Grid Automation Remote Monitoring and Control … Automation Remote Monitoring and Control REC615...

Relion® product family

Grid AutomationRemote Monitoring and Control REC615Product Guide

Contents

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

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

3. Protection functions......................................................10

4. Application...................................................................10

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

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

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

8. Fault location................................................................13

9. Disturbance recorder....................................................13

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

11. Fault recorder..............................................................14

12. Condition monitoring ..................................................14

13. Trip-circuit supervision.................................................14

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

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

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

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

18. Station communication................................................15

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

20. Local HMI....................................................................47

21. Mounting methods......................................................48

22. Relay case and plug-in unit.........................................48

23. Selection and ordering data.........................................48

24. Accessories and ordering data....................................48

25. Tools...........................................................................49

26. Connection diagrams..................................................51

27. References..................................................................53

28. Functions, codes and symbols....................................53

29. Document revision history...........................................58

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 2015 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.

Grid Automation 1MRS757811 CRemote Monitoring and Control REC615 Product version: 1.1

2 ABB

1. DescriptionREC615 is a dedicated grid automation relay designed forremote control and monitoring, protection, fault indication,power quality analysis and automation in medium-voltagesecondary distribution systems, including networks withdistributed power generation, with secondary equipment suchas medium-voltage disconnectors, switches and ring-mainunits.

REC615 is a member of the Relion® product family. The relayhas inherited features from the 615 series relays that arecharacterized by their compactness as well asenvironmentally friendly (RoHS compliance) and withdrawable-unit design. Re-engineered from the ground up, the relayshave been designed to unleash the full potential of the IEC61850 standard for communication and interoperabilitybetween substation automation devices.

With REC615, grid reliability can be enhanced, ranging frombasic, non-directional overload protection to extendedprotection functionality with power quality analyses. REC615meets today’s requirements for smart grids and supports theprotection of cable feeders in isolated neutral, resistance-earthed, compensated and solidly earthed networks. REC615is freely programmable with horizontal GOOSEcommunication, thus enabling sophisticated interlockingfunctions. REC615 includes sophisticated protectionfunctionality to detect, isolate and restore power in all typesof networks but especially in compensated networks. As partof an ABB smart grid solution, the relay provides superiorfault location, isolation and restoration (FLIR) to lower thefrequency and shorten the duration of faults.

The adaptable standard configurations allow the relay to betaken into use right after the application-specific parametershave been set, thus enabling rapid commissioning. Therelay's existing I/O is further extendable with RIO600.REC615 supports the same configuration tools as the otherrelays in the Relion product family. The freely programmablerelay contains six easily manageable setting groups.

One breaker and up to eight load-break switches can becontrolled via the relay's front panel HMI or a remote system.The relay's large, easy-to-read LCD screen with single-linediagram offers local control and parametrization possibilitieswith dedicated push buttons for safe operation. Easy Web-based parametrization tool is also available with downloadpossibility.

To protect the relay from unauthorized access and tomaintain the integrity of information, the relay is provided witha four-level, role-based user authentication system, withindividual passwords for the viewer, operator, engineer andadministrator levels. The access control system applies to the

front panel HMI, embedded Web browser-based HMI andProtection and Control IED Manager PCM600. In addition, therelay also includes cyber security features such as audit trail.

REC615 supports a variety of communication protocols forremote communication, such as IEC 60870-5-101/104, DNP3level 2 and Modbus, simultaneously also supporting IEC61850 with GOOSE messaging for high-speed protection,fault isolation and restoration.

2. Standard configurationsREC615 is available in three standard configurations. Anexample configuration suitable for the SECTOS type load-break switch applications with specific application, such asthe current based sectionalizing logic and load limitingfunctionality, is delivered with each standard configuration.This minimizes the required amount of engineering, allowingfast commissioning by just parameterizing the protectionfunctions. For applications where the example configuration isnot suitable, the standard signal configuration can be easilyaltered using the application configuration or signal matrixfunctionality of the Protection and Control IED ManagerPCM600. The application configuration functionality ofPCM600 also supports the creation of multilayer logicfunctions using various logical elements. By combiningprotection functions with logic function blocks, the relayconfiguration can be adapted to user-specific applicationrequirements.

Standard configuration A supports traditional current andvoltage transformers. The residual current for the earth-faultprotection is derived from the phase currents in a Holmgrenconnection. Alternatively the core balance currenttransformers can be used for measuring the residual current,especially when sensitive earth-fault protection is required.

Standard configuration B supports a combination oftraditional current and voltage transformers or alternativelyvoltage sensors. The residual current for the earth-faultprotection is derived from the phase currents in a Holmgrenconnection. Alternatively, the core balance currenttransformers can be used for measuring the residual current,especially when sensitive earth-fault protection is required.The sensor inputs are highly flexible and are type tested tosupport both ABB's capacitive and resistive voltage sensors.

Standard configuration C supports combined voltage andcurrent sensors which support traditional residual currentinputs in sensitive earth-fault applications. The sensor inputsfully support both ABB's voltage and current medium-voltagesensors. The wide characteristics of the current sensor inputsallow standardization of the primary equipment.

Grid Automation 1MRS757811 CRemote Monitoring and Control REC615 Product version: 1.1 Issued: 2015-03-06

Revision: C

ABB 3

Uo>59G

IEC

ANSI

RL

ClearESC

IA=0AIB=0AIC=0AIG=0. 0AVAB=0.00kVVBC=0. 00kVVCA=0. 00kV

3P=0kW3Q=0kVAr

Close

Open

Menu

Help

REF615

RL

ClearESCI

O

Configuration ASystemHMITimeAuthorization

RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

CONDITION MONITORING AND SUPERVISION

1 0 1 0 0 0 11 0 1 1 0 0 1 01 1 0 0 1 1 1 01 0 1 1 0 1 1 01 0 1 0 0 0 1 11 0 1 1 0 1 1 0

COMMUNICATION

Protocols: Master: IEC 61850-8-1 Slave: IEC 101, IEC 104, Modbus®, DNP3 Level 2

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

ALSO AVAILABLE

- Disturbance recorder- Event log - Fault recorder- Relay self-supervision- Load profile - Local/Remote push-button on LHMI- Recorded data- User management- Web HMI

ORAND

CONTROL AND INDICATION 1) MEASUREMENT

PROTECTION LOCAL HMI

REMOTE MONITORING AND CONTROL RELAY

Version 1.1

REC615

PQM3IPQM3I

PQM3UPQM3V

PQMUPQMV

PQUUBPQVUB

- I, U, Io, P, Q, E, pf, f- Symmetrical components- Limit value supervision- Power Quality functions

2×TCSTCM

FUSEF60

2×

PHSVPRPHSVPR

CBCMCBCM

Object Ctrl 2) Ind 3)

CB 1 -

DC 8 -

ES - 81) Check availability of binary inputs/outputs

from technical documentation2) Control and indication function for

primary object3) Status indication function for primary object

STANDARD CONFIGURATION

REMARKS

Optionalfunction

No. ofinstances

Alternative function to be defined when ordering

OR

Io/Uo

Calculatedvalue

3×

ATSABTCATSABTC

2×I2>46

3Ith>F49F

3I>>>50P/51P

2×Master Trip

Lockout relay94/86

2×Io>→67N-1

3×3U<27

U2>47O-

U1<47U+

3×3U>59

2×f>/f<,df/dt81

3I2f>68

Io>>→67N-2

Io>>51N-2

OR

I2/I1>46PD

Io>51N-1

OR

Io>>>50N/51N

3×Yo>→21YN

3×Po>→32N

Io>HA51NHA

OR

2×3I>→67-1

3I>51P-1

OR

OR

UL1

UL2

UL3

6×MAPMAP

3I>>→67-2

3I>>51P-2

OR

Uo

O→I79

FLOC21FL

UFLS/R81LSH

Voltage transformer 3

Conventional transformer inputs

Analog interface types 1)

Current transformer 4

1)

