product guide reg615 protection generator and interconnection · reg615 is a dedicated generator...

—RELION® 615 SERIES

Generator and InterconnectionProtectionREG615Product Guide

Contents

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

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

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

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

5. Supported ABB solutions............................................. 15

6. Control......................................................................... 16

7. Measurements............................................................. 17

8. Power quality................................................................17

9. Disturbance recorder....................................................17

10. Event log..................................................................... 17

11. Recorded data............................................................ 18

12. Condition monitoring .................................................. 18

13. Trip-circuit supervision.................................................18

14. Self-supervision...........................................................19

15. Fuse failure supervision............................................... 19

16. Access control............................................................ 19

17. Inputs and outputs...................................................... 19

18. Station communication................................................20

19. Technical data.............................................................25

20. Local HMI....................................................................61

21. Mounting methods...................................................... 62

22. Relay case and plug-in unit......................................... 62

23. Selection and ordering data.........................................62

24. Accessories and ordering data.................................... 63

25. Tools...........................................................................64

26. Cyber security............................................................. 65

27. Terminal diagrams.......................................................66

28. Certificates.................................................................. 69

29. References..................................................................69

30. Functions, codes and symbols.................................... 70

31. Document revision history........................................... 74

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 2018 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.

Generator and Interconnection Protection 1MRS758279 CREG615 Product version: 5.0 FP1

2 ABB

1. DescriptionREG615 is a dedicated generator and interconnectionprotection relay designed for the different power generationapplications. REG615 is available in three standardconfigurations denoted A, C and D. Standard configuration A isintended for the interconnection protection, control,measurement and supervision of the common point of couplingdistributed power generation into the utility network. Standardconfigurations C and D are designed for the protection, control,measurement and supervision of small or medium sizegenerators used in diesel, gas, hydroelectric, combined heatand power (CHP), and steam power plants. REG615 is a

member of ABB’s Relion® product family and part of its 615protection and control product series. The 615 seriesprotection relays are characterized by their compactness andwithdrawable unit design.

Re-engineered from the ground up, the 615 series has beendesigned to unleash the full potential of the IEC 61850 standardfor communication and interoperability between substationautomation devices. Once the standard configuration relay hasbeen given the application-specific settings, it can directly beput into service.

The generator protection relay provides main protection forsmall size power generators. The generator protection relay isalso used as back-up protection for medium size generators inpower applications, where an independent and redundantprotection system is required. The interconnection protectionrelay provides main protection fulfilling the grid codes toconnect distributed generation with the power grid.

The 615 series relays support a range of communicationprotocols including IEC 61850 with Edition 2 support, processbus according to IEC 61850-9-2 LE, IEC 60870-5-103,

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

2. Standard configurationsREG615 is available with three alternative standardconfigurations. The standard signal configuration can bealtered by means of the signal matrix or the graphicalapplication functionality of the Protection and Control IEDManager PCM600. Further, the application configurationfunctionality of PCM600 supports the creation of multi-layerlogic functions using various logical elements, including timersand flip-flops. By combining protection functions with logicfunction blocks, the relay configuration can be adapted to user-specific application requirements.

The protection relay is delivered from the factory with defaultconnections described in the functional diagrams for binaryinputs, binary outputs, function-to-function connections andalarm LEDs. Some of the supported functions in REG615 mustbe added with the Application Configuration tool to be availablein the Signal Matrix tool and in the relay. The positive measuringdirection of directional protection functions is towards thebusbar.

Generator and Interconnection Protection 1MRS758279 CREG615 Product version: 5.0 FP1 Issued: 2018-12-20

Revision: C

ABB 3

Io>>51N-2

ARC50L/50NL

Uo>59G

3Ith>F49F

3I>>>50P/51P

3I2f>68

I2>46

3I>/Io>BF51BF/51NBF

3I>>→67-2

3I>→67-1

TCSTCM

OPTSOPTM

2×MCS 3IMCS 3I

FUSEF60

CBCMCBCM

INTERCONNECTION PROTECTION RELAY STANDARD CONFIGURATION

PROTECTION LOCAL HMI

RL

ClearESCI

O

Configuration ASystemHMITimeAuthorization

RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

IoIo

REG615 A

ALSO AVAILABLE

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

SNTP, IRIG-B- User management- Web HMI

U2>47O-

U1<47U+

3I

3IUL1, L2, L3

Io

3×

Q>→, 3U<32Q, 27

P>/Q>32R/32O

2×

2×

Master TripLockout relay

94/86

Io>IEF→67NIEF

Io>→67N-1

Io>>→67N-2

2×

2×

3U<27

3U>59

U<RT27RT

VS78V

f>/f<,df/dt81

2×

2×

2×2×

6×

3×

U12

Uo

U12

UL1, L2, L3

Io

2×RTD1×mA

MAPMAP

18×

3×


94/86

3×

2×

COMMUNICATION

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

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

CONDITION MONITORING AND SUPERVISION

ORAND

2×

Object Ctrl 2) Ind 3)

CB

DC

ES1) Check availability of binary inputs/outputs from technical documentationControl and indication function for primary objectStatus indication function forprimary object

2)

3)

CONTROL AND INDICATION 1) MEASUREMENT

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

4

5

Analog interface types 1)

Current transformer

Voltage transformer1) Conventional transformer inputs

1 -

2 3

1 2

SYNC25

PQM3UPQM3V

PQMUPQMV

PQM3IPQM3I

PQUUBPQVUB

REMARKS

Optionalfunction

No. ofinstances

Alternative function to be defined when ordering

OR

Io/Uo

Calculatedvalue

3×

UL1, L2, L3

Io

GUID-608806E0-EC45-49E7-BBBB-3FD20DD5D84C V1 EN

Figure 1. Functionality overview for standard configuration A


4 ABB

Uo

Io>→67N-1

Io>>→67N-2

2×

Uo>59G

2×Io>>

51N-2G

TCSTCM

OPTSOPTM

2×

FUSEF60

CBCMCBCM

GENERATOR PROTECTION RELAY STANDARD CONFIGURATION


RL

ClearESCI

O


RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

Io

REG615 C

ALSO AVAILABLE




COMMUNICATION



3I

UL1, L2, L3

Io


94/86

Uo

MEASUREMENT


4

5


Current transformer


PQM3UPQM3V

PQMUPQMV

PQM3IPQM3I

2×RTD1×mA

MAPMAP

18×

ORAND

dUo>/Uo3H27/59THD


94/86

U2>47O-

U1<47U+

3U<27

2× 2×2×

3U>59

f>/f<,df/dt81

2× 6×

U/f>24

3I

ARC50L/50NL

3I>>>50P/51P

3I2f>68

3I>/Io>BF51BF/51NBF

P>/Q>32R/32O

3×

3I>51P-1

3I>>51P-2

I2>M46M

X<40

P<32U

2×3×

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

3I(U)>51V

Z<G21G

3×

∆IoIo

UL1, L2, L3

EXC.AVR

CONTROL AND INDICATION 1)


CB

DC


2)

3)

1 -

2 3

1 2

REMARKS

Optionalfunction

No. ofinstances


OR

Io/Uo

Calculatedvalue

3×


94/86

3×2×

PQUUBPQVUB

2×

OOS78

GUID-1536B574-54F9-4C47-BD65-175410DFEE46 V2 EN

Figure 2. Functionality overview for standard configuration C


ABB 5

CONTROL AND INDICATION 1)


CB

DC


2)

3)

1 -

2 3

1 2

SYNC25

U12

UL1, L2, L3

3dl>G87G

Uo>59G

2×

ARC50L/50NL

3I>>>50P/51P

3I2f>68

3I>/Io>BF51BF/51NBF

P>/Q>32R/32O

3×

3I>51P-1

3I>>51P-2

I2>M46M

X<40

P<32U

2×

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

3I(U)>51V

Io>>51N-2

G

GENERATOR PROTECTION RELAY STANDARD CONFIGURATION


RL

ClearESCI

O


RL

ClearESCI

O

U12 0. 0 kVP 0.00 kWQ 0.00 kVAr

IL2 0 A

A

Io

REMARKS

Optionalfunction

No. ofinstances


OR

Io/Uo

Calculatedvalue

3×

REG615 D

ALSO AVAILABLE



TCSTCM

OPTSOPTM

2×

FUSEF60

CBCMCBCM


COMMUNICATION



3I

3I

UL1, L2, L3

Io


94/86

Io>→67N-1

Io>>→67N-2

2×

U12

Uo

MEASUREMENT


7

5


Current transformer


PQM3UPQM3V

PQMUPQMV

PQM3IPQM3I

2×RTD1×mA

MAPMAP

18×

3×

ORAND

3I>→67-1

3I>>→67-2

U2>47O-

U1<47U+

3U<27

2× 2×2×

3U>59

f>/f<,df/dt81

2×

U/f>24

3I

∆Io

Io

UL1, L2, L3

EXC.AVR

2×


94/86


94/86

3×2×

PQUUBPQVUB

4×

2×

OOS78

GUID-309F67A9-5199-4215-95A7-7703EE262635 V2 EN

Figure 3. Functionality overview for standard configuration D

Table 1. Standard configurations

Description Std. conf.

