ABB 620 series IEC 2.0 FP1 Technical Manual

—

RELION ® PROTECTION AND CONTROL

620 series

Technical Manual

Document ID: 1MRS757644

Issued: 2022-02-0 4

Revision: H

Product version: 2.0 FP1

© Copyright 2022 ABB. All rights reserved

Copyright

This document and parts thereof must not be reproduced or copied without written permission from

ABB, and the contents thereof must not be imparted to a third party, nor used for any unauthorized purpose.

The software or hardware described in this document is furnished under a license and may be used, copied, or disclosed only in accordance with the terms of such license.

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.

Warranty

Please inquire about the terms of warranty from your nearest ABB representative.

www.abb.com/relion

Disclaimer

The data, examples and diagrams in this manual are included solely for the concept or product description and are not to be deemed as a statement of guaranteed properties. All persons responsible for applying the equipment addressed in this manual must satisfy themselves that each intended application is suitable and acceptable, including that any applicable safety or other operational requirements are complied with. In particular, any risks in applications where a system failure and/or product failure would create a risk for harm to property or persons (including but not limited to personal injuries or death) shall be the sole responsibility of the person or entity applying the equipment, and those so responsible are hereby requested to ensure that all measures are taken to exclude or mitigate such risks.

This product has been designed to be connected and communicate data and information via a network interface which should be connected to a secure network. It is the sole responsibility of the person or entity responsible for network administration to ensure a secure connection to the network and to take the necessary measures (such as, but not limited to, installation of firewalls, application of authentication measures, encryption of data, installation of anti virus programs, etc.) to protect the product and the network, its system and interface included, against any kind of security breaches, unauthorized access, interference, intrusion, leakage and/or theft of data or information. ABB is not liable for any such damages and/or losses.

This document has been carefully checked by ABB but deviations cannot be completely ruled out. In case any errors are detected, the reader is kindly requested to notify the manufacturer. Other than under explicit contractual commitments, in no event shall ABB be responsible or liable for any loss or damage resulting from the use of this manual or the application of the equipment.

Conformity

This product complies with following directive and regulations.

Directives of the European parliament and of the council:

• Electromagnetic compatibility (EMC) Directive 2014/30/EU

• Low-voltage Directive 2014/35/EU

• RoHS Directive 2011/65/EU

UK legislations:

• Electromagnetic Compatibility Regulations 2016

• Electrical Equipment (Safety) Regulations 2016

• The Restriction of the Use of Certain Hazardous Substances in Electrical and Electronic Equipment

Regulations 2012

These conformities are the result of tests conducted by the third-party testing in accordance with the product standard EN / BS EN 60255-26 for the EMC directive / regulation, and with the product standards EN / BS EN 60255-1 and EN / BS EN 60255-27 for the low voltage directive / safety regulation.

The product is designed in accordance with the international standards of the IEC 60255 series.

Contents

Contents

1

Introduction............................................................................................. 21

1.1 This manual.............................................................................................................................................21

1.2 Intended audience.................................................................................................................................21

1.3 Product documentation.......................................................................................................................22

1.3.1 Product documentation set................................................................................................ 22

1.3.2 Document revision history.................................................................................................. 23

1.3.3 Related documentation....................................................................................................... 23

1.4 Symbols and conventions....................................................................................................................24

1.4.1 Symbols...................................................................................................................................24

1.4.2 Document conventions........................................................................................................24

1.4.3 Functions, codes and symbols........................................................................................... 26

2

620 series overview.................................................................................36

2.1 Overview..................................................................................................................................................36

2.1.1 Product series version history............................................................................................36

2.1.2 PCM600 and IED connectivity package version..............................................................36

2.2 Local HMI.................................................................................................................................................37

2.2.1 Display..................................................................................................................................... 37

2.2.2 LEDs......................................................................................................................................... 38

2.2.3 Keypad.....................................................................................................................................38

2.3 Web HMI..................................................................................................................................................40

2.4 Authorization .........................................................................................................................................41

2.4.1 Audit trail................................................................................................................................ 42

2.5 Communication ....................................................................................................................................44

2.5.1 Self-healing Ethernet ring................................................................................................... 45

2.5.2 Ethernet redundancy............................................................................................................45

2.5.3 Process bus............................................................................................................................ 47

2.5.4 Secure communication........................................................................................................ 49

3

Basic functions........................................................................................ 50

3.1 General parameters..............................................................................................................................50

3.1.1 Analog input settings, phase currents............................................................................. 50

3.1.2 Analog input settings, residual current............................................................................ 51

3.1.3 Analog input settings, phase voltages..............................................................................51

3.1.4 Analog input settings, residual voltage............................................................................52

3.1.5 Authorization settings......................................................................................................... 53

3.1.6 Binary input settings............................................................................................................54

3.1.7 Binary signals in card location Xnnn................................................................................. 55

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8

3.1.8 Binary input settings in card location Xnnn.................................................................... 56

3.1.9 Ethernet front port settings...............................................................................................56

3.1.10 Ethernet rear port settings.................................................................................................56

3.1.11 General system settings...................................................................................................... 57

3.1.12 HMI settings...........................................................................................................................58

3.1.13 IEC 60870-5-103 settings.................................................................................................... 58

3.1.14 IEC 61850-8-1 MMS settings............................................................................................... 60

3.1.15 Modbus settings................................................................................................................... 62

3.1.16 DNP3 settings........................................................................................................................64

3.1.17 COM1 serial communication settings...............................................................................66

3.1.18 COM2 serial communication settings...............................................................................67

3.1.19 Time settings.........................................................................................................................68

3.2 Self-supervision.....................................................................................................................................68

3.2.1 Internal faults.........................................................................................................................68

3.2.2 Warnings................................................................................................................................. 74

3.2.3 Fail-safe principle for relay protection............................................................................. 76

3.3 LED indication control..........................................................................................................................83

3.3.1 Function block....................................................................................................................... 83

3.3.2 Functionality ......................................................................................................................... 83

3.4 Programmable LEDs.............................................................................................................................83

3.4.1 Function block....................................................................................................................... 83

3.4.2 Functionality.......................................................................................................................... 84

3.4.3 Signals.....................................................................................................................................86

3.4.4 Settings...................................................................................................................................87

3.4.5 Monitored data......................................................................................................................89

3.5 Time synchronization...........................................................................................................................90

3.5.1 Time master supervision GNRLLTMS............................................................................... 90

3.6 Parameter setting groups................................................................................................................... 92

3.6.1 Function block....................................................................................................................... 92

3.6.2 Functionality.......................................................................................................................... 92

3.7 Test mode...............................................................................................................................................94

3.7.1 Function blocks..................................................................................................................... 94

3.7.2 Functionality.......................................................................................................................... 94

3.7.3 Application configuration and Test mode.......................................................................95

3.7.4 Control mode.........................................................................................................................95

3.7.5 Application configuration and Control mode................................................................. 96

3.7.6 Authorization......................................................................................................................... 96

3.7.7 LHMI indications................................................................................................................... 96

3.7.8 Signals.....................................................................................................................................96

3.8 Fault recorder FLTRFRC.......................................................................................................................98

3.8.1 Function block....................................................................................................................... 98

3.8.2 Functionality.......................................................................................................................... 98

3.8.3 Settings...................................................................................................................................99

3.8.4 Monitored data......................................................................................................................99

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3.9 Nonvolatile memory........................................................................................................................... 108

3.10 Sensor inputs for currents and voltages........................................................................................108

3.11 Binary inputs......................................................................................................................................... 112

3.11.1 Binary input filter time........................................................................................................112

3.11.2 Binary input inversion......................................................................................................... 112

3.11.3 Oscillation suppression......................................................................................................113

3.12 Binary outputs...................................................................................................................................... 113

3.12.1 Power output contacts.......................................................................................................114

3.12.2 Signal output contacts....................................................................................................... 117

3.13 RTD/mA inputs.....................................................................................................................................119

3.13.1 Functionality.........................................................................................................................119

3.13.2 Operation principle............................................................................................................. 119

3.13.3 Signals................................................................................................................................... 128

3.13.4 RTD input settings.............................................................................................................. 129

3.13.5 Monitored data....................................................................................................................130

3.14 SMV function blocks............................................................................................................................133

3.14.1 IEC 61850-9-2 LE sampled values sending SMVSENDER ............................................ 133

3.14.2 IEC 61850-9-2 LE sampled values receiving SMVRCV...................................................135

3.14.3 ULTVTR function block.......................................................................................................135

3.14.4 RESTVTR function block.....................................................................................................138

3.15 GOOSE function blocks......................................................................................................................139

3.15.1 GOOSERCV_BIN function block .......................................................................................140

3.15.2 GOOSERCV_DP function block.........................................................................................140

3.15.3 GOOSERCV_MV function block ........................................................................................ 141

3.15.4 GOOSERCV_INT8 function block .....................................................................................142

3.15.5 GOOSERCV_INTL function block......................................................................................142

3.15.6 GOOSERCV_CMV function block ..................................................................................... 143

3.15.7 GOOSERCV_ENUM function block ..................................................................................144

3.15.8 GOOSERCV_INT32 function block ...................................................................................144

3.16 Type conversion function blocks..................................................................................................... 145

3.16.1 QTY_GOOD function block ...............................................................................................145

3.16.2 QTY_BAD function block ...................................................................................................145

3.16.3 QTY_GOOSE_COMM function block ...............................................................................146

3.16.4 T_HEALTH function block ................................................................................................. 147

3.16.5 T_F32_INT8 function block................................................................................................148

3.16.6 T_DIR function block...........................................................................................................148

3.16.7 T_TCMD function block......................................................................................................149

3.16.8 T_TCMD_BIN function block ............................................................................................ 150

3.16.9 T_BIN_TCMD function block .............................................................................................151

3.17 Configurable logic blocks.................................................................................................................. 152

3.17.1 Standard configurable logic blocks ................................................................................152

3.17.2 Minimum pulse timer..........................................................................................................165

3.17.3 Pulse timer function block PTGAPC.................................................................................169

3.17.4 Time delay off (8 pcs) TOFGAPC ......................................................................................171

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3.17.5 Time delay on (8 pcs) TONGAPC.......................................................................................172

3.17.6 Set-reset (8 pcs) SRGAPC ................................................................................................. 174

3.17.7 Move (8 pcs) MVGAPC ........................................................................................................177

3.17.8 Integer value move MVI4GAPC..........................................................................................178

3.17.9 Analog value scaling SCA4GAPC ......................................................................................179

3.17.10 Local/remote control function block CONTROL...........................................................182

3.17.11 Generic control point (16 pcs) SPCGAPC .......................................................................190

3.17.12 Remote generic control points SPCRGAPC....................................................................195

3.17.13 Local generic control points SPCLGAPC.........................................................................199

3.17.14 Programmable buttons FKEYGGIO................................................................................. 203

3.17.15 Generic up-down counter UDFCNT.................................................................................204

3.18 Factory settings restoration.............................................................................................................207

3.19 Load profile record LDPRLRC........................................................................................................... 207

3.19.1 Function block..................................................................................................................... 207

3.19.2 Functionality........................................................................................................................ 207

3.19.3 Configuration.......................................................................................................................210

3.19.4 Signals....................................................................................................................................211

3.19.5 Settings .................................................................................................................................211

3.19.6 Monitored data....................................................................................................................235

3.20 ETHERNET channel supervision function blocks.......................................................................... 235

3.20.1 Redundant Ethernet channel supervision RCHLCCH...................................................235

3.20.2 Ethernet channel supervision SCHLCCH........................................................................236

4 Protection functions.............................................................................239

4.1 Three-phase current protection.......................................................................................................239

4.1.1 Three-phase non-directional overcurrent protection PHxPTOC...............................239

4.1.2 Three-independent-phase non-directional overcurrent protection PH3xPTOC....256

4.1.3 Three-phase directional overcurrent protection DPHxPDOC.................................... 273

4.1.4 Directional three-independent-phase directional overcurrent protection

DPH3xPDOC....................................................................................................................298

4.1.5 Three-phase voltage-dependent overcurrent protection PHPVOC.......................... 327

4.1.6 Three-phase thermal protection for feeders, cables and distribution transformers T1PTTR....................................................................................................336

4.1.7 Three-phase thermal overload protection, two time constants T2PTTR................343

4.1.8 Motor load jam protection JAMPTOC............................................................................. 351

4.1.9 Loss of load supervision LOFLPTUC............................................................................... 355

4.1.10 Loss of phase, undercurrent PHPTUC............................................................................ 358

4.1.11 Thermal overload protection for motors MPTTR......................................................... 362

4.2 Earth-fault protection........................................................................................................................ 375

4.2.1 Non-directional earth-fault protection EFxPTOC.........................................................376

4.2.2 Directional earth-fault protection DEFxPDEF............................................................... 387

4.2.3 Transient-intermittent earth-fault protection INTRPTEF...........................................419

4.2.4 Admittance-based earth-fault protection EFPADM.................................................... 428

4.2.5 Rotor earth-fault protection MREFPTOC.......................................................................454

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4.2.6 Harmonics-based earth-fault protection HAEFPTOC.................................................460

4.2.7 Wattmetric-based earth-fault protection WPWDE......................................................468

4.2.8 Multifrequency admittance-based earth-fault protection MFADPSDE...................480

4.3 Differential protection....................................................................................................................... 501

4.3.1 Stabilized and instantaneous differential protection for machines MPDIF........... 502

4.3.2 Stabilized and instantaneous differential protection for two-winding transformers TR2PTDF................................................................................................. 519

4.3.3 Numerical stabilized low-impedance restricted earth-fault protection

LREFPNDF....................................................................................................................... 558

4.3.4 High-impedance based restricted earth-fault protection HREFPDIF......................569

4.3.5 High-impedance differential protection HIxPDIF........................................................ 582

4.3.6 High-impedance/flux-balance based differential protection for motors

MHZPDIF..........................................................................................................................597

4.4 Unbalance protection........................................................................................................................ 609

4.4.1 Negative-sequence overcurrent protection NSPTOC................................................. 609

4.4.2 Phase discontinuity protection PDNSPTOC.................................................................. 615

4.4.3 Phase reversal protection PREVPTOC............................................................................ 620

4.4.4 Negative-sequence overcurrent protection for machines MNSPTOC..................... 623

4.5 Voltage protection............................................................................................................................. 630

4.5.1 Three-phase overvoltage protection PHPTOV..............................................................630

4.5.2 Single-phase overvoltage protection PHAPTOV...........................................................637

4.5.3 Three-phase undervoltage protection PHPTUV........................................................... 645

4.5.4 Single-phase undervoltage protection PHAPTUV........................................................ 653

4.5.5 Residual overvoltage protection ROVPTOV.................................................................. 660

4.5.6 Negative-sequence overvoltage protection NSPTOV................................................. 664

4.5.7 Positive-sequence undervoltage protection PSPTUV................................................. 668

4.5.8 Overexcitation protection OEPVPH.................................................................................672

4.5.9 Low-voltage ride-through protection LVRTPTUV........................................................ 687

4.5.10 Voltage vector shift protection VVSPPAM.....................................................................695

4.6 Frequency protection........................................................................................................................ 700

4.6.1 Frequency protection FRPFRQ.........................................................................................700

4.6.2 Load-shedding and restoration LSHDPFRQ..................................................................709

4.7 Impedance protection........................................................................................................................719

4.7.1 Three-phase underexcitation protection UEXPDIS......................................................720

4.8 Power protection................................................................................................................................ 728

4.8.1 Underpower protection DUPPDPR.................................................................................. 728

4.8.2 Reverse power-directional overpower protection DOPPDPR.................................... 735

4.8.3 Directional reactive power undervoltage protection DQPTUV................................. 744

4.9 Arc protection ARCSARC................................................................................................................... 749

4.9.1 Identification....................................................................................................................... 749

4.9.2 Function block..................................................................................................................... 749

4.9.3 Functionality........................................................................................................................ 749

4.9.4 Operation principle.............................................................................................................750

4.9.5 Application............................................................................................................................751

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4.9.6 Signals................................................................................................................................... 755

4.9.7 Settings.................................................................................................................................756

4.9.8 Monitored data....................................................................................................................756

4.9.9 Technical data .....................................................................................................................756

4.9.10 Technical revision history.................................................................................................. 757

4.10 Motor start-up supervision STTPMSU............................................................................................ 757

4.10.1 Identification........................................................................................................................757

4.10.2 Function block......................................................................................................................757

4.10.3 Functionality.........................................................................................................................757


4.10.5 Application........................................................................................................................... 763

4.10.6 Signals...................................................................................................................................766

4.10.7 Settings.................................................................................................................................767

4.10.8 Monitored data....................................................................................................................768

4.10.9 Technical data .....................................................................................................................768

4.10.10 Technical revision history..................................................................................................768

4.11 Multipurpose protection MAPGAPC................................................................................................769

4.11.1 Identification....................................................................................................................... 769

4.11.2 Function block..................................................................................................................... 769

4.11.3 Functionality........................................................................................................................ 769


4.11.5 Application............................................................................................................................ 771

4.11.6 Signals....................................................................................................................................771

4.11.7 Settings................................................................................................................................. 771

4.11.8 Monitored data.................................................................................................................... 772

4.11.9 Technical data ..................................................................................................................... 772

4.12 Capacitor bank protection................................................................................................................ 772

4.12.1 Three-phase overload protection for shunt capacitor banks COLPTOC................. 772

4.12.2 Current unbalance protection for capacitor banks CUBPTOC.................................. 782

4.12.3 Shunt capacitor bank switching resonance protection, current based SRCPTOC794

5

Protection related functions............................................................... 801

5.1 Three-phase inrush detector INRPHAR...........................................................................................801

5.1.1 Identification....................................................................................................................... 801

5.1.2 Function block..................................................................................................................... 801

5.1.3 Functionality........................................................................................................................ 801


5.1.5 Application........................................................................................................................... 802

5.1.6 Signals...................................................................................................................................803

5.1.7 Settings................................................................................................................................ 804

5.1.8 Monitored data................................................................................................................... 805

5.1.9 Technical data .................................................................................................................... 805

5.1.10 Technical revision history................................................................................................. 805

5.2 Circuit breaker failure protection CCBRBRF................................................................................. 805

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5.2.1 Identification.......................................................................................................................805

5.2.2 Function block.....................................................................................................................806

5.2.3 Functionality........................................................................................................................806

5.2.4 Operation principle............................................................................................................ 806

5.2.5 Application............................................................................................................................812

5.2.6 Signals................................................................................................................................... 813

5.2.7 Settings.................................................................................................................................814

5.2.8 Monitored data....................................................................................................................815

5.2.9 Technical data .....................................................................................................................815


5.3 Master trip TRPPTRC.......................................................................................................................... 816

5.3.1 Identification........................................................................................................................816

5.3.2 Function block..................................................................................................................... 816

5.3.3 Functionality........................................................................................................................ 816


5.3.5 Application............................................................................................................................817

5.3.6 Signals................................................................................................................................... 818

5.3.7 Settings.................................................................................................................................819

5.3.8 Monitored data....................................................................................................................819


5.4 High-impedance fault detection PHIZ............................................................................................ 819

5.4.1 Identification........................................................................................................................819

5.4.2 Function block.....................................................................................................................820

5.4.3 Functionality........................................................................................................................820


5.4.5 Application........................................................................................................................... 822

5.4.6 Signals................................................................................................................................... 823

5.4.7 Settings.................................................................................................................................823

5.4.8 Monitored data....................................................................................................................825


5.5 Emergency start-up ESMGAPC.........................................................................................................825

5.5.1 Identification....................................................................................................................... 825

5.5.2 Function block..................................................................................................................... 825

5.5.3 Functionality........................................................................................................................ 826


5.5.5 Application........................................................................................................................... 826

5.5.6 Signals................................................................................................................................... 827

5.5.7 Settings.................................................................................................................................828

5.5.8 Monitored data................................................................................................................... 828

5.5.9 Technical data .....................................................................................................................828


5.6 Automatic switch-onto-fault logic CVPSOF.................................................................................. 828

5.6.1 Identification....................................................................................................................... 829

5.6.2 Function block..................................................................................................................... 829

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5.6.3 Functionality........................................................................................................................ 829


5.6.5 Application........................................................................................................................... 832

5.6.6 Signals...................................................................................................................................833

5.6.7 Settings................................................................................................................................ 834

5.6.8 Monitored data................................................................................................................... 834

5.6.9 Technical data......................................................................................................................835

5.7 Fault locator SCEFRFLO.....................................................................................................................835

5.7.1 Identification....................................................................................................................... 835

5.7.2 Function block..................................................................................................................... 835

5.7.3 Functionality........................................................................................................................ 835


5.7.5 Application...........................................................................................................................854

5.7.6 Signals...................................................................................................................................855

5.7.7 Settings................................................................................................................................ 856

5.7.8 Monitored data................................................................................................................... 858

5.7.9 Technical data .....................................................................................................................862


5.8 Circuit breaker uncorresponding position start-up UPCALH....................................................862

5.8.1 Identification....................................................................................................................... 862

5.8.2 Function block..................................................................................................................... 863

5.8.3 Functionality........................................................................................................................ 863


5.8.5 Application...........................................................................................................................864

5.8.6 Signals...................................................................................................................................864

5.8.7 Settings................................................................................................................................ 864

5.8.8 Technical data .................................................................................................................... 865

6

Supervision functions.......................................................................... 866

6.1 Trip circuit supervision TCSSCBR....................................................................................................866

6.1.1 Identification....................................................................................................................... 866

6.1.2 Function block.....................................................................................................................866

6.1.3 Functionality........................................................................................................................866


6.1.5 Application........................................................................................................................... 867

6.1.6 Signals...................................................................................................................................875

6.1.7 Settings.................................................................................................................................875

6.1.8 Monitored data....................................................................................................................876


6.2 Current circuit supervision CCSPVC................................................................................................876

6.2.1 Identification....................................................................................................................... 876

6.2.2 Function block..................................................................................................................... 876

6.2.3 Functionality........................................................................................................................ 877


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6.2.5 Application........................................................................................................................... 879

6.2.6 Signals...................................................................................................................................883

6.2.7 Settings................................................................................................................................ 884

6.2.8 Monitored data................................................................................................................... 884

6.2.9 Technical data .................................................................................................................... 884


6.3 Advanced current circuit supervision for transformers CTSRCTF............................................885

6.3.1 Identification....................................................................................................................... 885

6.3.2 Function block.....................................................................................................................885

6.3.3 Functionality........................................................................................................................885


6.3.5 Application........................................................................................................................... 887

6.3.6 Signals...................................................................................................................................888

6.3.7 Settings................................................................................................................................ 889

6.3.8 Monitored data................................................................................................................... 890

6.3.9 Technical data..................................................................................................................... 890

6.4 Current transformer supervision for high-impedance protection scheme HZCCxSPVC..... 891

6.4.1 Identification........................................................................................................................891

