TheWeb HMI functionality can be limited to read-only access.

The relay connectivity package is a collection of software andspecific relay information, which enables system products andtools to connect and interact with the protection relay. Theconnectivity packages reduce the risk of errors in systemintegration, minimizing device configuration and setup times.Further, the connectivity packages for protection relays of thisproduct series include a flexible update tool for adding oneadditional local HMI language to the protection relay. Theupdate tool is activated using PCM600, and it enables multipleupdates of the additional HMI language, thus offering flexiblemeans for possible future language updates.

Table 87. Tools

Description Version

PCM600 2.6 (Rollup 20150626) or later

Web browser IE 8.0, IE 9.0, IE 10.0 or IE 11.0

REV615 Connectivity Package 5.1 or later


ABB 49

Table 88. Supported functions

Function Web HMI PCM600

Relay parameter setting

Saving of relay parameter settings in the relay

Signal monitoring

Disturbance recorder handling

Alarm LED viewing

Access control management

Relay signal configuration (Signal Matrix) -

Modbus® communication configuration (communication management) -

DNP3 communication configuration (communication management) -

IEC 60870-5-103 communication configuration (communicationmanagement) -

Saving of relay parameter settings in the tool -

Disturbance record analysis -

XRIO parameter export/import

Graphical display configuration -

Application configuration -

IEC 61850 communication configuration, GOOSE (communicationconfiguration) -

Phasor diagram viewing -

Event viewing

Saving of event data on the user's PC

Online monitoring - = Supported

27. Cyber securityThe relay supports role based user authentication andauthorization. It can store 2048 audit trail events to a non-volatile memory. The non-volatile memory is based on amemory type which does not need battery backup or regularcomponent exchange to maintain the memory storage. FTP

and Web HMI use TLS encryption with a minimum of 128 bit keylength protecting the data in transit. In this case the usedcommunication protocols are FTPS and HTTPS. All rearcommunication ports and optional protocol services can bedeactivated according to the required system setup.


50 ABB

28. Terminal diagrams

REV615

X13Light sensor input 1 1)



1) Optional2) The IED features an automatic short-circuit mechanism in the CT connector when plug-in unit is detached3) BIO0005 Module (8BI+4BO) Alternative Module BIO0007 (8BI+3HSO)4) BIO0006 Module (6BI+3BO) Alternative Module RTD0001 (6RTD+2mA)

16

17

1918

X100

67

89

10

111213

15

14

2

1

3

45

22

212324

SO2

TCS2

PO4

SO1

TCS1

PO3

PO2

PO1

IRF

+

-Uaux

20

X110

34

56

7

89

10BI 6

BI 5

BI 4

BI 3

BI 2

BI 8

BI 712

13

11

BI 112

X110

16

14

15

19

17

18

22

20

21

SO3

SO2

SO1

23SO4

24

2)

X120

1

23

45

67

89

1011

1213

14

IL1unb1/5A

N

IL2unb

IL1

IL2

IL3

Io

1/5A

N1/5A

N1/5A

N1/5A

N1/5A

N1/5A

N

IL3unb

3)

3)

X130

12

3

45

6BI 4

BI 3

BI 2

BI 1

BI 6

BI 58

9

7

X130

12

10

11

15

13

14

18

16

17

SO3

SO2

SO1

4)

4)

GUID-E075C9E1-5D32-4556-ADD7-8B64EF861FA8 V1 EN

Figure 17. Terminal diagram for standard configuration A


ABB 51

REV615




1) Optional2) The IED features an automatic short-circuit mechanism in the CT connector when plug-in unit is detached3) BIO0005 Module (8BI+4BO) Alternative Module BIO0007 (8BI+3HSO)4) AIM0006 Module (5U+4BI) Alternative Module AIM0003 (5U+2RTD+1mA)

16

17

1918

X100

67

89

10

111213

15

14

2

1

3

45

22

212324

SO2

TCS2

PO4

SO1

TCS1

PO3

PO2

PO1

IRF

+

-Uaux

20

X110

34

56

7

89

10BI 6

BI 5

BI 4

BI 3

BI 2

BI 8

BI 712

13

11

BI 112

X110

16

14

15

19

17

18

22

20

21

SO3

SO2

SO1

23SO4

24

2)

X120

1

23

45

67

89

1011

1213

14

IL1unb1/5A

N

IL2unb

IL1

IL2

IL3

Io

1/5A

N1/5A

N1/5A

N1/5A

N1/5A

N1/5A

N

IL3unb

3)

3)

X13012

34

56

BI 4

BI 3

BI 2

BI 1

87

9101112

UoB

1314

U1

1516

U2

1718

U3

UoN

N

N

N

60 -

N

210V

60 -210V

60 -210V

60 -210V

60 -210V

4)

GUID-71A7F7FA-9605-46FE-A7EF-B53142C4EE9F V1 EN

Figure 18. Terminal diagram for standard configuration B


52 ABB

29. CertificatesDNV GL has issued an IEC 61850 Edition 2 Certificate Level A1

for Relion® 615 series. Certificate number: 7410570I-OPE/INC15-1136.