Interconnection protection for distributed power generation A

Generator protection with 100% stator earth-fault protection C

Generator protection with generator differential and directional overcurrent protection and synchro-check D


6 ABB

Table 2. Supported functions

Function IEC 61850 A C D

Protection Three-phase non-directional overcurrent protection, low stage PHLPTOC 1 1Three-phase non-directional overcurrent protection, high stage PHHPTOC 1 1Three-phase non-directional overcurrent protection, instantaneous stage PHIPTOC 1 1 1Three-phase directional overcurrent protection, low stage DPHLPDOC 2 1 TR

Three-phase directional overcurrent protection, high stage DPHHPDOC 1 1 TR

Three-phase voltage-dependent overcurrent protection PHPVOC 1 1Non-directional earth-fault protection, high stage EFHPTOC 1 1 1Directional earth-fault protection, low stage DEFLPDEF 2 2 2Directional earth-fault protection, high stage DEFHPDEF 1 1 1Transient/intermittent earth-fault protection INTRPTEF 1 1)

Negative-sequence overcurrent protection NSPTOC 2 Negative-sequence overcurrent protection for machines MNSPTOC 2 2Residual overvoltage protection ROVPTOV 2 2 2Three-phase undervoltage protection PHPTUV 2 2 2Three-phase overvoltage protection PHPTOV 2 2 2Positive-sequence undervoltage protection PSPTUV 2 2 2Negative-sequence overvoltage protection NSPTOV 2 2 2Frequency protection FRPFRQ 6 6 4Overexcitation protection OEPVPH 1 1Three-phase thermal protection for feeders, cables and distributiontransformers

T1PTTR 1

Three-phase thermal overload protection, two time constants T2PTTR 1 1Circuit breaker failure protection CCBRBRF 1 1 2) 1 2)

Three-phase inrush detector INRPHAR 1 1 1Master trip TRPPTRC 2

(3) 3)3(3) 3)

3(3) 3)

Arc protection ARCSARC (3) (3) 2) (3) 2)

Multipurpose protection MAPGAPC 18 18 18Stabilized and instantaneous differential protection for machines MPDIF 1Third harmonic-based stator earth-fault protection H3EFPSEF 1 Underpower protection DUPPDPR 2 2Reverse power/directional overpower protection DOPPDPR 2 3 2Three-phase underexcitation protection UEXPDIS 1 1Three-phase underimpedance protection UZPDIS 1 Out-of-step protection OOSRPSB 1 1Interconnection functionsDirectional reactive power undervoltage protection DQPTUV 1 Low-voltage ride-through protection LVRTPTUV 3 Voltage vector shift protection VVSPPAM 1 Power qualityCurrent total demand distortion CMHAI (1) 4) (1) 4) (1) 4)

Voltage total harmonic distortion VMHAI (1) 4) (1) 4) (1) 4)

Voltage variation PHQVVR (1) 4) (1) 4) (1) 4)

Voltage unbalance VSQVUB (1) 4) (1) 4) (1) 4)

ControlCircuit-breaker control CBXCBR 1 1 1Disconnector control DCXSWI 2 2 2Earthing switch control ESXSWI 1 1 1Disconnector position indication DCSXSWI 3 3 3Earthing switch indication ESSXSWI 2 2 2Synchronism and energizing check SECRSYN 1 1Condition monitoring and supervisionCircuit-breaker condition monitoring SSCBR 1 1 1Trip circuit supervision TCSSCBR 2 2 2


ABB 7

Table 2. Supported functions, continuedFunction IEC 61850 A C D

Current circuit supervision CCSPVC 1 Fuse failure supervision SEQSPVC 1 1 1Runtime counter for machines and devices MDSOPT 1 1 1MeasurementDisturbance recorder RDRE 1 1 1Load profile record LDPRLRC 1 1 1Fault record FLTRFRC 1 1 1Three-phase current measurement CMMXU 1 1 2Sequence current measurement CSMSQI 1 1 1Residual current measurement RESCMMXU 1 1 1Three-phase voltage measurement VMMXU 2 1 2Residual voltage measurement RESVMMXU 1 2 1Sequence voltage measurement VSMSQI 1 1 1Three-phase power and energy measurement PEMMXU 1 1 1RTD/mA measurement XRGGIO130 (1) (1) (1)Frequency measurement FMMXU 1 1 1

IEC 61850-9-2 LE sampled value sending 5)6) SMVSENDER (1) (1) (1)

IEC 61850-9-2 LE sampled value receiving (voltage sharing) 5)6) SMVRCV (1) (1) (1)

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

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

connected in the configuration to the corresponding master trip input.4) Power quality option includes current total demand distortion, voltage total harmonic distortion, voltage variation and voltage unbalance.5) Available only with IEC 61850-9-26) Available only with COM0031...0037


8 ABB

3. Protection functionsThe generator protection relay offers protection functionality forsynchronous generators and their prime mover against internalfaults and abnormal conditions of external systems. The mainfeature in the standard configuration D is the differentialprotection. The main feature in the standard configuration C isthe 3rd harmonic-based stator earth-fault protectioncompleting the detection coverage with the other earth-faultprotection provided. The generator protection relay alsofeatures reverse power and directional overpower protectionagainst delivering excessive power beyond the generator'scapacity and against the generator running like a motor. Theunderpower protection protects generators and prime moversagainst the effects of very low power outputs. A dedicatedprotection function detects any loss of synchronism (out-of-step condition) between the generator and the rest of the powersystem. The generator relay also includes back-up overcurrentprotection featuring voltage dependent overcurrent and, in thestandard configuration D, directional overcurrent protectionand, in the standard configuration C, underimpedanceprotection. Overexcitation protection (U/f) protects thegenerators against excessive flux density. Underexcitation (X<)protects the synchronous machine against the underexcitationor loss of excitation condition. Frequency and voltage basedprotection, thermal overload and unbalance protection are alsoincluded in both standard configurations C and D intended forgenerator protection.

The relay for the interconnection point of the power grid anddistributed power generation is provided with the standardconfiguration A where the main features are low-voltage ride-through protection, directional reactive power undervoltageprotection (QU) and the voltage vector shift protection. Themain features of the interconnection relay can be used tosupport utility grid stability and to detect islanding. Theprotection allows the monitoring of distributed generationduring low-voltage or fault ride through to determine whether

and when to disconnect from the grid. The voltage vector shiftprotection detects islanding from the grid by measuringcontinuously the duration of the voltage cycle and it can befurther secured with the provided frequency and voltage basedprotection. Standard configuration A additionally offersdirectional overcurrent protection, directional earth-faultprotection and reverse power and directional overpowerprotection.

The RTD/mA inputs are offered as an option for the defaultconfiguration. They can be used with Multipurpose protectionfunction for tripping and alarm purposes. Multipurposeprotection function uses RTD/mA measuring data or analogvalues via GOOSE messages.

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

The arc-fault protection sensor interface is available on theoptional communication module. Fast tripping increases staffsafety and security and limits material damage in an arc faultsituation. A binary input and output module can be selected asan option - having three high speed binary outputs (HSO) itfurther decreases the total operate time with typically 4...6 mscompared to the normal power outputs.