6.4.2 Function block..................................................................................................................... 891

6.4.3 Functionality........................................................................................................................ 891


6.4.5 Measuring modes............................................................................................................... 893

6.4.6 Application........................................................................................................................... 893

6.4.7 Signals...................................................................................................................................895

6.4.8 Settings................................................................................................................................ 895

6.4.9 Monitored data....................................................................................................................897

6.4.10 Technical data .....................................................................................................................897


6.5 Fuse failure supervision SEQSPVC.................................................................................................. 898

6.5.1 Identification....................................................................................................................... 898

6.5.2 Function block.....................................................................................................................898

6.5.3 Functionality........................................................................................................................898


6.5.5 Application........................................................................................................................... 902

6.5.6 Signals...................................................................................................................................902

6.5.7 Settings................................................................................................................................ 903

6.5.8 Monitored data................................................................................................................... 904

6.5.9 Technical data .................................................................................................................... 904

6.6 Runtime counter for machines and devices MDSOPT.................................................................905

6.6.1 Identification....................................................................................................................... 905

6.6.2 Function block.....................................................................................................................905

6.6.3 Functionality........................................................................................................................905


6.6.5 Application...........................................................................................................................906

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6.6.6 Signals...................................................................................................................................906

6.6.7 Settings.................................................................................................................................907

6.6.8 Monitored data................................................................................................................... 908

6.6.9 Technical data .................................................................................................................... 908


7

Condition monitoring functions.........................................................909

7.1 Circuit breaker condition monitoring SSCBR............................................................................... 909

7.1.1 Identification.......................................................................................................................909

7.1.2 Function block.....................................................................................................................909

7.1.3 Functionality........................................................................................................................909


7.1.5 Application........................................................................................................................... 918

7.1.6 Signals...................................................................................................................................920

7.1.7 Settings.................................................................................................................................922

7.1.8 Monitored data....................................................................................................................923

7.1.9 Technical data .....................................................................................................................924


8

Measurement functions....................................................................... 926

8.1 Basic measurements..........................................................................................................................926

8.1.1 Functions..............................................................................................................................926

8.1.2 Measurement functionality...............................................................................................926

8.1.3 Measurement function applications...............................................................................934

8.1.4 Three-phase current measurement CMMXU.................................................................934

8.1.5 Three-phase voltage measurement VMMXU.................................................................939

8.1.6 Single-phase voltage measurement VAMMXU............................................................. 944

8.1.7 Residual current measurement RESCMMXU.................................................................946

8.1.8 Residual voltage measurement RESVMMXU.................................................................948

8.1.9 Frequency measurement FMMXU....................................................................................951

8.1.10 Sequence current measurement CSMSQI......................................................................953

8.1.11 Sequence voltage measurement VSMSQI......................................................................957

8.1.12 Three-phase power and energy measurement PEMMXU...........................................960

8.2 Disturbance recorder RDRE.............................................................................................................. 965

8.2.1 Functionality........................................................................................................................965

8.2.2 Configuration...................................................................................................................... 970

8.2.3 Application............................................................................................................................971

8.2.4 Settings................................................................................................................................. 971

8.2.5 Monitored data....................................................................................................................975


8.3 Tap changer position indicator TPOSYLTC................................................................................... 976

8.3.1 Identification....................................................................................................................... 976

8.3.2 Function block..................................................................................................................... 976

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8.3.3 Functionality........................................................................................................................ 976


8.3.5 Application........................................................................................................................... 979

8.3.6 Signals.................................................................................................................................. 980

8.3.7 Settings.................................................................................................................................981

8.3.8 Monitored data....................................................................................................................981

8.3.9 Technical data .....................................................................................................................981


9

Control functions.................................................................................. 982

9.1 Circuit breaker control CBXCBR, Disconnector control DCXSWI and Earthing switch control ESXSWI...............................................................................................................................982

9.1.1 Identification....................................................................................................................... 982

9.1.2 Function block..................................................................................................................... 982

9.1.3 Functionality........................................................................................................................ 983


9.1.5 Application........................................................................................................................... 987

9.1.6 Signals...................................................................................................................................988

9.1.7 Settings.................................................................................................................................991

9.1.8 Monitored data................................................................................................................... 993


9.2 Disconnector position indicator DCSXSWI and earthing switch indication ESSXSWI......... 994

9.2.1 Identification....................................................................................................................... 994

9.2.2 Function block.....................................................................................................................994

9.2.3 Functionality........................................................................................................................995


9.2.5 Application........................................................................................................................... 995

9.2.6 Signals...................................................................................................................................995

9.2.7 Settings.................................................................................................................................997

9.2.8 Monitored data....................................................................................................................997


9.3 Synchronism and energizing check SECRSYN.............................................................................. 998

9.3.1 Identification....................................................................................................................... 998

9.3.2 Function block.....................................................................................................................998

9.3.3 Functionality........................................................................................................................999


9.3.5 Application.........................................................................................................................1006

9.3.6 Signals.................................................................................................................................1008

9.3.7 Settings.............................................................................................................................. 1009

9.3.8 Monitored data..................................................................................................................1010

9.3.9 Technical data ................................................................................................................... 1011

9.4 Autoreclosing DARREC..................................................................................................................... 1011

9.4.1 Identification...................................................................................................................... 1011

9.4.2 Function block....................................................................................................................1012

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Contents

9.4.3 Functionality.......................................................................................................................1012

9.4.4 Operation principle...........................................................................................................1014

9.4.5 Counters..............................................................................................................................1027

9.4.6 Application......................................................................................................................... 1028

9.4.7 Signals.................................................................................................................................1039

9.4.8 Settings.............................................................................................................................. 1040

9.4.9 Monitored data................................................................................................................. 1043

9.4.10 Technical data .................................................................................................................. 1044

9.4.11 Technical revision history............................................................................................... 1044

9.5 Tap changer control with voltage regulator OLATCC............................................................... 1045

9.5.1 Identification..................................................................................................................... 1045

9.5.2 Function block...................................................................................................................1045

9.5.3 Functionality......................................................................................................................1045

9.5.4 Operation principle.......................................................................................................... 1046

9.5.5 Application......................................................................................................................... 1067

9.5.6 Signals................................................................................................................................. 1073

9.5.7 Settings...............................................................................................................................1075

9.5.8 Monitored data..................................................................................................................1077

9.5.9 Technical data .................................................................................................................. 1080

9.5.10 Technical revision history................................................................................................1081

10 Power quality measurement functions............................................ 1082

10.1 Current total demand distortion CMHAI......................................................................................1082

10.1.1 Identification..................................................................................................................... 1082

10.1.2 Function block................................................................................................................... 1082

10.1.3 Functionality...................................................................................................................... 1082


10.1.5 Application......................................................................................................................... 1083

10.1.6 Signals.................................................................................................................................1084

10.1.7 Settings.............................................................................................................................. 1084

10.1.8 Monitored data................................................................................................................. 1085

10.2 Voltage total harmonic distortion VMHAI................................................................................... 1085

10.2.1 Identification..................................................................................................................... 1085

10.2.2 Function block...................................................................................................................1086

10.2.3 Functionality......................................................................................................................1086


10.2.5 Application......................................................................................................................... 1087

10.2.6 Signals.................................................................................................................................1087

10.2.7 Settings...............................................................................................................................1087

10.2.8 Monitored data................................................................................................................. 1088

10.2.9 Technical revision history............................................................................................... 1089

10.3 Voltage variation PHQVVR.............................................................................................................. 1089

10.3.1 Identification..................................................................................................................... 1089

10.3.2 Function block...................................................................................................................1089

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Contents

10.3.3 Functionality......................................................................................................................1089


10.3.5 Recorded data................................................................................................................... 1098

10.3.6 Application......................................................................................................................... 1100

10.3.7 Signals................................................................................................................................. 1102

10.3.8 Settings............................................................................................................................... 1102

10.3.9 Monitored data..................................................................................................................1105

10.3.10 Technical data ................................................................................................................... 1107

10.4 Voltage unbalance VSQVUB............................................................................................................ 1108

10.4.1 Identification......................................................................................................................1108

10.4.2 Function block................................................................................................................... 1108

10.4.3 Functionality...................................................................................................................... 1108


10.4.5 Application.......................................................................................................................... 1113

10.4.6 Signals..................................................................................................................................1114

10.4.7 Settings................................................................................................................................1115

10.4.8 Monitored data.................................................................................................................. 1116

10.4.9 Technical data ....................................................................................................................1117

11 General function block features........................................................ 1118

11.1 Definite time characteristics...........................................................................................................1118

11.1.1 Definite time operation.................................................................................................... 1118

11.2 Current based inverse definite minimum time characteristics................................................1122

11.2.1 IDMT curves for overcurrent protection....................................................................... 1122

11.2.2 Reset in inverse-time modes...........................................................................................1143

11.2.3 Inverse-timer freezing...................................................................................................... 1153

11.3 Voltage based inverse definite minimum time characteristics............................................... 1153

11.3.1 IDMT curves for overvoltage protection.......................................................................1153

11.3.2 IDMT curves for undervoltage protection....................................................................1160

11.4 Frequency measurement and protection ....................................................................................1164

11.5 Measurement modes........................................................................................................................1165

11.6 Calculated measurements...............................................................................................................1166

12 Requirements for measurement transformers............................... 1169

12.1 Current transformers....................................................................................................................... 1169

12.1.1 Current transformer requirements for overcurrent protection.............................. 1169

13 IED physical connections.................................................................... 1173

13.1 Module slot numbering.....................................................................................................................1173

13.2 Protective earth connections ......................................................................................................... 1173

13.3 Binary and analog connections.......................................................................................................1174

13.4 Communication connections.......................................................................................................... 1174

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Contents

13.4.1 Ethernet RJ-45 front connection.................................................................................... 1175

13.4.2 Ethernet rear connections............................................................................................... 1175

13.4.3 EIA-232 serial rear connection.........................................................................................1176

13.4.4 EIA-485 serial rear connection........................................................................................ 1176

13.4.5 Optical ST serial rear connection................................................................................... 1176

13.4.6 Communication interfaces and protocols ...................................................................1176

13.4.7 Rear communication modules........................................................................................ 1177

14 Technical data...................................................................................... 1192

14.1 Dimensions......................................................................................................................................... 1192

14.2 Power supply...................................................................................................................................... 1193

14.3 Energizing inputs.............................................................................................................................. 1194

14.4 Energizing inputs (sensors)............................................................................................................ 1195

14.5 Binary inputs...................................................................................................................................... 1196

14.6 RTD/mA inputs...................................................................................................................................1197

14.7 Signal output with high make and carry.......................................................................................1198

14.8 Signal outputs and IRF output........................................................................................................1199

14.9 Double-pole power outputs with TCS function X100: PO3 and PO4......................................1200

14.10 Signal/trip output with high make and carry and with TCS function.................................... 1201

14.11 Single-pole power output relays X100: PO1 and PO2.................................................................1202

14.12 High-speed output HSO.................................................................................................................. 1203

14.13 Ethernet interfaces...........................................................................................................................1204

14.14 Serial rear interface.......................................................................................................................... 1205

14.15 Fiber optic communication link..................................................................................................... 1206

14.16 IRIG-B................................................................................................................................................... 1207

14.17 Lens sensor and optical fiber for arc protection........................................................................1208

14.18 Degree of protection of flush-mounted protection relay.........................................................1209

14.19 Environmental conditions................................................................................................................1210

15 Protection relay and functionality tests...........................................1211

15.1 Electromagnetic compatibility tests............................................................................................. 1211

15.2 Insulation tests.................................................................................................................................. 1214

15.3 Mechanical tests................................................................................................................................ 1215

15.4 Environmental tests..........................................................................................................................1216

15.5 Product safety.................................................................................................................................... 1217

15.6 EMC compliance.................................................................................................................................1218

16 Applicable standards and regulations..............................................1219

17 Glossary................................................................................................ 1220

20 620 series

Technical Manual

1MRS757644 H Introduction

1

1.1

1.2

Introduction

This manual

The technical manual contains application and functionality descriptions and lists function blocks, logic diagrams, input and output signals, setting parameters and technical data sorted per function. The manual can be used as a technical reference during the engineering phase, installation and commissioning phase, and during normal service.

Intended audience

This manual addresses system engineers and installation and commissioning personnel, who use technical data during engineering, installation and commissioning, and in normal service.

The system engineer must have a thorough knowledge of protection systems, protection equipment, protection functions and the configured functional logic in the protection relays. The installation and commissioning personnel must have a basic knowledge in handling electronic equipment.

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21

Introduction

1.3

1.3.1

Product documentation

Product documentation set

1MRS757644 H

22

Figure 1: The intended use of documents during the product life cycle

Product series- and product-specific manuals can be downloaded from the ABB Web site www.abb.com/relion .

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1.3.2

1.3.3

Document revision history

Document revision/date

A/2013-05-07

B/2014-07-01

C/2015-07-15

D/2015-12-11

E/2016-09-27

F/2019-06-19

G/2021-12-21

H/2022-02-0 4

Product series version

20

20

20

2.0 FP1

2.0 FP1

2.0 FP1

2.0 FP1

2.0 FP1

History

First release

Content updated

Content updated

Content updated to correspond to the product series version

Content updated

Content updated

Content updated

Content fixed

Download the latest documents from the ABB Web site http:// www.abb.com/substationautomation .

Related documentation

Product series- and product-specific manuals can be downloaded from the ABB

Web site http://www.abb.com/substationautomation .

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23

Introduction 1MRS757644 H

1.4

1.4.1

1.4.2

24

Symbols and conventions

Symbols

The electrical warning icon indicates the presence of a hazard which could result in electrical shock.

The warning icon indicates the presence of a hazard which could result in personal injury.

The caution icon indicates important information or warning related to the concept discussed in the text. It might indicate the presence of a hazard which could result in corruption of software or damage to equipment or property.

The information icon alerts the reader of important facts and conditions.

The tip icon indicates advice on, for example, how to design your project or how to use a certain function.

Although warning hazards are related to personal injury, it is necessary to understand that under certain operational conditions, operation of damaged equipment may result in degraded process performance leading to personal injury or death. Therefore, comply fully with all warning and caution notices.

Document conventions

A particular convention may not be used in this manual.

• Abbreviations and acronyms are spelled out in the glossary. The glossary also contains definitions of important terms.

• Push-button navigation in the LHMI menu structure is presented by using the push-button icons.

To navigate between the options, use and .

• Menu paths are presented in bold.

Select Main menu > Settings.

• LHMI messages are shown in Courier font.

To save the changes in nonvolatile memory, select Yes and press .

• Parameter names are shown in italics.

The function can be enabled and disabled with the Operation setting.

• Parameter values are indicated with quotation marks.

The corresponding parameter values are "On" and "Off".

• Input/output messages and monitored data names are shown in Courier font.

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When the function starts, the START output is set to TRUE.

• This document assumes that the parameter setting visibility is "Advanced".

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1.4.3

26

Functions, codes and symbols

All available functions are listed in the table. All of them may not be applicable to all products.

Table 1: Functions included in the relays

Function IEC 61850

Protection

Three-phase non-directional overcurrent protection, low stage

Three-phase non-directional overcurrent protection, high stage

Three-phase non-directional overcurrent protection, instantaneous stage

Three-phase directional overcurrent protection, low stage

Three-phase directional overcurrent protection, high stage

Three-phase voltagedependent overcurrent protection

Non-directional earth-fault protection, low stage

Non-directional earth-fault protection, high stage

Non-directional earth-fault protection, instantaneous stage

Directional earthfault protection, low stage

PHLPTOC1

PHLPTOC2

PHHPTOC1

PHHPTOC2

PHIPTOC1

PHIPTOC2

DPHLPDOC1

DPHLPDOC2

DPHHPDOC1

DPHHPDOC2

PHPVOC1

PHPVOC2

EFLPTOC1

EFLPTOC2

EFHPTOC1

EFHPTOC2

EFIPTOC1

DEFLPDEF1

DEFLPDEF2

DEFLPDEF3

DEFHPDEF1 Directional earthfault protection, high stage

Table continues on the next page

IEC 60617

3I> (1)

3I> (2)

3I>> (1)

3I>> (2)

3I>>> (1)

3I>>> (2)

3I> -> (1)

3I> -> (2)

3I>> -> (1)

3I>> -> (2)

3I(U)> (1)

3I(U)> (2)

Io> (1)

Io> (2)

Io>> (1)

Io>> (2)

Io>>> (1)

Io> -> (1)

Io> -> (2)

Io> -> (3)

Io>> -> (1)

ANSI

51P-1 (1)

51P-1 (2)

51P-2 (1)

51P-2 (2)

50P/51P (1)

50P/51P (2)

67-1 (1)

67-1 (2)

67-2 (1)

67-2 (2)

51V (1)

51V (2)

51N-1 (1)

51N-1 (2)

51N-2 (1)

51N-2 (2)

50N/51N (1)

67N-1 (1)

67N-1 (2)

67N-1 (3)

67N-2 (1)

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Admittance-based earth-fault protection

Wattmetric-based earth-fault protection

EFPADM1

EFPADM2

EFPADM3

WPWDE1

WPWDE2

WPWDE3

MFADPSDE1 Multifrequency admittance-based earth-fault protection

Transient/intermittent earth-fault protection

Harmonics-based earth-fault protection

Negative-sequence overcurrent protection

Phase discontinuity protection

Residual overvoltage protection

INTRPTEF1

HAEFPTOC1

NSPTOC1

NSPTOC2

PDNSPTOC1

Three-phase undervoltage protection

ROVPTOV1

ROVPTOV2

ROVPTOV3

PHPTUV1

PHPTUV2

PHPTUV3

PHPTUV4

PHAPTUV1 Single-phase undervoltage protection, secondary side

Three-phase overvoltage protection

PHPTOV1

PHPTOV2

PHPTOV3

PHAPTOV1 Single-phase overvoltage protection, secondary side

Positive-sequence undervoltage protection

Negative-sequence overvoltage protection

PSPTUV1

PSPTUV2

NSPTOV1

NSPTOV2

Frequency protection FRPFRQ1

FRPFRQ2


ANSI

21YN (1)

21YN (2)

21YN (3)

32N (1)

32N (2)

32N (3)

67YN (1)

67NIEF (1)

51NHA (1)

46 (1)

46 (2)

46PD (1)

59G (1)

59G (2)

59G (3)

27 (1)

27 (2)

27 (3)

27 (4)

27_A (1)

59 (1)

59 (2)

59 (3)

59_A (1)

47U+ (1)

47U+ (2)

47O- (1)

47O- (2)

81 (1)

81 (2)

Io>HA (1)

I2> (1)

I2> (2)

I2/I1> (1)

Uo> (1)

Uo> (2)

Uo> (3)

3U< (1)

3U< (2)

3U< (3)

3U< (4)

U_A< (1)

IEC 60617

Yo> -> (1)

Yo> -> (2)

Yo> -> (3)

Po> -> (1)

Po> -> (2)

Po> -> (3)

Io> -> Y (1)

Io> -> IEF (1)

3U> (1)

3U> (2)

3U> (3)

U_A> (1)

U1< (1)

U1< (2)

U2> (1)

U2> (2) f>/f<,df/dt (1) f>/f<,df/dt (2)

27

Introduction


Overexcitation protection

FRPFRQ3

FRPFRQ4

FRPFRQ5

FRPFRQ6

OEPVPH1

OEPVPH2

T1PTTR1 Three-phase thermal protection for feeders, cables and distribution transformers

Three-phase thermal overload protection, two time constants

Negative-sequence overcurrent protection for machines

Loss of phase (undercurrent)

T2PTTR1

MNSPTOC1

MNSPTOC2

Loss of load supervision

PHPTUC1

PHPTUC2

LOFLPTUC1

LOFLPTUC2

JAMPTOC1 Motor load jam protection

Motor start-up supervision

Phase reversal protection

Thermal overload protection for motors

Stabilized and instantaneous differential protection for machines

High-impedance/ flux-balance based differential protection for motors

Stabilized and instantaneous differential protection for twowinding transformers

Numerical stabilized low-impedance restricted earth-fault protection

STTPMSU1

PREVPTOC1

MPTTR1

MPDIF1

MHZPDIF1

TR2PTDF1

LREFPNDF1

LREFPNDF2


1MRS757644 H

IEC 60617 f>/f<,df/dt (3) f>/f<,df/dt (4) f>/f<,df/dt (5) f>/f<,df/dt (6)

U/f> (1)

U/f> (2)

3Ith>F (1)

ANSI

81 (3)

81 (4)

81 (5)

81 (6)

24 (1)

24 (2)

49F (1)

3Ith>T/G/C (1)

I2>M (1)

I2>M (2)

3I< (1)

3I< (2)

3I< (1)

3I< (2)

Ist> (1)

Is2t n< (1)

I2>> (1)

3Ith>M (1)

3dl>M/G (1)

49T/G/C (1)

46M (1)

46M (2)

37 (1)

37 (2)

37 (1)

37 (2)

51LR (1)

49,66,48,51LR (1)

46R (1)

49M (1)

87M/G (1)

3dIHi>M (1) 87MH (1)

3dI>T (1) dIoLo> (1) dIoLo> (2)

87T (1)

87NL (1)

87NL (2)

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High-impedance based restricted earth-fault protection

Circuit breaker failure protection

HREFPDIF1

HREFPDIF2

CCBRBRF1

CCBRBRF2

CCBRBRF3

INRPHAR1 Three-phase inrush detector

Master trip

Arc protection

TRPPTRC1

TRPPTRC2

TRPPTRC3

TRPPTRC4

ARCSARC1

ARCSARC2

ARCSARC3

PHIZ1 High-impedance fault detection

Load-shedding and restoration

Multipurpose protection

LSHDPFRQ1

LSHDPFRQ2

LSHDPFRQ3

LSHDPFRQ4

LSHDPFRQ5

LSHDPFRQ6

MAPGAPC1

MAPGAPC2

MAPGAPC3

MAPGAPC4

MAPGAPC5

MAPGAPC6

MAPGAPC7

MAPGAPC8

MAPGAPC9

MAPGAPC10

MAPGAPC11

MAPGAPC12

MAPGAPC13

MAPGAPC14

MAPGAPC15

MAPGAPC16


ANSI

87NH (1)

87NH (2)

51BF/51NBF (1)

51BF/51NBF (2)

51BF/51NBF (3)

68 (1)

94/86 (1)

94/86 (2)

94/86 (3)

94/86 (4)

50L/50NL (1)

50L/50NL (2)

50L/50NL (3)

HIZ (1)

81LSH (1)

81LSH (2)

81LSH (3)

81LSH (4)

81LSH (5)

81LSH (6)

MAP (1)

MAP (2)

MAP (3)

MAP (4)

MAP (5)

MAP (6)

MAP (7)

MAP (8)

MAP (9)

MAP (10)

MAP (11)

MAP (12)

MAP (13)

MAP (14)

MAP (15)