A

Load

Source

UL1UL2UL3

3I

3I

2×MVI4MVI4

8×MVMV

12×SCA4SCA4

Io

Io>→IEF67NIEF

GUID-AAC747A2-E523-4BA1-A340-6EE7E40EEB15 V2 EN

Figure 1. Functionality overview of standard configuration A


4 ABB

3U>59

Voltage sensor 6


Current transformer 4

1) Conventional transformer inputs andvoltage sensor inputs

IEC

ANSI

RL

ClearESC


3P=0kW3Q=0kVAr

Close

Open

Menu

Help

REF615

RL

ClearESCI

O


RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A


1 0 1 0 0 0 11 0 1 1 0 0 1 01 1 0 0 1 1 1 01 0 1 1 0 1 1 01 0 1 0 0 0 1 11 0 1 1 0 0 1 0

COMMUNICATION



ALSO AVAILABLE


ORAND




Version

REC615

PQM3IPQM3I

PQM3UPQM3V

PQMUPQMV

PQUUBPQVUB


2×TCSTCM

FUSEF60

2×CBCMCBCM


CB 1 -

DC 8 -





REMARKS

Optionalfunction

No. ofinstances


OR

Io/Uo

Calculatedvalue

3×

Io>→IEF67NIEF

1.1

ATSABTCATSABTC

2×I2>46

3Ith>F49F

3I>>>50P/51P

2×Master Trip

Lockout relay94/86

2×Io>→67N-1

2×3U<27

2) 2)

3U<27

U2>47O-

U1<47U+

2×3U>59

Uo>59G

Uo>59G

2×f>/f<,df/dt81

3I2f>68

Io>>→67N-2

Io>>51N-2

OR

I2/I1>46PD

Io>51N-1

OR

Io>>>50N/51N

3×Yo>→21YN

3×Po>→32N

Io>HA51NHA

OR

2×3I>→67-1

3I>51P-1

OR

OR

3I>>→67-2

3I>>51P-2

OR

SYNC25

O→I79

6×MAPMAP

B

UFLS/R81LSH

FLOC21FL

2×MVI4MVI4

8×MVMV

12×SCA4SCA4

1) Instances 1 and 22) Instance 3

Load

Source

Uo

Uo

UL1bUL2bUL3b

UL1bUL2bUL3b

UL1UL2UL3

UL1

UL2

UL3

3I

3I

Io

PHSVPRPHSVPR

PHSVPRPHSVPR

1)

1)

1) 2)

1) Instance 1 2) Instance 2

GUID-3EF4B574-A7C6-423D-A5C7-10DE69ABEE94 V2 EN

Figure 2. Functionality overview of standard configuration B


ABB 5

IEC

ANSI

RL

ClearESC


3P=0kW3Q=0kVAr

Close

Open

Menu

Help

REF615

RL

ClearESCI

O


RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A


1 0 1 0 0 0 11 0 1 1 0 0 1 01 1 0 0 1 1 1 01 0 1 1 0 1 1 01 0 1 0 0 0 1 11 0 1 1 0 0 1 01 1 0 0 1 1 1 01 0 1 1 0 1 1 0

COMMUNICATION



ALSO AVAILABLE


ORAND




Version 1.1

REC615

PQM3IPQM3I

PQM3UPQM3V

PQMUPQMV

PQUUBPQVUB


2×TCSTCM

FUSEF60

2×CBCMCBCM


CB 1 -

DC 8 -





REMARKS

Optionalfunction

No. ofinstances


OR

Io/Uo

Calculatedvalue

3×

Load

2×I2>46

3Ith>F49F

3I>>>50P/51P

2×Master Trip

Lockout relay94/86

2×Io>→67N-1

3×3U<27

U2>47O-

U1<47U+

3×3U>59

Uo>59G

2×f>/f<,df/dt81

3I2f>68

Io>>→67N-2

Io>>51N-2

OR

I2/I1>46PD

Io>51N-1

OR

Io>>>50N/51N

3×Yo>→21YN

3×Po>→32N

Io>HA51NHA

OR

2×3I>→67-1

3I>51P-1

OR

OR

3I>>→67-2

3I>>51P-2

OR

UL1UL2UL3O→I79


Current sensor 3

Voltage sensor 3

Current transformer 11)

CSource

Combi sensor inputs with conventionalIo input

Uo

UL1

UL2

UL3

3I

6×MAPMAP

UFLS/R81LSH

FLOC21FL

2×MVI4MVI4

12×SCA4SCA4

3I

Io

Io>→IEF67NIEF

PHSVPRPHSVPR

ATSABTCATSABTC

8×MVMV

GUID-834B491A-C644-4CAC-9B21-2217860E38AE V2 EN

Figure 3. Functionality overview of standard configuration C


6 ABB

Table 1. Standard configurations

Description Std. conf.

Directional overcurrent and directional earth-fault protection with phase voltage-based protection and measurement functions,voltage protection, frequency and load-shedding protection, disconnector (switch) condition monitoring and disconnector(switch) control, counter logic A

Directional overcurrent and directional earth-fault protection with phase voltage-based protection and measurement functions,voltage protection, frequency and load-shedding protection, synchrocheck, disconnector (switch) condition monitoring,disconnector (switch) control and voltage sensor inputs, counter logic B

Directional overcurrent and directional earth-fault protection with phase voltage-based protection and measurement functions,voltage protection, frequency and load-shedding protection, disconnector (switch) condition monitoring, disconnector (switch)control and combi-sensor inputs, counter logic C


ABB 7

Table 2. Supported functions

Function IEC 61850 A B C

Protection1)2)

Three-phase non-directional overcurrent protection, low stage PHLPTOC (1)3) (1)3) (1)3)

Three-phase non-directional overcurrent protection, high stage PHHPTOC (1)3) (1)3) (1)3)

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

Three-phase directional overcurrent protection, low stage DPHLPDOC (2)3) (2)3) (2)3)

Three-phase directional overcurrent protection, high stage DPHHPDOC (1)3) (1)3) (1)3)

Non-directional earth-fault protection, low stage EFLPTOC (1)4)5) (1)4)5) (1)4)5)

Non-directional earth-fault protection, high stage EFHPTOC (1)4)5) (1)4)5) (1)4)5)

Non-directional earth-fault protection, instantaneous stage EFIPTOC 15) 15) 15)

Directional earth-fault protection, low stage DEFLPDEF (2)5)6)8) (2)5)6)8) (2)5)6)8)

Directional earth-fault protection, high stage DEFHPDEF (1)5)6)8) (1)5)6)8) (1)5)6)8)

Transient / intermittent earth-fault protection INTRPTEF (1)5)6)8) (1)5)6)8) (1)5)6)8)

Admittance based earth-fault protection EFPADM (3)5)7)8) (3)5)7)8) (3)5)7)8)

Wattmetric based earth-fault protection WPWDE (3)5)7)8) (3)5)7)8) (3)5)7)8)

Harmonics based earth-fault protection HAEFPTOC (1)5)7) (1)5)7) (1)5)7)

Negative-sequence overcurrent protection NSPTOC 2 2 2

Phase discontinuity protection PDNSPTOC 1 1 1

Residual overvoltage protection ROVPTOV (1)8) (2)9)10) (1)8)

Three-phase undervoltage protection PHPTUV (3) (3)11) (3)

Three-phase overvoltage protection PHPTOV (3) (3)11) (3)

Positive-sequence undervoltage protection PSPTUV (1) (1) (1)

Negative-sequence overvoltage protection NSPTOV (1) (1) (1)

Frequency protection FRPFRQ (2) (2) (2)

Three-phase thermal protection for feeders, cables and distribution transformers T1PTTR 1 1 1

Three-phase inrush detector INRPHAR 1 1 1

Master trip TRPPTRC 2 2 2

Multi-purpose protection MAPGAPC 6 6 6

Load shedding and restoration LSHDPFRQ (1) (1) (1)

Fault locator SCEFRFLO (1) (1) (1)

Power quality

Current total demand distortion CMHAI (1) (1) (1)

Voltage total harmonic distortion VMHAI (1) (1) (1)

Voltage variation PHQVVR (1) (1) (1)

Voltage unbalance VSQVUB (1) (1) (1)