4. ApplicationStandard configuration A is intended to be used in the commonpoint of coupling distributed power generation into the utilitynetwork. It ensures the grid stability and reliability according togiven grid codes and by determining whether and when todisconnect according to defined settings. A typical applicationexample of the distributed power generation is a wind powerplant or a solar power plant but it can also be a combined heatand power or hydroelectric power plant.


ABB 9

G G GG G

U12

3U

3I

Io

G

Common point of coupling distributed power generationinto the utility network

REG615

Std. conf.

ANSI IEC

25

27RT

32Q, 27

32R/32O

47O-/59

47U+/27

50L/50NL

60

78V

81

SYNC

U<RT

Q>→, 3U<

P>/Q>

U2>/3U>

U1</3U<

ARC

FUSEF

VS

f</f>, df/dt

A

GUID-FC594C90-D99A-4D1B-89FE-089A640794E4 V1 EN

Figure 4. Application example of wind power plant as distributed power generation coupled into the utility network

Standard configuration A is not designed for using all theavailable functionality content in one relay at the same time.Directional earth-fault protection functions must be added with

the Application Configuration tool. In order to ensure theperformance of the relay, the user specific configuration load isverified with the Application Configuration tool in PCM600.


10 ABB

REG615

Std. conf.

ANSI IEC

25

27RT

32Q, 27

32R/32O

47O-/59

47U+/27

50L/50NL

60

78V

81

SYNC

U<RT

Q>→, 3U<

P>/Q>

U2>/3U>

U1</3U<

ARC

FUSEF

VS

f</f>, df/dt

A

U12

3U

3I

Io

Common point of coupling distributed power generationinto the utility network

G

GUID-B99D5D42-A515-43E9-8F1C-74131A760E33 V1 EN

Figure 5. Application example of combined heat and power/hydro power plant as distributed power generation coupled into the utility network

Standard configurations C and D are intended to be used insynchronous power generator application where the protectioncoverage is a generator, field excitation system and primarymover. A typical application example is parallel connecteddiesel or gas generators with a common step-up transformerbut it can also be a generator in block connection with atransformer. In medium-size power generator applications

independent and redundant protection system can be arequirement or the protection system as a whole may requiremore than one protection relay in one set-up. Variousrecognized earthing principles exist and typically earthingselection depends on the complete system requirements wherethe generator is located. The earth-fault protection dependsmainly on the used earthing principle.


ABB 11

REG615

Std. conf.

ANSI IEC

40

32R/32O

32U

46M

47O-/59

47U+/27

49T/G/C

51P-1/51P-2

51V

59G

60

67N-1/67N-2

81

X<

P>/Q>

P<

I2>M

U2>/3U>

U1</3U<

3Ith>T/G/C

3I>/3I>>

3I(U)>

Uo>

FUSEF

Io>→/Io>>→

f>/f<, df/dt

C

REG615

Std. conf.

ANSI IEC

40

32R/32O

32U

46M

47O-/59

47U+/27

49T/G/C

51P-1/51P-2

51V

59G

60

67N-1/67N-2

81

X<

P>/Q>

P<

I2>M

U2>/3U>

U1</3U<

3Ith>T/G/C

3I>/3I>>

3I(U)>

Uo>

FUSEF

Io>→/Io>>→f>/f<, df/dt

C

3U

3I

Io

G

Uo

Io

3U

3I

Io

G

Uo

Io

GUID-FA8F2E27-11C7-4B88-8865-414DFB0D71F3 V1 EN

Figure 6. Application example for parallel with common step-up transformer connected Diesel/Gas generators protected with standardconfiguration C

Figure 6 illustrates several generator units connected in parallel.Each unit is individually high resistance earthed. Earth-faultcurrent is small, typically 3...5 A.


12 ABB

REG615

Std. conf.

ANSI IEC

49T/G/C

51BF/51NBF

51P-1/51P-2

51V

59G

60

67-1/67-2

87G

MAP

3Ith>T/G/C

3I>/Io>BF

3I>/3I>>

3I(U)>

Uo>

FUSEF

3I>→/3I>>→

3dI>G

MAP

D

REG615

Std. conf.

ANSI IEC

21G

27/59THD

32R/32O

32U

40

46M

47O-/59

47U+/27

49T/G/C

51BF/51NBF

51P-1/51P-2

51V

60

67N-1/67N-2

81

Z<G

dUo>/Uo3H

P>/Q>

P<

X<

I2>M

U2>/3U>

U1</3U<

3Ith>T/G/C

3I>/Io>BF

3I>/3I>>

3I(U)>

FUSEF

Io>→/Io>>→

f>/f<, df/dt

C

3U

3I

Io

G

Uo

Uo

Io

3IRTD

3I

GUID-D955F7DE-7A8E-4C73-BBD9-BD81F95A4414 V1 EN

Figure 7. Medium-sized generator protection application example with standard configuration C and D

In Figure 7 protection is implemented with two REG615generator protection relays. One REG615 takes care of thegenerator protection with 100% stator earth-fault protectionand the other REG615 provides the generator differentialprotection.

Standard configuration D is not designed for using all theavailable functionality content in one relay at the same time.

Three-phase directional overcurrent protection, three-phasevoltage protection, positive-sequence and negative-sequencevoltage protection functions must be added with theApplication Configuration tool. In order to ensure theperformance of the relay, the user specific configuration load isverified with the Application Configuration tool in PCM600.


ABB 13

RET615

Std. conf.

ANSI IEC

51BF/51NBF

51P-1/51P-2

87NL

87T

MAP

3I>/Io>BF

3I>/3I>>

dIoLo>

3dI>T

MAP

A

REG615

Std. conf.

ANSI IEC

21G

24

32R/32O

32U

40

46M

47O-/59

47U+/27

49T/G/C

51BF/51NBF

51P-1/51P-2

51V

59G

60

81

MAP

Z<G

U/f>

P>/Q>

P<

X<

I2>M

U2>/3U>

U1</3U<

3Ith>T/G/C

3I>/Io>BF

3I>/3I>>

3I(U)>

Uo>

FUSEF

f>/f<, df/dt

MAP

C

3U

3I

G

Uo

3I (LV)

RTD

3I (HV)

RTD

Io (HV)

GUID-B27F8FE3-1001-412B-A46B-7257A90AC757 V2 EN

Figure 8. Medium-sized generator in block connection with a transformer protection application example with standard configuration C andRET615

In Figure 8 generator protection is implemented with REG615generator protection relay. Transformer protection isimplemented with the RET615 transformer differentialprotection relay covering the generator in block connection with

a transformer. A single-phase voltage transformer is connectedto the generator neutral for the residual overvoltage protection.On the terminal side phase-to-earth voltages are connected tothe generator protection relay.


14 ABB

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

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

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

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

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

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

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

Table 3. Supported ABB solutions

Product Version

Substation Management Unit COM600S 4.0 SP1 or later

4.1 or later (Edition 2)

MicroSCADA Pro SYS 600 9.3 FP2 or later

9.4 or later (Edition 2)

System 800xA 5.1 or later


ABB 15

PCM600Ethernet switch

Utility: IEC 60870-5-104Industry: OPC

COM600SWeb HMI

ABBMicroSCADA Pro/

System 800xA

Analog and binary horizontal GOOSE communication IEC 61850

PCM600Ethernet switch

COM600SWeb HMI

Analog and binary horizontal GOOSE communication IEC 61850

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

Figure 9. ABB power system example using Relion relays, COM600S and MicroSCADA Pro/System 800xA

6. ControlREG615 integrates functionality for the control of a circuitbreaker via the front panel HMI or by means of remote controls.In addition to the circuit-breaker control the relay features twocontrol blocks which are intended for motor-operated control ofdisconnectors or circuit breaker truck and for their positionindications. Further, the relay offers one control block which isintended for motor-operated control of one earthing switchcontrol and its position indication.

Two physical binary inputs and two physical binary outputs areneeded in the relay for each controllable primary device takeninto use. By default, the circuit breaker closing is not connectedin the generator protection relay's standard configurations asthe generator circuit breaker is typically closed by an externalsynchronizer. Depending on the chosen standard configurationof the relay the number of unused binary inputs and binaryoutputs varies. Further, some standard configurations also offeroptional hardware modules that increase the number ofavailable binary inputs and outputs.