DNV GL has issued an IEC 61850 Edition 1 Certificate Level A1

for Relion® 615 series. Certificate number: 74105701-OPE/INC15-1145.

Additional certificates can be found on the product page.

30. ReferencesThe www.abb.com/substationautomation portal providesinformation on the entire range of distribution automationproducts and services.

The latest relevant information on the REV615 protection andcontrol relay is found on the product page. Scroll down thepage to find and download the related documentation.


ABB 53

http://new.abb.com/medium-voltage/distribution-automation/numerical-relays/capacitor-and-filter-bank/capacitor-bank-protection-and-control-rev615

HTTP://WWW.ABB.COM/SUBSTATIONAUTOMATION

http://new.abb.com/medium-voltage/distribution-automation/numerical-relays/capacitor-and-filter-bank/capacitor-bank-protection-and-control-rev615

31. Functions, codes and symbols

Table 89. Functions included in the relay

Function IEC 61850 IEC 60617 IEC-ANSI

Protection

Three-phase non-directional overcurrent protection, lowstage

PHLPTOC1 3I> (1) 51P-1 (1)

Three-phase non-directional overcurrent protection, highstage

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

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

Three-phase non-directional overcurrent protection,instantaneous stage

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

Non-directional earth-fault protection, low stage EFLPTOC1 Io> (1) 51N-1 (1)

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

Non-directional earth-fault protection, high stage EFHPTOC1 Io>> (1) 51N-2 (1)

Non-directional earth-fault protection, instantaneous stage EFIPTOC1 Io>>> (1) 50N/51N (1)

Directional earth-fault protection, low stage DEFLPDEF1 Io> -> (1) 67N-1 (1)

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

Directional earth-fault protection, high stage DEFHPDEF1 Io>> -> (1) 67N-2 (1)

Transient/intermittent earth-fault protection INTRPTEF1 Io> -> IEF (1) 67NIEF (1)

Negative-sequence overcurrent protection NSPTOC1 I2> (1) 46 (1)

NSPTOC2 I2> (2) 46 (2)

Residual overvoltage protection ROVPTOV1 Uo> (1) 59G (1)

ROVPTOV2 Uo> (2) 59G (2)

ROVPTOV3 Uo> (3) 59G (3)

Three-phase undervoltage protection PHPTUV1 3U< (1) 27 (1)

PHPTUV2 3U< (2) 27 (2)

Three-phase overvoltage protection PHPTOV1 3U> (1) 59 (1)

PHPTOV2 3U> (2) 59 (2)

Positive-sequence undervoltage protection PSPTUV1 U1< (1) 47U+ (1)

Negative-sequence overvoltage protection NSPTOV1 U2> (1) 47O- (1)

Three-phase thermal overload protection, two timeconstants

T2PTTR1 3Ith>T/G/C (1) 49T/G/C (1)

Circuit breaker failure protection CCBRBRF1 3I>/Io>BF (1) 51BF/51NBF (1)

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

TRPPTRC2 Master Trip (2) 94/86 (2)




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

ARCSARC2 ARC (2) 50L/50NL (2)

ARCSARC3 ARC (3) 50L/50NL (3)


54 ABB

Table 89. Functions included in the relay, continued


Multipurpose protection MAPGAPC1 MAP (1) MAP (1)

MAPGAPC2 MAP (2) MAP (2)

















Three-phase overload protection for shunt capacitor banks COLPTOC1 3I> 3I< (1) 51C/37 (1)

Current unbalance protection for shunt capacitor banks CUBPTOC1 dI>C (1) 51NC-1 (1)

Three-phase current unbalance protection for shuntcapacitor banks

HCUBPTOC1 3dI>C (1) 51NC-2 (1)

Shunt capacitor bank switching resonance protection,current based

SRCPTOC1 TD> (1) 55TD (1)

Power quality

Current total demand distortion CMHAI1 PQM3I (1) PQM3I (1)

Voltage total harmonic distortion VMHAI1 PQM3U (1) PQM3V (1)