MAP (16)

IEC 60617 dIoHi> (1) dIoHi> (2)

3I>/Io>BF (1)

3I>/Io>BF (2)

3I>/Io>BF (3)

3I2f> (1)

Master Trip (1)

Master Trip (2)

Master Trip (3)

Master Trip (4)

ARC (1)

ARC (2)

ARC (3)

HIF (1)

MAP (8)

MAP (9)

MAP (10)

MAP (11)

MAP (12)

MAP (13)

MAP (14)

MAP (15)

MAP (16)

UFLS/R (1)

UFLS/R (2)

UFLS/R (3)

UFLS/R (4)

UFLS/R (5)

UFLS/R (6)

MAP (1)

MAP (2)

MAP (3)

MAP (4)

MAP (5)

MAP (6)

MAP (7)

29



MAPGAPC17

MAPGAPC18

CVPSOF1 Automatic switch-onto-fault logic (SOF)

Voltage vector shift protection

Directional reactive power undervoltage protection

Underpower protection

VVSPPAM1

DQPTUV1

DQPTUV2

Reverse power/directional overpower protection

Three-phase underexcitation protection

Low-voltage ridethrough protection

Rotor earth-fault protection

High-impedance differential protection for phase A

High-impedance differential protection for phase B

High-impedance differential protection for phase C

Circuit breaker uncorresponding position start-up

HIAPDIF1

HIBPDIF1

HICPDIF1

Three-independentphase non- directional overcurrent protection, low stage

Three-independentphase non- directional overcurrent protection, high stage

UPCALH1

UPCALH2

UPCALH3

PH3LPTOC1

PH3LPTOC2

PH3HPTOC1

PH3HPTOC2


DUPPDPR1

DUPPDPR2

DOPPDPR1

DOPPDPR2

DOPPDPR3

UEXPDIS1

UEXPDIS2

LVRTPTUV1

LVRTPTUV2

LVRTPTUV3

MREFPTOC1

ANSI

MAP (17)

MAP (18)

SOFT/21/50 (1)

78V (1)

32Q,27 (1)

32Q,27 (2)

32U (1)

32U (2)

32R/32O (1)

32R/32O (2)

32R/32O (3)

40 (1)

40 (2)

27RT (1)

27RT (2)

27RT (3)

64R (1)

87A (1)

87B (1)

87C (1)

CBUPS (1)

CBUPS (2)

CBUPS (3)

51P-1_3 (1)

51P-1_3 (2)

51P-2_3 (1)

51P-2_3 (2)

IEC 60617

MAP (17)

MAP (18)

CVPSOF (1)

VS (1)

Q> -> ,3U< (1)

Q> -> ,3U< (2)

P< (1)

P< (2)

P>/Q> (1)

P>/Q> (2)

P>/Q> (3)

X< (1)

X< (2)

U<RT (1)

U<RT (2)

U<RT (3)

Io>R (1) dHi_A> (1) dHi_B> (1) dHi_C> (1)

CBUPS (1)

CBUPS (2)

CBUPS (3)

3I_3> (1)

3I_3> (2)

3I_3>> (1)

3I_3>> (2)

30 620 series

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Function

Three-independentphase non- directional overcurrent protection, instantaneous stage

Directional three-independent-phase directional overcurrent protection, low stage

Directional three-independent-phase directional overcurrent protection, high stage

Three-phase overload protection for shunt capacitor banks

Current unbalance protection for shunt capacitor banks

Shunt capacitor bank switching resonance protection, current based

IEC 61850

PH3IPTOC1

DPH3LPDOC1

DPH3LPDOC2

DPH3HPDOC1

DPH3HPDOC2

COLPTOC1

CUBPTOC1

SRCPTOC1

Control

Circuit-breaker control

CBXCBR1

CBXCBR2

CBXCBR3

Disconnector control DCXSWI1

DCXSWI2

DCXSWI3

DCXSWI4

Earthing switch control

ESXSWI1

ESXSWI2

ESXSWI3

DCSXSWI1 Disconnector position indication

DCSXSWI2

DCSXSWI3

DCSXSWI4

ESSXSWI1 Earthing switch indication

ESSXSWI2

ESSXSWI3

Emergency start-up ESMGAPC1


IEC 60617

3I_3>>> (1)

3I_3> -> (1)

3I_3> -> (2)

3I_3>> -> (1)

3I_3>> -> (2)

3I> 3I< (1) dI>C (1)

TD> (1)

ANSI

50P/51P_3 (1)

I <-> O CB (1)

I <-> O CB (2)

I <-> O CB (3)

I <-> O DCC (1)

I <-> O DCC (2)

I <-> O DCC (3)

I <-> O DCC (4)

I <-> O ESC (1)

I <-> O ESC (2)

I <-> O ESC (3)

I <-> O DC (1)

I <-> O DC (2)

I <-> O DC (3)

I <-> O DC (4)

I <-> O ES (1)

I <-> O ES (2)

I <-> O ES (3)

ESTART (1)

I <-> O CB (1)

I <-> O CB (2)

I <-> O CB (3)

I <-> O DCC (1)

I <-> O DCC (2)

I <-> O DCC (3)

I <-> O DCC (4)

I <-> O ESC (1)

I <-> O ESC (2)

I <-> O ESC (3)

I <-> O DC (1)

I <-> O DC (2)

I <-> O DC (3)

I <-> O DC (4)

I <-> O ES (1)

I <-> O ES (2)

I <-> O ES (3)

ESTART (1)

67-1_3 (1)

67-1_3 (2)

67-2_3 (1)

67-2_3 (2)

51C/37 (1)

51NC-1 (1)

55TD (1)

31

Introduction

32

1MRS757644 H

Function

Autoreclosing

IEC 61850

DARREC1

DARREC2

SECRSYN1 Synchronism and energizing check

Tap changer position indication

Tap changer control with voltage regulator

TPOSYLTC1

OLATCC1

Condition monitoring and supervision

Circuit-breaker condition monitoring

Trip circuit supervision

Current circuit supervision

SSCBR1

SSCBR2

SSCBR3

TCSSCBR1

TCSSCBR2

CCSPVC1

CCSPVC2

HZCCASPVC1 Current transformer supervision for high-impedance protection scheme for phase A

Current transformer supervision for high-impedance protection scheme for phase B

Current transformer supervision for high-impedance protection scheme for phase C

Advanced current circuit supervision for transformers

Fuse failure supervision

Runtime counter for machines and devices

HZCCBSPVC1

HZCCCSPVC1

CTSRCTF1

SEQSPVC1

MDSOPT1

MDSOPT2

Measurement

Three-phase current measurement

CMMXU1

CMMXU2


IEC 60617

O -> I (1)

O -> I (2)

SYNC (1)

TPOSM (1)

COLTC (1)

CBCM (1)

CBCM (2)

CBCM (3)

TCS (1)

TCS (2)

MCS 3I (1)

MCS 3I (2)

MCS I_A (1)

MCS I_B (1)

MCS I_C (1)

MCS 3I,I2 (1)

FUSEF (1)

OPTS (1)

OPTS (2)

3I (1)

3I (2)

ANSI

79 (1)

79 (2)

25 (1)

84M (1)

90V (1)

CBCM (1)

CBCM (2)

CBCM (3)

TCM (1)

TCM (2)

MCS 3I (1)

MCS 3I (2)

MCS I_A (1)

MCS I_B (1)

MCS I_C (1)

MCS 3I,I2 (1)

60 (1)

OPTM (1)

OPTM (2)

3I (1)

3I (2)

620 series

Technical Manual


620 series

Technical Manual

Function

Sequence current measurement

Residual current measurement

IEC 61850

CSMSQI1

CSMSQI2

RESCMMXU1

RESCMMXU2

VMMXU1 Three-phase voltage measurement

Single-phase voltage measurement

VAMMXU2

VAMMXU3

RESVMMXU1 Residual voltage measurement

Sequence voltage measurement

Three-phase power and energy measurement

Load profile record

Frequency measurement

Fault location

Fault locator

VSMSQI1

PEMMXU1

LDPRLRC1

FMMXU1

SCEFRFLO1

Power quality

Current total demand distortion

Voltage total harmonic distortion

Voltage variation

Voltage unbalance

CMHAI1

VMHAI1

PHQVVR1

VSQVUB1

Other

Minimum pulse timer

(2 pcs)

TPGAPC1

TPGAPC2

TPGAPC3

TPGAPC4

TPSGAPC1

TPSGAPC2

Minimum pulse timer

(2 pcs, second resolution)

Minimum pulse timer

(2 pcs, minute resolution)

Pulse timer (8 pcs)

TPMGAPC1

TPMGAPC2

PTGAPC1

PTGAPC2


FLOC (1)

PQM3I (1)

PQM3U (1)

PQMU (1)

PQUUB (1)

TP (1)

TP (2)

TP (3)

TP (4)

TPS (1)

TPS (2)

TPM (1)

TPM (2)

PT (1)

PT (2)

IEC 60617

I1, I2, I0 (1)

I1, I2, I0 (B) (1)

Io (1)

Io (2)

3U (1)

U_A (2)

U_A (3)

Uo (1)

U1, U2, U0 (1)

P, E (1)

LOADPROF (1) f (1)

ANSI

I1, I2, I0 (1)

I1, I2, I0 (B) (1)

In (1)

In (2)

3V (1)

V_A (2)

V_A (3)

Vn (1)

V1, V2, V0 (1)

P, E (1)

LOADPROF (1) f (1)

21FL (1)

PQM3I (1)

PQM3V (1)

PQMV (1)

PQVUB (1)

TP (1)

TP (2)

TP (3)

TP (4)

TPS (1)

TPS (2)

TPM (1)

TPM (2)

PT (1)

PT (2)

33

Introduction

34


Time delay off (8 pcs) TOFGAPC1

TOFGAPC2

TOFGAPC3

TOFGAPC4

Time delay on (8 pcs) TONGAPC1

TONGAPC2

Set-reset (8 pcs)

TONGAPC3

TONGAPC4

SRGAPC1

SRGAPC2

Move (8 pcs)

Integer value move

SRGAPC3

SRGAPC4

MVGAPC1

MVGAPC2

MVGAPC3

MVGAPC4

MVI4GAPC1

MVI4GAPC2

MVI4GAPC3

MVI4GAPC4

Analog value scaling SCA4GAPC1

SCA4GAPC2

Generic control point

(16 pcs)

SCA4GAPC3

SCA4GAPC4

SPCGAPC1

SPCGAPC2

SPCGAPC3

SPCRGAPC1 Remote generic control points

Local generic control points

Generic up-down counters

SPCLGAPC1

UDFCNT1

UDFCNT2

UDFCNT3

UDFCNT4

UDFCNT5

UDFCNT6

UDFCNT7

UDFCNT8


SPCL (1)

UDCNT (1)

UDCNT (2)

UDCNT (3)

UDCNT (4)

UDCNT (5)

UDCNT (6)

UDCNT (7)

UDCNT (8)

IEC 60617

SR (3)

SR (4)

MV (1)

MV (2)

MV (3)

MV (4)

MVI4 (1)

MVI4 (2)

TOF (1)

TOF (2)

TOF (3)

TOF (4)

TON (1)

TON (2)

TON (3)

TON (4)

SR (1)

SR (2)

MVI4 (3)

MVI4 (4)

SCA4 (1)

SCA4 (2)

SCA4 (3)

SCA4 (4)

SPC (1)

SPC (2)

SPC (3)

SPCR (1)

1MRS757644 H

SPCL (1)

UDCNT (1)

UDCNT (2)

UDCNT (3)

UDCNT (4)

UDCNT (5)

UDCNT (6)

UDCNT (7)

UDCNT (8)

ANSI

SR (3)

SR (4)

MV (1)

MV (2)

MV (3)

MV (4)

MVI4 (1)

MVI4 (2)

TOF (1)

TOF (2)

TOF (3)

TOF (4)

TON (1)

TON (2)

TON (3)

TON (4)

SR (1)

SR (2)

MVI4 (3)

MVI4 (4)

SCA4 (1)

SCA4 (2)

SCA4 (3)

SCA4 (4)

SPC (1)

SPC (2)

SPC (3)

SPCR (1)

620 series

Technical Manual

1MRS757644 H


UDFCNT9

UDFCNT10

UDFCNT11

UDFCNT12

FKEYGGIO1 Programmable buttons (16 buttons)

Logging functions

Disturbance recorder RDRE1

Fault recorder FLTRFRC1

Sequence event recorder

SER1

Introduction

IEC 60617

UDCNT (9)

UDCNT (10)

UDCNT (11)

UDCNT (12)

FKEY (1)

DR (1)

FAULTREC (1)

SER (1)

ANSI

UDCNT (9)

UDCNT (10)

UDCNT (11)

UDCNT (12)

FKEY (1)

DFR (1)

FAULTREC (1)

SER (1)

620 series

Technical Manual

35

620 series overview 1MRS757644 H

2

2.1

2.1.1

620 series overview

Overview

620 series is a product family of relays designed for protection, control, measurement and supervision of utility substations and industrial switchgear and equipment. The design of the relay has been guided by the IEC 61850 standard for communication and interoperability of substation automation devices.

The protection relays feature draw-out-type design with a variety of mounting methods, compact size and ease of use. Depending on the product, optional functionality is available at the time of order for both software and hardware, for example, ARC protection.

The 620 series protection relays support a range of communication protocols including IEC 61850 with GOOSE messaging, IEC 61850-9-2 LE, IEC 60870-5-103,

Modbus ® and DNP3.

Product series version history

Product series version

2.0

Product series history

New products:

• REF620 with configurations A and B

• REM620 with configuration A

• RET620 with configuration A

2.0 FP1

New configuration

• REM620 B

Platform enhancements

• IEC 61850 Edition 2

• Support for IEC 61850-9-2 LE

• Currents sending support with IEC 61850-9-2 LE

• Synchronism and energizing check support with IEC 61850-9-2 LE

• IEEE 1588 v2 time synchronization

• Configuration migration support

• Software closable Ethernet ports

• Report summary via WHMI

• Multifrequency admittance-based E/F

• Fault locator

• Profibus adapter support

• Setting usability improvements

36 620 series

Technical Manual

1MRS757644 H

2.1.2

620 series overview

PCM600 and IED connectivity package version

• Protection and Control IED Manager PCM600 2.6 (Rollup 20150626) or later

• REF620 Connectivity Package Ver.2.1 or later

• REM620 Connectivity Package Ver.2.1 or later

• RET620 Connectivity Package Ver.2.1 or later

Download connectivity packages from the ABB Web site www.abb.com/ substationautomation or directly with Update Manager in PCM600.

2.2

Local HMI

The LHMI is used for setting, monitoring and controlling the protection relay. The

LHMI comprises the display, buttons, LED indicators and communication port.

SG1

Enabled

SG2

Enabled

SG3

Enabled

SG4

Enabled

SG5

Enabled

SG6

Enabled

DR

Trigger

Trip Lockout

Reset

CB Block

Bypass

AR

Disable

Overcurrent protection

Earth-fault protection

Voltage protection

Frequency protection

Ph.unbalance or thermal ov.

Synchronism OK

Breaker failure protection

CB condition monitoring

Supervision

Autoreclose in progress

Arc detected

2.2.1

Figure 2: Example of the LHMI

Display

The LHMI includes a graphical display that supports one character size. The character size depends on the selected language. The amount of characters and rows fitting the view depends on the character size.

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Technical Manual

37


Table 2: Display

Character size 1

Small, mono-spaced (6 × 12 pixels)

Large, variable width (13 × 14 pixels)

Rows in the view

10

7

The display view is divided into four basic areas.

1 2

Characters per row

20

8 or more

2.2.2

2.2.3

3

1 Header

2 Icon

Figure 3: Display layout

4

3 Content

4 Scroll bar (displayed when needed)

LEDs

The LHMI includes three protection indicators above the display: Ready, Start and

Trip.

There are 11 matrix programmable LEDs on front of the LHMI. The LEDs can be configured with PCM600 and the operation mode can be selected with the LHMI,

WHMI or PCM600.

Keypad

The LHMI keypad contains push buttons which are used to navigate in different views or menus. With the push buttons you can give open or close commands to objects in the primary circuit, for example, a circuit breaker, a contactor or a disconnector. The push buttons are also used to acknowledge alarms, reset indications, provide help and switch between local and remote control mode.

38

1 Depending on the selected language

620 series

Technical Manual

1MRS757644 H 620 series overview

2.2.3.1

Figure 4: LHMI keypad with object control, navigation and command push buttons and RJ-45 communication port

Programmable push buttons with LEDs

620 series

Technical Manual

Figure 5: Programmable push buttons with LEDs

The LHMI keypad on the left side of the protection relay contains 16 programmable push buttons with red LEDs.

The buttons and LEDs are freely programmable, and they can be configured both for operation and acknowledgement purposes. That way, it is possible to get acknowledgements of the executed actions associated with the buttons.

This combination can be useful, for example, for quickly selecting or changing a setting group, selecting or operating equipment, indicating field contact status or indicating or acknowledging individual alarms.

39

620 series overview

2.3

1MRS757644 H

The LEDs can also be independently configured to bring general indications or important alarms to the operator's attention.

To provide a description of the button function, it is possible to insert a paper sheet behind the transparent film next to the button.

Web HMI

The WHMI allows secure access to the protection relay via a Web browser. When the Secure Communication parameter in the protection relay is activated, the

Web server is forced to take a secured (HTTPS) connection to WHMI using TLS encryption. The WHMI is verified with Internet Explorer 8.0, 9.0, 10.0 and 11.0.

WHMI is disabled by default.

Control operations are not allowed by WHMI.

WHMI offers several functions.

• Programmable LEDs and event lists

• System supervision

• Parameter settings

• Measurement display

• Disturbance records

• Fault records

• Load profile record

• Phasor diagram

• Single-line diagram

• Importing/Exporting parameters

• Report summary

The menu tree structure on the WHMI is almost identical to the one on the LHMI.

40 620 series

Technical Manual


2.4

Figure 6: Example view of the WHMI

The WHMI can be accessed locally and remotely.

• Locally by connecting the laptop to the protection relay via the front communication port.

• Remotely over LAN/WAN.

Authorization

Four user categories have been predefined for the LHMI and the WHMI, each with different rights and default passwords.

The default passwords in the protection relay delivered from the factory can be changed with Administrator user rights.

If the relay-specific Administrator password is forgotten, ABB can provide a onetime reliable key to access the protection relay. For support, contact ABB. The recovery of the Administrator password takes a few days.

User authorization is disabled by default for LHMI but WHMI always uses authorization.

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Technical Manual

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Table 3: Predefined user categories

Username

VIEWER

OPERATOR

ENGINEER

ADMINISTRATOR

User rights

Read only access

•

Selecting remote or local state with (only locally)

• Changing setting groups

• Controlling

• Clearing indications

• Changing settings

• Clearing event list

• Clearing disturbance records

• Changing system settings such as IP address, serial baud rate or disturbance recorder settings

• Setting the protection relay to test mode

• Selecting language

• All listed above

• Changing password

• Factory default activation

For user authorization for PCM600, see PCM600 documentation.

2.4.1

Audit trail

The protection relay offers a large set of event-logging functions. Critical system and protection relay security-related events are logged to a separate nonvolatile audit trail for the administrator.

Audit trail is a chronological record of system activities that allows the reconstruction and examination of the sequence of system and security-related events and changes in the protection relay. Both audit trail events and process related events can be examined and analyzed in a consistent method with the help of Event List in LHMI and WHMI and Event Viewer in PCM600.

The protection relay stores 2048 audit trail events to the nonvolatile audit trail.

Additionally, 1024 process events are stored in a nonvolatile event list. Both the audit trail and event list work according to the FIFO principle. Nonvolatile memory is based on a memory type which does not need battery backup nor regular component change to maintain the memory storage.

Audit trail events related to user authorization (login, logout, violation remote and violation local) are defined according to the selected set of requirements from IEEE

1686. The logging is based on predefined user names or user categories. The user audit trail events are accessible with IEC 61850-8-1, PCM600, LHMI and WHMI.

42 620 series

Technical Manual


620 series

Technical Manual

Table 4: Audit trail events

Audit trail event

Configuration change

Firmware change

Firmware change fail

Setting group remote

Setting group local

Control remote

Control local

Test on

Test off

Reset trips

Setting commit

Time change

View audit log

Login

Logout

Password change

Firmware reset

Audit overflow

Violation remote

Violation local

Description

Configuration files changed

Firmware changed

Firmware change failed

User changed setting group remotely

User changed setting group locally

DPC object control remote

DPC object control local

Test mode on

Test mode off

Reset latched trips (TRPPTRC*)

Settings have been changed

Time changed directly by the user. Note that this is not used when the protection relay is synchronised properly by the appropriate protocol (SNTP, IRIG-B, IEEE 1588 v2).

Administrator accessed audit trail

Successful login from IEC 61850-8-1 (MMS), WHMI, FTP or

LHMI.

Successful logout from IEC 61850-8-1 (MMS), WHMI, FTP or

LHMI.

Password changed

Reset issued by user or tool

Too many audit events in the time period

Unsuccessful login attempt from IEC 61850-8-1 (MMS),

WHMI, FTP or LHMI.

Unsuccessful login attempt from IEC 61850-8-1 (MMS),

WHMI, FTP or LHMI.

PCM600 Event Viewer can be used to view the audit trail events and process related events. Audit trail events are visible through dedicated Security events view. Since only the administrator has the right to read audit trail, authorization must be used in PCM600. The audit trail cannot be reset, but PCM600 Event Viewer can filter data. Audit trail events can be configured to be visible also in LHMI/WHMI Event list together with process related events.

To expose the audit trail events through Event list, define the Authority logging level parameter via Configuration > Authorization > Security.

This exposes audit trail events to all users.

Table 5: Comparison of authority logging levels


None Configuration change

●

Authority logging level

Setting group

Setting group, control

● ●

Settings edit

● Configuration change


All

●

43

620 series overview

2.5

44

1MRS757644 H


Firmware change

Firmware change fail

Setting group remote

Setting group local

Control remote

Control local

Test on

Test off

Reset trips

Setting commit

Time change

View audit log

Login

Logout

Password change

Firmware reset

Violation local

Violation remote

●

●

Authority logging level

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

Communication

The protection relay supports a range of communication protocols including

IEC 61850, IEC 61850-9-2 LE, IEC 60870-5-103, Modbus ® and DNP3. Profibus

DPV1 communication protocol is supported by using the protocol converter

SPA-ZC 302. Operational information and controls are available through these protocols. However, some communication functionality, for example, horizontal communication between the protection relays, is only enabled by the IEC 61850 communication protocol.