If the amount of available binary inputs or outputs of the chosenstandard configuration is not sufficient, the standardconfiguration can be modified to release some binary inputs oroutputs which have originally been configured for otherpurposes, when applicable, or an external input or outputmodule, for example, RIO600 can be integrated to the relay.The binary inputs and outputs of the external I/O module can beused for the less time critical binary signals of the application.The integration enables releasing of some initially reservedbinary inputs and outputs of the relay in the standardconfiguration.

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

The optional large graphical LCD of the relay's local HMIincludes a single-line diagram (SLD) with position indication for


16 ABB

the relevant primary devices. Interlocking schemes required bythe application are configured using the signal matrix or theapplication configuration functionality of PCM600. Dependingon the standard configuration, the relay also incorporates asynchrocheck function to ensure that the voltage, phase angleand frequency on either side of an open circuit breaker satisfythe conditions for safe interconnection of two networks.

7. MeasurementsThe relay continuously measures the phase currents andvoltages, the symmetrical components of the currents andvoltages and the residual current and voltage. The relay alsocalculates the demand value of the current over a user-selectable, preset time frame, the thermal overload of theprotected object, and the phase unbalance based on the ratiobetween the negative-sequence and positive-sequencecurrent. Furthermore, the relay offers three-phase power andenergy measurement including power factor.

The generator and interconnection relay is provided withfrequency adaptability support that can be enabled with asetting parameter. Frequency adaptability enables protectionand measurement operation over a wide frequency range of0.2...1.4 × Fn by using three phase-voltage inputs to track thenetwork frequency.

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

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

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

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

The protection relay has the following power quality monitoringfunctions.

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

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

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

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

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

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

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

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


ABB 17

11. Recorded dataThe relay has the capacity to store the records of the 128 latestfault events. The records can be used to analyze the powersystem events. Each record includes, for example, current,voltage and angle values and a time stamp. The fault recordingcan be triggered by the start or the trip signal of a protection

block, or by both. The available measurement modes includeDFT, RMS and peak-to-peak. Fault records store relaymeasurement values at the moment when any protectionfunction starts. In addition, the maximum demand current withtime stamp is separately recorded. The records are stored inthe non-volatile memory.

1024

PROCESS LEVELUSER LEVEL

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

BASI

C F

UN

CTI

ON

S

IEC

618

50-8

-1M

odbu

sIE

C 1

03D

NP3

LHM

IW

HM

IPC

M60

0 Process events (FIFO)

128

Fault records (FIFO)

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

2048

Audittrailevents(FIFO)

n…100

Disturbance records

...7 yrs

Load profile record

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

Function specific data

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

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

Figure 10. Recording and event capabilities overview

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

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

In addition, the relay includes a runtime counter for monitoringof how many hours a protected device has been in operationthus enabling scheduling of time-based preventivemaintenance of the device.

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


18 ABB

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

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

15. Fuse failure 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 to maintaininformation integrity, the relay is provided with a four-level, role-based authentication system with administrator-programmableindividual passwords for the viewer, operator, engineer andadministrator levels. The access control applies to the localHMI, the Web HMI and PCM600.

17. Inputs and outputsDepending on the standard configuration selected, the relay isequipped either with three or six phase-current inputs and one

residual current input, three phase-voltage inputs and oneresidual voltage input, and one voltage input that is used eitherfor synchro-check or for the 3rd harmonic-based stator earth-fault protection depending on the standard configuration.

The phase-current inputs are rated 1/5 A. Two optionalresidual-current inputs are available, that is, 1/5 A or 0.2/1 A.The 0.2/1 A input is normally used in applications requiringsensitive earth-fault protection and featuring core-balancecurrent transformers. The three phase-voltage inputs and theresidual-voltage input covers the rated voltages 60...210 V.Both phase-to-phase voltages and phase-to-earth voltagescan be connected.

The phase-current input 1 A or 5 A, the residual-current input 1A or 5 A, alternatively 0.2 A or 1 A, and the rated voltage of theresidual voltage input are selected in the relay software. Inaddition, the binary input thresholds 16…176 V DC are selectedby adjusting the relay’s parameter settings.

All binary input and output contacts are freely configurable withthe signal matrix or application configuration functionality ofPCM600.

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

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


ABB 19

Table 4. Input/output overview

Std. conf. Order code digit Analog channels Binary channels

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

A

AE / AF

AG 4 5 16 4 PO + 6 SO - -

FC 4 5 16 4 PO + 2 SO+ 3 HSO

- -

FE / FF

AD 4 5 12 4 PO + 6 SO 2 1

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

2 1

C

AE / AF

AG 4 5 16 4 PO + 6 SO - -

FC 4 5 16 4 PO + 2 SO+ 3 HSO

- -

FE / FF

AD 4 5 12 4 PO + 6 SO 2 1

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

2 1

D

BC / BD

AD 7 5 12 4 PO + 6 SO - -

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

- -

BE / BF

BA 7 5 8 4 PO + 6 SO 2 1

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

2 1

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

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

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

The IEC 61850 communication implementation supportsmonitoring and control functions. Additionally, parametersettings, disturbance recordings and fault records can beaccessed using the IEC 61850 protocol. Disturbancerecordings are available to any Ethernet-based application inthe standard COMTRADE file format. The relay supports

simultaneous event reporting to five different clients on thestation bus. The relay can exchange data with other devicesusing the IEC 61850 protocol.

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

The relay also supports IEC 61850 process bus by sendingsampled values of analog currents and voltages and byreceiving sampled values of voltages. With this functionality thegalvanic interpanel wiring can be replaced with Ethernetcommunication. The measured values are transferred assampled values using IEC 61850-9-2 LE protocol. The intendedapplication for sampled values shares the voltages to other 615series relays, having voltage based functions and 9-2 support.


20 ABB

615 relays with process bus based applications use IEEE 1588for high accuracy time synchronization.

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

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

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

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

Ethernet switchIEC 61850 PRPEthernet switch

SCADACOM600

GUID-334D26B1-C3BD-47B6-BD9D-2301190A5E9D V2 EN

Figure 11. Parallel redundancy protocol (PRP) solution

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

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


ABB 21

Ethernet switch

RedundancyBox

IEC 61850 HSR

RedundancyBox

RedundancyBox

REF615 REF620 RET620 REM620 REF615

SCADA Devices not supporting HSRCOM600

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

Figure 12. High availability seamless redundancy (HSR) solution

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

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

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


22 ABB

Managed Ethernet switchwith RSTP support

Managed Ethernet switchwith RSTP support

Client BClient A

Network ANetwork B

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

Figure 13. Self-healing Ethernet ring solution

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

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

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

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

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

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

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

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

Ethernet-based• SNTP (Simple Network Time Protocol)

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

Format B)


ABB 23

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

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

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

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

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

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

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

Table 5. Supported station communication interfaces and protocols

Interfaces/Protocols Ethernet Serial

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

IEC 61850-8-1 - -

IEC 61850-9-2 LE - -

MODBUS RTU/ASCII - -

MODBUS TCP/IP - -

DNP3 (serial) - -

DNP3 TCP/IP - -

IEC 60870-5-103 - - = Supported


24 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 protection relay 4.1 kg

Plug-in unit only 2.1 kg

Table 7. Power supply

Description Type 1 Type 2

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

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

Maximum interruption time in the auxiliary DCvoltage without resetting the relay

50 ms at Un

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

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

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

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

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

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

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

Fuse type T4A/250 V

Table 8. Energizing inputs

Description Value

Rated frequency 50/60 Hz

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

Thermal withstand capability:

• Continuously 4 A 20 A

• For 1 s 100 A 500 A

Dynamic current withstand:

• Half-wave value 250 A 1250 A

Input impedance <100 mΩ <20 mΩ

Voltage inputs Rated voltage 60...210 V AC

Voltage withstand:

• Continuous 240 V AC

• For 10 s 360 V AC

Burden at rated voltage <0.05 VA

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


ABB 25

Table 9. Binary inputs

Description Value

Operating range ±20% of the rated voltage

Rated voltage 24...250 V DC

Current drain 1.6...1.9 mA

Power consumption 31.0...570.0 mW

Threshold voltage 16...176 V DC

Reaction time <3 ms

Table 10. RTD/mA measurement (XRGGIO130)

Description Value

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

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

Supported resistance range 0...2 kΩ

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

Isolation 2 kV (inputs to protective earth)

Response time <4 s

RTD/resistance sensing current Maximum 0.33 mA rms

Operation accuracy Resistance Temperature

± 2.0% or ±1 Ω ±1°C10 Ω copper: ±2°C

mA inputs Supported current range 0…20 mA

Current input impedance 44 Ω ± 0.1%

Operation accuracy ±0.5% or ±0.01 mA

Table 11. Signal output X100: SO1

Description Value

Rated voltage 250 V AC/DC

Continuous contact carry 5 A

Make and carry for 3.0 s 15 A


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

1 A/0.25 A/0.15 A

Minimum contact load 100 mA at 24 V AC/DC


26 ABB

Table 12. Signal outputs and IRF output

Description Value




Make and carry 0.5 s 15 A


1 A/0.25 A/0.15 A


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

Description Value





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

5 A/3 A/1 A


Trip-circuit supervision (TCS):

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

• Current drain through the supervision circuit ~1.5 mA

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

Table 14. Single-pole power output relays

Description Value






5 A/3 A/1 A



ABB 27

Table 15. High-speed output HSO with BIO0007

Description Value





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

5 A/3 A/1 A

Operate time <1 ms

Reset <20 ms, resistive load

Table 16. Front port Ethernet interfaces

Ethernet interface Protocol Cable Data transfer rate

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

Table 17. IRIG-B

Description Value

IRIG time code format B004, B0051)

Isolation 500V 1 min

Modulation Unmodulated

Logic level 5 V TTL

Current consumption <4 mA

Power consumption <20 mW

1) According to the 200-04 IRIG standard

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

Description Value

Front side IP 54

Rear side, connection terminals IP 20

Table 19. Environmental conditions

Description Value

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

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

Relative humidity <93%, non-condensing

Atmospheric pressure 86...106 kPa

Altitude Up to 2000 m

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

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


28 ABB

Table 20. Electromagnetic compatibility tests

Description Type test value Reference

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

• Common mode 2.5 kV

• Differential mode 2.5 kV

3 MHz, 10 MHz and 30 MHz burst disturbancetest

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

• Common mode 2.5 kV

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

• Contact discharge 8 kV

• Air discharge 15 kV

Radio frequency interference test

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

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

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

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

10 V/mf = 900 MHz

ENV 50204IEC 60255-26, class III

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

IEEE C37.90.2-2004

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

• All ports 4 kV

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

• Communication 1 kV, line-to-earth

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

Power frequency (50 Hz) magnetic fieldimmunity test

IEC 61000-4-8

• Continuous• 1...3 s

300 A/m1000 A/m

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

IEC 61000-4-9

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

• 2 s 100 A/m

• 1 MHz 400 transients/s

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

IEC 61000-4-11


ABB 29

Table 20. Electromagnetic compatibility tests, continued


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

• Common mode 300 V rms

• Differential mode 150 V rms

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

IEC 61000-4-16

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

• Conducted

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

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

• Radiated

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

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

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

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

Table 21. Insulation tests


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

IEC 60255-27

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

IEC 60255-27

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

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

Table 22. Mechanical tests

Description Requirement Reference

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

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

Seismic test Class 2 IEC 60255-21-3


30 ABB

Table 23. Environmental tests


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

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

IEC 60068-2-1

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

IEC 60068-2-30

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

IEC60068-2-14

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

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

Table 24. Product safety

Description Reference

LV directive 2006/95/EC

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

Table 25. EMC compliance

Description Reference

EMC directive 2004/108/EC

Standard EN 60255-26 (2013)

Table 26. RoHS compliance

Description

Complies with RoHS directive 2002/95/EC


ABB 31

Protection functions

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

Characteristic Value

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

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

PHHPTOCandPHIPTOC

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

Start time 1)2) Minimum Typical Maximum

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

16 ms 11 ms

19 ms 12 ms

23 ms 14 ms

PHHPTOC and PHLPTOC:IFault = 2 × set Start value

23 ms

26 ms

29 ms

Reset time Typically 40 ms

Reset ratio Typically 0.96

Retardation time <30 ms

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

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

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

1) Set Operate delay time = 0,02 s, Operate curve type = IEC definite time, Measurement mode = default (depends on stage), current before fault = 0.0 × In, fn = 50 Hz, fault current in one phasewith nominal frequency injected from random phase angle, results based on statistical distribution of 1000 measurements

2) Includes the delay of the signal output contact3) Includes the delay of the heavy-duty output contact

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

Parameter Function Value (Range) Step

Start value PHLPTOC 0.05...5.00 × In 0.01

PHHPTOC 0.10...40.00 × In 0.01

PHIPTOC 1.00...40.00 × In 0.01

Time multiplier PHLPTOC and PHHPTOC 0.05...15.00 0.01

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

PHIPTOC 20...200000 ms 10

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

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

PHIPTOC Definite time

1) For further reference, see the Operation characteristics table


32 ABB

Table 29. 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 × UnPhase 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 × UnPhase angle: ±2°

Start time1)2) Minimum Typical Maximum

IFault = 2.0 × set Start value 39 ms 43 ms 47 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...20

Table 30. 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, see the Operating characteristics table


ABB 33

Table 31. Three-phase voltage-dependent overcurrent protection (PHPVOC)


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

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

Start time1)2) Typically 26 ms




Operate time accuracy in inverse time 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) Measurement mode = default, current before fault = 0.0 × In, 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 contact

Table 32. Three-phase voltage-dependent overcurrent protection (PHPVOC) main settings


Start value PHPVOC 0.05...5.00 × In 0.01

Start value low PHPVOC 0.05...1.00 × In 0.01

Voltage high limit PHPVOC 0.01...1.00 × Un 0.01

Voltage low limit PHPVOC 0.01...1.00 × Un 0.01

Start value Mult PHPVOC 0.8...10.0 0.1

Time multiplier PHPVOC 0.05...15.00 0.01

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

Operate delay time PHPVOC 40...200000 ms 10



34 ABB

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



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

EFHPTOCandEFIPTOC

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


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

16 ms11 ms

19 ms12 ms

23 ms14 ms

EFHPTOC and EFLPTOC:IFault = 2 × set Start value

23 ms

26 ms

29 ms






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

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

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

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


Start value EFLPTOC 0.010...5.000 × In 0.005

EFHPTOC 0.10...40.00 × In 0.01

EFIPTOC 1.00...40.00 × In 0.01

Time multiplier EFLPTOC and EFHPTOC 0.05...15.00 0.01

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

EFIPTOC 20...200000 ms 10

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

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

EFIPTOC Definite time



ABB 35

Table 35. Directional earth-fault protection (DEFxPDEF)



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

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


DEFHPDEFIFault = 2 × set Start value

42 ms

46 ms

49 ms

DEFLPDEFIFault = 2 × set Start value

58 ms 62 ms 66 ms






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

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

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


36 ABB

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


Start value DEFLPDEF 0.010...5.000 × In 0.005

DEFHPDEF 0.10...40.00 × In 0.01

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

-

Time multiplier DEFLPDEF 0.05...15.00 0.01

DEFHPDEF 0.05...15.00 0.01

Operate delay time DEFLPDEF 50...200000 ms 10

DEFHPDEF 40...200000 ms 10

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

DEFHPDEF Definite or inverse timeCurve type: 1, 3, 5, 15, 17

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

-

1) For further reference, see the Operating characteristics table

Table 37. 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 38. Transient/intermittent earth-fault protection (INTRPTEF) main settings


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

-

Operate delay time INTRPTEF 40...1200000 ms 10

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

Operation mode INTRPTEF 1 = Intermittent EF2 = Transient EF

-

Peak counter limit INTRPTEF 2...20 1

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


ABB 37

Table 39. Negative-sequence overcurrent protection (NSPTOC)