Voltage variation PHQVVR1 PQMU (1) PQMV (1)

Voltage unbalance VSQVUB1 PQUUB (1) PQVUB (1)

Control

Circuit-breaker control CBXCBR1 I <-> O CB (1) I <-> O CB (1)

Disconnector control DCXSWI1 I <-> O DCC (1) I <-> O DCC (1)

DCXSWI2 I <-> O DCC (2) I <-> O DCC (2)

Earthing switch control ESXSWI1 I <-> O ESC (1) I <-> O ESC (1)

Disconnector position indication DCSXSWI1 I <-> O DC (1) I <-> O DC (1)

DCSXSWI2 I <-> O DC (2) I <-> O DC (2)

DCSXSWI3 I <-> O DC (3) I <-> O DC (3)


ABB 55



Earthing switch indication ESSXSWI1 I <-> O ES (1) I <-> O ES (1)

ESSXSWI2 I <-> O ES (2) I <-> O ES (2)

Condition monitoring and supervision

Circuit-breaker condition monitoring SSCBR1 CBCM (1) CBCM (1)

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

TCSSCBR2 TCS (2) TCM (2)

Current circuit supervision CCSPVC1 MCS 3I (1) MCS 3I (1)

Fuse failure supervision SEQSPVC1 FUSEF (1) 60 (1)

Runtime counter for machines and devices MDSOPT1 OPTS (1) OPTM (1)

Measurement

Disturbance recorder RDRE1 DR (1) DFR (1)

Load profile record LDPRLRC1 LOADPROF (1) LOADPROF (1)

Fault record FLTRFRC1 FAULTREC (1) FAULTREC (1)

Three-phase current measurement CMMXU1 3I (1) 3I (1)

Sequence current measurement CSMSQI1 I1, I2, I0 (1) I1, I2, I0 (1)

Residual current measurement RESCMMXU1 Io (1) In (1)

Three-phase voltage measurement VMMXU1 3U (1) 3V (1)

Residual voltage measurement RESVMMXU1 Uo (1) Vn (1)

RESVMMXU2 Uo (2) Vn (2)

Sequence voltage measurement VSMSQI1 U1, U2, U0 (1) V1, V2, V0 (1)

Three-phase power and energy measurement PEMMXU1 P, E (1) P, E (1)

RTD/mA measurement XRGGIO130 X130 (RTD) (1) X130 (RTD) (1)

Frequency measurement FMMXU1 f (1) f (1)

IEC 61850-9-2 LE sampled value sending SMVSENDER SMVSENDER SMVSENDER

IEC 61850-9-2 LE sampled value receiving (voltagesharing)

SMVRCV SMVRCV SMVRCV

Other

Minimum pulse timer (2 pcs) TPGAPC1 TP (1) TP (1)

TPGAPC2 TP (2) TP (2)



Minimum pulse timer (2 pcs, second resolution) TPSGAPC1 TPS (1) TPS (1)

Minimum pulse timer (2 pcs, minute resolution) TPMGAPC1 TPM (1) TPM (1)

Pulse timer (8 pcs) PTGAPC1 PT (1) PT (1)

PTGAPC2 PT (2) PT (2)


56 ABB



Time delay off (8 pcs) TOFGAPC1 TOF (1) TOF (1)

TOFGAPC2 TOF (2) TOF (2)



Time delay on (8 pcs) TONGAPC1 TON (1) TON (1)

TONGAPC2 TON (2) TON (2)



Set-reset (8 pcs) SRGAPC1 SR (1) SR (1)

SRGAPC2 SR (2) SR (2)



Move (8 pcs) MVGAPC1 MV (1) MV (1)

MVGAPC2 MV (2) MV (2)

Generic control point (16 pcs) SPCGAPC1 SPC (1) SPC (1)

SPCGAPC2 SPC (2) SPC (2)

Analog value scaling SCA4GAPC1 SCA4 (1) SCA4 (1)

SCA4GAPC2 SCA4 (2) SCA4 (2)



Integer value move MVI4GAPC1 MVI4 (1) MVI4 (1)

32. Document revision history

Document revision/date Product version History

A/2014-01-24 5.0 First release

B/2015-10-30 5.0 FP1 Content updated to correspond to the product version

C/2016-05-20 5.0 FP1 Content updated


ABB 57

58

Contact us

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www.abb.com/mediumvoltage

www.abb.com/substationautomation

ABB India Limited,Distribution AutomationManeja WorksVadodara-390013, IndiaPhone +91 265 6724402Fax +91 265 6724423

www.abb.com/mediumvoltage

www.abb.com/substationautomation

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