The IEC 61850 communication implementation supports all monitoring and control functions. Additionally, parameter settings, disturbance recordings and fault records can be accessed using the IEC 61850 protocol. Disturbance recordings are available to any Ethernet-based application in the IEC 60255-24 standard

COMTRADE file format. The protection relay can send and receive binary signals from other devices (so-called horizontal communication) using the IEC 61850-8-1

GOOSE profile, where the highest performance class with a total transmission time of 3 ms is supported. Furthermore, the protection relay supports sending and receiving of analog values using GOOSE messaging. The protection relay meets the GOOSE performance requirements for tripping applications in distribution substations, as defined by the IEC 61850 standard.

The protection relay can support five simultaneous clients. If PCM600 reserves one client connection, only four client connections are left, for example, for IEC 61850 and Modbus.

All communication connectors, except for the front port connector, are placed on integrated optional communication modules. The protection relay can be

620 series

Technical Manual

1MRS757644 H

2.5.1

620 series overview connected to Ethernet-based communication systems via the RJ-45 connector

(100Base-FX) or the fiber-optic LC connector (100Base-FX).

Self-healing Ethernet ring

For the correct operation of self-healing loop topology, it is essential that the external switches in the network support the RSTP protocol and that it is enabled in the switches. Otherwise, connecting the loop topology can cause problems to the network. The protection relay itself does not support link-down detection or RSTP.

The ring recovery process is based on the aging of the MAC addresses, and the linkup/link-down events can cause temporary breaks in communication. For a better performance of the self-healing loop, it is recommended that the external switch furthest from the protection relay loop is assigned as the root switch (bridge priority = 0) and the bridge priority increases towards the protection relay loop.

The end links of the protection relay loop can be attached to the same external switch or to two adjacent external switches. A self-healing Ethernet ring requires a communication module with at least two Ethernet interfaces for all protection relays.

Client A Client B

Managed Ethernet switch with RSTP support

Network A

Network B

Managed Ethernet switch with RSTP support

Figure 7: Self-healing Ethernet ring solution

The Ethernet ring solution supports the connection of up to 30 protection relays. If more than 30 protection relays are to be connected, it is recommended that the network is split into several rings with no more than 30 protection relays per ring. Each protection relay has a 50-μs store-and-forward delay, and to fulfil the performance requirements for fast horizontal communication, the ring size is limited to 30 protection relays.

2.5.2

620 series

Technical Manual

Ethernet redundancy

IEC 61850 specifies a network redundancy scheme that improves the system availability for substation communication. It is based on two complementary

45

620 series overview 1MRS757644 H protocols defined in the IEC 62439-3:2012 standard: parallel redundancy protocol

PRP and high-availability seamless redundancy HSR protocol. Both protocols rely on the duplication of all transmitted information via two Ethernet ports for one logical network connection. Therefore, both are able to overcome the failure of a link or switch with a zero-switchover time, thus fulfilling the stringent real-time requirements for the substation automation horizontal communication and time synchronization.

PRP specifies that each device is connected in parallel to two local area networks.

HSR applies the PRP principle to rings and to the rings of rings to achieve cost-effective redundancy. Thus, each device incorporates a switch element that forwards frames from port to port. The HSR/PRP option is available for all 615 series protection relays. However, RED615 supports this option only over fiber optics.

IEC 62439-3:2012 cancels and replaces the first edition published in 2010.

These standard versions are also referred to as IEC 62439-3 Edition 1 and

IEC 62439-3 Edition 2. The protection relay supports IEC 62439-3:2012 and it is not compatible with IEC 62439-3:2010.

PRP

Each PRP node, called a double attached node with PRP (DAN), is attached to two independent LANs operated in parallel. These parallel networks in PRP are called LAN A and LAN B. The networks are completely separated to ensure failure independence, and they can have different topologies. Both networks operate in parallel, thus providing zero-time recovery and continuous checking of redundancy to avoid communication failures. Non-PRP nodes, called single attached nodes

(SANs), are either attached to one network only (and can therefore communicate only with DANs and SANs attached to the same network), or are attached through a redundancy box, a device that behaves like a DAN.

COM600

SCADA

Ethernet switch

IEC 61850 PRP

Ethernet switch

46

Figure 8: PRP solution

In case a laptop or a PC workstation is connected as a non-PRP node to one of the PRP networks, LAN A or LAN B, it is recommended to use a redundancy box device or an Ethernet switch with similar functionality between the PRP network

620 series

Technical Manual

1MRS757644 H 620 series overview and SAN to remove additional PRP information from the Ethernet frames. In some cases, default PC workstation adapters are not able to handle the maximum-length

Ethernet frames with the PRP trailer.

There are different alternative ways to connect a laptop or a workstation as SAN to a PRP network.

• Via an external redundancy box (RedBox) or a switch capable of connecting to

PRP and normal networks

• By connecting the node directly to LAN A or LAN B as SAN

• By connecting the node to the protection relay's interlink port

HSR

HSR applies the PRP principle of parallel operation to a single ring, treating the two directions as two virtual LANs. For each frame sent, a node, DAN, sends two frames, one over each port. Both frames circulate in opposite directions over the ring and each node forwards the frames it receives, from one port to the other. When the originating node receives a frame sent to itself, it discards that to avoid loops; therefore, no ring protocol is needed. Individually attached nodes, SANs, such as laptops and printers, must be attached through a “redundancy box” that acts as a ring element. For example, a 615 or 620 series protection relay with HSR support can be used as a redundancy box.

Figure 9: HSR solution

2.5.3

620 series

Technical Manual

Process bus

Process bus IEC 61850-9-2 defines the transmission of Sampled Measured Values within the substation automation system. International Users Group created a guideline IEC 61850-9-2 LE that defines an application profile of IEC 61850-9-2 to facilitate implementation and enable interoperability. Process bus is used for distributing process data from the primary circuit to all process bus compatible devices in the local network in a real-time manner. The data can then be processed

47

620 series overview 1MRS757644 H by any protection relay to perform different protection, automation and control functions.

UniGear Digital switchgear concept relies on the process bus together with current and voltage sensors. The process bus enables several advantages for the UniGear

Digital like simplicity with reduced wiring, flexibility with data availability to all devices, improved diagnostics and longer maintenance cycles.

With process bus the galvanic interpanel wiring for sharing busbar voltage value can be replaced with Ethernet communication. Transmitting measurement samples over process bus brings also higher error detection because the signal transmission is automatically supervised. Additional contribution to the higher availability is the possibility to use redundant Ethernet network for transmitting SMV signals.

Common Ethernet

Station bus (IEC 61850-8-1), process bus (IEC 61850-9-2 LE) and IEEE 1588 v2 time synchronization

48

Figure 10: Process bus application of voltage sharing and synchrocheck

The 620 series supports IEC 61850 process bus with sampled values of analog currents and voltages. The measured values are transferred as sampled values using the IEC 61850-9-2 LE protocol which uses the same physical Ethernet network as the IEC 61850-8-1 station bus. The intended application for sampled values is sharing the measured voltages from one 620 series protection relay to other devices with phase voltage based functions and 9-2 support.

The 620 series protection relays with process bus based applications use IEEE

1588 v2 Precision Time Protocol (PTP) according to IEEE C37.238-2011 Power

Profile for high accuracy time synchronization. With IEEE 1588 v2, the cabling infrastructure requirement is reduced by allowing time synchronization information to be transported over the same Ethernet network as the data communications.

620 series

Technical Manual


Primary

IEEE 1588 v2 master clock

Managed HSR

Ethernet switch

IEC 61850

HSR

Secondary

IEEE 1588 v2 master clock

(optional)

Managed HSR

Ethernet switch

2.5.4

Backup 1588 master clock

Figure 11: Example network topology with process bus, redundancy and IEEE 1588 v2 time synchronization

The process bus option is available for all 620 series protection relays equipped with phase voltage inputs. Another requirement is a communication card with IEEE

1588 v2 support (COM0031...COM0034 or COM0037). See the IEC 61850 engineering guide for detailed system requirements and configuration details.

Secure communication

The protection relay supports secure communication for WHMI and file transfer protocol. If the Secure Communication parameter is activated, protocols require

TLS based encryption method support from the clients. In this case WHMI must be connected from a Web browser using the HTTPS protocol and in case of file transfer the client must use FTPS.

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Technical Manual

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Basic functions 1MRS757644 H

3 Basic functions

3.1

General parameters

3.1.1

Analog input settings, phase currents

Table 6: Analog input settings, phase currents

Parameter

Primary current

Values (Range)

1.0...6000.0

Secondary current 1

Amplitude Corr A

2=1A

3=5A

0.9000...1.1000

Unit

A

Amplitude Corr B

Rated secondary

Val

Reverse polarity

0.9000...1.1000

Amplitude Corr C 0.9000...1.1000

Nominal current 2 39...4000

1.000...150.000

Angle Corr A

Angle Corr B

Angle Corr C

0=False

1=True

-8.000 … 8.000

-8.000 … 8.000

-8.000 … 8.000

A mV/Hz deg deg deg

Step

0.1

0.0001

0.0001

0.0001

1

0.001

0.0001

0.0001

0.0001

Default

100.0

2=1A

0.0000

0.0000

0.0000

1.0000

1.0000

1.0000

1300

3.000

0=False

Description

Rated primary current

Rated secondary current

Phase A amplitude correction factor

Phase B amplitude correction factor

Phase C amplitude correction factor

Network Nominal

Current (In)

Rated Secondary

Value (RSV) ratio

Reverse the polarity of the phase CTs

Phase A angle correction factor

Phase B angle correction factor

Phase C angle correction factor

50

1

2

For CT

For sensor

620 series

Technical Manual

1MRS757644 H Basic functions

3.1.2

Analog input settings, residual current

Table 7: Analog input settings, residual current

Parameter

Primary current

Secondary current

Amplitude Corr

Values (Range)

1.0...6000.0

1=0.2A

2=1A

3=5A

0.9000...1.1000

Unit

A

Reverse polarity

Angle correction

0=False

1=True

-8.000 … 8.000

deg

Step

0.1

0.0001

0.0001

Default

100.0

2=1A

1.0000

0=False

0.0000

Description

Primary current

Secondary current

Amplitude correction

Reverse the polarity of the residual

CT

Angle correction factor

3.1.3

Analog input settings, phase voltages

Table 8: Analog input settings, phase voltages

Parameter

Primary voltage 1

Values (Range)

0.100...440.000

Unit kV

V Secondary voltage 60...210

VT connection

Amplitude Corr A

1=Wye

2=Delta

3=U12

4=UL1

0.9000...1.1000

Step

0.001

1

0.0001

Default

20.000

100

2=Delta

1.0000

Amplitude Corr B 0.9000...1.1000


Division ratio 2 1000...20000

Voltage input type

1=Voltage trafo

3=CVD sensor


0.0001

0.0001

1

Description

Primary rated voltage

Secondary rated voltage

Voltage transducer measurement connection

1.0000

1.0000

10000

1=Voltage trafo

Phase A Voltage phasor magnitude correction of an external voltage transformer

Phase B Voltage phasor magnitude correction of an external voltage transformer

Phase C Voltage phasor magnitude correction of an external voltage transformer

Voltage sensor division ratio

Type of the voltage input

1

2

For VT

For sensor

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Technical Manual

51

Basic functions

Parameter

Angle Corr A

Values (Range)

-8.000 … 8.000

Unit deg

Angle Corr B -8.000 … 8.000

deg

Angle Corr C -8.000 … 8.000

deg

Step

0.0001

0.0001

0.0001

3.1.4

Analog input settings, residual voltage

Table 9: Analog input settings, residual voltage

Parameter Values (Range)

Primary voltage 0.100 ... 440.000

Secondary voltage 60...210

1

Amplitude Corr 0.9000 ... 1.1000

Angle correction -8.000 … 8.000

Unit kV

V deg

Step

0.001

1

0.0001

0.0001

Default

11.547

100

1.0000

0.0000

Default

0.0000

0.0000

0.0000

1MRS757644 H

Description

Phase A Voltage phasor angle correction of an external voltage transformer

Phase B Voltage phasor angle correction of an external voltage transformer

Phase C Voltage phasor angle correction of an external voltage transformer

Description

Primary voltage

Secondary voltage



52

1 In 9-2 applications, Primary voltage maximum is limited to 126 kV.

620 series

Technical Manual

1MRS757644 H

3.1.5

Authorization settings

Table 10: Authorization settings

Parameter

Local override

Values (Range)

0=False 1

1=True 2

Remote override

0=False 3

1=True 4

Local viewer

Local operator

Local engineer

Local administrator

Remote viewer

Remote operator

Remote engineer

Remote administrator

Authority logging

1=None

2=Configuration change

3=Setting group

4=Setting group, control

5=Settings edit

6=All

Unit Step

Basic functions

Default

1=True

1=True

Description

Disable authority

Disable authority

0

0

0

0

0

0

0

0

4=Setting group, control

Set password

Set password

Set password

Set password

Set password

Set password

Set password

Set password

Authority logging level

3

4

1

2

Authorization override disabled, LHMI password required

Authorization override enabled, LHMI password not required

Authorization override disabled, communication tools request a password to enter the IED

Authorization override enabled, other communication tools than WHMI do not request a password to enter the IED

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53

Basic functions

3.1.6

Binary input settings

Table 11: Binary input settings


Threshold voltage 16...176

Input osc. level 2...50

Unit

Vdc events/s

Step

2

1

Input osc. hyst 2...50

events/s 1

1MRS757644 H

Default

16

30

10

Description

Binary input threshold voltage

Binary input oscillation suppression threshold

Binary input oscillation suppression hysteresis

54 620 series

Technical Manual


3.1.7

Binary signals in card location Xnnn

Table 12: Binary input signals in card location Xnnn

Name

Xnnn-Input m 1 , 2

Type

BOOLEAN

Table 13: Binary output signals in card location Xnnn

Name

Xnnn-Pmm 1 , 3

Type

BOOLEAN

Default

0=False

Description

See the application manual for terminal connections

Description

See the application manual for terminal connections

1

2

3

Xnnn = Slot ID, for example, X100, X110, as applicable m =For example, 1, 2, depending on the serial number of the binary input in a particular BIO card

Pmm = For example, PO1, PO2, SO1, SO2, as applicable

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3.1.8

Binary input settings in card location Xnnn

Table 14: Binary input settings in card location Xnnn

Name 1

Input m 2 filter time

Input m inversion

Value

5…1000

0= False

1= True

Unit ms

Step Default

5

0=False

3.1.9

Ethernet front port settings

Table 15: Ethernet front port settings

Parameter

IP address

Values (Range) Unit

Mac address

Step Default Description

192.168.0.254

IP address for front port (fixed)

XX-XX-XX-XX-XX-XX Mac address for front port

3.1.10

Ethernet rear port settings

Table 16: Ethernet rear port settings

Parameter

IP address


Subnet mask

Default gateway

Mac address

Step Default Description

192.168.2.10

255.255.255.0

IP address for rear port(s)

Subnet mask for rear port(s)

192.168.2.1

Default gateway for rear port(s)

XX-XX-XX-XX-XX-XX Mac address for rear port(s)

56

1

2

Xnnn = Slot ID, for example, X100, X110, as applicable m = For example, 1, 2, depending on the serial number of the binary input in a particular BIO card

620 series

Technical Manual

1MRS757644 H

3.1.11

General system settings

Table 17: General system settings

Parameter

Rated frequency

Phase rotation

Blocking mode

Values (Range)

1=50Hz

2=60Hz

1=ABC

2=ACB

1=Freeze timer

2=Block all

3=Block OPERATE output

Unit

Bay name 1

IDMT Sat point 10...50

I/I>

SMV Max Delay

0=1.90 1.58 ms

1=3.15 2.62 ms

2=4.40 3.67 ms

3=5.65 4.71 ms

4=6.90 5.75 ms

Step

1

Basic functions

Default

1=50Hz

1=ABC

1=Freeze timer

Description

Rated frequency of the network

Phase rotation order

Behaviour for function BLOCK inputs

REx620 2

50

1=3.15 2.62 ms

Bay name in system

Overcurrent IDMT saturation point

SMV Maximum allowed delay

1

2

Used in the IED main menu header and as part of the disturbance recording identification

Depending on the product variant

620 series

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57

Basic functions

3.1.12

HMI settings

Table 18: HMI settings

Parameter

FB naming convention

Values (Range)

1=IEC61850

2=IEC60617

3=IEC-ANSI

Default view

1=Measurements

2=Main menu

3=SLD

Backlight timeout 1...60

Web HMI mode

1=Active read only

2=Active

3=Disabled

Web HMI timeout 1...60

SLD symbol format 1=IEC

2=ANSI

Autoscroll delay 0...30

Unit min min s

Setting visibility

1=Basic

2=Advanced

Step

1

1

1

3.1.13

IEC 60870-5-103 settings

Table 19: IEC 60870-5-103 settings

Parameter

Operation

Serial port

Address

Start delay

Values (Range)

1=on

5=off

1=COM 1

2=COM 2

1...255

0...20

Unit char char End delay

DevFunType

UsrFunType

UsrInfNo

0...20

0...255

0...255

0...255

Step

1

1

1

1

1

1


58

1MRS757644 H

Default

1=IEC61850

Description

FB naming convention used in IED

1=Measurements LHMI default view

3

3=Disabled

3

1=IEC

0

1=Basic

LHMI backlight timeout

Web HMI functionality

Web HMI login timeout

Single Line Diagram symbol format

Autoscroll delay for Measurements view

Setting visibility for

HMI

Default

5=off

1=COM 1

4

9

1

4

10

230

Description

Selects if this protocol instance is enabled or disabled

COM port

Unit address

Start frame delay in chars

End frame delay in chars

Device Function

Type

Function type for

User Class 2 Frame

Information Number for User Class2

Frame

620 series

Technical Manual

1MRS757644 H

Parameter

Class1Priority

Values (Range)

0=Ev High

1=Ev/DR Equal

2=DR High

0...86400

Class2Interval

Frame1InUse

-1=Not in use

0=User frame

1=Standard frame 1

2=Standard frame 2

3=Standard frame

3

4=Standard frame

4

5=Standard frame

5

6=Private frame 6

7=Private frame 7

Frame2InUse

-1=Not in use

0=User frame

1=Standard frame 1

2=Standard frame 2

3=Standard frame

3

4=Standard frame

4

5=Standard frame

5

6=Private frame 6

7=Private frame 7

Frame3InUse

-1=Not in use

0=User frame

1=Standard frame 1

2=Standard frame 2

3=Standard frame

3

4=Standard frame

4

5=Standard frame

5

6=Private frame 6

7=Private frame 7


Unit s

Step

1

Basic functions

Default Description

0=Ev High

30

Class 1 data sending priority relationship between

Events and Disturbance Recorder data.

Interval in seconds to send class 2 response

6=Private frame 6 Active Class2

Frame 1

-1=Not in use Active Class2

Frame 2

-1=Not in use Active Class2

Frame 3

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59

Basic functions

Parameter

Frame4InUse

Class1OvInd

Class1OvFType

Class1OvInfNo

Class1OvBackOff

GI Optimize

DR Notification

Block Monitoring

Internal Overflow

EC_FRZ

0...500

0=Standard behaviour

1=Skip spontaneous

2=Only overflown

3=Combined

0=False

1=True

0=Not in use

1=Discard events

2=Keep events

0=False

1=True

0=False

1=True

Values (Range)

-1=Not in use

0=User frame

1=Standard frame 1

2=Standard frame 2

3=Standard frame

3

4=Standard frame

4

5=Standard frame

5

6=Private frame 6

7=Private frame 7

Unit

0=No indication

1=Both edges

2=Rising edge

0...255

0...255

3.1.14

Step

1

1

1

IEC 61850-8-1 MMS settings

1MRS757644 H

Default

-1=Not in use

Description

Active Class2

Frame 4

2=Rising edge Overflow Indication

10

255

500

0=Standard behaviour

Function Type for

Class 1 overflow indication

Information Number for Class 1 overflow indication

Backoff Range for

Class1 buffer

Optimize GI traffic

0=False

0=Not in use

0=False

0=False

Disturbance Recorder spontaneous indications enabled/disabled

Blocking of Monitoring Direction

Internal Overflow:

TRUE-System level overflow occured

(indication only)

Control point for freezing energy counters

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1MRS757644 H

Table 20: IEC 61850-8-1 MMS settings

Parameter

Unit mode

Values (Range)

1=Primary 1

0=Nominal 2

2=Primary-Nominal

3

Unit

Basic functions

Step Default

0=Nominal

Description

IEC 61850-8-1 unit mode

3

1

2

MMS client expects primary values from event reporting and data attribute reads.

MMS client expects nominal values from event reporting and data attribute reads; this is the default for PCM600.

For PCM600 use only, When Unit mode is set to "Primary", the PCM600 client can force its session to "Nominal" by selecting "Primary-Nominal" and thus parameterizing in native form. The selection is not stored and is therefore effective only for one session. This value has no effect if selected via the LHMI.

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61

Basic functions

3.1.15

Modbus settings

Table 21: Modbus settings

Parameter

Operation

Port

Values (Range)

1=on

5=off

1=COM 1

2=COM 2

3=Ethernet - TCP 1

Unit

Mapping selection 1...2

Address

Link mode

1...254

1=RTU

2=ASCII

1...65535

TCP port

Parity

Start delay

End delay

CRC order

0=none

1=odd

2=even

0...20

0...20

0=Hi-Lo

1=Lo-Hi

Client IP

Write authority

Time format

0=Read only

1=Disable 0x write

2=Full access

0=UTC

1=Local

Event ID selection

0=Address

1=UID


Step

1

1

1

1

1

62

1MRS757644 H

Default

5=off

Description

Enable or disable this protocol instance

3=Ethernet - TCP 1 Port selection for this protocol instance. Select between serial and

Ethernet based communication.

1

1

1=RTU

Chooses which mapping scheme will be used for this protocol instance.

Unit address

502

Selects between

ASCII and RTU mode. For TCP, this should always be

RTU.

Defines the listening port for the

Modbus TCP server. Default = 502.

2=even Parity for the serial connection.

4

4

0=Hi-Lo

0.0.0.0

2=Full access

1=Local

0=Address

Start delay in character times for serial connection

End delay in character times for serial connections

Selects between normal or swapped byte order for checksum for serial connection. Default: Hi-Lo.

Sets the IP address of the client. If set to zero, connection from any client is accepted.

Selects the control authority scheme

Selects between

UTC and local time for events and timestamps.

Selects whether the events are reported using the MB address or the UID number.

620 series

Technical Manual

1MRS757644 H

Parameter

Event buffering

Event backoff

Values (Range)

0=Keep oldest

1=Keep newest

1...500

Unit

ControlStructPWd 1

ControlStructPWd

2

ControlStructPWd

3

ControlStructPWd

4

ControlStructPWd

5

ControlStructPWd

6

ControlStructPWd

7

ControlStructPWd

8

Step

1

Basic functions

Default

0=Keep oldest

200

****

****

****

****

****

****

****

****

Description

Selects whether the oldest or newest events are kept in the case of event buffer overflow.