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

±1.5% of the set value or ±0.002 × In


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

23 ms15 ms

26 ms18 ms

28 ms20 ms







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

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

Table 40. Negative-sequence overcurrent protection (NSPTOC) main settings


Start value NSPTOC 0.01...5.00 × In 0.01

Time multiplier NSPTOC 0.05...15.00 0.01

Operate delay time NSPTOC 40...200000 ms 10

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


Table 41. Negative-sequence overcurrent protection for machines (MNSPTOC)


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



IFault = 2.0 × set Start value 23 25 ms 28 ms







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

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


38 ABB

Table 42. Negative-sequence overcurrent protection for machines (MNSPTOC) main settings


Start value MNSPTOC 0.01...0.50 × In 0.01

Operating curve type MNSPTOC Definite or inverse timeCurve type: 5, 15, 17, 18

Operate delay time MNSPTOC 100...120000 ms 10

Operation MNSPTOC 1 = on5 = off

-

Cooling time MNSPTOC 5...7200 s 1

Table 43. Residual overvoltage protection (ROVPTOV)


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

±1.5% of the set value or ±0.002 × Un


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






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

measurements2) Includes the delay of the signal output contact

Table 44. Residual overvoltage protection (ROVPTOV) main settings


Start value ROVPTOV 0.010...1.000 × Un 0.001

Operate delay time ROVPTOV 40...300000 ms 1


ABB 39

Table 45. Three-phase undervoltage protection (PHPTUV)


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



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


Reset ratio Depends on the set Relative hysteresis





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 46. 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


Table 47. Three-phase overvoltage protection (PHPTOV)





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







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


40 ABB

Table 48. 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 49. Positive-sequence undervoltage protection (PSPTUV)





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

52 ms44 ms

55 ms47 ms

58 ms50 ms






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

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

Table 50. Positive-sequence undervoltage protection (PSPTUV) main settings


Start value PSPTUV 0.010...1.200 × Un 0.001

Operate delay time PSPTUV 40...120000 ms 10

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


ABB 41

Table 51. Negative-sequence overvoltage protection (NSPTOV)


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



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

33 ms24 ms

35 ms26 ms

37 ms28 ms






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

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

Table 52. Negative-sequence overvoltage protection (NSPTOV) main settings


Start value NSPTOV 0.010...1.000 × Un 0.001

Operate delay time NSPTOV 40...120000 ms 1

Table 53. Frequency protection (FRPFRQ)


Operation accuracy f>/f< ±5 mHz

df/dt ±50 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



42 ABB

Table 54. 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 -0.2000...0.2000 × fn/s 0.005

Operate Tm Freq FRPFRQ 80...200000 ms 10

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

Table 55. Overexcitation protection (OEPVPH)



±3.0% of the set value

Start time 1)2) Frequency change:Typically 200 ms

Voltage change:Typically 40 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 ±50 ms

1) fn = 50 Hz, results based on statistical distribution of 1000 measurements

2) Includes the delay of the signal output contact

Table 56. Overexcitation protection (OEPVPH) main settings


Start value OEPVPH 100...200% 1

Operating curve type OEPVPH Definite or inverse timeCurve type: 5, 15, 17, 18, 19, 20

Time multiplier OEPVPH 0.1...100.0 0.1

Operate delay time OEPVPH 200...200000 ms 10

Cooling time OEPVPH 5...10000 s 1


ABB 43

Table 57. Three-phase thermal protection for feeders, cables and distribution transformers (T1PTTR)



Current measurement: ±1.5% of the set value or ±0.002 × In (at currentsin 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

Table 58. Three-phase thermal protection for feeders, cables and distribution transformers (T1PTTR) main settings


Env temperature Set T1PTTR -50...100°C 1

Current reference T1PTTR 0.05...4.00 × In 0.01

Temperature rise T1PTTR 0.0...200.0°C 0.1

Time constant T1PTTR 60...60000 s 1

Maximum temperature T1PTTR 20.0...200.0°C 0.1

Alarm value T1PTTR 20.0...150.0°C 0.1

Reclose temperature T1PTTR 20.0...150.0°C 0.1

Current multiplier T1PTTR 1...5 1

Initial temperature T1PTTR -50.0...100.0°C 0.1

Table 59. Three-phase thermal overload protection, two time constants (T2PTTR)



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

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

1) Overload current > 1.2 x Operate level temperature

Table 60. Three-phase thermal overload protection, two time constants (T2PTTR) main settings


Temperature rise T2PTTR 0.0...200.0°C 0.1

Max temperature T2PTTR 0.0...200.0°C 0.1

Operate temperature T2PTTR 80.0...120.0% 0.1

Short time constant T2PTTR 6...60000 s 1

Weighting factor p T2PTTR 0.00...1.00 0.01

Current reference T2PTTR 0.05...4.00 × In 0.01

Operation T2PTTR 1 = on5 = off

-


44 ABB

Table 61. Circuit breaker failure protection (CCBRBRF)







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


Current value CCBRBRF 0.05...2.00 × In 0.05

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

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

-

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

-

Retrip time CCBRBRF 0...60000 ms 10

CB failure delay CCBRBRF 0...60000 ms 10

CB fault delay CCBRBRF 0...60000 ms 10

Table 63. Three-phase inrush detector (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 64. Three-phase inrush detector (INRPHAR) main settings


Start value INRPHAR 5...100% 1

Operate delay time INRPHAR 20...60000 ms 1


ABB 45

Table 65. Arc protection (ARCSARC)


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

Operate time Minimum Typical Maximum

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

9 ms3)

4 ms4)12 ms3)

6 ms4)15 ms 3)

9 ms4)

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

4 ms4)10 ms3)

6 ms4)12 ms3)

7 ms4)



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

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

Table 66. Arc protection (ARCSARC) main settings


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

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

Operation mode ARCSARC 2 = Light only3 = BI controlled

-

Table 67. Multipurpose protection (MAPGAPC)


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

Table 68. Multipurpose protection (MAPGAPC) main settings


Start value MAPGAPC -10000.0...10000.0 0.1

Operate delay time MAPGAPC 0...200000 ms 100

Operation mode MAPGAPC 1 = Over2 = Under

-


46 ABB

Table 69. Stabilized and instantaneous differential protection for machines (MPDIF)


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

±3% of the set value or ±0.002 x In

Operate time 1)2) Minimum Typical Maximum

Low stage 36 ms 40 ms 42 ms

High stage 18 ms 22 ms 27 ms

Reset time <40 ms



1) Fn = 50 Hz, results based on statistical distribution of 1000 measurements

2) Includes the delay of the power output contact

Table 70. Stabilized and instantaneous differential protection for machines (MPDIF) main settings


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

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

Slope section 2 MPDIF 10...50% 1

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

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

DC restrain enable MPDIF 0 = False1 = True

-

CT connection type MPDIF 1 = Type 12 = Type 2

-

CT ratio Cor Line MPDIF 0.40...4.00 0.01

CT ratio Cor Neut MPDIF 0.40...4.00 0.01

Table 71. Third harmonic-based stator earth-fault protection (H3EFPSEF)


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

±5% of the set value or ±0.004 × Un



Reset ratio Typically 0.96 (differential mode)Typically 1.04 (under voltage mode)

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




ABB 47

Table 72. Third harmonic-based stator earth-fault protection (H3EFPSEF) main settings


Beta H3EFPSEF 0.50...10.00 0.01

Voltage N 3.H Lim H3EFPSEF 0.005...0.200 × Un 0.001

Operate delay time H3EFPSEF 20...300000 ms 10

Voltage selection H3EFPSEF 1 = No voltage2 = Measured Uo3 = Calculated Uo4 = Phase A5 = Phase B6 = Phase C

-

CB open factor H3EFPSEF 1.00...10.00 0.01

Table 73. Underpower protection (DUPPDPR)


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

Power measurement accuracy ±3% of the set value or ±0.002 × SnPhase angle: ±2°






1) Measurement mode = “Pos Seq” (default)2) U = Un, fn = 50 Hz, results based on statistical distribution of 1000 measurements


Table 74. Underpower protection (DUPPDPR) main settings


Start value DUPPDPR 0.01...2.00 × Sn 0.01

Operate delay time DUPPDPR 40...300000 ms 10

Pol reversal DUPPDPR 0 = False1 = True

-

Disable time DUPPDPR 0...60000 ms 1000


48 ABB

Table 75. Reverse power/directional overpower protection (DOPPDPR)