Control

Circuit-breaker control12) CBXCBR 1 1 1


8 ABB

Table 2. Supported functions, continued

Function IEC 61850 A B C

Disconnector control DCXSWI 8 8 8

Earthing switch indication ESSXSWI 8 8 8

Autoreclosing DARREC (1) (1) (1)

Synchronism and energizing check SECRSYN - 1 -

Automatic transfer switch ATSABTC (1) (1) (1)

Condition monitoring and supervision

Circuit-breaker condition monitoring SSCBR 2 2 2

Trip circuit supervision TCSSCBR 2 2 2

Fuse failure supervision SEQRFUF 1 1 1

Runtime counter for machines and devices MDSOPT 1 1 1

Voltage presence PHSVPR 1 2 1

Measurement

Disturbance recorder RDRE 1 1 1

Three-phase current measurement CMMXU 1 1 1

Sequence current measurement CSMSQI 1 1 1

Residual current measurement RESCMMXU 1 1 1

Three-phase voltage measurement VMMXU 1 1 (2)13) 1

Sequence voltage measurement VSMSQI 1 1 (2)13) 1

Three-phase power and energy measurement PEMMXU 1 1 1

Frequency measurement FMMXU 1 1 1

Load profile LDPMSTA 1 1 1

Other

Minimum pulse timer (2 pcs) TPGAPC 2 2 2

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

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

Pulse timer (8 pcs) PTGAPC 2 2 2

Time delay off (8 pcs) TOFGAPC 2 2 2

Time delay on (8 pcs) TONGAPC 2 2 2

Set reset (8 pcs) SRGAPC 2 2 2

Move (8 pcs) MVGAPC 8 8 8

Generic control point (16 pcs) SPCGGIO 2 2 2

Remote generic control points SPCRGGIO 1 1 1

Local generic control points SPCLGGIO 1 1 1

Generic up-down counters UDFCNT 3 3 3

Analog value scaling function SCA4GAPC 12 12 12

Integer value moving function MVI4GAPC 2 2 2

1, 2, ... = number of included instances() = optional


ABB 9

1) All directional protection functions can also be used in the non-directional mode2) The instances of a protection function represent the number of identical protection function blocks available in the standard configuration3) Only one can be ordered as an option at a time with OC or directional OC4) Can be ordered as an option when OC is also chosen5) Io selectable by parameter, Io measured by default6) Can be ordered as an option when OC or directional OC is also chosen7) One of the three can be ordered as an option when directional OC and directional EF are chosen: Admittance based EF, Wattmetric based EF or Harmonics based EF8) Uo calculated is always used9) Uo calculated is always used with the first instance10) UoB calculated is always used with the second instance11) Voltage group B is always used with the third instance12) Must be added with Application Configuration to be available in Signal Matrix and in the relay13) Voltage group B is always used with the second instance

3. Protection functionsTo allow the customers to customize the relay according totheir requirements, it can be ordered as a basic relay orenhanced with selected protection functions. The selectiondepends on the application, whether it is a compensatednetwork, and whether the compensated network is withdistributed generation or closed-loop feeders.

As a standard offering, the relay includes non-directionalovercurrent and non-directional earth-fault functions, as wellas other protection functions commonly accepted as a meansto significantly improve the grid reliability in grid automationapplications, such as negative-sequence overcurrentprotection to detect a broken conductor. Alternatively, a moresensitive phase-discontinuity protection is available. Thermalprotection, which is used for protecting feeders, cables anddistribution transformers, is also included.

The optional functionalities of the relay include moreadvanced methods to detect the earth faults in variousdistribution networks. On top of the permanent earth faults,the relay can be equipped with algorithms that can be usedto detect intermittent and transient temporary faults. This canbe used to localize possible future problem points in the

distribution network, even before they develop to a fault thatcauses interruption in the power distribution seen by the endusers.

A syncrocheck function is offered with standard configurationB. The synchrocheck function ensures that the voltage, phaseangle and frequency on either side of an open circuit breakermeet the conditions for a safe interconnection of twonetworks.

Some advanced protection functions are optionally availablein REC615.

4. ApplicationREC615 is a dedicated grid automation relay and suitable fora variety of applications, ranging from basic applications onthe line breaker to sophisticated applications includingdistributed generation and demanding interlockingapplications. Because of the large number of protectionfunctions, the illustrated applications are only exampleapplications which can be extended to meet tomorrow'srequirements.

3I3U

RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

M

M

REC615Std. conf.

ANSI IEC

A

49F

50P/51P

50/51N

3Ith>F

3I>>>

3I/3Io

GUID-35A65B65-06B1-4134-84BE-F43CA715D144 V1 EN

Figure 4. RMU (Ring Main Unit) with an outgoing circuit breaker for a distribution transformer


10 ABB

Figure 4 illustrates remotely controllable load-break switcheson cable feeders and current-based protection functions fordistribution transformers. Additionally, the applicationincludes embedded communication with SCADA via, for

example, IEC 60870-5-104, a graphical local HMI and powermeasurements P, Q, S and cosφ and power qualityfunctionality.

3Ub

3U

3I REC615Std. conf.

ANSI IEC

21YN 1)

25

50P/51P

67/67N

PQ

Yo>→1)

SYNC

3I>>>

3I→/Io→

B

1) or 51NHA (Io>HA), 32N (Po>→)

RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

M

M

GUID-06E97939-580E-48EB-81A6-5EAC5F1B61C1 V1 EN

Figure 5. RMU controller with synchrocheck functionality

Figure 5 illustrates remotely controllable load-break switchesfor cable feeders in radial networks requiring synchrocheckfunctionality to reliably close the loop. Accurate fault passindication and disturbance recording on outgoing feeder are

also included. Additionally, embedded communication withSCADA via, for example, IEC 60870-5-104, a graphical localHMI and power measurements P, Q, S and cosφ, and powerquality functionality are available.

3UDG

3Ub

3I

REC615Std. conf.

ANSI IEC

21YN 1)

25

47O-/59

47U+/27

49F

50P/51P

67/67N

79

81

Yo>→1)

SYNC

U2>/3U>

U1</3U<

3Ith>F

3I>>>

3I→/Io→

O→I

f</f>,df/dt

B

1) or 51NHA (Io>HA), 32N (Po>→)

RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

M

M

IEC 61850 and GOOSE

RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

GUID-52B08C6E-28D5-4597-9F33-CE6B2EB0B95D V1 EN

Figure 6. Remote control and protection of distributed generation plant

The advanced protection functionality of REC615 ensuressecure protection of distributed generation against faults, and

early indication of loss-of-mains through IEC 61850 andGOOSE communication as shown in Figure 6. Safe


ABB 11

reconnection is ensured by using the synchrocheckfunctionality.

3U

3I

RIO600

RTD

REC615Std. conf.

ANSI IEC

21YN 1)

46PD

49F

50P/51P

67/67N

79

Yo>→1)

I2/I1>

3Ith>F

3I>>>

3I→/Io→

O→I

C

1) or 51NHA (Io>HA), 32N (Po>→)

RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

M

M

M

M

M

PSM_H

Ready

DIM8_H

RIO600

Ready

IRF

DI1

DI2

DI3

DI4

DI5

DI6

DI7

DI8

LECM

Ready

IRF

Rx/Tx

10M/100M

DOM

Ready

IRF

DO1

DO2

DO3

DO4

IEC 61850 and GOOSE

GUID-9F9F0767-5865-4C46-A2FB-425EC2DFF523 V2 EN

Figure 7. Remote control and protection of RMU station

Remotely controllable load-break switches on cable feederswith sensor measurement enable the selective protection ofradial feeders with advanced directional earth-fault andovercurrent protection, and autoreclosing functionality ashown in Figure 7. Additionally, embedded communication

with SCADA via, for example, IEC 60870-5-104, a graphicallocal HMI, energy measurement in all four quadrants, andpower quality functionality are available. RIO600 is used toextend the number of I/Os and for temperature measurementof the distribution transformer.