Defines how many events have to be read after event buffer overflow to allow new events to be buffered. Applicable in "Keep oldest" mode only.

Password for control operations using Control Struct mechanism, which is available on 4x memory area.








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63


3.1.16

DNP3 settings

Table 22: DNP3 settings

Parameter

Operation

Port

Unit address

Master address

Mapping select

ClientIP

TCP port

Values (Range)

1=on

5=off

1=COM 1

2=COM 2

3=Ethernet - TCP 1

4=Ethernet

TCP+UDP 1

1...65519

1...65519

1...2

20000...65535

Unit

TCP write authority

0=No clients

1=Reg. clients

2=All clients

0...65535

Link keep-alive

Validate master addr s

Self address

Need time interval

Time format

1=Disable

2=Enable

1=Disable

2=Enable

0...65535

0=UTC

1=Local

1...65535

min

CROB select timeout

Data link confirm s

Data link confirm TO

Data link retries

Data link Rx to Tx delay

Data link inter char delay

App layer confirm

0=Never

1=Only Multiframe

2=Always

100...65535

0...65535

0...255

0...20

App confirm TO

App layer fragment

1=Disable

2=Enable

100...65535

256...2048

UR mode

1=Disable

2=Enable

Table continues on the next page ms ms char ms bytes

Step

1

1

1

1

1

1

1

1

1

1

1

1

1

Default

5=off

Description

Operation Off / On

3=Ethernet - TCP 1 Communication interface selection

1

3

1

0.0.0.0

20000

2=All clients

0

1=Disable

2=Enable

30

1=Local

10

0=Never

3000

3

0

4

1=Disable

5000

2048

1=Disable

DNP unit address

DNP master and UR address

Mapping select

IP address of client

TCP Port used on ethernet communication

0=no client controls allowed;

1=Controls allowed by registered clients; 2=Controls allowed by all clients

Link keep-alive interval for

DNP

Validate master address on receive

Support self address query function

Period to set IIN need time bit

UTC or local. Coordinate with master.

Control Relay Output Block select timeout

Data link confirm mode

Data link confirm timeout

Data link retries count

Turnaround transmission delay

Inter character delay for incoming messages

Application layer confirm mode

Application layer confirm and

UR timeout

Application layer fragment size

Unsolicited responses mode

64 620 series

Technical Manual


Parameter

UR retries

UR TO

UR offline interval

UR Class 1 Min events

UR Class 1 TO


Values (Range)

0...65535

0...65535

0...65535

0...999

0...65535

0...999

Unit ms min ms

UR Class 2 TO


0...65535

0...999

ms

UR Class 3 TO

Legacy master UR

0...65535

1=Disable

2=Enable

Legacy master SBO

1=Disable

2=Enable

Default Var Obj 01

1=1:BI

2=2:BI&status

Default Var Obj 02

1=1:BI event

2=2:BI event&time

Default Var Obj 03

1=1:DBI

2=2:DBI&status

Default Var Obj 04

1=1:DBI event

2=2:DBI event&time

Default Var Obj 20

1=1:32bit Cnt

2=2:16bit Cnt

5=5:32bit Cnt noflag

6=6:16bit Cnt noflag

Default Var Obj 21

1=1:32bit FrzCnt

2=2:16bit FrzCnt

5=5:32bit

FrzCnt&time

6=6:16bit

FrzCnt&time

9=9:32bit FrzCnt noflag

10=10:16bit FrzCnt noflag

Default Var Obj 22

1=1:32bit Cnt evt

2=2:16bit Cnt evt

5=5:32bit Cnt evt&time


Table continues on the next page ms

1

1

1

1

1

1

1

1

Step

1

Default

3

5000

15

2

50

2

50

2

50

1=Disable

1=Disable

Description

Unsolicited retries before switching to UR offline mode

Unsolicited response timeout

Unsolicited offline interval

Min number of class 1 events to generate UR

Max holding time for class 1 events to generate UR





Legacy DNP master unsolicited mode support. When enabled relay does not send initial unsolicited message.

Legacy DNP Master SBO sequence number relax enable

1=BI; 2=BI with status.

1=1:BI

2=2:BI event&time 1=BI event; 2=BI event with time.

1=1:DBI 1=DBI; 2=DBI with status.

2=2:DBI event&time 1=DBI event; 2=DBI event with time.

2=2:16bit Cnt 1=32 bit counter; 2=16 bit counter; 5=32 bit counter without flag; 6=16 bit counter without flag.

6=6:16bit

FrzCnt&time


1=32 bit frz counter; 2=16 bit frz counter; 5=32 bit frz counter with time; 6=16 bit frz counter with time; 9=32 bit frz counter without flag;10=16 bit frz counter without flag.

1=32 bit counter event; 2=16 bit counter event; 5=32 bit counter event with time; 6=16 bit counter event with time.

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Parameter

Default Var Obj 23

Default Var Obj 30

Default Var Obj 32

Default Var Obj 40

Default Var Obj 42

3.1.17

Values (Range)

1=1:32bit FrzCnt evt

2=2:16bit FrzCnt evt

5=5:32bit FrzCnt evt&time


Unit

1=1:32bit AI

2=2:16bit AI

3=3:32bit AI noflag

4=4:16bit AI noflag

5=5:AI float

6=6:AI double

1=1:32bit AI evt

2=2:16bit AI evt

3=3:32bit AI evt&time

4=4:16bit AI evt&time

5=5: float AI evt

6=6:double AI evt

7=7:float AI evt&time

8=8:double AI evt&time

1=1:32bit AO

2=2:16bit AO

3=3:AO float

4=4:AO double

1=1:32bit AO evt

2=2:16bit AO evt

3=3:32bit AO evt&time


5=5:float AO evt

6=6:double AO evt

7=7:float AO evt&time

8=8:double AO evt&time

Step Default


Description

1=32 bit frz counter event;

2=16 bit frz counter event;

5=32 bit frz counter event with time; 6=16 bit frz counter event with time.

5=5:AI float

7=7:float AI evt&time

2=2:16bit AO


1=32 bit AI; 2=16 bit AI; 3=32 bit AI without flag; 4=16 bit AI without flag; 5=AI float; 6=AI double.

1=32 bit AI event; 2=16 bit AI event; 3=32 bit AI event with time; 4=16 bit AI event with time; 5=float AI event; 6=double AI event; 7=float AI event with time; 8=double AI event with time.

1=32 bit AO; 2=16 bit AO; 3=AO float; 4=AO double.

1=32 bit AO event; 2=16 bit

AO event; 3=32 bit AO event with time; 4=16 bit AO event with time; 5=float AO event;

6=double AO event; 7=float

AO event with time; 8=double

AO event with time.

COM1 serial communication settings

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Table 23: COM1 serial communication settings

Parameter

Fiber mode

Serial mode

CTS delay

RTS delay

Baudrate

Values (Range)

0=No fiber

2=Fiber optic

Unit

1=RS485 2Wire

2=RS485 4Wire

3=RS232 no handshake

4=RS232 with handshake

0...60000

0...60000

1=300

2=600

3=1200

4=2400

5=4800

6=9600

7=19200

8=38400

9=57600

10=115200 ms ms

Step

1

1

Default

0=No fiber

1=RS485 2Wire

Description

Fiber mode for

COM1

Serial mode for

COM1

0

0

6=9600

CTS delay for COM1

RTS delay for COM1

Baudrate for COM1

3.1.18

COM2 serial communication settings

Table 24: COM2 serial communication settings

Parameter

Fiber mode

Serial mode

CTS delay

RTS delay

Baudrate

Values (Range)

0=No fiber

2=Fiber optic

Unit

1=RS485 2Wire

2=RS485 4Wire

3=RS232 no handshake

4=RS232 with handshake

0...60000

0...60000

1=300

2=600

3=1200

4=2400

5=4800

6=9600

7=19200

8=38400

9=57600

10=115200 ms ms

Step

1

1

Default

0=No fiber

1=RS485 2Wire

0

0

6=9600

Description

Fiber mode for

COM2

Serial mode for

COM2

CTS delay for COM2

RTS delay for COM2

Baudrate for COM2

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3.1.19

Time settings

Table 25: Time settings

Parameter

Time format

Date format

Values (Range)

1=24H:MM:SS:MS

2=12H:MM:SS:MS

1=DD.MM.YYYY

2=DD/MM/YYYY

3=DD-MM-YYYY

4=MM.DD.YYYY

5=MM/DD/YYYY

6=YYYY-MM-DD

7=YYYY-DD-MM

8=YYYY/DD/MM

Unit

3.2

3.2.1

Step Default

1=24H:MM:SS:MS

Description

Time format

1=DD.MM.YYYY

Date format

Self-supervision

The protection relay's extensive self-supervision system continuously supervises the relay’s software, hardware and certain external circuits. It handles the run-time fault situation and informs the user about a fault via the LHMI and through the communication channels. The target of the self-supervision is to safeguard the relay’s reliability by increasing both dependability and security. The dependability can be described as the relay’s ability to operate when required. The security can be described as the relay scheme’s ability to refrain from operating when not required.

The dependability is increased by letting the system operators know about the problem, giving them a chance to take the necessary actions as soon as possible.

The security is increased by preventing the relay from making false decisions, such as issuing false control commands.

There are two types of fault indications.

• Internal faults

• Warnings

Internal faults

When an internal relay fault is detected, the relay protection operation is disabled, the green Ready LED begins to flash and the self-supervision output relay is deenergized, i.e. the change-over contact is released.

Internal fault indications have the highest priority on the LHMI. None of the other LHMI indications can override the internal fault indication.

An indication about the fault is shown as a message on the LHMI. The text

Internal Fault with an additional text message, a code, date and time, is shown to indicate the fault type.

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Different actions are taken depending on the severity of the internal fault. In case of a temporary fault, the protection relay tries to recover from the situation by restarting. Restarting varies per fault type. The restart procedure includes two stages; when the relay detects a fault, it restarts itself in a few seconds after the fault occurrence. If the relay did not recover after the first fast self-recovery attempts (typically 1-2 restarts), or the fault reoccurs during the next 60 minutes, the next self-recovery attempts (typically 3 restarts) are delayed for 10 minutes.

Exact recovery mechanism is described in

Table 26

. In case of a permanent fault, the protection relay stays in the internal fault mode. All output relays are de-energized and contacts are released for the internal fault. The protection relay continues to perform internal tests during the fault situation. If the internal fault disappears, the green Ready LED stop flashing and the protection relay returns to the normal service state. Internal Fault: All ok event appears in the event list after succesfull recovery.

One possible cause for an internal fault situation is a so-called soft error. The soft error is a probabilistic phenomenon which is rare in a single device, statistically not happening more often than once in a relay’s lifetime. No hardware failures are expected and a full recovery from the soft error is possible by a self-supervision controlled restart of the relay.

The self-supervision signal output operates on the closed-circuit principle. Under normal conditions, the protection relay is energized and the contact gaps 3-5 in slot

X100 is closed. If the auxiliary power supply fails or an internal fault is detected, the contact gaps 3-5 are opened.

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Figure 12: Output contact

The internal fault code indicates the type of internal relay fault. When a fault appears, the code must be recorded so that it can be reported to ABB customer service.

69


Table 26: Internal fault indications and codes

Fault indication Fault code

Internal Fault

System error

Internal Fault

System error

Internal Fault

System error

Internal Fault

System error

Internal Fault

System error

Internal Fault

System error

Internal Fault

System error

Internal Fault

File system error

Internal Fault

Test

Internal Fault

SW watchdog error

Internal Fault

SO-relay(s),X105

2

2

2

2

2

2

2

7

8

10

40

Additional information

Start up error:

HW/SW mismatch

Start up or runtime error: Data bus error, CPU module

Start up error: SCL file missing

Fast selfrecovery attempt

(# of attempts)

No

Yes (2)

No

Start up error: Missing order number

No

Start up error: FPGA

HW error, CPU module

Start up error: FPGA image corrupted,

CPU module

Runtime error: CPU internal fault

Start up error or runtime error: file system error

Internal fault test activated manually by the user.

Yes (2)

Yes (2)

Yes (2)

Yes (2)

No

Start up error:

Watchdog reset has occurred too many times within an hour. Note! This is different indication than Warning code

10: Watchdog reset

No

Runtime error: Faulty Signal Output relay(s) in card located in slot X105.

Yes (2)

Slow 10 min selfrecovery

(# of attempts)

No

Immediate permanen t IRFmode

Action in permanent fault state

Yes

Yes (3) No

If relay SW has just been updated, redo it. If not recovered, contact your nearest

ABB representative to check the next possible corrective action.

Restart the relay. If recovered by restarting, continue relay normal operation. If not recover by restarting, replace the relay, most probably hardware failure in

CPU module.

No Yes

No

Yes (3)

Yes (3)

Yes (3)

Yes (3)

No

No

-

Yes

No

No

No

No

Yes

Do factory restore or rewrite configuration using PCM600.

Do factory restore. If not recovered, contact your nearest ABB representative to check the next possible corrective action.


CPU module.

Restart the relay or if relay SW has just been updated, redo it. If recovered by restarting, continue relay normal operation. If not recovered by restarting or redoing SW update, replace the relay, most probably hardware failure in CPU module.


CPU module.


CPU module.

Just check the "Internal fault test" -setting parameter position, if relay is in test mode

Restart the relay. If recovered by restarting, continue relay normal operation. If not recover by restarting, replace the relay.

Yes (3) No Check wirings. Restart the relay. If recovered by restarting, continue relay normal operation. If not recover by restarting, exchange the hardware module in slot X105.


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Internal Fault

SO-relay(s),X115

41



(# of attempts)


Yes (2)

Internal Fault

SO-relay(s),X100

Internal Fault

SO-relay(s),X110

Internal Fault

SO-relay(s),X120

Internal Fault

SO-relay(s),X130

Fault in PO-relay(s) attached to X105



Internal Fault

PO-relay(s),X110

Internal Fault

PO-relay(s),X120

Internal Fault

PO-relay(s),X130

Internal Fault

Light sensor error

43

44

45

46

50

51

53

54

55

56

57





Runtime error: Faulty Power Output relay(s) in card located in slot X105.






Runtime error: Faulty ARC light sensor input(s).

Yes (2)

Yes (2)

Yes (2)

Yes (2)

Yes (2)

Yes (2)

Yes (2)

Yes (2)

Yes (2)

Yes (2)

Yes (2)


(# of attempts)

Yes (3)



No

Yes (3) No

Check wirings. Restart the relay. If recovered by restarting, continue relay normal operation. If not recover by restarting, exchange the hardware module in slot X115.


Yes (3) No

Yes (3)

Yes (3)

Yes (3)

Yes (3)

Yes (3)

Yes (3)

Yes (3)

Yes (3)

Yes (3)

No

No

No

No

No

No

No

No

No










Check light sensors and their connection to relay. Restart the relay. If recovered by restarting, continue relay normal operation. If not recover by restarting, exchange the communication module including ARC inputs in slot X000.


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Internal Fault

Conf. error,X105

60


Start up error: Card in slot X105 is wrong type, is missing, does not belong to original configuration or card firmware is faulty.

No


(# of attempts)

Internal Fault

Conf. error,X115

Internal Fault

Conf. error,X000

Internal Fault

Conf. error,X100

Internal Fault

Conf. error,X110

Internal Fault

Conf. error,X120

61

62

63

64

65






No

No

No

No

No


(# of attempts)

No



Yes

No Yes

Check that the card in slot X105 is proper type and properly installed. Check that the plug-in unit is properly installed and plug-in unit handle is properly fixed to closed position. Then restart the relay. If does not recover by restarting, it is hardware module failure most likely.

Exchange the hardware module in slot

X105.

Check that the card in slot X115 is proper type and properly installed. Check that the plug-in unit is properly installed and plug-in unit handle is properly fixed to closed position. Then restart the relay.If does not recover by restarting, it is hardware module failure most likely.


X115.

No

No

No

No

Yes

Yes

Yes

Yes

"Check that the communication card in slot X000 is proper type and properly installed. Check that the plug-in unit is properly installed and plug-in unit handle is properly fixed to closed position.

Then restart the relay. If does not recover by restarting, it is hardware module failure most likely. Exchange the communication module in slot X000. In some rare cases also communication storm may cause this. Detach the ethernet communication cable(s) from the communication module and reboot the relay. If not recover,exchange the communication module in slot X000. "



X100.

Check that the card in slot X110 is proper type and properly installed. Check that the plug-in unit is properly installed and plug-in unit handle is properly fixed to closed position. Then restart the relay. If does not then recover by restarting, hardware module failure most likely.


X110.



X120.


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Internal Fault

Conf. error,X130

66



No


(# of attempts)

Internal Fault

Card error,X105

70

Internal Fault

Card error,X115

Internal Fault

Card error,X000

71

72

Internal Fault

Card error,X100

Internal Fault

Card error,X110

Internal Fault

Card error,X120

Internal Fault

Card error,X130

Internal Fault

LHMI module

Internal Fault

RAM error

Internal Fault

ROM error

Internal Fault

EEPROM error

Internal Fault

EEPROM error

73

74

75

76

79

80

81

82

82

Card in slot X105 is faulty.







Runtime error: LHMI

LCD error. The fault indication may not be seen on the LHMI during the fault.

Runtime error: Error in the RAM memory on the CPU module.

Runtime error: Error in the ROM memory on the CPU module.

Start up error: Error in the EEPROM memory on the CPU module.

Start up error: CRC check failure in the

EEPROM memory on boot-up on the

CPU module.


Yes (2)

Yes (2)

Yes (2)

Yes (2)

Yes (2)

Yes (2)

Yes (2)

Yes (2)

Yes (2)

Yes (2)

No

Yes (2)


(# of attempts)

No



Yes

Yes (3) No



X130.


X105.

Yes (3) No

Yes (3)

Yes (3)

Yes (3)

Yes (3)

Yes (3)

Yes (3)

Yes (10)

Yes (3)

No

Yes (3)

No

No

No

No

No

No

No

No

Yes

No


X115.

"Check the plug-in unit connector pins in the card by detaching the plug-in unit.

If pins are OK, exchange the communication module in slot X000. In some rare cases also communication storm may cause this. Detach the ethernet communication cable(s) from the communication module and reboot the relay. If not recover,exchange the communication module in slot X000. "


X100.


X110.


X120.

Check the plug-in unit connector pins in the card by detaching the plug-in unit.

If pins are OK, exchange the hardware module in slot X130.

Restart the relay. If recovered by restarting, continue relay normal operation. If not recover by restarting, check LHMI connection cable and connection to be proberly fixed. If then not recovered by restarting, exchange the LHMI module.


CPU module.


CPU module.


CPU module.


CPU module.

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Internal Fault

FPGA error

83



(# of attempts)

Runtime error: Error in the FPGA on the

CPU module.

Yes (2)

Internal Fault

RTC error

Internal Fault

RTD card error,X105

84

90

Start up error: Error in the RTC on the

CPU module.

Yes (2)


(# of attempts)

Yes (3)



No

Yes (3) No


CPU module.


CPU module.

Yes (3) No Restart the relay. If recovered by restarting, continue relay normal operation. If not recover by restarting, exchange the

RTD hardware module in slot X105.

Internal Fault

RTD card error,X110

Internal Fault

RTD card error,X130

Internal Fault

COM card error

94

96

116

Runtime error: RTD card located in slot

X105 may have permanent fault. Temporary error has occurred too many times within a short time.

Yes (2)



Yes (2)



Yes (2)

Runtime error: Error in the COM card.

Yes (2)

Yes (3)

Yes (3)

Yes (3)

No

No

No

Restart the relay. If recovered by restarting, continue relay normal operation. If not recover by restarting, exchange the

RTD hardware module in slot X110.

Restart the relay. If recovered by restarting, continue relay normal operation. If not recover by restarting, exchange the hardware module in slot X130.

Restart the relay. If recovered by restarting, continue relay normal operation. If not recover by restarting, exchange the communication module in slot X000.

For further information on internal fault indications, see the operation manual.

3.2.2

Warnings

In case of a warning, the protection relay continues to operate except for those protection functions possibly affected by the fault, and the green Ready LED remains lit as during normal operation.

Warnings are indicated with the text Warning additionally provided with the name of the warning, a numeric code and the date and time on the LHMI. The warning indication message can be manually cleared.

If a warning appears, record the name and code so that it can be provided to ABB customer service.

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Table 27: Warning indications and codes

Warning indication

Warning

System warning

Warning

Watchdog reset

Warning

Power down det.

Warning

IEC61850 error

Warning

Modbus error

Warning

DNP3 error

Warning

Dataset error

Warning

Report cont. error

Warning code Additional information

2 An internal system error has occurred.

Warning

GOOSE contr. error

Warning

SCL config error

Warning

Logic error

Warning

SMT logic error

Warning

GOOSE input error

ACT error

Warning

GOOSE Rx. error

Warning

AFL error


10

11

20

21

22

24

25

26

27

28

29

30

31

32

33

A watchdog reset has occurred.

The auxiliary supply voltage has dropped too low.

Error when building the IEC 61850 data model.

Error in the Modbus communication.

Error in the DNP3 communication.

Error in the Data set(s).

Error in the Report control block(s).

Error in the GOOSE control block(s).

Error in the SCL configuration file or the file is missing.

Too many connections in the configuration.

Error in the SMT connections.

Error in the GOOSE connections.

Error in the ACT connections.

Error in the GOOSE message receiving.

Analog channel configuration error.

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3.2.3

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1MRS757644 H

Warning indication

SMV Warning

Warning

Comm. channel down

Warning

Unack card comp.

Warning

Protection comm.

Warning

ARC1 cont. light

Warning

ARC2 cont. light

Warning

ARC3 cont. light

Warning

RTD card error,X105

Warning

RTD card error,X110

Warning

RTD card error,X130

Warning

RTD meas. error,X105

Warning


Warning


Warning code Additional information

34 Error in the SMV configuration

35 Redundant Ethernet (HSR/PRP) communication interrupted.

40

50

85

86

87

90

94

96

100

104

106

A new composition has not been acknowledged/accepted.

Error in protection communication.

A continuous light has been detected on the

ARC light input 1.


ARC light input 2.


ARC light input 3.

Temporary error occurred in RTD card located in slot X105

Temporary error occurred in RTD card located in slot X110

Temporary error occurred in RTD card located in slot X130.

Measurement error in RTD card located in slot X105.



For further information on warning indications, see the operation manual.

Fail-safe principle for relay protection

The relay behavior during an internal fault situation has to be considered when engineering trip circuits under the fail-safe principle. The considerations discussed and examples given are mainly based on the need of protection scheme reliability.

The reliability need can be divided into two subparts: dependability and security.

The dependability can be described as the protection scheme’s ability to operate when required. The security can be described as the protection scheme’s ability to refrain from operating when not required. The protection scheme fail-safe principle

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1MRS757644 H

3.2.3.1

Basic functions is typically related to satisfying these two performance criteria. Depending on the requirements set to the electricity distribution process, one of the criteria may get more attention than the other. However, in some industrial electricity distribution networks, the main (productization) process is so dependent on reliable electricity supply that both criteria are addressed equally.