Operation accuracy 1)

Depending on the frequency of the measured current and voltage:f = fn ±2 Hz

Power measurement accuracy ±3% of the set value or ±0.002 × SnPhase angle: ±2°






1) Measurement mode = “Pos Seq” (default)2) U = Un, fn = 50 Hz, results based on statistical distribution of 1000 measurements


Table 76. Reverse power/directional overpower protection (DOPPDPR) main settings


Start value DOPPDPR 0.01...2.00 × Sn 0.01

Operate delay time DOPPDPR 40...300000 ms 10

Directional mode DOPPDPR 2 = Forward3 = Reverse

-

Power angle DOPPDPR -90...90° 1

Table 77. Three-phase under excitation protection (UEXPDIS)


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

±3.0% of the set value or ±0.2% Zb




Retardation time Total retardation time when the impedance returns from the operatingcircle <40 ms



1) fn= 50Hz, results based on statistical distribution of 1000 measurements



ABB 49

Table 78. Three-phase underexcitation protection (UEXPDIS) main settings


Diameter UEXPDIS 1...6000 %Zn 1

Offset UEXPDIS -1000...1000 %Zn 1

Displacement UEXPDIS -1000...1000 %Zn 1

Operate delay time UEXPDIS 60...200000 ms 10

External Los Det Ena UEXPDIS 0 = Disable1 = Enable

-

Table 79. Three-phase underimpedance protection (UZPDIS)


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

±3.0% of the set value or ±0.2 %Zb








Table 80. Three-phase underimpedance protection (UZPDIS) main settings


Percentage reach UZPDIS 1...6000% Zn 1

Operate delay time UZPDIS 40...200000 ms 10

Table 81. Out-of-step protection OOSRPSB


Impedance reach Depending on the frequency of the measured current and voltage: fn ±2Hz

±3.0% of the reach value or ±0.2% of Un/(√3 × In)

Reset time ±1.0% of the set value or ±40 ms


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


50 ABB

Table 82. Out-of-step protection (OOSRPSB) main settings


Oos trip mode OOSRPSB 1 = Way in2 = Way out3 = Adaptive

-

Forward reach OOSRPSB 0.00...6000.00 Ω 0.01

Reverse reach OOSRPSB 0.00...6000.00 Ω 0.01

Inner blinder R OOSRPSB 1.00...6000.00 Ω 0.01

Outer blinder R OOSRPSB 1.01...10000.00 Ω 0.01

Impedance angle OOSRPSB 10.0...90.0° 0.1

Swing time OOSRPSB 20...300000 ms 10

Trip delay time OOSRPSB 20...60000 ms 10

Zone 1 reach OOSRPSB 1...100% 1

Table 83. 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 51

Interconnection functions

Table 84. Directional reactive power undervoltage protection (DQPTUV )


Operation accuracy Depending on the frequency of the measured current and voltage:fn ±2 HzReactive power range |PF| <0.71

Power:±3.0% or ±0.002 × QnVoltage:±1.5% of the set value or ±0.002 × Un


Reset time <50 ms




1) Start value = 0.05 × Sn, reactive power before fault = 0.8 × Start value, reactive power overshoot 2 times, results based on statistical distribution of 1000 measurements


Table 85. Directional reactive power undervoltage protection (DQPTUV) main settings


Voltage start value DQPTUV 0.20...1.20 × Un 0.01

Operate delay time DQPTUV 100...300000 ms 10

Min reactive power DQPTUV 0.01...0.50 × Sn 0.01

Min Ps Seq current DQPTUV 0.02...0.20 × In 0.01

Pwr sector reduction DQPTUV 0...10° 1

Table 86. Low-voltage ride-through protection (LVRTPTUV)





Reset time Based on maximum value of Recovery time setting



1) Tested for Number of Start phases = 1 out of 3, results based on statistical distribution of 1000 measurements2) Includes the delay of the signal output contact


52 ABB

Table 87. Low-voltage ride-through protection (LVRTPTUV) main settings


Voltage start value LVRTPTUV 0.05...1.20 × Un 0.01

Num of start phases LVRTPTUV 4 = Exactly 1 of 35 = Exactly 2 of 36 = Exactly 3 of 3

-

Voltage selection LVRTPTUV 1 = Highest Ph-to-E2 = Lowest Ph-to-E3 = Highest Ph-to-Ph4 = Lowest Ph-to-Ph5 = Positive Seq

-

Active coordinates LVRTPTUV 1...10 1

Voltage level 1 LVRTPTUV 0.00...1.20 xUn 0.01










Recovery time 1 LVRTPTUV 0...300000 ms 1










Table 88. Voltage vector shift protection (VVSPPAM)



±1°

Operate time1)2) Typically 53 ms




ABB 53

Table 89. Voltage vector shift protection (VVSPPAM) main settings


Start value VVSPPAM 2.0...30.0° 0.1

Over Volt Blk value VVSPPAM 0.40...1.50 × Un 0.01

Under Volt Blk value VVSPPAM 0.15...1.00 × Un 0.01

Phase supervision VVSPPAM 7 = Ph A + B + C8 = Pos sequence

-


54 ABB

Power quality functions

Table 90. Voltage variation (PHQVVR)


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

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

Table 91. Voltage unbalance (VSQVUB)


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



ABB 55

Control functions

Table 92. Synchronism and energizing check (SECRSYN)


Operation accuracy Depending on the frequency of the voltage measured: fn ±1 Hz

Voltage:±3.0% of the set value or ±0.01 × UnFrequency:±10 mHzPhase angle:±3°

Reset time <50 ms



Table 93. 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

-

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

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

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

Control mode SECRSYN 1 = Continuous2 = Command

-

Close pulse SECRSYN 200...60000 ms 10

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


56 ABB

Supervision functions

Table 94. Circuit-breaker condition monitoring (SSCBR)


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


Travelling time measurement +10 ms / -0 ms

Table 95. Current circuit supervision (CCSPVC)


Operate time 1) <30 ms

1) Including the delay of the output contact

Table 96. Current circuit supervision (CCSPVC) main settings


Start value CCSPVC 0.05...0.20 × In 0.01

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

Table 97. Fuse failure supervision (SEQSPVC)


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

<33 ms

UFault = 5.0 × set Neg Seq voltageLev

<18 ms

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

ΔU = 2.0 × set Voltage change rate <24 ms

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

measurements

Table 98. Runtime counter for machines and devices (MDSOPT)

Description Value

Motor runtime measurement accuracy1) ±0.5%

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


ABB 57

Measurement functions

Table 99. 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 100. Sequence current measurement (CSMSQI)


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

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


Table 101. Residual current measurement (RESCMMXU)


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

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


Table 102. 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 103. Residual voltage measurement (RESVMMXU)


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

±0.5% or ±0.002 × Un



58 ABB

Table 104. Sequence voltage measurement (VSMSQI)


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

±1.0% or ±0.002 × Un


Table 105. Three-phase power and energy measurement (PEMMXU)


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

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

±1.5% for reactive power Q and reactive energy2)

±0.015 for power factor


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

Table 106. RTD/mA measurement (XRGGIO130)

Description Value

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

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

Supported resistance range 0...2 kΩ

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

Isolation 2 kV (inputs to protective earth)

Response time <4 s

RTD/resistance sensing current Maximum 0.33 mA rms

Operation accuracy Resistance Temperature

± 2.0% or ±1 Ω ±1°C10 Ω copper: ±2°C

mA inputs Supported current range 0…20 mA

Current input impedance 44 Ω ± 0.1%

Operation accuracy ±0.5% or ±0.01 mA

Table 107. Frequency measurement (FMMXU)


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


ABB 59

Other functions

Table 108. Pulse timer (PTGAPC)



Table 109. Time delay off (8 pcs) (TOFPAGC)



Table 110. Time delay on (8 pcs) (TONGAPC)




60 ABB

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

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

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

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

IECA070904 V3 EN

Figure 14. Small display

IECA070901 V3 EN

Figure 15. Large display

Table 111. Small display

Character size1) Rows in the view Characters per row

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

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

1) Depending on the selected language

Table 112. Large display

Character size1) Rows in the view Characters per row

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

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

1) Depending on the selected language


ABB 61

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 cases canalso be mounted in a tilted position (25°) using specialaccessories.