5. Supported ABB solutionsREC615 integrates fully with other ABB products such asRIO600, the grid automation controller COM600,MicroSCADA, SYS600, DMS600, and with ABB's secure,reliable and tested communication solutions, RER601 and theM2M gateway. ABB offers a solution which meets thedemanding customer requirements regarding smart grids,and which also contributes to faster engineering.

To facilitate and streamline 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 alsoincludes event and parameter lists. With the connectivitypackages, the relays can be readily configured using PCM600and integrated with the grid automation controller COM600 orthe network control and management system MicroSCADAPro.

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 protection

system approach, enabled by the full implementation of theIEC 61850 substation automation standard, are fastcommunication capability, continuous supervision of theintegrity of the protection and communication system, and aninherent flexibility regarding reconfiguration and upgrades.

At substation level, COM600 uses the data content of the bay-level devices to enhance substation level functionality.COM600 features a Web browser-based HMI, which providesa customizable graphical display for visualizing single-linemimic diagrams for switchgear bay solutions. The Web HMI ofCOM600 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, COM600 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 COM600. The history data can be used foraccurate monitoring of process and equipment performance,


12 ABB

using calculations based on both real-time and history values.A better understanding of the process dynamics is achievedby combining time-based process measurements withproduction and maintenance events.

COM600 can also function as a gateway and providesseamless connectivity between the substation devices andnetwork-level control and management systems, such asMicroSCADA Pro and System 800xA.

Table 3. Supported ABB solutions

Product Version

Grid automation controller COM600 4.0 SP1 or later

MicroSCADA Pro SYS 600 9.4 or later

System 800xA 5.1 or later

6. ControlOne circuit breaker and up to eight load-break switches canbe controlled via the front panel HMI of REC615 or via aremote system. The relay also provides position indication foreight earthing switches.

If the amount of available binary inputs or outputs of thechosen standard configuration is not sufficient, theconfiguration can be modified to release some binary inputsor outputs originally configured for other purposes. In thiscase, an external input/output module, for example, RIO600,can be integrated with the relay and its binary inputs andoutputs used for the less time-critical binary signals of theapplication.

The suitability of the relay's binary outputs selected forcontrolling primary devices should be carefully verified, forexample, regarding the make and carry and 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 includesa single-line diagram with position indication for the relevantprimary devices. Interlocking schemes required by theapplication are configured using the signal matrix or theapplication configuration function of PCM600. Depending onthe standard configuration, the relay also has a synchrocheckfunction to ensure that the voltage, phase angle andfrequency on either side of an open circuit breaker meet theconditions for a safe interconnection of two networks.

7. MeasurementThe relay continuously measures the phase currents andvoltages, the symmetrical components of the currents, andthe residual current. The relay additionally offers frequencymeasurement. The relay also calculates the demand value ofthe current over a user-selectable, pre-set time frame, thethermal overload of the protected object, and the phaseunbalance based on the ratio between the negative-sequence

and positive-sequence current. Active and reactive power aswell as residual voltage are also calculated.

Power quality measurement, such as total harmonic valuesfor both current and voltage, voltage sags and swells, andvoltage unbalance, is supported.

Furthermore, the relay offers three-phase power and energymeasurement including power factor.

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

8. Fault locationThe relay features an optional impedance-measuring faultlocation function suitable for locating short-circuits in radialdistribution systems. Earth faults can be located in effectivelyand low-resistance earthed networks. Under circumstanceswhere the fault current magnitude is at least of the sameorder of magnitude or higher than the load current, earthfaults can also be located in isolated neutral distributionnetworks. The fault location function identifies the type of thefault and then calculates the distance to the fault point. Anestimate of the fault resistance value is also calculated. Theestimate provides information about the possible fault causeand the accuracy of the estimated distance to the fault point.

9. Disturbance recorderThe relay is provided with a disturbance recorder with up to12 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,the set values. The binary signal channels can be set to starta recording either on the rising or the falling edge of thebinary signal or on both.


ABB 13

By default, the binary channels are set to record external orinternal relay signals, for example, the start or trip signals ofthe relay stages, or external blocking or control signals.Binary relay signals, such as protection start and trip signals,or an external relay control signal via a binary input, can beset to trigger the recording. Recorded information is stored ina non-volatile memory and can be uploaded for subsequentfault analysis.

10. Event logTo collect sequence-of-events information, the relay has anon-volatile memory with a capacity of storing 1024 eventswith associated time stamps. The non-volatile memory retainsits data also in case the relay temporarily loses its auxiliarysupply. The event log facilitates detailed pre- and post-faultanalyses of feeder faults and disturbances. The increasedcapacity to process and store data and events in the relayoffers prerequisites to support the growing informationdemand of future network configurations.

The sequence-of-events information can be accessed eitherlocally via the user interface on the relay's front panel, orremotely via the communication interface of the relay. Theinformation can also be accessed using the Web browser-based user interface, either locally or remotely.

11. Fault recorderThe relay has the capacity to store the records of the 128latest fault events. The records enable the user to analyze thepower system events. The available measurement modesinclude DFT, RMS and peak-to-peak. Fault records storerelay measurement values at the moment when anyprotection function starts. In addition, the maximum demandcurrent with time stamp is separately recorded. By default,the records are stored in the non-volatile memory.

Furthermore, the relay includes a load profile recordercapable of storing measurement values into the relay'smemory. The selected measurement values averaged overthe selected period, ranging from one minute to three hours,are stored in a non-volatile memory. Depending on theselected measurements and averaging period, the overalllength of the load profile recording ranges from some days toseveral months, even a year, making this feature suitable formonitoring long-time load behavior for the interested loads.

12. Condition monitoringThe condition monitoring functions of the relay constantlymonitors 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.

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

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 usedfor alerting the operator.

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

15. Fuse failure supervisionThe fuse failure supervision detects failures between thevoltage measurement circuit and the relay. The failures aredetected either by the negative sequence-based algorithm orby the delta voltage and delta current algorithm. Upon thedetection of a failure, the fuse failure supervision functionactivates an alarm and blocks voltage-dependent protectionfunctions from unintended operation.

16. Access controlTo protect the relay from unauthorized access and tomaintain information integrity, the relay is provided with a four-level, role-based authentication system with administrator-programmable individual passwords for the viewer, operator,engineer and administrator level. The access control appliesto the front-panel user interface, the Web browser-baseduser interface and PCM600.

17. Inputs and outputsDepending on the selected standard configuration, the relayis equipped with different analog input channels. Standardconfiguraton A provides three phase-current inputs, oneresidual current input and three voltage inputs. Standardconfiguration B provides three phase-current inputs, oneresidual current input and six sensor voltage inputs or voltagetransformers. Standard configuration C supports combi-sensors with sensitive residual current measurement.

The phase-current inputs are rated 1/5 A and the residualcurrent input 0.2/1 A. The residual current is suitable forapplications requiring sensitive earth-fault protection andwhich have core balance current transformers. As the residualcurrent is usually limited to small values, it can also be usedin applications where even the phase current is 5A. The threephase voltage inputs cover the rated voltages 60...210 V.Both phase-to-phase voltages and phase-to-earth voltagescan be connected.


14 ABB

The nominal secondary voltage of voltage sensor inputs isuser-programmable, supporting both capacitive and resistivevoltage sensors from 5 kV up to 38 kV.

Current sensor inputs are designed for ABB's Rogowskisensors, and the nominal current is user-programmable. Thewide input characteristics allow standardization of the primaryequipment, which is why one and the same primarymeasuring device can be used for both measuring andprotection, where the nominal current IN ranges from 39 A to

4000 A.

The phase current input 1 A or 5 A, the residual current input0.2 A or 1 A, and the rated voltage input are selected in therelay software. In addition, the binary input thresholds 18…176 V DC are selected by adjusting the relay's parametersettings.

All the binary input and output contacts are freelyconfigurable with the Application Configuration or SignalMatrix tool in PCM600.

