Motor Protection and Control REM620 Product Guide · 2018. 5. 10. · Local generic control points...

Relion® 620 series

Motor Protection and ControlREM620Product Guide

Contents

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

2. Default configuration.......................................................3

3. Protection functions........................................................9

4. Application.....................................................................9

5. Supported ABB solutions.............................................12

6. Control.........................................................................13

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

8. Disturbance recorder....................................................14

9. Event log......................................................................14

10. Recorded data............................................................14

11. Trip-circuit supervision.................................................14

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

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

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

15. Access control............................................................14

16. Inputs and outputs......................................................15

17. Station communication................................................16

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

19. Local HMI....................................................................46

20. Mounting methods......................................................46

21. IED case and IED plug-in unit......................................47

22. Selection and ordering data.........................................48

23. Accessories and ordering data....................................50

24. Tools...........................................................................50

25. Connection diagrams..................................................52

26. References..................................................................54

27. Functions, codes and symbols....................................55

28. Document revision history...........................................59

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 2013 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.

Motor Protection and Control 1MRS757845 AREM620 Product version: 2.0

2 ABB

1. DescriptionREM620 is a dedicated motor IED perfectly aligned for theprotection, control, measurement and supervision of medium-size and large asynchronous motors, requiring also differentialprotection, in the manufacturing and process industry.

REM620 is a member of ABB’s Relion® protection andcontrol product family and its 620 series. The 620 series IEDsare characterized by their functional scalability andwithdrawable-unit design.

The 620 series has been designed to unleash the full potentialof the IEC 61850 standard for communication andinteroperability of substation automation devices.

2. Default configurationThe 620 series IEDs are configured with defaultconfigurations, which can be used as examples of the 620

series engineering with different function blocks. The defaultconfigurations are not aimed to be used as real end-userapplications. The end-users always need to create their ownapplication configuration with the configuration tool. However,the default configuration can be used as a starting point bymodifying it according to the requirements.

REM620 is available with one default configuration targetingfor differential protection. The default signal configuration canbe altered by means of the graphical signal matrix or thegraphical application functionality of the Protection andControl IED Manager PCM600. Furthermore, the applicationconfiguration functionality of the IED supports the creation ofmulti-layer logic functions using various logical elementsincluding timers and flip-flops. By combining protectionfunctions with logic function blocks, the IED configuration canbe adapted to user-specific application requirements.

Motor Protection and Control 1MRS757845 AREM620 Product version: 2.0 Issued: 2013-05-07

Revision: A

ABB 3

CONDITION MONITORING AND SUPERVISION

COMMUNICATION

Protocols: IEC 61850-8-1 Modbus®

IEC 60870-5-103 DNP3

Interfaces: Ethernet: TX (RJ-45), FX (LC) Serial: Serial glass fiber (ST), RS-485, RS-232/485 D-sub 9, IRIG-B

Redundant protocols: HSR PRP RSTP

1 0 1 0 0 0 1 1 0 0 1 1 0 01 0 1 1 0 0 1 0 1 1 1 0 0 1 01 1 0 0 1 1 1 0 1 1 0 1 01 0 1 1 0 1 1 0 1 1 0 1 0 01 0 1 0 0 0 1 1 0 0 1 1 0 0 1 0 1 0 0 0 1 1 0 0 1 1 0 01 0 1 1 0 0 1 0 1 1 1 0 0 1 01 1 0 0 1 1 1 0 1 1 0 1 01 0 1 1 0 1 1 0 1 1 0 1 0 0

ORAND

ALSO AVAILABLE

- 16× prog. push-buttons on LHMI- Disturbance and fault recorders- Event log and recorded data- High-Speed Output module (optional)- IED self-supervision - Local/Remote push-button on LHMI- Sequence event recorder- User management- Web HMI

REMARKS

Optionalfunction

No. ofinstances

Alternative function to be defined when ordering

OR

Io/Uo

Calculatedvalue

3×

CONTROL AND INDICATION 1) MEASUREMENT

PROTECTION LOCAL HMI

MOTOR PROTECTION AND CONTROL IED

Version 2.0

REM620 EXAMPLECONFIGURATION

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

Analog interface types 1)

Current transformer

Voltage transformer1) Conventional transformer inputs

- I, U, Io, Uo, P, Q, E, pf, f- Symmetrical components- Limit value supervision- Load profile

7

5

2 -

4 4

2 2

FUSEF60

SYNC25

3I>>>50P/51P

3×ARC

50L/50NL

2×Master Trip

Lockout relay94/86

Io>>→67N-2

3×3U<27

2×U2>47O-

2×U1<47U+

3×3U>59

3×Uo>59G

6×f>/f<,df/dt81

Io>>51N-2

3I>→67-1

2×3I>>→67-2

2×3I>/Io>BF

51BF/51NBF3I>

51P-1

2×CBCMCBCM

MCS 3IMCS 3I

2×TCSTCM

2×OPTSOPTM

ESTARTESTART

2×3I<

37M

3I

3I

UL1

UL2

UL3

UL1UL2UL3

U12

U12

Uo

Uo

Io

IoIo

Io>51N-1

UL1

UL2

UL3

Io

Is2t n<49, 66, 48, 51LR

RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

12×MAPMAP

Io>>>50N/51N

N

2×I2>M46M

Ist>51LR

I2>>46R

3×

3Ith>M49M

3dl>M87M

3I

Io>→67N-1

12×RTD4×mA

GUID-A641F704-024A-447F-9112-E61DF258CA8C V1 EN

Figure 1. Functionality overview


4 ABB

Table 1. Supported functions

Functionality CTs & VTs

Protection

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

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

Three-phase directional overcurrent protection, low stage, instance 1

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

Three-phase directional overcurrent protection, high stage, instance 2

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

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

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

Directional earth-fault protection, low stage, instance 1

Directional earth-fault protection, high stage

Residual overvoltage protection, instance 1



Three-phase undervoltage protection, instance 1



Three-phase overvoltage protection, instance 1



Positive-sequence undervoltage protection, instance 1

Positive-sequence undervoltage protection, instance 2

Negative-sequence overvoltage protection, instance 1

Negative-sequence overvoltage protection, instance 2

Frequency protection, instance 1






Negative-sequence overcurrent protection for motors, instance 1

Negative-sequence overcurrent protection for motors, instance 2

Loss of load supervision, instance 1

Loss of load supervision, instance 2

Motor load jam protection

Motor startup supervision

Phase reversal protection


ABB 5

Table 1. Supported functions, continued


Thermal overload protection for motors

Motor differential protection

Circuit breaker failure protection, instance 1

Circuit breaker failure protection, instance 2

Master trip, instance 1

Master trip, instance 2

Arc protection, instance 1



Multipurpose analog protection, instance 1












Control

Circuit-breaker control, instance 1

Circuit-breaker control, instance 2

Disconnector control, instance 1


Earthing switch control, instance 1



Earthing switch control, instance 2

Disconnector position indication, instance 1


Earthing switch position indication, instance 1



Earthing switch position indication, instance 2

Emergency startup

Synchronism and energizing check


6 ABB



Condition monitoring

Circuit-breaker condition monitoring, instance 1

Circuit-breaker condition monitoring, instance 2

Trip circuit supervision, instance 1

Trip circuit supervision, instance 2

Current circuit supervision

Fuse failure supervision

Runtime counter for machines and devices, instance 1

Runtime counter for machines and devices, instance 2

Measurement

Three-phase current measurement, instance 1

Three-phase current measurement, instance 2

Sequence current measurement

Residual current measurement

Three-phase voltage measurement

Residual voltage measurement

Sequence voltage measurement

Three-phase power and energy measurement

Frequency measurement

Other

Minimum pulse timer (2 pcs), instance 1




Minimum pulse timer (2 pcs, second resolution), instance 1

Minimum pulse timer (2 pcs, second resolution), instance 2

Minimum pulse timer (2 pcs, minute resolution), instance 1

Minimum pulse timer (2 pcs, minute resolution), instance 2

Pulse timer (8 pcs), instance 1

Pulse timer (8 pcs), instance 2

Time delay off (8 pcs), instance 1




Time delay on (8 pcs), instance 1





ABB 7



Set reset (8 pcs), instance 1




Move (8 pcs), instance 1




Generic control points, instance 1



Remote generic control points

Local generic control points

Generic up-down counters, instance 1












Programmable buttons (16 buttons)

Logging functions

Disturbance recorder

Fault recorder

Sequence event recorder

Load profile

= Included, = Optional at the time of the order


8 ABB

3. Protection functionsThe IED offers all the functionality needed to manage motorstarts and normal operation, also including protection andfault clearance in abnormal situations. The main features ofthe IED include motor differential protection, thermal overloadprotection, motor startup time supervision, locked rotorprotection and protection against too frequent motor starts.The IED also incorporates non-directional earth-faultprotection, negative phase-sequence current unbalanceprotection and backup overcurrent protection. Furthermore,the IED offers motor running stall protection, loss-of-loadsupervision and phase-reversal protection.