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

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

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

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

48

177

160

177

153

164

IECA070900 V4 EN

Figure 16. Flush mounting

98

177

160

186

103

IECA070903 V4 EN

Figure 17. Semi-flush mounting

230

107

25°

133

190

IECA070902 V4 EN

Figure 18. Semi-flush mounting in a 25º tilt

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

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

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


62 ABB

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

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

24. Accessories and ordering data

Table 113. Cables

Item Order number

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

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








Table 114. Mounting accessories

Item Order number

Semi-flush mounting kit 1MRS050696

Wall mounting kit 1MRS050697

Inclined semi-flush mounting kit 1MRS050831

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

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

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

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

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

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

Functional earthing flange for RTD modules1) 2RCA036978A0001

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

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

Replacement kit for two Strömberg SP_J3 series relays 2RCA027880A0001

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

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

Replacement kit for a Strömberg SP_J6 series relay 2RCA027881A0001

Replacement kit for three BBC S_ series relays 2RCA027882A0001

Replacement kit for a SPA 300 series relay 2RCA027885A0001

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


ABB 63

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

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

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

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

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

Table 115. Tools

Description Version

PCM600 2.6 (Rollup 20150626) or later

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

REG615 Connectivity Package 5.1 or later


64 ABB

Table 116. Supported functions

Function Web HMI PCM600

Relay parameter setting

Saving of relay parameter settings in the relay

Signal monitoring

Disturbance recorder handling

Alarm LED viewing

Access control management

Relay signal configuration (Signal Matrix) -

Modbus® communication configuration (communication management) -

DNP3 communication configuration (communication management) -

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

Saving of relay parameter settings in the tool -

Disturbance record analysis -

XRIO parameter export/import

Graphical display configuration -

Application configuration -

IEC 61850 communication configuration, GOOSE (communicationconfiguration) -

Phasor diagram viewing -

Event viewing

Saving of event data on the user's PC

Online monitoring - = Supported

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

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


ABB 65

27. Terminal diagrams

GUID-4BA6AD56-1833-4BA6-B3CC-3C44FD9767BF V1 EN

Figure 19. Terminal diagram of standard configuration A


66 ABB

GUID-7E974B34-D8B8-4114-A24A-40F38BECF594 V1 EN

Figure 20. Terminal diagram of standard configuration C


ABB 67

GUID-6756612D-B6DA-4B52-822D-B2794FADCC23 V1 EN

Figure 21. Terminal diagram of standard configuration D


68 ABB

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

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

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

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

Additional certificates can be found on the product page.

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

The latest relevant information on the REG615 protection andcontrol relay is found on the product page. Scroll down thepage to find and download the related documentation.


ABB 69

http://new.abb.com/distribution-automation/numerical-relays/power-generator-protection-and-control/generator-and-interconnection-protection-reg615-iec

HTTP://WWW.ABB.COM/SUBSTATIONAUTOMATION

http://new.abb.com/distribution-automation/numerical-relays/power-generator-protection-and-control/generator-and-interconnection-protection-reg615-iec

30. Functions, codes and symbols

Table 117. Functions included in the relay

Function IEC 61850 IEC 60617 IEC-ANSI

Protection

Three-phase non-directional overcurrent protection,low stage

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

Three-phase non-directional overcurrent protection,high stage

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

Three-phase non-directional overcurrent protection,instantaneous stage

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

Three-phase directional overcurrent protection, lowstage

DPHLPDOC1 3I> -> (1) 67-1 (1)

DPHLPDOC2 3I> -> (2) 67-1 (2)

Three-phase directional overcurrent protection, highstage

DPHHPDOC1 3I>> -> (1) 67-2 (1)

Three-phase voltage-dependent overcurrentprotection

PHPVOC1 3I(U)> (1) 51V (1)

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

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

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

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

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

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

NSPTOC2 I2> (2) 46 (2)

Negative-sequence overcurrent protection formachines

MNSPTOC1 I2>M (1) 46M (1)

MNSPTOC2 I2>M (2) 46M (2)

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

ROVPTOV2 Uo> (2) 59G (2)

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

PHPTUV2 3U< (2) 27 (2)

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

PHPTOV2 3U> (2) 59 (2)

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

PSPTUV2 U1< (2) 47U+ (2)

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

NSPTOV2 U2> (2) 47O- (2)

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

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






70 ABB

Table 117. Functions included in the relay, continued


Overexcitation protection OEPVPH1 U/f> (1) 24 (1)

Three-phase thermal protection for feeders, cablesand distribution transformers

T1PTTR1 3Ith>F (1) 49F (1)

Three-phase thermal overload protection, two timeconstants

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

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

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

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

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





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

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

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

Multipurpose protection MAPGAPC1 MAP (1) MAP (1)

MAPGAPC2 MAP (2) MAP (2)

















Stabilized and instantaneous differential protectionfor machines

MPDIF1 3dI>G/M (1) 87G/M (1)

Third harmonic-based stator earth-fault protection H3EFPSEF1 dUo>/Uo3H (1) 27/59THD (1)

Underpower protection DUPPDPR1 P< (1) 32U (1)

DUPPDPR2 P< (2) 32U (2)


ABB 71



Reverse power/directional overpower protection DOPPDPR1 P>/Q> (1) 32R/32O (1)

DOPPDPR2 P>/Q> (2) 32R/32O (2)

DOPPDPR3 P>/Q> (3) 32R/32O (3)

Three-phase underexcitation protection UEXPDIS1 X< (1) 40 (1)

Three-phase underimpedance protection UZPDIS1 Z<G (1) 21G (1)

Out-of-step protection OOSRPSB1 OOS (1) 78 (1)

Interconnection functions

Directional reactive power undervoltage protection DQPTUV1 Q> ->,3U< (1) 32Q,27 (1)

Low-voltage ride-through protection LVRTPTUV1 U<RT (1) 27RT (1)

LVRTPTUV2 U<RT (2) 27RT (2)

LVRTPTUV3 U<RT (3) 27RT (3)

Voltage vector shift protection VVSPPAM1 VS (1) 78V (1)

Power quality

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

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

Voltage variation PHQVVR1 PQMU (1) PQMV (1)

Voltage unbalance VSQVUB1 PQUUB (1) PQVUB (1)

Control

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

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

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

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

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

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

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

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

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

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

Condition monitoring and supervision

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

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

TCSSCBR2 TCS (2) TCM (2)

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

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

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

Measurement

Disturbance recorder RDRE1 DR (1) DFR (1)

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


72 ABB



Fault record FLTRFRC1 FAULTREC (1) FAULTREC (1)

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

CMMXU2 3I (2) 3I (2)

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

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

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

VMMXU2 3U (2) 3V (2)

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

RESVMMXU2 Uo (2) Vn (2)

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

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

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

Frequency measurement FMMXU1 f (1) f (1)

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

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

SMVRCV SMVRCV SMVRCV

Other

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

TPGAPC2 TP (2) TP (2)



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

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

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

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

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

TOFGAPC2 TOF (2) TOF (2)



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

TONGAPC2 TON (2) TON (2)



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

SRGAPC2 SR (2) SR (2)




ABB 73



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

MVGAPC2 MV (2) MV (2)

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

SPCGAPC2 SPC (2) SPC (2)

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

SCA4GAPC2 SCA4 (2) SCA4 (2)



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

31. Document revision history

Document revision/date Product version History

A/2016-05-20 5.0 FP1 First release

B/2018-06-06 5.0 FP1 Content updated

C/2018-12-20 5.0 FP1 Content updated


74 ABB

ABB Distribution SolutionsDistribution AutomationP.O. Box 699FI-65101 VAASA, FinlandPhone +358 10 22 11

ABB Distribution AutomationManeja WorksVadodara-390013, IndiaPhone +91 265 2604386Fax +91 265 2638922

www.abb.com/mediumvoltagewww.abb.com/relionwww.abb.com/substationautomation

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