Table 4. Number of physical connections in standard configurations

Configuration Analog channels Binary channels

Current Voltage Inputs Outputs

A 4 3 8(14)1) 10(13)1)

B 4 62) 12 10

C 3+13) 33) 8 10

1) With optional BIO0006 module2) Support for phase voltage sensors or phase voltage transformer with the SIM0001 module3) Support for three current sensors, three voltage sensors and one conventional Io input with the SIM0002 module

18. Station communicationThe relay supports a variety of communication protocols,including IEC 61850 and the most common remote controlprotocols IEC 60870-5-104, IEC 60870-5-101 Modbus andDNP3. Operational information and controls are availablethrough these protocols. However, some communicationfunctionality, for example horizontal communication betweenthe relays, is only possible through the IEC 61850communication protocol.

The IEC 61850 communication implementation supports allthe monitoring and control functions. Additionally, parametersettings, disturbance recordings and fault records can beaccessed using the IEC 61850 protocol. Disturbancerecordings are available for any Ethernet-based application inthe standard COMTRADE file format. The relay supportssimultaneous event reporting to five different clients over thestation bus.

The relay can send binary signals to other devices (so-calledhorizontal communication) using the IEC 61850-8-1 GOOSEprofile. Binary GOOSE messaging can, for example, be usedfor protection and interlocking-based protection schemes.The relay meets the GOOSE performance requirements fortripping applications in distribution substations, as defined bythe IEC 61850 standard. Furthermore, the relay supports thesending and receiving of analog values using GOOSEmessaging. Analog GOOSE messaging enables fast transferof the analog measurement values over the station bus. This

facilitates, for example, the sharing of RTD input values, suchas surrounding temperature, with other relay applications.

All communication connectors, except for the front portconnector, are placed on integrated optional communicationmodules. Modbus implementation supports RTU, ASCII andTCP modes. In addition to the standard Modbus functionality,the relay supports retrieval of timestamped events, changingthe active setting group and uploading the latest faultrecords. If a Modbus TCP connection is used, four clients canbe connected to the relay at the same time. Modbus serialand Modbus TCP can also be used in parallel and IEC 61850and Modbus simultaneously, if required. In addition to thebasic standard functionality, the relay supports changing ofthe active setting group and uploading of disturbancerecordings in the IEC 60870-5-101/104 format. DNP3supports both serial and TCP modes for connection to onemaster. Changing of the active setting group is alsosupported. When the relay uses the RS-485 bus for serialcommunication, both 2-wire and 4-wire connections aresupported. Termination and pull-up/down resistors can beconfigured with jumpers on the communication card,therefore no external resistors are required.

The relay supports several time synchronization methods witha time-stamping resolution of 1 ms. SNTP and IEC60870-5-104 can be used in Ethernet based timesynchronization and IRIG-B is available with special timesynchronization wiring. In addition, the relay supports time


ABB 15

synchronization via the serial communication protocolsModbus, DNP3 and IEC 60870-5-101.

Control center

Secondary Switchgear

3I

1

6 9

5 1

6 9

5

1

1 15

0

LAN

RS2

OFF ON

DC IN

+ –

CONSOLE/RS1

CONSOLE/RS1

1

ø

RER601

IEC 60780-5-104

REC615

REF615 REF615

COM600IEC 61850

IEC 60780-5-104

VPN Tunnel

VPN Tunnel

NCC

M2Mgateway

Fiber optic

PublicGPRS

RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

M

M

POWER

FP

A M

DC

+ –

M USB LA

Primary Switchgear

GUID-DDBA51AA-BA4F-4E81-8EF4-9CAC517326F5 V1 EN

Figure 8. System overview of utility communication

The communication solutions used with secondarysubstations are typically different from the ones used withprimary substations. In the example illustrated in Figure 8, theprimary substation communication is established by fibreoptics and, for example, a COM600 Grid Automation

Controller while the communication to the secondarysubstation is handled with REC615 as the gateway and aRER601 communication unit providing an end-to-endintelligent and secure connection.

Table 5. 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 60870-5-101 - - ● ●

IEC 60870-5-104 ● ● - -● = Supported


16 ABB

19. 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 relay 4.1 kg

plug-in unit only 2.1 kg

Table 7. Power supply

Description Value

Uauxnominal 24, 30, 48, 60 V DC

Maximum interruption time in the auxiliary DC voltage without resettingthe relay

Uauxvariation 50...120% of Un (12...72 V DC)

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

Burden of auxiliary voltage supply under quiescent (Pq)/operatingcondition

DC <12.0 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 A1) 20 A

• For 1 s 100 A1) 500 A

Dynamic current withstand

• Half-wave value 250 A1) 1250 A

Input impedance <100 mΩ1) <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


ABB 17

Table 9. Energizing inputs of SIM0001

Description Value

Voltage sensor input Rated voltage 5 kV...38 kV1)

Continuous voltage withstand 125 V AC2)

Input impedance at 50/60 Hz 1 MΩ3)

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) This range is covered with sensor division ratio of 10 000:12) Test to this voltage3) Neutral input impedance is close to zero

Table 10. Energizing inputs of SIM0002

Description Value

Current sensor input Rated current voltage (in secondaryside)

75 mV...2812.5 mV1)

Continuous voltage withstand 125 V

Input impedance at 50/60 Hz 2...3 MΩ2)

Voltage sensor input Rated voltage 6 kV...30 kV3)

Continuous voltage withstand 50 V

Input impedance at 50/60 Hz 3 MΩ

1) Equals the current range of 39...4000 A with a 80 A, 3 mV/Hz Rogowski2) Depending on the used nominal current (hardware gain)3) This range is covered (up to 2*rated) with sensor division ratio of 10 000:1

Table 11. 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


18 ABB

Table 12. 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: SO1X110: SO1, SO2X130: SO1, SO2 when REC615 is equipped with BIO0006

Table 13. Signal outputs and IRF output

Description Value 1)




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


1) X100: IRF,SO2X110: SO3, SO4X130: SO3 when REC615 is equipped with BIO0006

Table 14. Double-pole power outputs with TCS function X100: PO3 and PO4

Description Value





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


ABB 19

Table 15. Single-pole power output relays X100: PO1 and PO2

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


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

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 the 200-04 IRIG standard

Table 19. Degree of protection of flush-mounted relay

Description Value

Front side IP 54

Rear side, connection terminals IP 20


20 ABB

Table 20. 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 21

Table 21. 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 immunity test IEC 61000-4-10

• 2 s 100 A/m

• 1 MHz 400 transients/s

Power frequency immunity test Binary inputs only IEC 61000-4-16IEC 60255-22-7, class A

• Common mode 300 V rms

• Differential mode 150 V rms


22 ABB

Table 21. Electromagnetic compatibility tests, continued


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 22. 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 MΩ, 500 V DC IEC 60255-5 andIEC 60255-27

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

Table 23. 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

Table 24. Environmental tests


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

IEC 60068-2-2

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 relays with an LC communication interface the maximum operating temperature is +70oC


ABB 23

Table 25. Product safety

Description Reference

LV directive 2006/95/EC

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

Table 26. EMC compliance

Description Reference

EMC directive 2004/108/EC

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

Table 27. RoHS compliance

Description

Complies with RoHS directive 2002/95/EC


24 ABB

Protection functions

Table 28. 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 x set Start value

22 ms

24 ms

25 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)

±5.0% of the theoretical value or ±40 ms 3)4)

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 onephase with 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 contact4) Valid for FPHLPTOC


ABB 25

Table 29. 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 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


26 ABB

Table 30. 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 × InVoltage:±1.5% of the set value or ±0.002 × Un

Phase angle: ±2°

DPHHPDOC 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 × Un

Phase angle: ±2°

Start time1)2) Minimum Typical Maximum

IFault = 2.0 × set Start value 38 ms 43 ms 46 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 × fn, where n = 2, 3, 4, 5,…

1) Measurement mode and Pol quantity = default, current before fault = 0.0 × In, voltage before fault = 1.0 × 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 × In, Start value multiples in range of 1.5 to 20

4) Valid for FDPHLPDOC

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


Start value DPHLPDOC 0.05...5.00 × In 0.01

DPHHPDOC 0.10...40.00 × 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° 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


ABB 27

Table 32. 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

22 ms

24 ms

25 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

4) Valid for FEFLPTOC

Table 33. 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 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 40...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 34. 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 × Un

Phase 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 × Un

Phase angle:±2°


DEFHPDEFIFault = 2 × set Start value

42 ms

44 ms

46 ms

DEFLPDEFIFault = 2 × set Start value

61 ms 64 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

4) Valid for FDEFLPDEF


ABB 29

Table 35. 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 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

Technical data

Table 36. 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 37. 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 (voltage startvalue for transient EF)

INTRPTEF 0.01...0.50 × Un 0.01

Operation mode INTRPTEF 1=Intermittent EF2=Transient EF

-

Peak counter limit (Minrequirement for peak counterbefore start in IEF mode)

INTRPTEF 2...20 -

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


30 ABB

Table 38. Admittance-based earth-fault protection (EFPADM)


Operation accuracy1) At the frequency f = fn

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

Start time2) Minimum Typical Maximum

56 ms 60 ms 64 ms

Reset time 40 ms

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

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

1) Uo = 1.0 × Un2) Includes the delay of the signal output contact. Results based on statistical distribution of 1000 measurements.