The default configuration additionally offers directional earth-fault protection, three-phase undervoltage protection,negative phase-sequence overvoltage and positive-sequenceundervoltage protection. Furthermore, the configuration offersfrequency protection including overfrequency, underfrequencyand rate-of-change frequency protection modes.

The RTD/mA module offered as an option for the defaultconfiguration enabled the use of the optional multipurposeprotection function which can be used for tripping and alarmpurposes using RTD/mA measuring data or analog values viaGOOSE messages.

In certain motor drives of special importance, there must be apossibility to override the motor thermal overload protectionto perform an emergency start of a hot motor. To enable anemergency hot start, REM620 offers a forced start executionfeature.

Enhanced with optional hardware and software, the IED alsofeatures three light detection channels for arc fault protectionof the circuit breaker, busbar and cable compartment ofmetal-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. Optional high speed outputs help to minimize thearc impacts.

4. ApplicationREM620 has been designed to be the main protection in themanufacturing and process industry for medium-sized andlarge asynchronous motors that require also differentialprotection. Typically, the motor protection IED is used withcircuit breaker- or contactor-controlled MV motors and withcontactor-controlled, medium-sized and large LV motors, in avariety of drives. These include both continuously andintermittently operated asynchronous motor drives withvarying load.

REM620 can be used with either single- or double-busbarconfigurations with either one or two breakers and withnumerous switching device configurations. It supports asubstantial number of both manually and motor-operateddisconnectors and earthing switches, and it is capable ofrunning large configurations. The number of controllabledevices depends on the number of inputs and outputs leftfree from other application needs. The number of available I/Os can be increased with the RIO600 Remote I/O device.

REM620 offers extensive possibilities to tailor theconfigurations to end application requirements. The tool suitefor all Relion IEDs is Protection and control IED managerPCM600, which contains all the necessary tools forconfiguring the device, including functionality,parameterization, the HMI and communication.

REM620 is thoroughly adapted for earth-fault protection. Byusing cable current transformers, a sensitive and reliableearth-fault protection can be achieved. Also phase-currenttransformers in Holmgreen (summation) connection can beused for earth-fault protection. To further improve the arcfault protection and minimize the effects of an arc fault, the620 series IEDs ordered with the arc fault protection optioncan be equipped with an I/O card featuring high-speedoutputs operating in one millisecond.


ABB 9

Io

3U

Uo

3I

Io

3I

3I

RTD

REF620Example conf.

ANSI IEC

N

47O-/59

47U+/27

50L/50NL

59G

60

81

U2>/3U>

U1</3U<

ARC

Uo>

FUSEF

f>/f<,df/dt

3U Uo

Io

3I

3I

47O-/59

47U+/27

49,66,48,51LR

49M

50L/50NL

50P/51P

51LR

51P/51N

81

87M

ESTART

MAP

OPTM

U2>/3U>

U1</3U<

Is2t n<

3Ith>M

ARC

3I>>>

Ist>

3I/Io

f>/f<,df/dt

3dI>M

ESTART

MAP

OPTS

REM620Example conf.

ANSI IEC

N

RTD

Io

3I

47O-/59

47U+/27

49,66,48,51LR

49M

50L/50NL

50P/51P

51LR

51P/51N

81

ESTART

MAP

OPTM

U2>/3U>

U1</3U<

Is2t n<

3Ith>M

ARC

3I>>>

Ist>

3I/Io

f>/f<,df/dt

ESTART

MAP

OPTS

REM620Example conf.

ANSI IEC

N

RTD

47O-/59

47U+/27

49,66,48,51LR

49M

50L/50NL

50P/51P

51LR

51P/51N

81

87M

ESTART

MAP

OPTM

U2>/3U>

U1</3U<

Is2t n<

3Ith>M

ARC

3I>>>

Ist>

3I/Io

f>/f<,df/dt

3dI>M

ESTART

MAP

OPTS

REM620Example conf.

ANSI IEC

N

25

47O-/59

47U+/27

49F

50L/50NL

50P/51P

51BF/51NBF

67/67N

81

81LSH

SYNC

U2>/3U>

U1</3U<

3Ith>F

ARC

3I>>>

3I>/Io>BF

3I→/Io→

f>/f<,df/dt

UFLS/R

REF620Example conf.

ANSI IEC

N

GUID-6F004016-C4D6-4BBB-B046-18FDDED4346A V1 EN

Figure 2. A dedicated motor substation with the different motor starting methods combined in one switchgear


10 ABB

Io

3I

3I

3U Uo

RTD

47O-/59

47U+/27

49,66,48,51LR

49M

50L/50NL

50P/51P

51LR

51P/51N

81

87M

ESTART

MAP

OPTM

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U1</3U<

Is2t n<

3Ith>M

ARC

3I>>>

Ist>

3I/Io

f>/f<,df/dt

3dI>M

ESTART

MAP

OPTS

REM620Example conf.

ANSI IEC

N

GUID-012EABD8-57B0-496C-B5C3-B726B0DAF97D V1 EN

Figure 3. Direct-on-load starting method, with the motor directly connected to the medium-voltage switchgear

Io

3I

3I

3U Uo

RTD

47O-/59

47U+/27

49,66,48,51LR

49M

50L/50NL

50P/51P

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51P/51N

81

87M

ESTART

MAP

OPTM

U2>/3U>

U1</3U<

Is2t n<

3Ith>M

ARC

3I>>>

Ist>

3I/Io

f>/f<,df/dt

3dI>M

ESTART

MAP

OPTS

REM620Example conf.

ANSI IEC

N

GUID-96593CE9-3E6D-46F5-AE9E-619C73CFBB39 V1 EN

Figure 4. Motor started over reactor choke, which decreases motor starting current over the reactor and helps handle the load flow in themedium-voltage network


ABB 11

Io

3I

3U Uo

RTD

47O-/59

47U+/27

49,66,48,51LR

49M

50L/50NL

50P/51P

51LR

51P/51N

81

ESTART

MAP

OPTM

U2>/3U>

U1</3U<

Is2t n<

3Ith>M

ARC

3I>>>

Ist>

3I/Io

f>/f<,df/dt

ESTART

MAP

OPTS

REM620Example conf.

ANSI IEC

N

GUID-D4876FE7-FC25-4F7E-BCF2-C6C3508BBF96 V1 EN

Figure 5. Motor starting method with variable-frequency drives VFD that make the control easier and optimize energy consumption

5. Supported ABB solutionsABB’s 620 series protection and control IEDs together withthe Grid Automation controller COM600 constitute a genuineIEC 61850 solution for reliable power distribution in utility andindustrial power systems. To facilitate and streamline thesystem engineering ABB’s IEDs are supplied withConnectivity Packages containing a compilation of softwareand IED-specific information including single-line diagramtemplates, a full IED data model including event andparameter lists. By utilizing the Connectivity Packages theIEDs can be readily configured via the PCM600 Protectionand Control IED Manager and integrated with the GridAutomation controller COM600 or the MicroSCADA Pronetwork control and management system.

The 620 series IEDs offer native support for the IEC 61850standard also including binary and analog horizontal GOOSEmessaging. Compared to traditional hard-wired inter-devicesignaling, peer-to-peer communication over a switchedEthernet LAN offers an advanced and versatile platform forpower system protection. Fast software-basedcommunication, continuous supervision of the integrity of theprotection and communication system, and inherent flexibilityfor reconfiguration and upgrades are among the distinctivefeatures of the protection system approach enabled by thefull implementation of the IEC 61850 substation automationstandard.

At the substation level COM600 uses the data content of thebay level IEDs to offer enhanced substation level functionality.COM600 features a Web browser-based HMI providing acustomizable graphical display for visualizing single line mimicdiagrams for switchgear bay solutions. Furthermore, the WebHMI of COM600 offers an overview of the whole substation,including IED-specific single-line diagrams, thus enablingconvenient information accessibility. To enhance personnelsafety, the Web HMI also enables remote access tosubstation devices and processes. Furthermore, COM600can be used as a local data warehouse for technicaldocumentation of the substation and for network datacollected by the IEDs. The collected network data facilitatesextensive reporting and analyzing of network fault situationsusing the data historian and event handling features ofCOM600. The data historian can be used for accurateprocess performance monitoring by following process andequipment performance calculations with real-time andhistory values. Better understanding of the process behaviourby joining time-based process measurements with productionand maintenance events helps the user in understanding theprocess dynamics.

COM600 also features gateway functionality providingseamless connectivity between the substation IEDs andnetwork-level control and management systems such asMicroSCADA Pro and System 800xA

Table 2. Supported ABB solutions

Product Version

Grid Automation controller COM600 4.0 or later

MicroSCADA Pro SYS 600 9.3 FP2 or later

System 800xA 5.1 or later


12 ABB

GUID-8E5ABC5B-5A9B-4248-B2B1-DB5AFA42D801 V1 EN

Figure 6. Industrial power system example using 620 series IEDs, Grid Automation controller COM600 and System 800xA

6. ControlREM620 integrates functionality for the control of circuitbreakers, disconnectors and earth switches via the frontpanel HMI or by means of remote controls. The IED includestwo circuit breaker control blocks. In addition to the circuitbreaker control, the IED features four disconnector controlblocks intended for the motor-operated control ofdisconnectors or circuit breaker truck. Furthermore, the IEDoffers two control blocks intended for the motor-operatedcontrol of earthing switch. On top of that, the IED includesadditional four disconnector position indication blocks andtwo earth switch position indication blocks usable withmanually-only controlled disconnectors and earth switches.