The examples presented focus on the relay’s protection role in the fail-safe circuitry using traditional hardwiring. If communication between the relays, or to an upper level system, is a part of the fail-safe functionality, it must be also be a part of the circuitry.

Motor feeder

The target is to prevent the motor from running uncontrollably and to secure the emergency stop circuit functionality.

-F1

Control +

ES

-A1

IRF

TO AUX. POWER

-Q0

<U TC1

Control -

Figure 13: Motor feeder fail-safe trip circuit principle, example 1

A1

ES

Protection relay

Emergency stop

Q0 Circuit breaker (CB)

TO Protection relay trip output

IRF Internal relay fault indication

<U CB undervoltage trip coil

TC1 CB trip coil 1

DCS Distributed process control system

F1 Miniature circuit breaker

In example 1, the fail-safe approach aims at securing motor shutdown via an emergency switch and in case the control voltage disappears. In case of a temporary internal relay fault, the circuit breaker is immediately tripped before the relay recovers from the situation. In case the IRF output relay is directly connected to the undervoltage trip coil circuit, the output’s performance figures (make and break values) must be checked.

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1MRS757644 H

-F1

Control +

ES

-A1

TO

IRF AUX. POWER

-Q0

<U TC1

DCS

Control -


A1

ES

Protection relay

Emergency stop





TC1 CB trip coil 1

DCS Distributed process control system


In example 2, the fail-safe approach aims at securing motor shutdown via an emergency switch and in case the control voltage disappears. In case of internal relay fault, the necessary actions must be initiated by the process operators or by the control system.

-F1

Control +

-K1

ES

-A1

TO

IRF AUX. POWER

-Q0

<U TC1

-K1

Control -


A1

ES

Protection relay

Emergency stop




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TC1 CB trip coil 1

K1 OFF delay time relay


In example 3, the fail-safe approach aims at securing motor shutdown via an emergency switch and in case the control voltage disappears. In case of internal relay fault, the circuit breaker is tripped via an undervoltage coil after a preset time delay. The additional time delay allows the relay to recover from the internal fault situation without tripping the circuit breaker.

-F1

Control + +J01

-F1

Control + +J02

+J02 -A1 +J01 -A1

IRF IRF

ES

+J02 -A1

TO2

-A1

TO1 BI1

ES

+J01 -A1

TO2

-A1

TO1 BI1

-Q0

<U TC1

-Q0

<U

Control Control -


TC1

J01 Feeder #1 panel

J02 Feeder #2 panel

ES Emergency stop

Q0 Circuit breaker

TO1 Relay trip output #1


IRF Relay internal fault indication

BI1 Relay binary input #1


TC1 CB trip coil 1


In example 4, the fail-safe approach aims at securing motor shutdown via an emergency switch and in case the control voltage disappears. The adjacent panels provide backup for each other in internal relay fault situations. In case of an internal relay fault, the situation is noticed by the relay in the adjacent panel and the circuit breaker in the panel with the faulty relay is tripped after a preset time delay. The additional time delay allows the relay to recover from the internal fault situation without tripping the circuit breaker.

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Basic functions

3.2.3.2

1MRS757644 H

Other critical feeders

The examples given for motor feeders can be applied for other types of feeders as well. The following examples are for critical feeders in which the protection system dependability, security or both are the drivers.

-F1

Control + +J01

-A1

TO AUX. POWER SO

-F1

Control +

-A1

-TO -R1

+J0x

Incomer protec on start +

-A1

IRF AUX. POWER

-Q0

TC

Control -

Incomer protec on start +

Incomer protec on start -

-Q0

TC

Control -

R1

Incomer protec on start -

Figure 17: Redundant protection fail-safe principle, example 1

A1

R1

TC

F1

J01 Incomer feeder panel

J0x Load feeder panels


TO Relay trip output

SO Relay start output

Protection relay

Auxiliary relay

CB trip coil

Miniature circuit breaker

In example 1, the fail-safe approach aims at securing circuit breaker tripping even if a relay fails. The incomer panel relay indicates the start of selected protection functions. This start signal is distributed to all load feeder panels. If a relay in the load feeder panel indicates an IRF status, the start signal of the incomer panel relay results in circuit breaker tripping. This approach offers basic protection for a load feeder while the actual protection relay performs a self-supervision controlled restart sequence.

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-F1

Control +

-A1

-TO1

+J02 -A1

-TO2

+J01

+J02-F1 control +

-A1

AUX. POWER

-F1

Control +

-A1

-TO1

+J02

+J01-F1 control +

+J01 -A1

-TO2

-A1

AUX. POWER

-Q0

TC1 TC2

-Q0

TC1

Control -

+J02-F1 control -

Control -

+J01-F1 control -


TC2

J01 Feeder #1 panel

J02 Feeder #2 panel




A1 Protection relay

TC1 CB trip coil 1

TC2 CB trip coil 2


In example 2, the fail-safe approach aims at securing circuit breaker tripping even if a relay fails. A relay in a panel measures also the adjacent panel’s currents (and voltages) and receives the necessary primary device’s position information. In other words, the relay in a panel functions as a backup relay for the adjacent panel.

This approach allows service continuation while the failed relay is waiting for spare parts or a complete replacement. The backup protection features provided by the adjacent panel’s relay do not necessarily fully match the features available in the main relay.

-F1

Control +

-A1

AUX. POWER TO

-A2

TO AUX. POWER

-Q0

TC1 TC2

Control -


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1MRS757644 H


A1 Protection relay #1



TC1 CB trip coil 1

TC2 CB trip coil 2


In example 3, the fail-safe approach aims at securing circuit breaker tripping even if one of the redundant relays fails. The scheme is often referred to as the 1-outof- 2 approach. This approach allows service continuation while the failed relay is waiting for spare parts or a complete replacement. The redundancy in this example covers relays and circuit breaker tripping coils but it can be expanded to auxiliary power supplies (two station batteries and isolated distribution), cabling, circuit breaker failure protection, and so on. Another variant of this approach is to have a main relay and a backup relay instead of two fully redundant relays. The backup relay does not have all the features of the main relay, mainly containing a minimum acceptable set of protection functions.

-F1

Control +

-A1

AUX. POWER

-A2

AUX. POWER

-A3

AUX. POWER

-A1

-TO1

-A2

-TO1

-A2

-TO2

-A3

-TO1

-A1

-TO2

-A3

-TO2

Same principle as for TC1

-Q0

TC1 TC2

Control -






TO# Protection relay trip output

TC1 CB trip coil 1

TC2 CB trip coil 2


In example 4, the fail-safe approach aims at securing circuit breaker tripping even if one of the redundant relays fails and, in addition, no single relay alone can cause the circuit breaker tripping. The scheme is often referred to as the 2-outof-3 approach. This approach allows service continuation while the failed relay is waiting for spare parts or a complete replacement. The redundancy in this example covers relays and circuit breaker tripping coils but it can be expanded to auxiliary power supplies (two station batteries and isolated distribution), cabling, circuit breaker failure protection, and so on. All three relays are similar with the same

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1MRS757644 H

3.3

3.3.1

Basic functions protection functions. This principle is used in cases where the primary process requires absolute dependability and security from the supplying feeder protection.

LED indication control

Function block

3.3.2

3.4

Figure 21: Function block

Functionality

The protection relay includes a global conditioning function LEDPTRC that is used with the protection indication LEDs.

LED indication control should never be used for tripping purposes.

There is a separate trip logic function TRPPTRC available in the relay configuration.

LED indication control is preconfigured in a such way that all the protection function general start and operate signals are combined with this function

(available as output signals OUT_START and OUT_OPERATE ). These signals are always internally connected to Start and Trip LEDs. LEDPTRC collects and combines phase information from different protection functions (available as output signals

OUT_ST_A /_B /_C and OUT_OPR_A /_B /_C ). There is also combined earth fault information collected from all the earth-fault functions available in the relay configuration (available as output signals OUT_ST_NEUT and OUT_OPR_NEUT ).

Programmable LEDs

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3.4.1

Function block

1MRS757644 H

3.4.2


Functionality

The programmable LEDs reside on the right side of the display on the LHMI.

84

Figure 23: Programmable LEDs on the right side of the display

All the programmable LEDs in the HMI of the protection relay have two colors, green and red. For each LED, the different colors are individually controllable. For example:

LEDx is green when AR is in progress and red when AR is locked out.

Each LED has two control inputs, ALARM and OK . The color setting is common for all the LEDs. It is controlled with the Alarm colour setting, the default value being

"Red". The OK input corresponds to the color that is available, with the default value being "Green".

Changing the Alarm colour setting to "Green" changes the color behavior of the

OK inputs to red.

The ALARM input has a higher priority than the OK input.

Each LED is seen in the Application Configuration tool as an individual function block. Each LED has user-editable description text for event description. The state

("None", "OK", "Alarm") of each LED can also be read under a common monitored data view for programmable LEDs.

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The LED status also provides a means for resetting the individual LED via communication. The LED can also be reset from configuration with the RESET input.

The resetting and clearing function for all LEDs is under the Clear menu.

The menu structure for the programmable LEDs is presented in

Figure 24 . The

common color selection setting Alarm colour for all ALARM inputs is in the General menu, while the LED-specific settings are under the LED-specific menu nodes.

Programmable LEDs

General

LED 1

LED 2

Alarm color

Alarm mode

Description

Red

Green

Follow-S

Follow-F

Latched-S

LatchedAck-F-S

Programmable LED description

Figure 24: Menu structure

Alarm mode alternatives

The ALARM input behavior can be selected with the alarm mode settings from the alternatives "Follow-S", "Follow-F", "Latched-S" and "LatchedAck-F-S". The OK input behavior is always according to "Follow-S". The alarm input latched modes can be cleared with the reset input in the application logic.

Figure 25: Symbols used in the sequence diagrams

"Follow-S": Follow Signal, ON

In this mode ALARM follows the input signal value, Non-latched.

Activating signal

LED

Figure 26: Operating sequence "Follow-S"

"Follow-F": Follow Signal, Flashing

Similar to "Follow-S", but instead the LED is flashing when the input is active,

Non-latched.

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"Latched-S": Latched, ON

This mode is a latched function. At the activation of the input signal, the alarm shows a steady light. After acknowledgement by the local operator pressing any key on the keypad, the alarm disappears.

Activating signal

LED

Acknow.

Figure 27: Operating sequence "Latched-S"

"LatchedAck-F-S": Latched, Flashing-ON

This mode is a latched function. At the activation of the input signal, the alarm starts flashing. After acknowledgement, the alarm disappears if the signal is not present and gives a steady light if the signal is present.

Activating signal

LED

Acknow.

Figure 28: Operating sequence "LatchedAck-F-S"

Signals

Table 28: Input signals

Name Type

OK

ALARM

RESET

OK

ALARM

RESET

OK

ALARM

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN


Default

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

Description

Ok input for LED 1

Alarm input for LED 1

Reset input for LED 1

Ok input for LED 2



Ok input for LED 3


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Name

OK

ALARM

RESET

OK

ALARM

RESET

OK

ALARM

RESET

OK

ALARM

RESET

OK

ALARM

RESET

OK

ALARM

RESET

RESET

OK

ALARM

RESET

OK

ALARM

RESET

3.4.4

Settings

Table 29: Non group settings

Parameter

Alarm color

Values (Range)

1=Green

2=Red

Alarm mode

0=Follow-S

1=Follow-F

2=Latched-S

3=LatchedAck-F-S


Unit

620 series

Technical Manual

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Step

Default

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

Default

2=Red

0=Follow-S

Description


Ok input for LED 4



Ok input for LED 5



Ok input for LED 6



Ok input for LED 7



Ok input for LED 8



Ok input for LED 9



Ok input for LED 10

Alarm input for LED

10

Reset input for LED

10

Ok input for LED 11

Alarm input for LED

11


Description

Color for the alarm state of the LED

Alarm mode for programmable LED

1

87

Basic functions

Parameter

Description

Alarm mode

Values (Range)

0=Follow-S

1=Follow-F

2=Latched-S

3=LatchedAck-F-S

Description

Alarm mode

0=Follow-S

1=Follow-F

2=Latched-S

3=LatchedAck-F-S

Description

Alarm mode

0=Follow-S

1=Follow-F

2=Latched-S

3=LatchedAck-F-S

Description

Alarm mode

0=Follow-S

1=Follow-F

2=Latched-S

3=LatchedAck-F-S

Description

Alarm mode

0=Follow-S

1=Follow-F

2=Latched-S

3=LatchedAck-F-S

Description

Alarm mode

0=Follow-S

1=Follow-F

2=Latched-S

3=LatchedAck-F-S

Description

Alarm mode

0=Follow-S

1=Follow-F

2=Latched-S

3=LatchedAck-F-S

Description

Alarm mode

0=Follow-S

1=Follow-F

2=Latched-S

3=LatchedAck-F-S

Description


Unit

88

Step

1MRS757644 H

Default

Programmable

LEDs LED 1

0=Follow-S

Description

Programmable LED description


2

Programmable

LEDs LED 2

0=Follow-S



3

Programmable

LEDs LED 3

0=Follow-S



4

Programmable

LEDs LED 4

0=Follow-S



5

Programmable

LEDs LED 5

0=Follow-S



6

Programmable

LEDs LED 6

0=Follow-S



7

Programmable

LEDs LED 7

0=Follow-S



8

Programmable

LEDs LED 8

0=Follow-S



9

Programmable

LEDs LED 9


620 series

Technical Manual


Parameter

Alarm mode

Description

Alarm mode

Values (Range)

0=Follow-S

1=Follow-F

2=Latched-S

3=LatchedAck-F-S

Unit

0=Follow-S

1=Follow-F

2=Latched-S

3=LatchedAck-F-S

Description

Step

3.4.5

Monitored data

Table 30: Monitored data

Name

Programmable LED 1

Type

Enum

Programmable LED 2

Programmable LED 3

Programmable LED 4

Programmable LED 5

Programmable LED 6

Programmable LED 7

Programmable LED 8

Programmable LED 9

Enum

Enum

Enum

Enum

Enum

Enum

Enum

Enum

Values (Range)

0=None

1=Ok

3=Alarm

0=None

1=Ok

3=Alarm

0=None

1=Ok

3=Alarm

0=None

1=Ok

3=Alarm

0=None

1=Ok

3=Alarm

0=None

1=Ok

3=Alarm

0=None

1=Ok

3=Alarm

0=None

1=Ok

3=Alarm

0=None

1=Ok

3=Alarm


620 series

Technical Manual

Unit

Default

0=Follow-S

Description


10

Programmable

LEDs LED 10

0=Follow-S



11

Programmable

LEDs LED 11


89

Description

Status of programmable LED 1









Basic functions

Name Type

Programmable LED 10 Enum

Programmable LED 11 Enum

3.5

3.5.1

3.5.1.1

Values (Range)

0=None

1=Ok

3=Alarm

0=None

1=Ok

3=Alarm

Unit

Time synchronization

Time master supervision GNRLLTMS

Function block

1MRS757644 H

Description



3.5.1.2

90


Functionality

The protection relay has an internal real-time clock which can be either free-running or synchronized from an external source. The real-time clock is used for time stamping events, recorded data and disturbance recordings.

The protection relay is provided with a 48 hour capacitor backup that enables the real-time clock to keep time in case of an auxiliary power failure.

The setting Synch source determines the method to synchronize the real-time clock.

If it is set to “None”, the clock is free-running and the settings Date and Time can be used to set the time manually. Other setting values activate a communication protocol that provides the time synchronization. Only one synchronization method can be active at a time. IEEE 1588 v2 and SNTP provide time master redundancy.

The protection relay supports SNTP, IRIG-B, IEEE 1588 v2, DNP3, Modbus and IEC

60870-5-103 to update the real-time clock. IEEE 1588 v2 with GPS grandmaster clock provides the best accuracy ±1 µs. The accuracy using IRIG-B and SNTP is ±1 ms.

The protection relay's 1588 time synchronization complies with the IEEE

C37.238-2011 Power Profile, interoperable with IEEE 1588 v2. According to the power profile, the frame format used is IEEE 802.3 Ethernet frames with 88F7 Ethertype as communication service and the delay mechanism is P2P. PTP announce mode determines the format of PTP announce frames sent by the protection relay when acting as 1588 master, with options “Basic IEEE1588” and “Power Profile”. In the

“Power Profile” mode, the TLVs required by the IEEE C37.238-2011 Power Profile are included in announce frames.

620 series

Technical Manual


IEEE 1588 v2 time synchronization requires a communication card with redundancy support (COM0031...COM0037).

When Modbus TCP or DNP3 over TCP/IP is used, SNTP or IRIG-B time synchronization should be used for better synchronization accuracy.

With the legacy protocols, the synchronization message must be received within four minutes from the previous synchronization.

Otherwise bad synchronization status is raised for the protection relay.

With SNTP, it is required that the SNTP server responds to a request within 12 ms, otherwise the response is considered invalid.

The relay can use one of two SNTP servers, the primary or the secondary server. The primary server is mainly in use, whereas the secondary server is used if the primary server cannot be reached. While using the secondary SNTP server, the relay tries to switch back to the primary server on every third SNTP request attempt. If both the

SNTP servers are offline, event time stamps have the time invalid status. The time is requested from the SNTP server every 60 seconds. Supported SNTP versions are 3 and 4.

IRIG-B time synchronization requires the IRIG-B format B004/B005 according to the 200-04 IRIG-B standard. Older IRIG-B standards refer to these as B000/B001 with IEEE-1344 extensions. The synchronization time can be either UTC time or local time. As no reboot is necessary, the time synchronization starts immediately after the IRIG-B sync source is selected and the IRIG-B signal source is connected.

IRIG-B time synchronization requires a COM card with an IRIG-B input.

3.5.1.3

3.5.1.4

Signals

Table 31: GNRLLTMS output signals

Name

ALARM

WARNING

Type

BOOLEAN

BOOLEAN

Settings

Description

Time synchronization alarm

Time synchronization warning

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91


Table 32: Time settings

Parameter

Time format

Date format

Values (Range)

1=24H:MM:SS:MS

2=12H:MM:SS:MS

1=DD.MM.YYYY

2=DD/MM/YYYY

3=DD-MM-YYYY

4=MM.DD.YYYY

5=MM/DD/YYYY

6=YYYY-MM-DD

7=YYYY-DD-MM

8=YYYY/DD/MM

Unit

3.6

3.6.1

Step

Parameter setting groups

Function block

Default

1=24H:MM:SS:MS

Description

Time format

1=DD.MM.YYYY

Date format

3.6.2


Functionality

The protection relay supports six setting groups. Each setting group contains parameters categorized as group settings inside application functions. The customer can change the active setting group at run time.

The active setting group can be changed by a parameter or via binary inputs depending on the mode selected with the Configuration > Setting Group > SG

operation mode setting.

The default value of all inputs is FALSE, which makes it possible to use only the required number of inputs and leave the rest disconnected. The setting group selection is not dependent on the SG_x_ACT outputs.

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Table 33: Optional operation modes for setting group selection

SG operation mode Description

Operator (Default) Setting group can be changed with the setting Settings > Setting

group > Active group.

Value of the SG_LOGIC_SEL output is FALSE.

Logic mode 1 Setting group can be changed with binary inputs

( BI_SG_2...BI_SG_6

active setting group.

). The highest TRUE binary input defines the

Value of the SG_LOGIC_SEL output is TRUE.

Logic mode 2

Setting group can be changed with binary inputs where used for selecting setting groups 1-3 or 4-6.

BI_SG_4 is

When binary input BI_SG_4 is FALSE , setting groups 1-3 are selected with binary inputs BI_SG_2 and BI_SG_3 . When binary input

BI_SG_4 is TRUE , setting groups 4-6 are selected with binary inputs

BI_SG_5 and BI_SG_6 .

Value of the SG_LOGIC_SEL output is TRUE.

The setting group (SG) is changed whenever switching the SG operation mode setting from "Operator" to either "Logic mode 1" or "Logic mode

2." Thus, it is recommended to select the preferred operation mode at the time of installation and commissioning and not change it throughout the protection relay's service. Changing the SG operation mode setting from "Logic mode 1" to "Logic mode 2" or from "Logic mode 2" to "Logic mode 1" does not affect the setting group (SG).

For example, six setting groups can be controlled with three binary inputs. The SG operation mode is set to “Logic mode 2” and inputs BI_SG_2 and BI_SG_5 are connected together the same way as inputs BI_SG_3 and BI_SG_6 .

Table 34: SG operation mode = “Logic mode 1”

BI_SG_2

FALSE

TRUE any any any any

BI_SG_3

FALSE

FALSE

TRUE any any any

Input

BI_SG_4

FALSE

FALSE

FALSE

TRUE any any

BI_SG_5

FALSE

FALSE

FALSE

FALSE

TRUE any

BI_SG_6

FALSE

FALSE

FALSE

FALSE

FALSE

TRUE

Active group

3

4

1

2

5

6

Table 35: SG operation mode = “Logic mode 2”

Input

BI_SG_2

FALSE

TRUE

BI_SG_3

FALSE

FALSE


BI_SG_4

FALSE

FALSE

BI_SG_5 any any

BI_SG_6 any any

Active group

1

2

93

Basic functions

3.7

3.7.1

1MRS757644 H

BI_SG_2 any any any any

BI_SG_3

TRUE any any any

Input

BI_SG_4

FALSE

TRUE

TRUE

TRUE

BI_SG_5 any

FALSE

TRUE any

BI_SG_6 any

FALSE

FALSE

TRUE

Active group

5

6

3

4

The setting group 1 can be copied to any other or all groups from HMI (Copy group

1).

Test mode

Function blocks

3.7.2

Figure 31: Function blocks

Functionality

The mode of all the logical nodes in the relay's IEC 61850 data model can be set with

Test mode. Test mode is selected through one common parameter via the WHMI path Tests > IED test. By default, Test mode can only be set locally through LHMI.

Test mode is also available via IEC 61850 communication (LD0.LLN0.Mod).

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3.7.3

3.7.4

620 series

Technical Manual

Table 36: Test mode

Test mode Description

Normal mode

IED blocked

Normal operation

Protection working as in “Normal mode” but

ACT configuration can be used to block physical outputs to process. Control function commands blocked.

IED test Protection working as in “Normal mode” but protection functions are working in parallel with test parameters.

IED test and blocked Protection working as in “Normal mode” but protection functions are working in parallel with test parameters. ACT configuration can be used to block physical outputs to process.

Control function commands blocked.

Protection BEH_BLK

FALSE

TRUE

FALSE

TRUE

Behavior data objects in all logical nodes follow LD0.LLN0.Mod value. If

"Normal mode" is selected, behaviour data objects follow mode (.Mod) data object of the corresponding logical device.