Table 39. Admittance-based earth-fault protection (EFPADM) main settings


Voltage start value EFPADM 0.01...5.00 × Un 0.01

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

Operation mode EFPADM 1 = Yo2 = Go3 = Bo4 = Yo, Go5 = Yo, Bo6 = Go, Bo7 = Yo, Go, Bo

Operate delay time EFPADM 60...200000 ms 10

Circle radius EFPADM 0.05...500.00 mS 0.01

Circle conductance EFPADM -500.00...500.00 mS 0.01

Circle susceptance EFPADM -500.00...500.00 mS 0.01

Conductance forward EFPADM -500.00...500.00 mS 0.01

Conductance reverse EFPADM -500.00...500.00 mS 0.01

Conductance tilt Ang EFPADM -30...30° 1

Susceptance forward EFPADM -500.00...500.00 mS 0.01

Susceptance reverse EFPADM -500.00...500.00 mS 0.01

Susceptance tilt Ang EFPADM -30...30° 1


ABB 31

Table 40. Wattmetric based earth-fault protection (WPWDE)



Current and voltage:±1.5% of the set value or ±0.002 × InPower:±3% of the set value or ±0.002 × Pn

Start time 1)2) Typically 63 ms




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

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

1) Io varied during the test. Uo = 1.0 × Un = phase to earth voltage during earth fault in compensated or un-earthed network. The residual power value before fault = 0.0 pu, f n = 50 Hz,

results based on statistical distribution of 1000 measurement.2) Includes the delay of the signal output contact.

Table 41. Wattmetric based earth-fault protection (WPWDE) main settings


Directional mode WPWDE 2 = Forward3 = Reverse

Current start value WPWDE 0.010...5.000 × In 0.001

Voltage start value WPWDE 0.010...1.000 × Un 0.001

Power start value WPWDE 0.003...1.000 × Pn 0.001

Reference power WPWDE 0.050...1.000 × Pn 0.001

Characteristic angle WPWDE -179...180° 1

Time multiplier WPWDE 0.05...2.00 0.01

Operating curve type WPWDE Definite or inverse timeCurve type: 5, 15, 20

Operate delay time WPWDE 60...200000 ms 10

Min operate current WPWDE 0.010...1.000 × In 0.001

Min operate voltage WPWDE 0.01...1.00 × Un 0.01


32 ABB

Table 42. Harmonics earth-fault protection (HAEFPTOC)



±5% of the set value or ±0.004 × In

Start time 1)2) Typically 77 ms




Operate time accuracy in IDMT mode 3) ±5.0% of the set value or ±20 ms

Suppression of harmonics -50 dB at f = fn

-3 dB at f = 13 × fn

1) Fundamental frequency current = 1.0 × In. Harmonics current before fault = 0.0 × In, harmonics fault current 2.0 × Start value. Results based on statistical distribution of 1000

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

Table 43. HAEFPTOC main settings


Start value HAEFPTOC 0.05...5.00 × In 0.01

Time multiplier HAEFPTOC 0.05...15.00 0.01

Operate delay time HAEFPTOC 100...200000 ms 10

Minimum operate time HAEFPTOC 100...200000 ms 10

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

Table 44. Three-phase overvoltage protection (PHPTOV)


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

±1.5% of the set value or ±0.002 × Un


UFault = 1.1 × set Start value 22 ms 24 ms 26 ms


Reset ratio Depends of the set Relative hysteresis





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


ABB 33

Table 45. 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 46. Three phase undervoltage protection (PHPTUV)


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





Reset ratio Depends on the set Relative hysteresis





1) Start value = 1.0 × Un, Voltage before fault = 1.1 × Un, fn = 50 Hz, undervoltage in one phase-to-phase with nominal frequency injected from random phase 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 47. 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



34 ABB

Table 48. Positive-sequence undervoltage protection (PSPTUV)





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

51 ms43 ms

53 ms45 ms

54 ms46ms


Reset ratio Depends of the set Relative hysteresis




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

Table 49. 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...1.0 × Un 0.01

Table 50. 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



ABB 35

Table 51. 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 × fn 0.0001

Start value Freq< FRPFRQ 0.8000...1.1000 × fn 0.0001

Start value df/dt FRPFRQ -0.200...0.200 × fn/s 0.005

Operate Tm Freq FRPFRQ 80...200000 ms 10

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

Table 52. Negative-sequence overvoltage protection (NSPTOV)





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 53. 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


36 ABB

Table 54. Residual overvoltage protection (ROVPTOV)











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

Table 55. 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 56. Negative phase-sequence overcurrent protection (NSPTOC)



±1.5% of the set value or ±0.002 × In


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

22 ms14 ms

24 ms16 ms

25 ms17 ms







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


ABB 37

Table 57. Negative phase-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 58. Phase discontinuity protection (PDNSPTOC)



±2% of the set value

Start time <70 ms






Table 59. Phase discontinuity protection (PDNSPTOC) main settings


Start value (Current ratio setting I2/I1)

PDNSPTOC 10...100% 1

Operate delay time PDNSPTOC 100...30000 ms 1

Min phase current PDNSPTOC 0.05...0.30 × In 0.01

Table 60. Three-phase thermal overload protection for feeders (T1PTTR)



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

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

1) Overload current > 1.2 × Operate level temperature


38 ABB

Table 61. Three-phase thermal overload (T1PTTR) main settings


Env temperature Set (Ambienttemperature used when theAmbSens is set to Off)

T1PTTR -50...100°C 1

Current multiplier (Currentmultiplier when function is usedfor parallel lines)

T1PTTR 1...5 1

Current reference T1PTTR 0.05...4.00 × In 0.01

Temperature rise (Endtemperature rise above ambient)

T1PTTR 0.0...200.0°C 0.1

Time constant (Time constant ofthe line in seconds)

T1PTTR 60...60000 s 1

Maximum temperature(temperature level for operate)

T1PTTR 20.0...200.0°C 0.1

Alarm value (Temperature levelfor start (alarm)

T1PTTR 20.0...150.0°C 0.1

Reclose temperature(Temperature for reset of blockreclose after operate)

T1PTTR 20.0...150.0°C 0.1

Initial temperature (Temperatureraise above ambient temperatureat startup)

T1PTTR -50.0...100.0°C 0.1

Table 62. Three-phase inrush current detection (INRPHAR)


Operation accuracy At the frequency f = fn

Current measurement:±1.5% of the set value or ±0.002 × InRatio I2f/I1f measurement:±5.0% of the set value

Reset time +35 ms / -0 ms


Operate time accuracy +35 ms / -0 ms

Table 63. Three-phase inrush detection (INRPHAR) main settings


Start value (Ratio of the 2nd to the1st harmonic leading to restraint)

INRPHAR 5...100% 1

Operate delay time INRPHAR 20...60000 ms 1

Table 64. Multipurpose protection (MAPGAPC)


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


ABB 39

Table 65. 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

-

Table 66. Load shedding (LSHDPFRQ)