Two physical binary inputs and two physical binary outputsare needed in the IED for each controllable primary devicetaken into use. Depending on the chosen hardwareconfiguration of the IED, the number of binary inputs andbinary outputs varies. In case the amount of available binaryinputs or outputs of the chosen hardware configuration is notsufficient, connecting an external input or output module, forexample RIO600, to the IED can extend binary inputs andoutputs utilizable in the IED configuration. The binary inputsand outputs of the external I/O module can be used for theless time-critical binary signals of the application. Theintegration enables releasing of some initially reserved binaryinputs and outputs of the IED.

The suitability of the binary outputs of the IED which havebeen selected for the controlling of primary devices should becarefully verified, for example, the make and carry as well asthe breaking capacity. In case the requirements for thecontrol circuit of the primary device are not met, the use ofexternal auxiliary relays should be considered.

The graphical LCD of the IED's HMI includes a single-linediagram (SLD) with position indication for the relevant primarydevices. Interlocking schemes required by the application areconfigured using the Signal Matrix or the ApplicationConfiguration tools in PCM600.

A synchrocheck function is incorporated to ensure that thevoltage, phase angle and frequency on either side of an opencircuit breaker satisfy the conditions for a safeinterconnection of two networks.

7. MeasurementThe IED continuously measures the phase currents and theneutral current. Furthermore, the IED measures the phasevoltages and the residual voltage. In addition, the IEDcalculates the symmetrical components of the currents andvoltages, the system frequency, the active and reactivepower, the power factor, the active and reactive energyvalues as well as the demand value of current and power overa user-selectable preset time frame. Calculated values are


ABB 13

also obtained from the protections and condition monitoringfunctions of the IED.

The IED is also offered with RTD/mA inputs and can measureup to 16 analog signals such as stator winding and bearingtemperatures via the 12 RTD inputs or the four mA inputsusing transducers.

The values measured can be accessed locally via the userinterface on the IED front panel or remotely via thecommunication interface of the IED. The values can also beaccessed locally or remotely using the web-browser baseduser interface.

8. Disturbance recorderThe IED is provided with a disturbance recorder featuring upto 12 analog and 64 binary signal channels. The analogchannels can be set to record either the waveform or thetrend of the currents and voltages measured.

The analog channels can be set to trigger the recordingfunction when the measured value falls below or exceeds theset values. The binary signal channels can be set to start arecording on the rising or the falling edge of the binary signalor both.

By default, the binary channels are set to record external orinternal IED signals, for example the start or trip signals of theIED stages, or external blocking or control signals. Binary IEDsignals, such as a protection start or trip signal, or an externalIED control signal over a binary input can be set to trigger therecording. The recorded information is stored in a nonvolatilememory and can be uploaded for subsequent fault analysis.

9. Event logTo collect sequence-of-events (SoE) information, the IEDincorporates a non-volatile memory with a capacity of storing1024 events with associated time stamps. The non-volatilememory retains its data also in case the IED temporarily losesits auxiliary supply. The event log facilitates detailed pre- andpost-fault analyses of feeder faults and disturbances. Theincreased capacity to process and store data and events inthe IED offers prerequisites to support the growinginformation demand of future network configurations.

The SoE information can be accessed locally via the userinterface on the IED front panel or remotely via thecommunication interface of the IED. The information canfurther be accessed, either locally or remotely, using the web-browser based user interface.

10. Recorded dataThe IED has the capacity to store the records of 128 latestfault events. The records enable the user to analyze thepower system events. The available measurement modesinclude DFT, RMS and peak-to-peak. Fault records store IED

measurement values at the moment when any protectionfunction starts. Both Min. and Max. current demand valuesare recorded with time stamp. Also both Min. and Max.power demand values (P, Q, S) are recorded with time stamp.By default, the records are stored in a nonvolatile memory.

Furthermore, the IED includes a load profile recorder capableof storing measurement values into the IED's memory. Theselected measurement values averaged over the selectedperiod, ranging from one minute to three hours, are stored ina nonvolatile memory. Depending on the selectedmeasurements and averaging period, the overall length of theload profile recording ranges from some days to severalmonths, even a year, making this feature suitable formonitoring long-time load behavior for the interested loads.

11. 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 itsclosed and in its open position. It also detects loss of circuit-breaker control voltage.

12. Self-supervisionThe IED’s built-in self-supervision system continuouslymonitors the state of the IED hardware and the operation ofthe IED software. Any fault or malfunction detected is usedfor alerting the operator.

13. Fuse failure supervisionThe fuse failure supervision detects failures between thevoltage measurement circuit and the IED. The failures aredetected by the negative-sequence based algorithm or by thedelta voltage and delta current algorithm. Upon the detectionof a failure the fuse failure supervision function activates analarm and blocks voltage-dependent protection functionsfrom unintended operation.

14. Current circuit supervisionCurrent circuit supervision is used for detecting faults in thecurrent transformer secondary circuits. On detecting of a faultthe current circuit supervision function activates an alarm LEDand blocks 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 separatecores in the phase current transformers.

15. Access controlTo protect the IED from unauthorized access and to maintaininformation integrity, the IED is provided with a four-level, role-based authentication system with administrator-programmable individual passwords for the viewer, operator,


14 ABB

engineer and administrator level. The access control appliesto the front-panel user interface, the web-browser based userinterface and the PCM600 tool.

16. Inputs and outputsThe IED is equipped with six phase current inputs, oneresidual-current input, three phase voltage inputs, oneresidual-voltage input and one phase-to-phase voltage forsyncrocheck input. In addition to current and voltagemeasurements, the IED's basic configuration includes 12binary inputs and 10 binary outputs. Additionally, basicconfiguration offers six RTD inputs and two mA inputs. Thephase current inputs and the residual-current inputs are rated1/5 A, that is, the inputs allow the connection of either 1 A or5 A secondary current transformers. The optional sensitiveresidual-current input 0.2/1 A is normally used in applicationsrequiring sensitive earth-fault protection and featuring corebalance current transformers. The three phase voltage inputsand the residual-voltage input covers the rated voltages 60...210 V. Both phase-to-phase voltages and phase-to-earthvoltages can be connected.

As an optional addition, the IED basic configuration includesone empty slot which can be equipped with one of thefollowing optional modules. The first option, additional binaryinputs and outputs module, adds eight binary inputs and fourbinary outputs to the IED. This option is especially neededwhen connecting the IED to several controllable objects. Thesecond option, an additional RTD/mA input module,increases the IED with six RTD inputs and two mA inputswhen additional sensor measurements e.g. for temperatures,pressures, levels and so on are of interest with the protected

motor. The third option is a high-speed output boardincluding eight binary inputs and three high-speed outputs.The high-speed outputs have a shorter activation timecompared to the conventional mechanical output relays,shortening the overall IED operation time with very time-critical applications like arc protection. The high-speedoutputs are freely configurable in the IED application and notlimited to arc protection only.

The rated values of the current and voltage inputs aresettable parameters of the IED. In addition, the binary inputthresholds are selectable within the range of 18…176 V DCby adjusting the IED’s parameter settings.

All binary input and output contacts are freely configurablewith the Signal Matrix or Application Configuration tool ofPCM600.

See the Input/output overview table and the terminaldiagrams for detailed information about the inputs andoutputs.

If the number of the IED’s own inputs and outputs does notcover all the intended purposes, connecting to an externalinput or output module, for example RIO600, increases thenumber of binary inputs and outputs utilizable in the IEDconfiguration. In this case, the external inputs and outputs areconnected to the IED via IEC 61850 GOOSE to reach fastreaction times between the IED and RIO600 information. Theneeded binary input and output connections between the IEDand RIO600 units can be configured in a PCM600 tool andthen utilized in the IED configuration.

Table 3. Input/output overview table

Conf. Analog channels Binary channels

CT VT RTD/mA BI BO

A 7 5 6/2 12(20)1) 10(14)1)

6/2 12(20)2) 10(13)2)

6/2(12/4)3) 12 10

1) With optional BIO0005 module2) With optional BIO0007 module3) With optional RTD0003 module


ABB 15

17. Station communicationThe IED supports a range of communication protocols

including IEC 61850, IEC 60870-5-103, Modbus® and DNP3.Operational information and controls are available throughthese protocols. However, some communication functionality,for example, horizontal communication between the IEDs, isonly enabled by the IEC 61850 communication protocol.

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 inthe standard COMTRADE file format. The IED supportssimultaneous event reporting to five different clients on thestation bus. The IED can exchange signals with other IEDsusing the IEC 61860 protocol.