Application configuration and Test mode

The physical outputs from control commands to process are blocked with ”IED blocked” and “IED test and blocked” modes. If physical outputs need to be blocked from the protection, the application configuration must be used to block these signals. Blocking scheme needs to use BEH_BLK output of PROTECTION function block.

Control mode

The mode of all logical nodes located under CTRL logical device can be set with

Control mode. The Control mode parameter is available via the HMI or PCM600 path Configuration > Control > General. By default, Control mode can only be set locally through LHMI. To set the parameters from WHMI the Remote test mode parameter under Tests > IED test > Test mode should first be set to “All Levels”.

Control mode inherits its value from Test mode but Control mode ”On”, “Blocked” and “Off” can also be set independently. Control mode is also available via IEC 61850 communication (CTRL.LLN0.Mod).

Table 37: Control mode

Control mode

On

Blocked

Off

Description

Normal operation

Control function commands blocked

Control functions disabled

Control BEH_BLK

FALSE

TRUE

FALSE

Behavior data objects under CTRL logical device follow CTRL.LLN0.Mod

value. If "On" is selected, behavior data objects follow the mode of the corresponding logical device.

95


3.7.5

3.7.6

3.7.7

3.7.8

96

Application configuration and Control mode

The physical outputs from commands to process are blocked with “Blocked“ mode.

If physical outputs need to be blocked totally, meaning also commands from the binary inputs, the application configuration must be used to block these signals.

Blocking scheme uses BEH_BLK output of CONTROL function block.

Authorization

By default, Test mode and Control mode can only be changed from LHMI. It is possible to write test mode by remote client, if it is needed in configuration. This is done via LHMI only by setting the Remote test mode parameter via Tests >

IED test > Test mode. Remote operation is possible only when control position of the relay is in remote position. Local and remote control can be selected with R/L button or via Control function block in application configuration.

When using the Signal Monitoring tool to force online values, the following conditions need to be met.

• Remote force is set to “All levels”

• Test mode is enabled

• Control position of the relay is in remote position

Table 38: Remote test mode

Remote test mode

Off

Maintenance

All levels

61850-8-1-MMS

No access

Command originator category maintenance

All originator categories

WHMI/PCM600

No access

No access

Yes

LHMI indications

The yellow Start LED flashes when the relay is in “IED blocked” or “IED test and blocked” mode. The green Ready LED flashes to indicate that the “IED test and blocked” mode or "IED test" mode is activated.

Signals

Table 39: PROTECTION input signals

Name

BI_SG_2

Type

BOOLEAN

BI_SG_3 BOOLEAN


Default

0

0

Description

Setting group 2 is active


620 series

Technical Manual


Name

BI_SG_4

BI_SG_5

BI_SG_6

Type

BOOLEAN

BOOLEAN

BOOLEAN

Default

0

0

0

Table 40: CONTROL input signals

Name

CTRL_OFF

CTRL_LOC

CTRL_STA

CTRL_REM

CTRL_ALL

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Table 41: PROTECTION output signals

Name

SG_LOGIC_SEL

Type

BOOLEAN

SG_1_ACT

SG_2_ACT

SG_3_ACT

SG_4_ACT

SG_5_ACT

SG_6_ACT

BEH_BLK

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BEH_TST

FRQ_ADP_FAIL

BOOLEAN

BOOLEAN

Default

0

0

0

0

0

Description




Description

Control OFF

Control local

Control station

Control remote

Control all

Description

Logic selection for setting group







Logical device LD0 block status

Logical device LD0 test status

Frequency adaptivity status fail

620 series

Technical Manual

Table 42: CONTROL output signals

Name Type

OFF

LOCAL

STATION

REMOTE


BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Description

Control OFF

Control local

Control station

Control remote

97

Basic functions

3.8

3.8.1

3.8.2

98

1MRS757644 H

Name

ALL

BEH_BLK

BEH_TST

Type

BOOLEAN

BOOLEAN

BOOLEAN

Description

Control all

Logical device LD0 block status

Logical device LD0 test status

Fault recorder FLTRFRC

Function block


Functionality

The protection relay has the capacity to store the records of 128 latest fault events.

Fault records include fundamental or RMS current values. The records enable the user to analyze recent power system events. Each fault record (FLTRFRC) is marked with an up-counting fault number and a time stamp that is taken from the beginning of the fault.

The fault recording period begins from the start event of any protection function and ends if any protection function trips or the start is restored before the operate event. If a start is restored without an operate event, the start duration shows the protection function that has started first.

Start duration that has the value of 100% indicates that a protection function has operated during the fault and if none of the protection functions has been operated, Start duration shows always values less than 100%.

The Fault recorded data Protection and Start duration is from the same protection function. The Fault recorded data operate time shows the time of the actual fault period. This value is the time difference between the activation of the internal start and operate signals. The actual operate time also includes the starting time and the delay of the output relay. The Fault recorded data Breaker clear time is the time difference between internal operate signal and activation of CB_CLRD input.

If some functions in relay application are sensitive to start frequently it might be advisable to set the setting parameter Trig mode to “From operate”. Then only faults that cause an operate event trigger a new fault recording.

The fault-related current, voltage, frequency, angle values, shot pointer and the active setting group number are taken from the moment of the operate event, or from the beginning of the fault if only a start event occurs during the fault. The maximum current value collects the maximum fault currents during the fault. In case

620 series

Technical Manual

1MRS757644 H Basic functions frequency cannot be measured, nominal frequency is used for frequency and zero for Frequency gradient and validity is set accordingly.

Measuring mode for phase current and residual current values can be selected with the Measurement mode setting parameter.

3.8.3

Settings

Table 43: FLTRFRC Non group settings (Basic)

Parameter

Operation

Trig mode

Values (Range)

1=on

5=off

0=From all faults

1=From operate

2=From only start

Unit Step

Table 44: FLTRFRC Non group settings (Advanced)

Parameter

A measurement mode

Values (Range)

1=RMS

2=DFT

3=Peak-to-Peak

Unit Step

Default

1=on

Description

Operation Off / On

0=From all faults Triggering mode

Default

2=DFT

Description

Selects used measurement mode phase currents and residual current

3.8.4

Monitored data

Table 45: FLTRFRC Monitored data

Name

Fault number

Time and date

Type

INT32

Timestamp


Values (Range)

0...999999

Unit Description

Fault record number

Fault record time stamp

620 series

Technical Manual

99

Basic functions

Name

Protection

Type

Enum


Values (Range)

0=Unknown 1

1=PHLPTOC1

2=PHLPTOC2

6=PHHPTOC1

7=PHHPTOC2

8=PHHPTOC3

9=PHHPTOC4

12=PHIPTOC1

13=PHIPTOC2

17=EFLPTOC1

18=EFLPTOC2

19=EFLPTOC3

22=EFHPTOC1

23=EFHPTOC2

24=EFHPTOC3

25=EFHPTOC4

30=EFIPTOC1

31=EFIPTOC2

32=EFIPTOC3

35=NSPTOC1

36=NSPTOC2

-7=INTRPTEF1

-5=STTPMSU1

-3=JAMPTOC1

Unit

1MRS757644 H

Description

Protection function

1 When TRPPTRC is triggered by any signal which does not light up the START or TRIP LEDs

100 620 series

Technical Manual

1MRS757644 H

Name Type


Values (Range)

67=LSHDPFRQ3

68=LSHDPFRQ4

69=LSHDPFRQ5

71=DPHLPDOC1

72=DPHLPDOC2

74=DPHHPDOC1

77=MAPGAPC1

78=MAPGAPC2

79=MAPGAPC3

85=MNSPTOC1

86=MNSPTOC2

88=LOFLPTUC1

90=TR2PTDF1

91=LNPLDF1

92=LREFPNDF1

94=MPDIF1

96=HREFPDIF1

41=PDNSPTOC1

44=T1PTTR1

46=T2PTTR1

48=MPTTR1

50=DEFLPDEF1

51=DEFLPDEF2

53=DEFHPDEF1

56=EFPADM1

57=EFPADM2

58=EFPADM3

59=FRPFRQ1

60=FRPFRQ2

61=FRPFRQ3

62=FRPFRQ4

63=FRPFRQ5

64=FRPFRQ6

65=LSHDPFRQ1

66=LSHDPFRQ2

Unit

Basic functions

Description

620 series

Technical Manual

101

Basic functions

Name Type


Values (Range)

-89=SPHHPTOC2

-88=SPHHPTOC1

-87=SPHPTUV4

-86=SPHPTUV3

-85=SPHPTUV2

-84=SPHPTUV1

-83=SPHPTOV4

-82=SPHPTOV3

-81=SPHPTOV2

-80=SPHPTOV1

-25=OEPVPH4

-24=OEPVPH3

-23=OEPVPH2

-22=OEPVPH1

-19=PSPTOV2

-18=PSPTOV1

-15=PREVPTOC1

100=ROVPTOV1

101=ROVPTOV2

102=ROVPTOV3

104=PHPTOV1

105=PHPTOV2

106=PHPTOV3

108=PHPTUV1

109=PHPTUV2

110=PHPTUV3

112=NSPTOV1

113=NSPTOV2

116=PSPTUV1

118=ARCSARC1

119=ARCSARC2

120=ARCSARC3

-96=SPHIPTOC1

-93=SPHLPTOC2

-92=SPHLPTOC1

Unit

1MRS757644 H

Description

102 620 series

Technical Manual

1MRS757644 H

Name Type


Values (Range)

11=PHHPTOC6

28=EFHPTOC7

29=EFHPTOC8

107=PHPTOV4

111=PHPTUV4

114=NSPTOV3

115=NSPTOV4

-30=PHDSTPDIS1

-29=TR3PTDF1

-28=HICPDIF1

-27=HIBPDIF1

-26=HIAPDIF1

-32=LSHDPFRQ8

-31=LSHDPFRQ7

70=LSHDPFRQ6

80=MAPGAPC4

81=MAPGAPC5

82=MAPGAPC6

83=MAPGAPC7

-12=PHPTUC2

-11=PHPTUC1

-9=PHIZ1

5=PHLTPTOC1

20=EFLPTOC4

26=EFHPTOC5

27=EFHPTOC6

37=NSPTOC3

38=NSPTOC4

45=T1PTTR2

54=DEFHPDEF2

75=DPHHPDOC2

89=LOFLPTUC2

103=ROVPTOV4

117=PSPTUV2

-13=PHPTUC3

3=PHLPTOC3

10=PHHPTOC5

Unit

Basic functions

Description

620 series

Technical Manual

103

Basic functions

Name Type


104

Values (Range)

-102=MAPGAPC12

-101=MAPGAPC11

-100=MAPGAPC10

-99=MAPGAPC9

-98=RESCPSCH1

-57=FDEFLPDEF2

-56=FDEFLPDEF1

-54=FEFLPTOC1

-53=FDPHLPDOC2

-52=FDPHLPDOC1

-50=FPHLPTOC1

-47=MAP12GAPC8

-46=MAP12GAPC7

-45=MAP12GAPC6

-44=MAP12GAPC5

-43=MAP12GAPC4

-42=MAP12GAPC3

-41=MAP12GAPC2

-40=MAP12GAPC1

-37=HAEFPTOC1

-35=WPWDE3

-34=WPWDE2

-33=WPWDE1

52=DEFLPDEF3

84=MAPGAPC8

93=LREFPNDF2

97=HREFPDIF2

-117=XDEFLPDEF2

-116=XDEFLPDEF1

-115=SDPHLPDOC2

-114=SDPHLPDOC1

-113=XNSPTOC2

-112=XNSPTOC1

-111=XEFIPTOC2

-110=XEFHPTOC4

-109=XEFHPTOC3

-108=XEFLPTOC3

-107=XEFLPTOC2

-66=DQPTUV1

-65=VVSPPAM1

-64=PHPVOC1

-63=H3EFPSEF1

-60=HCUBPTOC1

-59=CUBPTOC1

-72=DOPPDPR1

-69=DUPPDPR1

-61=COLPTOC1

-106=MAPGAPC16

-105=MAPGAPC15

-104=MAPGAPC14

Unit

1MRS757644 H

Description

620 series

Technical Manual

1MRS757644 H

Name Type

Start duration FLOAT32

Operate time

Breaker clear time

Fault distance

Fault resistance

Active group

Shot pointer

Max diff current IL1



Diff current IL1

Diff current IL2

Diff current IL3

Max bias current IL1


FLOAT32

FLOAT32

FLOAT32

FLOAT32

INT32

INT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

620 series

Technical Manual

Values (Range)

-103=MAPGAPC13

-76=MAPGAPC18

-75=MAPGAPC17

-62=SRCPTOC1

-74=DOPPDPR3

-73=DOPPDPR2

-70=DUPPDPR2

-58=UZPDIS1

-36=UEXPDIS1

14=MFADPSDE1

-10=LVRTPTUV1

-8=LVRTPTUV2

-6=LVRTPTUV3

-122=DPH3LPDOC1

-121=DPH3HPDOC2

-120=DPH3HPDOC1

-119=PH3LPTOC2

-118=PH3LPTOC1

-79=PH3HPTOC2

-78=PH3HPTOC1

-77=PH3IPTOC1

-127=PHAPTUV1

-124=PHAPTOV1

-123=DPH3LPDOC2

-68=PHPVOC2

-67=DQPTUV2

-39=UEXPDIS2

98=MHZPDIF1

-4=MREFPTOC1

0.00...100.00

0.000...999999.999

0.000...3.000

0.00...3000.00

0.00...1000000.00

1...6

1...7

0.000...80.000

0.000...80.000

0.000...80.000

0.000...80.000

0.000...80.000

0.000...80.000

0.000...50.000

Unit pu pu pu pu pu pu pu

% s s pu ohm

Basic functions

Description

Maximum start duration of all stages during the fault

Operate time

Breaker clear time

Distance to fault measured in pu

Fault resistance

Active setting group

Autoreclosing shot pointer value

Maximum phase A differential current

Maximum phase B differential current

Maximum phase C differential current

Differential current phase A

Differential current phase B

Differential current phase C

Maximum phase A bias current

105

Basic functions

Name



Bias current IL1

Bias current IL2

Bias current IL3

Diff current Io

Bias current Io

Max current IL1

Max current IL2

Max current IL3

Max current Io

Current IL1

Current IL2

Current IL3

Current Io

Current Io-Calc

Current Ps-Seq

Current Ng-Seq

Max current IL1B

Max current IL2B

Max current IL3B

Max current IoB

Current IL1B

Current IL2B

Current IL3B

Current IoB

Current Io-CalcB

Current Ps-SeqB

Current Ng-SeqB

Max current IL1C

Max current IL2C

Max current IL3C

FLOAT32

FLOAT32

FLOAT32

FLOAT32

Max current IoC FLOAT32

Current IL1C

Current IL2C

Current IL3C

Current IoC

FLOAT32

FLOAT32

FLOAT32

FLOAT32


Type

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

106 xIn xIn xIn xIn xIn xIn xIn xIn xIn xIn xIn xIn xIn xIn xIn xIn xIn xIn xIn xIn xIn xIn xIn xIn xIn xIn xIn pu pu pu pu pu xIn

Unit pu pu xIn xIn

Values (Range)

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...80.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

0.000...50.000

1MRS757644 H

Description

Maximum phase A current (b)

Maximum phase B current (b)

Maximum phase C current (b)

Maximum residual current (b)

Phase A current (b)

Phase B current (b)

Phase C current (b)

Residual current (b)

Calculated residual current (b)

Positive sequence current (b)

Negative sequence current (b)

Maximum phase A current (c)

Maximum phase B current (c)

Maximum phase C current (c)

Maximum residual current (c)

Phase A current (c)

Phase B current (c)

Phase C current (c)

Residual current (c)

Maximum phase B bias current

Maximum phase C bias current

Bias current phase A

Bias current phase B

Bias current phase C

Differential current residual

Bias current residual

Maximum phase A current

Maximum phase B current

Maximum phase C current

Maximum residual current

Phase A current

Phase B current

Phase C current

Residual current

Calculated residual current

Positive sequence current

Negative sequence current

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Technical Manual

1MRS757644 H

Name

Current Io-CalcC

Current Ps-SeqC

Current Ng-SeqC

Voltage UL1

Voltage UL2

Voltage UL3

Voltage U12

Voltage U23

Voltage U31

Voltage Uo

Voltage Zro-Seq

Voltage Ps-Seq

Voltage Ng-Seq

Voltage UL1B

Voltage UL2B

Voltage UL3B

Voltage U12B

Voltage U23B

Voltage U31B

Voltage UoB

Voltage Zro-SeqB

Voltage Ps-SeqB

Voltage Ng-SeqB

PTTR thermal level

Type

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

PDNSPTOC1 rat. I2/I1

Frequency

Frequency gradient

Conductance Yo

Susceptance Yo

Angle Uo - Io

Angle U23 - IL1

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

Angle U31 - IL2 FLOAT32

Angle U12 - IL3 FLOAT32

Angle UoB - IoB FLOAT32


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Technical Manual

Values (Range)

0.000...50.000

0.000...50.000

0.000...50.000

0.000...4.000

0.000...4.000

0.000...4.000

0.000...4.000

0.000...4.000

0.000...4.000

0.000...4.000

0.000...4.000

0.000...4.000

0.000...4.000

0.000...4.000

0.000...4.000

0.000...4.000

0.000...4.000

0.000...4.000

0.000...4.000

0.000...4.000

0.000...4.000

0.000...4.000

0.000...4.000

0.00...99.99

0.00...999.99

30.00...80.00

-10.00...10.00

-1000.00...1000.00

-1000.00...1000.00

-180.00...180.00

-180.00...180.00

-180.00...180.00

-180.00...180.00

-180.00...180.00

%

Hz

Hz/s mS mS deg deg deg deg deg xUn xUn xUn xUn xUn xUn xUn xUn xUn xUn xUn xUn xUn xUn xUn

Unit xIn xIn xIn xUn xUn xUn xUn xUn

Basic functions

Description

Calculated residual current (c)

Positive sequence current (c)

Negative sequence current (c)

Phase A voltage

Phase B voltage

Phase C voltage

Phase A to phase B voltage

Phase B to phase C voltage

Phase C to phase A voltage

Residual voltage

Zero sequence voltage

Positive sequence voltage

Negative sequence voltage

Phase A voltage (b)

Phase B voltage (b)

Phase B voltage (b)

Phase A to phase B voltage (b)

Phase B to phase C voltage (b)

Phase C to phase A voltage (b)

Residual voltage (b)

Zero sequence voltage

(b)

Positive sequence voltage (b)

Negative sequence voltage (b)

PTTR calculated temperature of the protected object relative to the operate level

PDNSPTOC1 ratio I2/I1

Frequency

Frequency gradient

Conductance Yo

Susceptance Yo

Angle residual voltage residual current

Angle phase B to phase

C voltage - phase A current

Angle phase C to phase

A voltage - phase B current

Angle phase A to phase

B voltage - phase C current

Angle residual voltage residual current (b)

107


Name

Angle U23B - IL1B

Angle U31B - IL2B

Angle U12B - IL3B

Type

FLOAT32

FLOAT32

FLOAT32

3.9

Values (Range)

-180.00...180.00

-180.00...180.00

-180.00...180.00

Unit deg deg deg

Description

Angle phase B to phase

C voltage - phase A current (b)

Angle phase C to phase

A voltage - phase B current (b)

Angle phase A to phase

B voltage - phase C current (b)

Nonvolatile memory

In addition to the setting values, the protection relay can store some data in the nonvolatile memory.

• Up to 1024 events are stored. The stored events are visible in LHMI, WHMI and

Event viewer tool in PCM600.

• Recorded data

- Fault records (up to 128)

- Maximum demands

• Circuit breaker condition monitoring

• Latched alarm and trip LEDs' statuses

• Trip circuit lockout

• Counter values

3.10

Sensor inputs for currents and voltages

This chapter gives short examples on how to define the correct parameters for sensor measurement interfaces.

Sensors can have correction factors, measured and verified by the sensor manufacturer, to increase the measurement accuracy. Correction factors are recommended to be set to the relay. Two types of correction factors are available for voltage and current (Rogowski) sensors. The Amplitude correction factor is named Amplitude corr. A(B/C) and Angle correction factor is named Angle corr A(B/C). These correction factors can be found on the Sensor's rating plate and/or sensor routine test protocol. If the correction factors are not available, contact the sensor manufacturer for more information.

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Figure 33: Example of ABB Rogowski current sensor KECA 80 D85 rating plate

Current (Rogowski) sensor setting example

In this example, an 80 A/0.150 V at 50 Hz (0.180 V at 60 Hz) sensor, such as the example shown in

Figure 33

, is used in a 50 Hz electrical network. The application has a 150 A nominal current (In) corresponding to the protected object’s nominal current. The application nominal current is set to Rogowski sensor setting Primary current. Taken from the sensor’s technical data, this example sensor can be used with up to 4000 A application nominal current.

As the Rogowski sensor is linear and does not saturate, the 80 A/0.150 V at 50 Hz sensor also works as a 150 A/0.28125 V at 50 Hz sensor. When defining another primary value for the sensor, also the nominal voltage has to be redefined to maintain the same transformation ratio. However, the setting in the protection relay ( Rated Secondary Value) is not in V but in mV/Hz, which makes the same setting Rated Secondary Value valid for both

50 and 60 Hz nominal frequency.

RSV

=

I n

I pr

× f n

K r

(Equation 1)

RSV

I n

I pr f n

K r

Rated Secondary Value in mV/Hz

Application nominal current

Sensor-rated primary current

Network nominal frequency

Sensor-rated voltage at the rated current in mV

In this example, the value is as calculated using the equation.

150 A

× 150 mV

80 A

50 Hz

= mV

Hz

(Equation 2)

With this information, the protection relay's current (Rogowski) sensor settings can be set.

109

Basic functions

110

1MRS757644 H

Table 46: Example setting values for current (Rogowski) sensor

Setting

Primary current

Rated secondary value

Value

150 A

5.625 mV/Hz

When considering setting values for current sensor interfaces and for protection functions utilizing these measurements, it should be noted that the sensor measurement inputs in the relay have limits for linear behavior. When this limit is exceeded, the input starts to saturate. The saturation is reflected to the protection functions connected to the sensor inputs. To ensure that the related protection functions operate correctly, the start value setting for protection functions utilizing either instantaneous or definite minimum time characteristics must not exceed the linear measurement range. Furthermore, the effect on protection functions utilizing inverse time characteristics should be considered. The upper limit of the linear measurement range depends on the selected

application nominal current and the type of the current sensor used. Table

47

shows the limits for an 80A/150mV 50Hz sensor.