Operation accuracy 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< <80 ms

df/dt <120 ms

Reset time <150 ms


Table 67. Load shedding (LSHDPFRQ) main settings


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

-

Restore mode LSHDPFRQ DisabledAutoManual

-

Start value Freq LSHDPFRQ 0.800...1.200 × fn 0.001

Start value df/dt LSHDPFRQ -0.200...-0.005 × fn 0.005

Operate Tm Freq LSHDPFRQ 80...200000 ms 10

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

Restore start Val LSHDPFRQ 0.800...1.200 × fn 0.001

Restore delay time LSHDPFRQ 80...200000 ms 10

Table 68. Fault locator function (SCEFRFLO)


Measurement accuracy At the frequency f = fn

Impedance:±2.5% or ±0.25 Ω

Distance:±2.5% or ±0.16 km/0.1 mile

XC0F_CALC:±2.5% or ±50 Ω

IFLT_PER_ILD:±5% or ±0.05


40 ABB

Table 69. Fault locator (SCEFRFLO) main settings


Z Max phase load SCEFRFLO 1.0...10000.00 Ω 0.1

Ph leakage Ris SCEFRFLO 20...1000000 Ω 1

Ph capacitive React SCEFRFLO 10...1000000 Ω 1

R1 line section A SCEFRFLO 0.000...1000.000 Ω/pu 0.001

X1 line section A SCEFRFLO 0.000...1000.000 Ω/pu 0.001

R0 line section A SCEFRFLO 0.000...1000.000 Ω/pu 0.001

X0 line section A SCEFRFLO 0.000...1000.000 Ω/pu 0.001

Line Len section A SCEFRFLO 0.000...1000.000 pu 0.001

Table 70. 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


ABB 41

Control functions

Table 71. Autoreclosing (DARREC)



Table 72. Synchrocheck (SECRSYN)



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

Frequency:±10 mHzPhase angle:±3°

Reset time <50 ms



Table 73. 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 × Un 0.01

Difference frequency SECRSYN 0.001...0.100 × fn 0.001

Difference angle SECRSYN 5...90° 1

Synchrocheck mode SECRSYN 1 = Off2 = Synchronous3 = Asynchronous

Control mode SECRSYN 1 = Continuous2 = Command

Dead line value SECRSYN 0.1...0.8 × Un 0.1

Live line value SECRSYN 0.2...1.0 × Un 0.1

Close pulse SECRSYN 200...60000 ms 10

Max energizing V SECRSYN 0.50...1.15 × Un 0.01

Phase shift SECRSYN -180...180° 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

Table 74. Automatic transfer switch (ATSABTC)


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

Table 75. Automatic transfer switch (ATSABTC) main settings


Operation ATSABTC 1=on5=off

Main bus priority ATSABTC 1=Bus 12=Bus 2

Operate delay CB tr ATSABTC 0...120000 ms 10 ms

Transfer dead time ATSABTC 0...120000 ms 10 ms

Reconnection delay ATSABTC 0...300000 ms 10 ms


ABB 43

Measurement functions

Table 76. 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 77. Current sequence components (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 78. 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 79. Voltage sequence components (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 80. 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



44 ABB

Table 81. Three-phase power and energy (PEMMXU)


Operation accuracy At all three currents in range 0.10…1.20 × InAt all three voltages in range 0.50…1.15 × 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 82. Frequency measurement (FMMXU)


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


ABB 45

Supervision functions

Table 83. Fuse failure supervision (SEQRFUF)


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 84. Motor run time counter (MDSOPT)

Description Value

Motor run-time measurement accuracy1) ±0.5%

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

Table 85. Voltage presence (PHSVPR)




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

Table 86. Voltage presence (PHSVPR) main settings


Num of phases PHSVPR 1=1 out of 32=2 out of 33=3 out of 3

V live value PHSVPR 0.2...1.0 × Un 0.1

V live time PHSVPR 40...10000 ms 1 ms

V dead value PHSVPR 0.1...0.8 × Un 0.1

V dead time PHSVPR 40...10000 ms 1 ms


46 ABB

20. Local HMIThe relay is available with two optional displays, a large oneand a small one. The large display is suited for relayinstallations where the front panel user interface is frequentlyused and a single line diagram is required. The small displayis suited for remotely controlled substations where the relay isonly occasionally accessed locally via the front panel userinterface.

Both LCD displays offer front-panel user interfacefunctionality with menu navigation and menu views. However,the large display offers increased front-panel usability withless menu scrolling and improved information overview. Inaddition, the large display includes a user-configurable singleline diagram (SLD) with position indication for the associatedprimary equipment. Depending on the chosen standardconfiguration, the relay displays the related measuring values,

apart from the default single line diagram. The SLD view canalso be accessed using the Web browser-based userinterface. The default SLD can be modified according to userrequirements by using the Graphical Display Editor inPCM600.

The local HMI includes a push button (L/R) for local/remoteoperation of the relay. When the relay is in the local mode, itcan be operated only by using the local front panel userinterface. When the relay is in the remote mode, it canexecute commands sent from a remote location. The relaysupports the remote selection of local/remote mode via abinary input. This feature facilitates, for example, the use ofan external switch at the substation to ensure that all relaysare in the local mode during maintenance work and that thecircuit breakers cannot be operated remotely from thenetwork control center.

IECA070904 V3 EN

Figure 9. Small display

IECA070901 V3 EN

Figure 10. Large display

Table 87. Small display

Character size1) Rows in the view Characters per row

Small, mono-spaced (6x12 pixels) 5 20

Large, variable width (13x14 pixels) 4 8 or more

1) Depending on the selected language

Table 88. Large display

Character size1) Rows in the view Characters per row

Small, mono-spaced (6x12 pixels) 10 20

Large, variable width (13x14 pixels) 8 8 or more

1) Depending on the selected language


ABB 47

21. 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 casescan also 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.

Mounting methods:

• Flush mounting• Semi-flush mounting• Semi-flush mounting in a 25° tilt• Rack mounting• Wall mounting• Mounting to a 19" equipment frame

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 11. Flush mounting

98

177

160

186

103

IECA070903 V4 EN

Figure 12. Semi-flush mounting

230

107

25°

133

190

IECA070902 V4 EN

Figure 13. Semi-flush with a 25º tilt

22. Relay case and plug-in unitFor safety reasons, the relay cases for current measuringrelays are provided with automatically operating contacts forshort-circuiting the CT secondary circuits when a relay unit iswithdrawn from its case. The relay case is further providedwith a mechanical coding system preventing currentmeasuring relay units from being inserted into a relay case for

a voltage measuring relay unit and vice versa, that is, therelay cases are assigned to a certain type of plug-in unit.

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

24. Accessories and ordering data

Table 89. 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


48 ABB

http://search.abb.com/library/Download.aspx?DocumentID=1MRS758059&LanguageCode=en&Action=Launch

25. ToolsThe relay is delivered as a pre-configured unit. The defaultparameter setting values can be changed from the front-paneluser interface, the Web browser-based user interface (WebHMI) or the PCM600 tool in combination with the relay-specific connectivity package.

The Protection and Control IED Manager PCM600 offersextensive relay configuration functions such as relay 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, therelay can be accessed either locally or remotely, using a Webbrowser (Internet Explorer). For security reasons, the Web

browser-based user interface is disabled by default. Theinterface can be enabled with PCM600 or via the front paneluser interface. The functionality of the interface can be limitedto read-only access through PCM600.

The relay connectivity package is a collection of software andspecific relay information, which enable system products andtools to connect and interact with the relay. The connectivitypackages reduce the risk of errors in system integration,minimizing device configuration and set-up times. Further, theconnectivity packages for this product series relays include aflexible update tool for adding one additional local HMIlanguage to the relay. The update tool is activated usingPCM600, and it enables multiple updates of the additionalHMI language, thus offering flexible means for possible futurelanguage updates.