The IED can send binary signals to other IEDs (so calledhorizontal communication) using the IEC 61850-8-1 GOOSE(Generic Object Oriented Substation Event) profile. BinaryGOOSE messaging can, for example, be employed forprotection and interlocking-based protection schemes. TheIED meets the GOOSE performance requirements for trippingapplications in distribution substations, as defined by the IEC61850 standard. The IED also supports the sending andreceiving of analog values using GOOSE messaging. AnalogGOOSE messaging enables fast transfer of analogmeasurement values over the station bus, thus facilitating forexample sharing of RTD input values, such as surroundingtemperature values, to other IED applications.

For redundant Ethernet solution, the IED offers a fibre-opticcommunication module providing two optical and onegalvanic Ethernet network interfaces. Alternatively, the IED

features a galvanic communication module with two galvanicand one optical Ethernet network interfaces or three galvanicinterfaces. The third Ethernet interface provides connectivityfor any other Ethernet devices to an IEC 61850 station businside in a switchgear bay. The redundant solution can beapplied to the Ethernet-based IEC 61850, Modbus and DNP3protocols.

Ethernet network redundancy can be achieved using the high-availability seamless redundancy (HSR) protocol or theparallel redundancy protocol (PRP) or a with self-healing ringusing RSTP in managed switches. Ethernet redundancy canbe applied to all Ethernet-based IEC 61850, Modbus andDNP3 protocols.

The IEC 61850 standard specifies network redundancy whichimproves the system availability for the substationcommunication. The network redundancy is based on twocomplementary protocols defined in the IEC 62439-3standard: PRP and HSR protocols. Both the protocols areable to overcome a failure of a link or switch with a zeroswitch-over time. In both the protocols, each network nodehas two identical Ethernet ports dedicated for one networkconnection. The protocols rely on the duplication of alltransmitted information and provide a zero switch-over time ifthe links or switches fail, thus fulfilling all the stringent real-time requirements 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.


16 ABB

Ethernet switchIEC 61850 PRPEthernet switch

REF615 REF620 RET620 REM620 REF615

SCADACOM600

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

Figure 7. 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,one through 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.When the originating sender node receives the frame it sent,

the sender node discards the frame to avoid loops. The HSRring with 620 series IEDs supports the connection of up tothirty IEDs. If more than 30 IEDs are to be connected, it isrecommended to split the network into several rings toguarantee the performance for real-time applications.

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 8. 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 with

standard Rapid Spanning Tree l Protocol (RSTP) support. Themanaged switch controls the consistency of the loop, routesthe data and corrects the data flow in case of acommunication switch-over. The IEDs in the ring topology actas unmanaged switches forwarding unrelated data traffic. The


ABB 17

Ethernet ring solution supports the connection of up to thirty620 series IEDs. If more than 30 IEDs are to be connected, itis recommended to split the network into several rings. The

self-healing Ethernet ring solution avoids single point of failureconcerns and improves the reliability of the communication.

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 9. Self-healing Ethernet ring solution

All communication connectors, except for the front portconnector, are placed on integrated optional communicationmodules. The IED can be connected to Ethernet-basedcommunication systems via the RJ-45 connector (100Base-TX) or the fibre-optic LC connector (100Base-FX). Ifconnection to a serial bus is required, the 10-pin RS-485screw-terminal or the fibre-optic ST connector can be used.

Modbus implementation supports RTU, ASCII and TCPmodes. Besides standard Modbus functionality, the IEDsupports retrieval of time-stamped events, changing theactive setting group and uploading of the latest fault records.If a Modbus TCP connection is used, five clients can beconnected to the IED simultaneously. Further, Modbus serialand Modbus TCP can be used in parallel, and if required bothIEC 61850 and Modbus protocols can be run simultaneously.

The IEC 60870-5-103 implementation supports two parallelserial bus connections to two different masters. Besidesbasic standard functionality, the IED supports changing of theactive setting group and uploading of disturbance recordingsin IEC 60870-5-103 format. Further, IEC 60870-5-103 can beused at the same time with the IEC 61850 protocol.

DNP3 supports both serial and TCP modes for connection toone master. Further, changing of the active setting group is

supported. DNP3 can also be used at the same time with theIEC 61850 protocol.

When the IED 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 soexternal resistors are not needed.

The IED 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)

In addition, the IED supports time synchronization via thefollowing serial communication protocols:• Modbus• DNP3• IEC 60870-5-103


18 ABB

Table 4. Supported station communication interfaces and protocols

Interfaces/Protocols Ethernet Serial

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

IEC 61850 - -

MODBUS RTU/ASCII - -

MODBUS TCP/IP - -

DNP3 (serial) - -

DNP3 TCP/IP - -

IEC 60870-5-103 - - = Supported


ABB 19

18. Technical data

Table 5. Dimensions

Description Value

Width Frame 262.2 mm

Case 246 mm

Height Frame 177 mm, 4U

Case 160 mm

Depth 201 mm

Weight Complete IED max. 5.1 kg

Plug-in unit only max. 3.0 kg

Table 6. Power supply

Description Type 1 Type 2

Uaux nominal 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 IED

50 ms at Un rated

Uaux 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 <12.0 W (nominal)/<19.0 W (max)AC <13.0 W (nominal)/<21.0 W (max)

DC <12.0 W (nominal)/<19.0 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 7. 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 8. 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 18...176 V DC

Reaction time 3 ms

Table 9. RTD/mA measurement

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 10. Signal output with high make and carry

Description Value 1)

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

1) X100: SO1X105: SO1, SO2, when any of the IEDs is equipped with BIO0005.X115: SO1, SO2 when REF620 or REM620 is equipped with BIO0005


ABB 21

Table 11. Signal outputs and IRF output





Make and carry 0.5 s 15 A

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

1 A / 0.25 A / 0.15 A


1) X100: IRF,SO2X105: SO3, SO4, when any of the IEDs is equipped with BIO0005X115:SO3, SO4, when REF620 or REM620 is equipped with BIO0005

Table 12. Double-pole power outputs with TCS function X100: PO3 and PO4






Breaking capacity when the control-circuit time constant L/R < 40 ms,at 48/110/220 V DC (two contacts connected in series)

5 A/3 A/1 A


Trip-circuit monitoring (TCS):

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

• Current drain through the monitoring circuit ~1.5 mA

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

1) PSM0003: PO3, PSM0004: PO3, PSM0003: PO4 and PSM0004: PO4.

Table 13. Signal/trip output with high make and carry and with TCS function

Description Value





Breaking capacity when the control-circuit time constant L/R < 40 ms,at 48/110/220 V DC (two contacts connected in series)

1A/0.25A/0.15A



22 ABB

Table 14. Single-pole power output relays X100: PO1 and PO2

Description Value






5 A/3 A/1 A


Table 15. High-speed output HSO







5 A/3 A/1 A

Start 1 ms

Reset 20 ms, resistive load

1) X105: HSO1, HSO2 HSO3, when any of the IEDs is equipped with BIO0007

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. Station communication link, fibre-optic

Connector Fibre type1) Wave length Max. distance Permitted path attenuation2)

LC MM 62.5/125 or 50/125 μmglass fibre core

1300 nm 2 km <8 dB

ST MM 62.5/125 or 50/125 μmglass fibre core

820-900 nm 1 km <11 dB

1) (MM) multi-mode fibre, (SM) single-mode fibre2) Maximum allowed attenuation caused by connectors and cable together


ABB 23

Table 18. IRIG-B

Description Value

IRIG time code format B004, B0051)

Isolation 500V 1 min.

Modulation Unmodulated

Logic level TTL Level

Current consumption 2...4 mA

Power consumption 10...20 mW

1) According to 200-04 IRIG -standard

Table 19. Lens sensor and optical fibre for arc protection

Description Value

Fibre-optic cable including lens 1.5 m, 3.0 m or 5.0 m

Normal service temperature range of the lens -40...+100°C

Maximum service temperature range of the lens, max 1 h +140°C

Minimum permissible bending radius of the connection fibre 100 mm

Table 20. Degree of protection of flush-mounted IED

Description Value

Front side IP 54

Table 21. 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 IEDs with an LC communication interface the maximum operating temperature is +70 ºC


24 ABB

Table 22. Electromagnetic compatibility tests

Description Type test value Reference

1 MHz/100 kHz burst disturbance test: IEC 61000-4-18IEC 60255-22-1, 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 60255-22-1, class III

• Common mode 2.5 kV

Electrostatic discharge test: IEC 61000-4-2IEC 60255-22-2IEEE C37.90.3-2001

• Contact discharge 8 kV

• Air discharge 15 kV

Radio frequency interference test:

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

IEC 61000-4-6IEC 60255-22-6, class III

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

IEC 61000-4-3IEC 60255-22-3, class III

10 V/mf=900 MHz

ENV 50204IEC 60255-22-3, class III

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

IEEE C37.90.2-2004

Fast transient disturbance test: IEC 61000-4-4IEC 60255-22-4IEEE C37.90.1-2002

• All ports 4 kV

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

• 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 immunitytest:

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


ABB 25

Table 22. Electromagnetic compatibility tests, continued


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 60255-25

• 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

Table 23. Insulation tests


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

IEC 60255-5 andIEC 60255-27

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

IEC 60255-5 andIEC 60255-27

Insulation resistance measurements >100 MΏ, 500 V DC IEC 60255-5 andIEC 60255-27

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

Table 24. 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


26 ABB

Table 25. Environmental tests


Dry heat test • 96 h at +55ºC• 16 h at +85ºC1)

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

1) For IEDs with an LC communication interface the maximum operating temperature is +70oC

Table 26. Product safety

Description Reference

LV directive 2006/95/EC

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

Table 27. EMC compliance

Description Reference

EMC directive 2004/108/EC

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

Table 28. RoHS compliance

Description

Complies with RoHS directive 2002/95/EC


ABB 27

Protection functions

Table 29. Three-phase non-directional overcurrent protection (PHxPTOC)

Characteristic Value

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

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

PHHPTOC1)

andPHIPTOC

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

Start time 2)3) Minimum Typical Maximum

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

16 ms 11 ms

19 ms 12 ms

23 ms 14 ms

PHHPTOC1) and PHLPTOC:IFault = 2 x set Start value

22 ms

24 ms

25 ms

Reset time < 40 ms

Reset ratio Typical 0.96

Retardation time < 30 ms

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

Operate time accuracy in inverse time mode ±5.0% of the theoretical value or ±20 ms 4)

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

1) Not included in REM6202) Set Operate delay time = 0,02 s, Operate curve type = IEC definite time, Measurement mode = default (depends on stage), current before fault = 0.0 x In, fn = 50 Hz, fault current in one

phase with nominal frequency injected from random phase angle, results based on statistical distribution of 1000 measurements3) Includes the delay of the signal output contact4) Includes the delay of the heavy-duty output contact


28 ABB

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

Parameter Function Value (Range) Step

Start Value PHLPTOC 0.05...5.00 x In 0.01

PHHPTOC 0.10...40.00 x In 0.01

PHIPTOC 1.00...40.00 x In 0.01

Time multiplier PHLPTOC 0.05...15.00 0.01

PHHPTOC 0.05...15.00 0.01

Operate delay time PHLPTOC 40...200000 ms 10

PHHPTOC 40...200000 ms 10

PHIPTOC 20...200000 ms 10

Operating curve type1) PHLPTOC Definite or inverse 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 Operation characteristics table

Table 31. Three-phase directional overcurrent protection (DPHxPDOC)


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

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

Phase angle: ±2°

DPHHPDOC Current:±1.5% of the set value or ±0.002 x In(at currents in the range of 0.1…10 x In)±5.0% of the set value(at currents in the range of 10…40 x In)Voltage:±1.5% of the set value or ±0.002 x Un

Phase angle: ±2°

Start time1)2) Minimum Typical Maximum

IFault = 2.0 x set Start value 38 ms 43 ms 46 ms

Reset time < 40 ms




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

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

1) Measurement mode and Pol quantity = default, current before fault = 0.0 x In, voltage before fault = 1.0 x Un, fn = 50 Hz, fault current in one phase with nominal frequency injected from

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


ABB 29

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


Start value DPHLPDOC 0.05...5.00 x In 0.01

DPHHPDOC 0.10...40.00 x In 0.01

Time multiplier DPHxPDOC 0.05...15.00 0.01

Operate delay time DPHxPDOC 40...200000 ms 10

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

Characteristic angle DPHxPDOC -179...180 deg 1

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

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

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

Table 33. Non-directional earth-fault protection (EFxPTOC)



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

EFHPTOCandEFIPTOC

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


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

16 ms11 ms

19 ms12 ms

23 ms14 ms

EFHPTOC and EFLPTOC:IFault = 2 x set Start value

22 ms

24 ms

25 ms

Reset time < 40 ms





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

1) Measurement mode = default (depends on stage), current before fault = 0.0 x In, fn = 50 Hz, earth-fault current with nominal frequency injected from random phase angle, results based

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


30 ABB

Table 34. Non-directional earth-fault protection (EFxPTOC) main settings


Start value EFLPTOC 0.010...5.000 x In 0.005

EFHPTOC 0.10...40.00 x In 0.01

EFIPTOC 1.00...40.00 x In 0.01

Time multiplier EFLPTOC 0.05...15.00 0.01

EFHPTOC 0.05...15.00 0.01

Operate delay time EFLPTOC 40...200000 ms 10

EFHPTOC 40...200000 ms 10

EFIPTOC 20...200000 ms 10

Operating curve type1) EFLPTOC Definite or inverse 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



ABB 31

Table 35. Directional earth-fault protection (DEFxPDEF)



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

Phase angle:±2°

DEFHPDEF Current:±1.5% of the set value or ±0.002 x In(at currents in the range of 0.1…10 x In)±5.0% of the set value(at currents in the range of 10…40 x In)Voltage:±1.5% of the set value or ±0.002 x Un

Phase angle:±2°


DEFHPDEFIFault = 2 x set Start value

42 ms

44 ms

46 ms

DEFLPDEFIFault = 2 x set Start value

61 ms 64 ms 66 ms

Reset time < 40 ms





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

1) Set Operate delay time = 0.06 s,Operate curve type = IEC definite time, Measurement mode = default (depends on stage), current before fault = 0.0 x In, fn = 50 Hz, earth-fault current

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


32 ABB

Table 36. Directional earth-fault protection (DEFxPDEF) main settings


Start Value DEFLPDEF 0.010...5.000 x In 0.005

DEFHPDEF 0.10...40.00 x In 0.01

Directional mode DEFLPDEF 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 60...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 DEFLPDEF and DEFHPDEF 1=Phase angle2=IoSin3=IoCos4=Phase angle 805=Phase angle 88

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

Table 37. Residual overvoltage protection (ROVPTOV)


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

±1.5% of the set value or ±0.002 x Un


UFault = 1.1 x set Start value 55 ms 56 ms 58 ms

Reset time < 40 ms





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

measurements2) Includes the delay of the signal output contact

Table 38. Residual overvoltage protection (ROVPTOV) main settings


Start value ROVPTOV 0.010...1.000 x Un 0.001

Operate delay time ROVPTOV 40...300000 ms 1


ABB 33

Table 39. Three phase undervoltage protection (PHPTUV)





UFault = 0.9 x set Start value 62 ms 64 ms 66 ms

Reset time < 40 ms

Reset ratio Depends on the set Relative hysteresis





1) Start value = 1.0 x Un, Voltage before fault = 1.1 x Un, fn = 50 Hz, undervoltage in one phase-to-phase with nominal frequency injected from random phase angle, results based on

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

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


Start value PHPTUV 0.05...1.20 x Un 0.01

Time multiplier PHPTUV 0.05...15.00 0.01

Operate delay time PHPTUV 60...300000 ms 10

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


Table 41. Positive-sequence undervoltage protection (PSPTUV)





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

51 ms43 ms

53 ms45 ms

54 ms46 ms

Reset time < 40 ms

Reset ratio Depends of the set Relative hysteresis




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

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


34 ABB

Table 42. Positive-sequence undervoltage protection (PSPTUV) main settings


Start value PSPTUV 0.010...1.200 x Un 0.001

Operate delay time PSPTUV 40...120000 ms 10

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

Table 43. Negative-sequence overvoltage protection (NSPTOV)



±1.5% of the set value or ±0.002 × Un


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

33 ms24 ms

35 ms26 ms

37 ms28 ms

Reset time < 40 ms




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

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

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

Table 44. Negative-sequence overvoltage protection (NSPTOV) main settings


Start value NSPTOV 0.010...1.000 x Un 0.001

Operate delay time NSPTOV 40...120000 ms 1

Table 45. Frequency protection (FRPFRQ)


Operation accuracy f>/f< ±10 mHz

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

Start time f>/f< < 80 ms

df/dt < 120 ms

Reset time < 150 ms

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


ABB 35

Table 46. Frequency protection (FRPFRQ) main settings


Operation mode FRPFRQ 1=Freq<2=Freq>3=df/dt4=Freq< + df/dt5=Freq> + df/dt6=Freq< OR df/dt7=Freq> OR df/dt

Start value Freq> FRPFRQ 0.9000...1.2000 xFn 0.0001

Start value Freq< FRPFRQ 0.8000...1.1000 xFn 0.0001

Start value df/dt FRPFRQ -0.200...0.200 xFn /s 0.005

Operate Tm Freq FRPFRQ 80...200000 ms 10

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

Table 47. Negative phase-sequence overcurrent protection for motors (MNSPTOC)



±1.5% of the set value or ±0.002 x In



Reset time < 40 ms






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

2) Includes the delay of the signal output contact3) Start value multiples in range of 1.10 to 5.00

Table 48. Negative phase-sequence overcurrent protection for motors (MNSPTOC) main settings


Start value MNSPTOC 0.01...0.50 x In 0.01

Operating curve type MNSPTOC ANSI Def. TimeIEC Def. TimeInv. Curve AInv. Curve B

-

Operate delay time MNSPTOC 100...120000 ms 10

Cooling time MNSPTOC 5...7200 s 1

Operation MNSPTOC OffOn

-


36 ABB

Table 49. Loss of load supervision (LOFLPTUC)




Start time Typical 300 ms

Reset time < 40 ms




Table 50. Loss of load supervision (LOFLPTUC) main settings


Start value high LOFLPTUC 0.01...1.00 x In 0.01

Start value low LOFLPTUC 0.01...0.50 x In 0.01

Operate delay time LOFLPTUC 400...600000 ms 10

Operation LOFLPTUC OffOn

-

Table 51. Motor load jam protection (JAMPTOC)




Reset time < 40 ms




Table 52. Motor load jam protection (JAMPTOC) main settings


Operation JAMPTOC OffOn

-

Start value JAMPTOC 0.10...10.00 x In 0.01

Operate delay time JAMPTOC 100...120000 ms 10


ABB 37

Table 53. Motor startup supervision (STTPMSU)





IFault = 1.1 x set Start detection A 27 ms 30 ms 34 ms



1) Current before = 0.0 x In, fn = 50 Hz, overcurrent in one phase, results based on statistical distribution of 1000 measurements

2) Includes the delay of the signal output contact

Table 54. Motor start-up supervision (STTPMSU) main settings


Motor start-up A STTPMSU 1.0...10.0 x In 0.1

Motor start-up time STTPMSU 1...80.0 s 1

Lock rotor time STTPMSU 2...120 s 1

Operation STTPMSU OffOn

-

Operation mode STTPMSU IItIIt, CBIIt & stallIIt & stall, CB

-

Restart inhibit time STTPMSU 0...250 min 1

Table 55. Phase reversal protection (PREVPTOC)






Reset time < 40 ms





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

2) Includes the delay of the signal output contact


38 ABB

Table 56. Phase reversal protection (PREVPTOC) main settings


Start value PREVPTOC 0.05...1.00 x In 0.01

Operate delay time PREVPTOC 100...60000 ms 10

Operation PREVPTOC OffOn

-

Table 57. Three-phase thermal overload protection for motors (MPTTR)



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

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

1) Overload current > 1.2 x Operate level temperature

Table 58. Thermal overload protection for motors (MPTTR) main settings


Env temperature mode MPTTR FLC OnlyUse RTDSet Amb Temp

-

Env temperature set MPTTR -20.0...70.0 °C 0.1

Alarm thermal value MPTTR 50.0...100.0 % 0.1

Restart thermal value MPTTR 20.0...80.0 % 0.1

Overload factor MPTTR 1.00...1.20 0.01

Weighting factor p MPTTR 20.0...100.0 0.1

Time constant normal MPTTR 80...4000 s 1

Time constant start MPTTR 80...4000 s 1

Operation MPTTR OffOn

-

Table 59. Stabilized differential protection for motors (MPDIF)


Operation accuracy At the frequency f = fn

±3% of the set value or ±0.002 x In

Operate time 1)2) Biased low stage Instantaneoushigh stage3)

Typical 40 ms (±10 ms)Typical 15 ms (±10 ms)

Reset time < 40 ms



1) Fn = 50 Hz, results based on statistical distribution of 1000 measurements2) Includes the delay of the high speed power output contact3) Ifault = 2 x High operate value


ABB 39

Table 60. Stabilized differential protection for motors (MPDIF) main settings


High operate value MPDIF 100...1000 %Ir 10

Low operate value MPDIF 5...30 %Ir 1

Slope section 2 MPDIF 10...50 % 1

End section 1 MPDIF 0...100 %Ir 1

End section 2 MPDIF 100...300 %Ir 1

DC restrain enable MPDIF 0=False1=True

CT connection type MPDIF 1=Type 12=Type 2

CT ratio Cor Line MPDIF 0.40...4.00 0.01

CT ratio Cor Neut MPDIF 0.40...4.00 0.01

Table 61. Circuit breaker failure protection (CCBRBRF)






Table 62. Circuit breaker failure protection (CCBRBRF) main settings


Current value (Operating phasecurrent)

CCBRBRF 0.05...1.00 x In 0.05

Current value Res (Operatingresidual current)

CCBRBRF 0.05...1.00 x In 0.05

CB failure mode (Operating modeof function)

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


40 ABB

Table 63. Arc protection (ARCSARC)


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

Operate time Minimum Typical Maximum

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

12 ms3)

7 ms4)14 ms3)

8 ms4)16 ms3)

11 ms4)

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

4 ms4)10 ms3)

6 ms4)12 ms3)

6 ms4)

Reset time < 40 ms3)

< 55 ms4)


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

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

Table 64. Arc protection (ARCSARC) main settings


Phase start value (Operatingphase current)

ARCSARC 0.50...40.00 x In 0.01

Ground start value (Operatingresidual current)

ARCSARC 0.05...8.00 x In 0.01

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

Table 65. Multipurpose protection (MAPGAPC)


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

Table 66. Multipurpose analog protection (MAPGAPC) main settings


Start value MAPGAPC -10000.0...10000.0 0.1

Operate delay time MAPGAPC 0...200000 ms 100

Operation mode MAPGAPC OverUnder

-


ABB 41

Control functions

Table 67. Emergency start function (ESMGAPC) main settings


Operation ESMGAPC OffOn

-

Motor stand still A ESMGAPC 0.05...0.20 x In 0.01

Table 68. Synchrocheck (SECRSYN)



Voltage: ±3.0% of the set value or ±0.01 x Un

Frequency: ±10 mHzPhase angle: ±3°

Reset time < 50 ms



Table 69. Synchronism and energizing check (SECRSYN) main settings


Live dead mode SECRSYN -1=Off1=Both Dead2=Live L, Dead B3=Dead L, Live B4=Dead Bus, L Any5=Dead L, Bus Any6=One Live, Dead7=Not Both Live

Difference voltage SECRSYN 0.01...0.50 xUn 0.01

Difference frequency SECRSYN 0.001...0.100 xFn 0.001

Difference angle SECRSYN 5...90 deg 1

Synchrocheck mode SECRSYN 1=Off2=Synchronous3=Asynchronous

Control mode SECRSYN 1=Continuous2=Command

Dead line value SECRSYN 0.1...0.8 xUn 0.1

Live line value SECRSYN 0.2...1.0 xUn 0.1

Close pulse SECRSYN 200...60000 ms 10

Max energizing V SECRSYN 0.50...1.15 xUn 0.01

Phase shift SECRSYN -180...180 deg 1

Minimum Syn time SECRSYN 0...60000 ms 10

Maximum Syn time SECRSYN 100...6000000 ms 10

Energizing time SECRSYN 100...60000 ms 10

Closing time of CB SECRSYN 40...250 ms 10


42 ABB

Measurement functions

Table 70. Three-phase current measurement (CMMXU)



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

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

Table 71. Current sequence components (CSMSQI)


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

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


Table 72. Residual current measurement (RESCMMXU)



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


Table 73. 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 x Un

±0.5% or ±0.002 x Un


Table 74. Voltage sequence components (VSMSQI)


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

±1.0% or ±0.002 x Un



ABB 43

Table 75. Residual voltage measurement (RESVMMXU)



±0.5% or ±0.002 x Un


Table 76. Three-phase power and energy (PEMMXU)


Operation accuracy At all three currents in range 0.10…1.20 x InAt all three voltages in range 0.50…1.15 x Un

At the frequency fn ±1 HzActive power and energy in range |PF| > 0.71Reactive power and energy in range |PF| < 0.71

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


Table 77. Frequency measurement (FMMXU)


Operation accuracy ±10 mHz(in measurement range 35 - 75 Hz)


44 ABB

Supervision functions

Table 78. Current circuit supervision (CCRDIF)


Operate time1) < 30 ms

1) Including the delay of the output contact

Table 79. Current circuit supervision (CCRDIF) main settings


Start value CCRDIF 0.05...0.20 x In 0.01

Maximum operate current CCRDIF 1.00...5.00 x In 0.01

Table 80. Fuse failure supervision (SEQRFUF)


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

< 33 ms

UFault = 5.0 x set Neg Seq voltageLev

< 18 ms

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

ΔU = 2.0 x 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 81. Motor run time counter (MDSOPT)

Description Value

Motor run-time measurement accuracy1) ±0.5%

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


ABB 45

19. Local HMIThe IED supports process information and status monitoringfrom the IED's local HMI via its display and indication/alarmLEDs. The local LHMI also enables control operations for theequipment connected and controlled by the IED, either viadisplay or via manual push buttons available on the local HMI.

LCD display offers front-panel user interface functionality withmenu navigation and menu views. In addition, the displayincludes a user-configurable two-page single-line diagram(SLD) with a position indication for the associated primaryequipment and primary measurements from the process. TheSLD can be modified according to user requirements by usingGraphical Display Editor in PCM600.