Table 90. Tools

Configuration and setting tools Version

PCM600 2.6 or later

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

REC615 Connectivity Package 1.1 or later


ABB 49

Table 91. 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 (communicationmanagement) - ●

DNP3 communication configuration (communicationmanagement) - ●

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

IEC 60870-5-101/104 communication configuration(communication management) - ●

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(communication configuration) - ●

Phasor diagram viewing ● -

Event viewing ● ●

Saving of event data on the user's PC ● -

Online monitoring - ●● = Supported


50 ABB

26. Connection diagrams

REC615

16

17

1918

X100

67

8910

111213

15

14

2

1

3

45

22

212324

SO2

TCS2

PO4

SO1

TCS1

PO3

PO2

PO1

IRF

+

-Uaux

20

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

X110

34

56

7

89

10BI 6

BI 5

BI 4

BI 3

BI 2

BI 8

BI 712

13

11

BI 112

X13012

3

45

6BI 4

BI 3

BI 2

BI 1

BI 6

BI 58

9

7

1)

2)

X120

1

23

4567

89

1011

12

14Io

IL1

IL2

IL3

1/5A

N1/5A

N1/5A

N0.2/1A

N

13

U1

U2

U360 -

N

210V

60 -

N

210V

60 -

N

210V

L1L2L3

S1

S2

P1

P2

P2

P1 S1

S2

PositiveCurrentDirection

1)

X110

16

14

15

19

17

18

22

20

21

SO3

23SO4

24

SO1

SO2

X130

12

10

11

15

13

14

18

16

17

SO3

SO1

SO2

a n N A

GUID-193798C8-FA4C-424B-B5C8-1697646E2059 V2 EN

Figure 14. Connection diagram for the A configuration


ABB 51

REC615

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

1) The relay features an automatic short-circuit mechanism in the CT connector when plug-in unit is detached

X110

34

56

7

89

10BI 6

BI 5

BI 4

BI 3

BI 2

BI 8

BI 712

13

11

BI 112

1)

X120

12

3

4

567

89

1011

12

14Io

IL1

IL2

BI 4

BI 3

BI 2

BI 1

IL3

1/5A

N1/5A

N1/5A

N0.2/1A

N

13

L1L2L3

S1

S2

P1

P2


X13012

3

45

6

87

9101112

13

1415

16

1718

No Connection

U1

U2

U3

U1B

U2B

U3B

No Connection

X110

16

14

15

19

17

18

22

20

21

SO3

23SO4

24

SO1

SO2

GUID-6F4E9EF0-E1A3-496E-8CCC-2799E80CCBF2 V2 EN

Figure 15. Connection diagram for the B configuration


52 ABB

REC615

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

X130

12

X131

45

IL1

78

U1

X132

45

IL2

78

U2

X133

45

IL3

78

U3

Io0.2/1A

N

P2

P1 S1

S2


I

I

I

L1L2L3

X110

16

14

15

19

17

18

22

20

21

SO3

23SO4

24

SO1

SO2

GUID-044DC636-26E9-483A-B255-D7FC2A4815C5 V1 EN

Figure 16. Connection diagram for the C configuration

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

You will find the latest relevant information on the REC615protection and control relay on the product page.

28. Functions, codes and symbolsAll available functions are listed in the table. All of them maynot be applicable to all products.


ABB 53

HTTP://WWW.ABB.COM/SUBSTATIONAUTOMATION

http://new.abb.com/medium-voltage/distribution-automation/grid-automation/remote-monitoring-and-control-rec615

Table 92. Functions included in the relay

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,high stage, instance 1 PHHPTOC1 3I>> (1) 51P-2 (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, lowstage, instance 2 DPHLPDOC2 3I> -> (2) 67-1 (2)

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

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, low stage, instance 2 DEFLPDEF2 Io> -> (2) 67N-1 (2)

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

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

Admittance based earth-fault protection, instance 1 EFPADM1 Yo> -> (1) 21YN (1)



Wattmetric based earth-fault protection, instance 1 WPWDE1 Po> -> (1) 32N (1)



Harmonics based earth-fault protection, instance 1 HAEFPTOC1 Io>HA (1) 51NHA (1)

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

Negative-sequence overcurrent protection, instance 2 NSPTOC2 I2> (2) 46 (2)

Phase discontinuity protection, instance 1 PDNSPTOC1 I2/I1> (1) 46PD (1)

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

Residual overvoltage protection, instance 2 ROVPTOV2 Uo> (2) 59G (2)

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



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




54 ABB

Table 92. Functions included in the relay, continued


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

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

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

Frequency protection, instance 2 FRPFRQ2 f>/f<,df/dt (2) 81 (2)

Three-phase thermal protection for feeders, cablesand distribution transformers, instance 1 T1PTTR1 3Ith>F (1) 49F (1)

Three-phase inrush detector, instance 1 INRPHAR1 3I2f> (1) 68 (1)

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

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

Multi-purpose protection, instance 1 MAPGAPC1 MAP (1) MAP (1)






Load shedding and restoration, instance 1 LSHDPFRQ1 UFLS/R (1) 81LSH (1)

Fault locator, instance 1 SCEFRFLO1 FLOC (1) 21FL (1)

Power quality

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

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

Voltage variation, instance 1 PHQVVR1 PQMU (1) PQMV (1)

Voltage unbalance, instance 1 VSQVUB1 PQUUB (1) PQVUB (1)

Control

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

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








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







ABB 55





Autoreclosing, instance 1 DARREC1 O -> I (1) 79 (1)

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

Automatic transfer switch, instance 1 ATSABTC1 ATSABTC (1) ATSABTC (1)

Condition monitoring and supervision

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

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

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

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

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

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

Voltage presence, instance 1 PHSVPR1 PHSVPR(1) PHSVPR(1)

Voltage presence, instance 2 PHSVPR2 PHSVPR(2) PHSVPR(2)

Measurement

Disturbance recorder, instance 1 RDRE1 DR (1) DFR (1)

Three-phase current measurement, instance 1 CMMXU1 3I (1) 3I (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, instance 1 VMMXU1 3U (1) 3V (1)

Three-phase voltage measurement, instance 2 VMMXU2 3U (B) (1) 3V (B) (1)

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

Sequence voltage measurement, instance 2 VSMSQI2 U1, U2, U0 (B) (1) V1, V2, V0 (B) (1)

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

Frequency measurement, instance 1 FMMXU1 f (1) f (1)

Load profile, instance 1 LDPMSTA1 LOADPROF (1) LOADPROF (1)

Other

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

Minimum pulse timer (2 pcs), instance 2 TPGAPC2 TP (2) TP (2)

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

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

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 off (8 pcs), instance 2 TOFGAPC2 TOF (2) TOF (2)

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


56 ABB



Time delay on (8 pcs), instance 2 TONGAPC2 TON (2) TON (2)

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

Set reset (8 pcs), instance 2 SRGAPC2 SR (2) SR (2)

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








Generic control point (16 pcs), instance 1 SPCGGIO1 SPCGGIO (1) SPCGGIO (1)

Generic control point (16 pcs), instance 2 SPCGGIO2 SPCGGIO (2) SPCGGIO (2)

Remote generic control points, instance 1 SPCRGGIO1 SPCRGGIO (1) SPCRGGIO (1)

Local generic control points, instance 1 SPCLGGIO1 SPCLGGIO (1) SPCLGGIO (1)

Generic up-down counters, instance 1 UDFCNT1 UDCNT (1) UDCNT (1)



Analog value scaling function, instance 1 SCA4GAPC1 SCA4 (1) SCA4 (1)












Integer value moving function , instance 1 MVI4GAPC1 MVI4 (1) MVI4 (1)

Integer value moving function , instance 2 MVI4GAPC2 MVI4 (2) MVI4 (2)


ABB 57

29. Document revision history

Document revision/date Product version History

A/2013-09-17 1.0 First release

B/2013-11-15 1.0 Content updated

C/2015-03-06 1.1 Content updated to correspond to the product version


58 ABB

Contact us

ABB OyMedium Voltage Products,Distribution AutomationP.O. Box 699FI-65101 VAASA, FinlandPhone +358 10 22 11Fax +358 10 22 41094

www.abb.com/substationautomation

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Grid Automation Remote Monitoring and Control … Automation Remote Monitoring and Control REC615...

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