The local HMI also includes 11 programmable LEDs. TheseLEDs can be configured to show alarms and indications asneeded by PCM600 graphical configuration tool. The LEDsinclude two separately controllable colors, red and green,making one LED able to indicate better the different states ofthe monitored object.

The IED also includes 16 configurable manual push buttons,which can freely be configured by the PCM600 graphicalconfiguration tool. These buttons can be configured to controlthe IED's internal features e.g. changing setting group,triggering disturbance recordings and changing operationmodes for functions or to control IED external equipment, e.g.starting or stopping the equipment, via IED binary outputs.These buttons also include a small indication LED for eachbutton. This LED is freely configurable, making it possible touse push button LEDs to indicate button activities or asadditional indication/alarm LEDs in addition to the 11programmable LEDs.

The local HMI includes a push button (L/R) for the local/remote operation of the IED. When the IED is in the localmode, the IED can be operated only by using the local front-panel user interface. When the IED is in the remote mode, theIED can execute commands sent remotely. The IED supportsthe remote selection of local/ remote mode via a binary input.This feature facilitates, for example, the use of an externalswitch at the substation to ensure that all the IEDs are in thelocal mode during maintenance work and that the circuit

breakers cannot be operated remotely from the networkcontrol center.

GUID-7A40E6B7-F3B0-46CE-8EF1-AAAC3396347F V1 EN

Figure 10. Example of the LHMI

20. Mounting methodsBy means of appropriate mounting accessories, the standardIED case for the 620 series IED can be flush-mounted, semi-flush-mounted or wall-mounted.

Furthermore, the IEDs can be mounted in any standard 19”instrument cabinet by means of 19” mounting panels availablewith cut-outs for one IED. Alternatively, the IED can bemounted in 19” instrument cabinets by means of 4UCombiflex equipment frames.

Mounting methods:

• Flush mounting• Semi-flush mounting• Rack mounting• Wall mounting• Mounting to a 19" equipment frame

Panel cut-out for flush mounting:• Height: 162 ± 1 mm• Width: 248 ± 1 mm


46 ABB

48

153

177

160

262,2246

GUID-89F4B43A-BC25-4891-8865-9A7FEDBB84B9 V1 EN

Figure 11. Flush mounting

98

280

160

177

246

103

GUID-1DF19886-E345-4B02-926C-4F8757A0AC3E V1 EN

Figure 12. Semi-flush mounting

48

482.6 (19")

160

246

177

153

GUID-D83E2F4A-9D9B-4400-A2DC-AFF08F0A2FCA V1 EN

Figure 13. Rack mounting

259

186

318

GUID-65A893DF-D304-41C7-9F65-DD33239174E5 V1 EN

Figure 14. Wall mounting

21. IED case and IED plug-in unitFor safety reasons, the IED cases for current measuring IEDsare provided with automatically operating contacts for short-circuiting the CT secondary circuits when a IED unit iswithdrawn from its case. The IED case is further provided witha mechanical coding system preventing current measuringIED units from being inserted into a IED case for a voltagemeasuring IED unit and vice versa, i.e. the IED cases areassigned to a certain type of IED plug-in unit.


ABB 47

22. Selection and ordering dataThe IED type and serial number label identifies the protectionIED. The label is placed above the HMI on the upper part ofthe plug-in unit. An order number label is placed on the sideof the plug-in unit as well as inside the case. The order

number consists of a string of codes generated from theIED's hardware and software modules.

Use the ordering key information to generate the ordernumber when ordering complete IEDs.

# Description

1 IED

620 series IED (including case) N

2 Standard

IEC B

CN C

3 Main application

Motor protection and control M

4 Functional application

Example configuration N

5-6 Analog inputs and outputs

7I (I0 1/5 A) + 5U + 12BI + 10BO + 6RTD in + 2mA in AA

7I (I0 0,2/1 A) + 5U + 12BI + 10BO + 6RTD in + 2mA in AB

7-8 Optional board

Optional I/Os 8BI+ 4BO AA

Optional RTDs 6RTD in + 2mA in AB

Optional Fast I/Os 8BI + 3HSO AC

No optional board NN

9 -

10

Communication modules (Serial)

Serial RS-485, incl. an input for IRIG-B + Ethernet 100Base-FX (1 x LC)

AA

Serial RS-485, incl. an input for IRIG-B + Ethernet 100Base-TX (1 x RJ-45)

AB

Serial RS-485, incl. an input for IRIG-B AN

Serial glass fibre (ST) + Serial RS-485 connector, RS-232/485 D-Sub 9 connector + input for IRIG-B (cannot be combined with arc protection)

BN

Serial glass fibre (ST) + Ethernet 100Base-TX (1 x RJ-45) + Serial RS-485 connector, RS-232/485 D-Sub 9 connector + input for IRIG-B (cannot be combined with arc protection)

BB

Serial glass fibre (ST) + Ethernet 100Base-TX (3 x RJ-45) with HSR/PRP BD

Serial glass fibre (ST) + Ethernet 100Base-TX and -FX (2 x RJ-45 + 1 x LC) with HSR/PRP

BC

Serial glass fibre (ST) + Ethernet 100Base-TX and -FX (1 x RJ-45 + 2 x LC) with HSR/PRP

BE

Ethernet 100Base-FX (1 x LC) NA

Ethernet 100Base-TX (1 x RJ-45) NB

Ethernet 100Base-TX and -FX (2 x RJ-45 + 1 x LC) with HSR/PRP

NC

Ethernet 100Base-TX (3 x RJ-45) with HSR/PRP ND

Ethernet 100Base-TX and -FX (1 x RJ-45 + 2 x LC) with HSR/PRP

NE

No communication module NN

If serial communication is chosen, please choose a serial communication module including Ethernet (for example “BC”) if a service bus for PCM600 or the WebHMI is required.

N B M N A A N N A B C 1 B N N 1 X F

GUID-7DDA4163-29F6-469A-8E69-A6D3FE3F24D0 V1 EN


48 ABB

# Description

11 Communication protocols

IEC 61850 (for Ethernet communication modules and IEDs with-out a communication module )

A

Modbus (for Ethernet/serial or Ethernet + serial communication modules)

B

IEC 61850 + Modbus (for Ethernet or serial + Ethernet communi-cation modules)

C

IEC 60870-5-103 (for serial or Ethernet + serial communication modules)

D

DNP3 (for Ethernet/serial or Ethernet + serial communication modules)

E

IEC 61850 + IEC 60870-5-103(for serial + Ethernet communica-tion modules)

G

IEC 61850 + DNP3(for Ethernet or serial + Ethernet communica-tion modules)

H

12 Language

English 1

English and Chinese 2

13 Front panel

Large LCD with Single Line Diagram - IEC B

Large LCD with Single Line Diagram - CN D

14 Option 1

Arc protection (requires a communication module, cannot be combined with communication module optionsS BN or BB)

B

None N

15 Option 2

None N

16 Power supply

Power supply 48-250 VDC, 100-240 VAC 1

Power supply 24-60 VDC 2

17 -

18

Reserved

Product version 2.0 XF

N B M N A A N N A B C 1 B N N 1 X F

GUID-600ABF01-7959-4459-A46C-BAB01DB6AF72 V1 EN

Example code: N B M N A A N N A B C 1 B N N 1 X F

Your ordering code:

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

CodeGUID-161F35FF-C0CC-4411-B6F4-2109C0623B48 V1 EN

Figure 15. Ordering key for complete IEDs


ABB 49

23. Accessories and ordering data

Table 82. Cables

Item Order number

Cable for optical sensors for arc protection 1.5 m 1MRS120534-1.5



Table 83. Mounting accessories

Item Order number

Semi-flush mounting kit 2RCA030573A0001

Wall mounting kit 2RCA030894A0001

19" Mounting panel kit 2RCA031135A0001

24. ToolsThe IED is delivered as a pre-configured unit including theexample configuration. The default parameter setting valuescan be changed from the front-panel user interface, the Web-browser based user interface (WebHMI) or the PCM600 toolin combination with the IED-specific connectivity package.

The Protection and Control IED Manager PCM600 offersextensive IED configuration functions such as IED signalconfiguration, application configuration, graphical displayconfiguration including single line diagram configuration, andIEC 61850 communication configuration including horizontalGOOSE communication.

When the Web-browser based user interface is used, the IEDcan be accessed either locally or remotely using a Webbrowser (IE 7.0 IE 8.0 or IE 9.0). For security reasons, the

Web-browser based user interface is disabled by default. Theinterface can be enabled with the PCM600 tool or from thefront panel user interface. The functionality of the interfacecan be limited to read-only access by means of PCM600.

The IED connectivity package is a collection of software andspecific IED information, which enable system products andtools to connect and interact with the IED. The connectivitypackages reduce the risk of errors in system integration,minimizing device configuration and set-up times.Furthermore, the Connectivity Packages for the 620 seriesIEDs include a flexible update tool for adding one additionallocal HMI language to the IED. The update tool is activatedusing PCM600 and it enables multiple updates of theadditional HMI language, thus offering flexible means forpossible future language updates.

Table 84. Tools

Configuration and setting tools Version

PCM600 2.5 or later

Web-browser based user interface IE 7.0, IE 8.0 or IE 9.0

REM620 Connectivity Package 2.0


50 ABB

Table 85. Supported functions

Function WebHMI PCM600

IED parameter setting

Saving of IED parameter settings in the IED

Signal monitoring

Disturbance recorder handling

Alarm LED viewing

Access control management

IED signal configuration (signal matrix) -

Modbus® communication configuration (communicationmanagement) -

DNP3 communication configuration (communicationmanagement) -

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

Saving of IED parameter settings in the tool -

Disturbance record analysis -

XRIO parameter export/import

Graphical display configuration -

Application configuration -

IEC 61850 communication configuration, GOOSE(communication configuration) -

Phasor diagram viewing -

Event viewing

Saving of event data on the user's PC -

Online monitoring - = Supported


ABB 51

25. Connection diagrams

REM620

X13Light sensor input 1 1)



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

X115

34

56

7

89

10BI 6

BI 5

BI 4

BI 3

BI 2

BI 8

BI 712

13

11

BI 112

1) Order selectable -Optional2) The IED features an automatic short-circuit mechanism in the CT connector when plug-in unit is detached

X13012

34

56

BI 4

BI 3

BI 2

BI 1

87

9101112

U_SYN

1314

U1

1516

U2

1718

U3

Uo60 -

N

210V

60 -

N

210V

60 -

N

210V

60 -

N

210V

60 -

N

210V

2)

X120

7

89

1011

12

14Io

IL1

IL2

IL3

1/5A

N1/5A

N1/5A

N1/5A

N

13

1

23

45

6

IL1_N

IL2_N

IL3_N

1/5A

N1/5A

N1/5A

N

X110

1314

56

789

10RTD 1

1112

RTD 2

mA 1mA

mA 2mA

1516

RTD 3

2122

1718

RTD 4

1920

RTD 5

RTD 6

Common RTD GNDCommon RTD GND

L1L2L3

P2

P1 S1

S2

da dn

a

nN

A

S1

S2

P1

P2

X115

16

14

15

19

17

18

22

20

21

SO3

23SO4

24

SO1

SO2

PositiveCurrentDirection

Uab

S1

S2

P1

P2

M3~

GUID-19F39D16-3819-4030-877F-08E5872EEC5D V1 EN

Figure 16. Connection diagram for the A configuration


52 ABB

620 BIO optionX105

34

56

7

89

10BI 6

BI 5

BI 4

BI 3

BI 2

BI 8

BI 712

13

11

BI 112

X105

16

14

15

19

17

18

22

20

21

SO3

23SO4

24

SO1

SO2

GUID-5298DCA3-4597-44C2-850A-889384DF423B V1 EN

Figure 17. Optional BIO0005 module (slot X105)

X105

2

3

5

6

7BI 6

BI 5

BI 4

BI 3

BI 2

BI 8

BI 7

10

8

BI 11

4

9

X105

1516

19

23

20

24

HSO3

HSO2

HSO1

620 BIO option

GUID-D019E095-29EF-41B1-BDF4-D9D427201B88 V1 EN

Figure 18. Optional BIO0007 module for fast outputs (slot X105)

X105

1314

56

789

10RTD 1

1112

RTD 2

mA 1mA

mA 2mA

1516

RTD 3

2122

1718

RTD 4

1920

RTD 5

RTD 6

Common RTD GNDCommon RTD GND

620 RTD option

GUID-987D427B-C5F7-4073-8D5F-D0C37BEAF5E5 V1 EN

Figure 19. Optional RTD0003 module (slot X105)


ABB 53

26. ReferencesThe www.abb.com/substationautomation portal offers youinformation about the distribution automation product andservice range.

You will find the latest relevant information on the REM620protection IED on the product page.

The download area on the right hand side of the web pagecontains the latest product documentation, such as technicalmanual, installation manual, operation manual, etc.

The Features and Application tabs contain product relatedinformation in a compact format.


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HTTP://WWW.ABB.COM/SUBSTATIONAUTOMATION

27. Functions, codes and symbols

Table 86. REM620 functions, codes and symbols

Function IEC 61850 IEC 60617 IEC-ANSI

Protection

Three-phase non-directional overcurrent protection,low stage, instance 1 PHLPTOC1 3I> (1) 51P-1 (1)

Three-phase non-directional overcurrent protection,instantaneous stage, instance 1 PHIPTOC1 3I>>> (1) 50P/51P (1)

Three-phase directional overcurrent protection, lowstage, instance 1 DPHLPDOC1 3I> -> (1) 67-1 (1)

Three-phase directional overcurrent protection, highstage, instance 1 DPHHPDOC1 3I>> -> (1) 67-2 (1)

Three-phase directional overcurrent protection, highstage, instance 2 DPHHPDOC2 3I>> -> (2) 67-2 (2)

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

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

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

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

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

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



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



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



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

Positive-sequence undervoltage protection, instance 2 PSPTUV2 U1< (2) 47U+ (2)

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

Negative-sequence overvoltage protection, instance 2 NSPTOV2 U2> (2) 47O- (2)

Frequency protection, instance 1 FRPFRQ1 f>/f<,df/dt (1) 81 (1)






Negative-sequence overcurrent protection for motors,instance 1 MNSPTOC1 I2>M (1) 46M (1)


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Table 86. REM620 functions, codes and symbols, continued


Negative-sequence overcurrent protection for motors,instance 2 MNSPTOC2 I2>M (2) 46M (2)

Loss of load supervision, instance 1 LOFLPTUC1 3I< (1) 37M (1)

Loss of load supervision, instance 2 LOFLPTUC2 3I< (2) 37M (2)

Motor load jam protection JAMPTOC1 Ist> (1) 51LR (1)

Motor start-up supervision STTPMSU1 Is2t>, n> (1) 49,66,48,51LR (1)

Phase reversal protection PREVPTOC1 I2>> (1) 46R (1)

Thermal overload protection for motors MPTTR1 3Ith>M (1) 49M (1)

Motor differential protection MPDIF1 3dl>M (1) 87M (1)

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

Circuit breaker failure protection, instance 2 CCBRBRF2 3I>/Io>BF (2) 51BF/51NBF (2)

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

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

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



Multipurpose analog protection, instance 1 MAPGAPC1 MAP (1) MAP (1)












Control

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

Circuit-breaker control, instance 2 CBXCBR2 I <-> O CB (2) I <-> O CB (2)

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


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



Earthing switch control, instance 2 ESXSWI2 I <-> O ESC (2) I <-> O ESC (2)

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


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



Earthing switch position indication, instance 2 ESSXSWI2 I <-> O ES (2) I <-> O ES (2)

Emergergency startup ESMGAPC1 ESTART (1) ESTART (1)

Synchronism and energizing check SECRSYN1 SYNC (1) 25 (1)

Condition monitoring

Circuit-breaker condition monitoring, instance 1 SSCBR1 CBCM (1) 52CM (1)

Circuit-breaker condition monitoring, instance 2 SSCBR2 CBCM (2) 52CM (2)

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

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

Current circuit supervision, instance 1 CCRDIF1 MCS 3I (1) CSM 3I (1)

Fuse failure supervision SEQRFUF1 FUSEF (1) 60 (1)

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

Runtime counter for machines and devices, instance 2 MDSOPT2 OPTS (2) OPTM (2)

Measurement

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

Three-phase current measurement, instance 2 CMMXU2 3I(B) (1) 3I(B) (1)

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

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

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

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

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)

Frequency measurement FMMXU1 f (1) f (1)

Other

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




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

Minimum pulse timer (2 pcs, second resolution),instance 2 TPSGAPC2 TPS (2) TPS (2)

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

Minimum pulse timer (2 pcs, minute resolution),instance 2 TPMGAPC2 TPM (2) TPM (2)


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

Pulse timer (8 pcs), instance 2 PTGAPC2 PT (2) PT (2)

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




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




Set reset (8 pcs), instance 1 SRGAPC1 SR (1) SR (1)




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




Generic control points, instance 1 SPCGGIO1 SPCGGIO (1) SPCGGIO (1)



Remote Generic control points SPCRGGIO1 SPCRGGIO (1) SPCRGGIO (1)

Local Generic control points SPCLGGIO1 SPCLGGIO (1) SPCLGGIO (1)

Generic Up-Down Counters, instance 1 UDFCNT1 UDCNT (1) UDCNT (1)












Programmable buttons(16 buttons) FKEYGGIO1 FKEY (1) FKEY (1)

Logging functions

Disturbance recorder RDRE1 DR (1) DFR (1)


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Fault recorder FLTMSTA1 FR (1) FR (1)

Sequence event recorder SER1 SER (1) SER (1)

Load profile LDPMSTA1 LOADPROF (1) LOADPROF (1)

28. Document revision history

Document revision/date Product version History

A/2013-05-07 2.0 First release


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Contact us

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Motor Protection and Control REM620 Product Guide · 2018. 5. 10. · Local generic control points...

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