Table 47: Application nominal current relation to the upper limit of linear measurement range

Application nominal current (In)

40...800 A

800...1250 A

1250...2500 A

2500...4000 A

Rated secondary value with 80A / 0.150 V at 50

Hz (0.180 V at 60 Hz)

1.500...30.000 mV/Hz

30.000...46.875 mV/Hz

46.875...93.750 mV/Hz

93.750...150.000 mV/Hz

Upper limit of linear measurement range

60 × I n

60...40 × I n

40...20 × I n

20...12.5 × I n

Table 47 shows the upper limits of the linear measurement range based

on a certain range in application nominal current. The linear measurement limit for a given application nominal current can be derived from the values stated in the table with a simple proportion equation. For example, the upper limit for linear measurement for 3000 A application nominal current would be 17.5 xIn.

It can also be calculated from Table 47 that with the stated sensor the relay

input can linearly measure up to 50 kA (RMS) short circuit currents.

Rogowski sensor and overcurrent protection setting evaluation example

A 20 kV utility substation with a single busbar switchgear rated up to 40 kA shortcircuit currents has one incomer and 20 outgoing feeder relays using 80 A/0.150 V at 50 Hz Rogowski current sensors with rating plate

values similar to Figure 33 . For the incomer panel, electrical system designer

has evaluated the application nominal current to be 1250 A. Customer specification for these protection relays defines normal instantaneous and time-delayed overcurrent and earth-fault protection functions. Overcurrent protection requires functions to be settable up to 20 xIn.

The sensor setting Primary current is set to be the same as the evaluated application nominal current 1250 A. According to the sensor’s technical data,

620 series

Technical Manual

1MRS757644 H Basic functions the application nominal current matches the sensor’s capability which is up to 4000 A.

The setting

Rated secondary value is calculated by using Equation 1 .

1250

80 A

A

50

.

150

Hz mV mV

Hz

(Equation 3)

From

Table 47

it is seen that with the 1250 A application nominal current value, the maximum setting for overcurrent protection is 40 xIn. This covers the customer specification requirements for overcurrent settings of up to

20 xIn.

Voltage sensor setting example

The voltage sensor is based on the resistive divider or capacitive divider principle. Therefore, the voltage is linear throughout the whole measuring range. The output signal is a voltage, directly proportional to the primary voltage. For the voltage sensor, all parameters are readable directly from its rating plate and/or sensor routine test protocol, and conversions are not needed.

620 series

Technical Manual

Figure 34: Example of ABB voltage sensor KEVA 17.5 B21 rating plate

In this example the system phase-to-phase voltage rating is 10 kV. Thus, the

Primary voltage parameter is set to 10 kV. For protection relays with sensor measurement support, the Voltage input type is set to "Voltage sensor". The

VT connection parameter is set to the "WYE" type. The division ratio for ABB voltage sensors is most often 10000:1. Thus, the Division ratio parameter is usually set to "10000". The primary voltage is proportionally divided by this division ratio.

Table 48: Example setting values for voltage sensor

Setting

Primary voltage

VT connection


Value

10 kV

Wye

111


Setting

Voltage input type

Division ratio

Value

3=Voltage sensor

10000

3.11

3.11.1

Binary inputs

Use only DC power for binary inputs. Use of AC power or half-waverectified AC power may cause damage to the binary input modules.

Binary input filter time

The filter time eliminates debounces and short disturbances on a binary input. The filter time is set for each binary input of the protection relay.

1 2

3

4

5 5

1 t

0

2 t

1

3 Input signal

Figure 35: Binary input filtering

4

5

Filtered input signal

Filter time

At the beginning, the input signal is at the high state, the short low state is filtered and no input state change is detected. The low state starting from the time t

0 exceeds the filter time, which means that the change in the input state is detected and the time tag attached to the input change is t

0 is detected and the time tag t

1

is attached.

. The high state starting from t

1

Each binary input has a filter time parameter "Input # filter", where # is the number of the binary input of the module in question (for example "Input 1 filter").

Table 49: Input filter parameter values

Parameter

Input # filter time

Values

5...1000 ms

Default

5 ms

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3.11.2

3.11.3

Basic functions

Binary input inversion

The parameter Input # invert is used to invert a binary input.

Table 50: Binary input states

Control voltage

No

Yes

No

Yes

Input # invert

1

1

0

0

State of binary input

FALSE (0)

TRUE (1)

TRUE (1)

FALSE (0)

When a binary input is inverted, the state of the input is TRUE (1) when no control voltage is applied to its terminals. Accordingly, the input state is FALSE (0) when a control voltage is applied to the terminals of the binary input.

Oscillation suppression

Oscillation suppression is used to reduce the load from the system when a binary input starts oscillating. A binary input is regarded as oscillating if the number of valid state changes (= number of events after filtering) during one second is equal to or greater than the set oscillation level value. During oscillation, the binary input is blocked (the status is invalid) and an event is generated. The state of the input will not change when it is blocked, that is, its state depends on the condition before blocking.

The binary input is regarded as non-oscillating if the number of valid state changes during one second is less than the set oscillation level value minus the set oscillation hysteresis value. Note that the oscillation hysteresis must be set lower than the oscillation level to enable the input to be restored from oscillation. When the input returns to a non-oscillating state, the binary input is deblocked (the status is valid) and an event is generated.

Table 51: Oscillation parameters

Parameter

Input osc. level

Input osc. hyst

Value

2...50 events/s

2...50 events/s

Default

30 events/s

10 events/s

3.12

Binary outputs

The protection relay provides a number of binary outputs used for tripping, executing local or remote control actions of a breaker or a disconnector, and for connecting the protection relay to external annunciation equipment for indicating, signalling and recording.

Power output contacts are used when the current rating requirements of the contacts are high, for example, for controlling a breaker, such as energizing the breaker trip and closing coils.

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113

Basic functions

3.12.1

3.12.1.1

1MRS757644 H

The contacts used for external signalling, recording and indicating, the signal outputs, need to adjust to smaller currents, but they can require a minimum current

(burden) to ensure a guaranteed operation.

The protection relay provides both power output and signal output contacts. To guarantee proper operation, the type of the contacts used are chosen based on the operating and reset time, continuous current rating, make and carry for short time, breaking rate and minimum connected burden. A combination of series or parallel contacts can also be used for special applications. When appropriate, a signal output can also be used to energize an external trip relay, which in turn can be confiugred to energize the breaker trip or close coils.

Using an external trip relay can require an external trip circuit supervision relay. It can also require wiring a separate trip relay contact back to the protection relay for breaker failure protection function.

All contacts are freely programmable, except the internal fault output IRF.

Power output contacts

Power output contacts are normally used for energizing the breaker closing coil and trip coil, external high burden lockout or trip relays.

Dual single-pole power outputs PO1 and PO2

Dual (series-connected) single-pole (normally open/form A) power output contacts

PO1 and PO2 are rated for continuous current of 8 A. The contacts are normally used for closing circuit breakers and energizing high burden trip relays. They can be arranged to trip the circuit breakers when the trip circuit supervision is not available or when external trip circuit supervision relay is provided.

The power outputs are included in slot X100 of the power supply module.

X100

PO1

6

7

PO2

8

9

Figure 36: Dual single-pole power output contacts PO1 and PO2

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3.12.1.2

3.12.1.3

Double-pole power outputs PO3 and PO4 with trip circuit supervision

The power outputs PO3 and PO4 are double-pole normally open/form A power outputs with trip circuit supervision.

When the two poles of the contacts are connected in series, they have the same technical specification as PO1 for breaking duty. The trip circuit supervision hardware and associated functionality which can supervise the breaker coil both during closing and opening condition are also provided. Contacts PO3 and PO4 are almost always used for energizing the breaker trip coils.

PO3

TCS1

PO4

TCS2

X100

16

17

15

19

18

20

22

21

23

24

Figure 37: Double-pole power outputs PO3 and PO4 with trip circuit supervision

Power outputs PO3 and PO4 are included in the power supply module located in slot

X100 of the protection relay.

Dual single-pole signal/trip output contact SO3

The dual parallel-connected, single-pole, normally open/form A output contact SO3 has a continuous rating of 5 A but has a lower breaking capacity than the other POs.

When used in breaker tripping applications, an external contact, such as breaker auxiliary contact, is recommended to break the circuit. When the application requires, an optional BIO card with HSO contact can be ordered with the protection relay.

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3.12.1.4

116

Figure 38: Signal/trip output contact SO3

The signal/trip output contact is included in the module RTD0002 located in slot

X130 of the protection relay.

Dual single-pole high-speed power outputs HSO1, HSO2 and HSO3

HSO1, HSO2 and HSO3 are dual parallel connected, single-pole, normally open/form

A high-speed power outputs. The high-speed power output is a hybrid discrete and electromechanical output that is rated as a power output.

The outputs are normally used in applications that require fast relay output contact activation time to achieve fast opening of a breaker, such as, arc-protection or breaker failure protection, where fast operation is required either to minimize fault effects to the equipment or to avoid a fault to expand to a larger area. With the high-speed outputs, the total time from the application to the relay output contact activation is 5...6 ms shorter than when using output contacts with conventional mechanical output relays. The high-speed power outputs have a continuous rating of 6 A. When two of HSO contacts are connected in series, the breaking rate is equal to that of output contact PO1.

X110

15

HSO1

16

19

HSO2

20

23

HSO3

24

Figure 39: High-speed power outputs HSO1, HSO2 and HSO3

The reset time of the high-speed output contacts is longer than that of the conventional output contacts.

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3.12.2

3.12.2.1

3.12.2.2

High-speed power contacts are part of the card BIO0007 with eight binary inputs and three HSOs. They are optional alternatives to conventional BIO cards of the protection relay.

Signal output contacts

Signal output contacts are single-pole, single (normally open/form A or changeover/form C) signal output contacts (SO1, SO2,...) or parallel connected dual contacts.

The signal output contacts are used for energizing, for example, external low burden trip relays, auxiliary relays, annunciators and LEDs.

A single signal contact is rated for a continuous current of 5 A. It has a make and carry for 0.5 seconds at 15 A.

When two contacts are connected in parallel, the relay is of a different design. It has the make and carry rating of 30 A for 0.5 seconds. This can be applied for energizing breaker close coil and tripping coil. Due to the limited breaking capacity, a breaker auxiliary contact can be required to break the circuit.

When the application requires high making and breaking duty, it is possible to use HSO contacts in the protection relay or an external interposing auxiliary relay.

Internal fault signal output IRF

The internal fault signal output (change-over/form C) IRF is a single contact included in the power supply module of the protection relay.

IRF

X100

3

4

5

Figure 40: Internal fault signal output IRF

Signal outputs SO1 and SO2 in power supply module

Signal outputs (normally open/form A or change-over/form C) SO1 (dual parallel form C) and SO2 (single contact/form A) are part of the power supply module of the protection relay.

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3.12.2.3

3.12.2.4

118

SO1

X100

10

11

12

SO2

X100

13

14

Figure 41: Signal outputs SO1 and SO2 in power supply module

Signal outputs SO1 and SO2 in RTD0002

The signal ouputs SO1 and SO2 (single contact/change-over /form C) are included in the RTD0002 module.

SO1

X130

9

10

11

12

SO2

13

14

Figure 42: Signal output in RTD0002

Signal outputs SO1, SO2, SO3 and SO4 in BIO0005

The optional card BIO0005 provides the signal outputs SO1, SO2 SO3 and SO4.

Signal outputs SO1 and SO2 are dual, parallel form C contacts; SO3 is a single form

C contact, and SO4 is a single form A contact.

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SO1

SO2

SO3

SO4

Figure 43: Signal output in BIO0005

19

18

X110

20

22

21

23

X110

14

16

15

17

24

3.13

3.13.1

3.13.2

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Technical Manual

RTD/mA inputs

Functionality

The RTD and mA analog input module is used for monitoring and metering current

(mA), temperature (°C) and resistance (Ω). Each input can be linearly scaled for various applications, for example, transformer’s tap changer position indication.

Each input has independent limit value supervision and deadband supervision functions, including warning and alarm signals.

Operation principle

All the inputs of the module are independent RTD and mA channels with individual protection, reference and optical isolation for each input, making them galvanically isolated from each other and from the rest of the module. However, the RTD inputs share a common ground.

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3.13.2.1

3.13.2.2

Selection of input signal type

The function module inputs accept current or resistance type signals. The inputs are configured for a particular type of input type by the channel-specific Input mode setting. The default value for all inputs is “Not in use”, which means that the channel is not sampled at all, and the output value quality is set accordingly.

Table 52: Limits for the RTD/mA inputs

Input mode

Not in use

0...20 mA

Resistance

Pt100

Pt250

Ni100

Ni120

Ni250

Cu10

Description

Default selection. Used when the corresponding input is not used.

Selection for analog DC milliampere current inputs in the input range of

0...20 mA.

Selection for RTD inputs in the input range of 0...2000 Ω.

Selection for RTD inputs, when temperature sensor is used. All the selectable sensor types have their resistance vs. temperature characteristics stored in the module; default measuring range is -40...200°C.

Selection of output value format

Each input has independent Value unit settings that are used to select the unit for the channel output. The default value for the Value unit setting is “Dimensionless”.

Input minimum and Input maximum, and Value maximum and Value minimum settings have to be adjusted according to the input channel. The default values for these settings are set to their maximum and minimum setting values.

When the channel is used for temperature sensor type, set the Value unit setting to

“Degrees celsius”. When Value unit is set to “Degrees celsius”, the linear scaling is not possible, but the default range (-40…200 °C) can be set smaller with the Value maximum and Value minimum settings.

When the channel is used for DC milliampere signal and the application requires a linear scaling of the input range, the Value unit setting value has to be

"Dimensionless”, where the input range can be linearly scaled with settings Input minimum and Input maximum to Value minimum and Value maximum. When milliampere is used as an output unit, Value unit has to be "Ampere”. When Value unit is set to “Ampere”, the linear scaling is not possible, but the default range (0…

20 mA) can be set smaller with the Value maximum and Value minimum settings.

When the channel is used for resistance type signals and the application requires a linear scaling of the input range, the Value unit setting value has to be

"Dimensionless”, where the input range can be linearly scaled with the setting

Input minimum and Input maximum to Value minimum and Value maximum. When resistance is used as an output unit, Value unit has to be "Ohm". When Value unit is set to “Ohm”, the linear scaling is not possible, but the default range (0…2000 Ω) can be set smaller with the Value maximum and Value minimum settings.

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3.13.2.3

3.13.2.4

Input linear scaling

Each RTD/mA input can be scaled linearly by the construction of a linear output function in respect to the input. The curve consists of two points, where the y-axis

( Input minimum and Input maximum) defines the input range and the x-axis (Value minimum and Value maximum) is the range of the scaled value of the input.

The input scaling can be bypassed by selecting Value unit = "Ohm" when

Input mode = "Resistance" is used and by selecting Value unit = "Ampere" when Input mode = "0...20 mA" is used.

Example for linear scaling

Milliampere input is used as tap changer position information. The sensor information is from 4 mA to 20 mA that is equivalent to the tap changer position from -36 to 36, respectively.

X130-Input#

20 mA

Input maximum

”0..20mA”

Input mode

4 mA

Input minimum

AI_VAL#

-36

Value minimum

”Dimensionless”

Value unit

36

Value maximum

Figure 44: Milliampere input scaled to tap changer position information

Measurement chain supervision

Each input contains a functionality to monitor the input measurement chain. The circuitry monitors the RTD channels continuously and reports a circuitry break of any enabled input channel. If the measured input value is outside the limits, minimum/maximum value is shown in the corresponding output. The quality of the corresponding output is set accordingly to indicate misbehavior in the RTD/mA input.

Table 53: Function identification, limits for the RTD/mA inputs

Input

RTD temperature, high

RTD temperature, low mA current, high

Resistance, high

Limit value

> 200 °C

< -40 °C

> 23 mA

> 2000 Ω

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121


3.13.2.5

3.13.2.6

3.13.2.7

122

Self-supervision

Each input sample is validated before it is fed into the filter algorithm. The samples are validated by measuring an internally set reference current immediately after the inputs are sampled. Each RTD sensor type has expected current based on the sensor type. If the measured offset current deviates from the reference current more than 20%, the sample is discarded and the output is set to invalid. The invalid measure status deactivates as soon as the measured input signal is within the measurement offset.

Calibration

RTD and mA inputs are calibrated at the factory. The calibration circuitry monitors the RTD channels continuously and reports a circuitry break of any channel.

Limit value supervision

The limit value supervision function indicates whether the measured value of

AI_INST# exceeds or falls below the set limits. All the measuring channels have an individual limit value supervision function. The measured value contains the corresponding range information AI_RANGE# and has a value in the range of 0 to 4:

• 0: “normal”

• 1: “high”

• 2: “low”

• 3: “high-high”

• 4: “low-low”

The range information changes and the new values are reported.

Y

Value maximum

Out of Range

AI_RANGE#=3

Val high high limit

Hysteresis

AI_RANGE#=1

Val high limit

AI_RANGE#=0

AI_RANGE#=0 t

Val low limit

AI_RANGE#=2

Val low low limit

AI_RANGE#=4

Value Reported

Value minimum

Figure 45: Limit value supervision for RTD

The range information of “High-high limit” and “Low-low limit” is combined from all measurement channels to the Boolean ALARM output. The range information of “High limit” and “Low limit” is combined from all measurement channels to the

Boolean WARNING output.

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3.13.2.8

Table 54: Settings for RTD analog input limit value supervision

Function

RTD analog input

Settings for limit value supervision

Out of range

High-high limit

High limit

Low limit

Low-low limit

Out of range

Value maximum

Val high high limit

Val high limit

Val low limit

Val low low limit

Value minimum

When the measured value exceeds either the Value maximum setting or the Value minimum setting, the corresponding quality is set to out of range and a maximum or minimum value is shown when the measured value exceeds the added hysteresis, respectively. The hysteresis is added to the extreme value of the range limit to allow the measurement slightly to exceed the limit value before it is considered out of range.

Deadband supervision

Each input has an independent deadband supervision. The deadband supervision function reports the measured value according to integrated changes over a time period.

620 series

Technical Manual

Figure 46: Integral deadband supervision

The deadband value used in the integral calculation is configured with the Value deadband setting. The value represents the percentage of the difference between the maximum and minimum limits in the units of 0.001 percent * seconds. The reporting delay of the integral algorithms in seconds is calculated with the formula:

=

(

Value maximum − Value minimum

)

⋅ deadband

100000

∆ Y s

(Equation 4)

123


3.13.2.9

124

Example of RTD analog input deadband supervision

Temperature sensor Pt100 is used in the temperature range of 15...180 °C.

Value unit “Degrees Celsius” is used and the set values Value minimum and

Value maximum are set to 15 and 180, respectively.

Value deadband = 7500 (7.5% of the total measuring range 165)

AI_VAL# = AI_DB# = 85

If AI_VAL# changes to 90, the reporting delay is:

=

( 180 C 15

°

C )

⋅

7500 %s s

100000

90 C 85

°

C

≈

s

(Equation 5)

Table 55: Settings for RTD analog input deadband supervision

Funtion

RTD analog input

Setting

Value deadband

Maximum/minimum

(=range)

Value maximum / Value minimum (=20000)

Since the function can be utilized in various measurement modes, the default values are set to the extremes; thus, it is very important to set correct limit values to suit the application before the deadband supervision works properly.

RTD temperature vs. resistance

Table 56: Temperature vs. resistance

Temp

°C

Platinum TCR 0.00385

Pt 100 Pt 250

0

10

20

30

40

50

-40

-30

-20

-10

84.27

88.22

92.16

96.09

100

103.9

107.79

111.67

115.54

119.4


210.675

220.55

230.4

240.225

250

259.75

269.475

279.175

288.85

298.5

Nickel TCR 0.00618

Ni 100

79.1

84.1

89.3

94.6

100

105.6

111.2

117.1

123

129.1

Ni 120

94.92

100.92

107.16

113.52

120

126.72

133.44

140.52

147.6

154.92

Ni 250

197.75

210.25

223.25

236.5

250

264

278

292.75

307.5

322.75

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Technical Manual

Copper

TCR

0.00427

Cu 10

-

7.49

-

8.263

-

9.035

-

9.807

-

10.58


3.13.2.10

3.13.2.11

Temp

°C

100

120

140

150

60

70

80

90

160

180

200

Platinum TCR 0.00385

Nickel TCR 0.00618

Pt 100

123.24

127.07

130.89

134.7

138.5

146.06

-

153.58

161.04

168.46

175.84

Pt 250

308.1

317.675

327.225

336.75

346.25

365.15

-

383.95

402.6

421.15

439.6

Ni 100

135.3

141.7

148.3

154.9

161.8

176

190.9

198.6

206.6

223.2

240.7

Ni 120

162.36

170.04

177.96

185.88

194.16

211.2

229.08

238.32

247.92

267.84

288.84

Ni 250

338.25

354.25

370.75

387.25

404.5

440

477.25

496.5

516.5

558

601.75

RTD/mA input connection

RTD inputs can be used with a 2-wire or 3-wire connection with common ground.

When using the 3-wire connection, it is important that all three wires connecting the sensor are symmetrical, that is, the wires are of the same type and length. Thus the wire resistance is automatically compensated.

In the 2-wire connection, the lead resistance is not compensated. This scheme may be adopted when the lead resistance is negligible when compared to the RTD resistance or when the error so introduced is acceptable for the application in which it is used.

RTD/mA card variants

The available variants of RTD cards are 6RTD/2mA and 2RTD/1mA. The features are similar in both cards.

The available variants of RTD cards are 6RTD/2mA and 2RTD/1mA/3SO with an RTD capability. The features are similar in both cards.

6RTD/2mA card

This card accepts two milliampere inputs and six inputs from the RTD sensors. The inputs 1 and 2 are used for current measurement, whereas inputs from 3 to 8 are used for resistance type of measurements.

RTD/mA input connection

Resistance and temperature sensors can be connected to the 6RTD/2mA board with 3-wire and 2-wire connections.

Copper

TCR

0.00427

Cu 10

-

11.352

-

12.124

12.897

13.669

-

14.442

-

-

15.217

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125


126

Resistor sensor

X110

5

+

6

-

7

+

8

mA mA

9

+

10

mA1 mA2

RTD1

11

+

12

-

RTD2

13

+

-

14

15

16

...

RTD3

Figure 47: Three RTD sensors and two resistance sensors connected according to the 3-wire connection for 6RTD/2mA card

Resistor sensor

X110

5

+

6

-

7

+

8

mA mA

9

+

10

mA1 mA2

RTD1

11

+

12

-

RTD2

13

+

-

14

15

16

...

...

RTD3

Figure 48: Three RTD sensors and two resistance sensors connected according to the 2-wire connection for 6RTD/2mA card

620 series

Technical Manual


620 series

Technical Manual

Sensor

Transducer

X110

5

+

6

-

Shunt

(44 Ω )

15

16

...

...

...

Figure 49: mA wiring connection for 6RTD/2mA card

2RTD/1mA card

This type of card accepts one milliampere input, two inputs from RTD sensors and five inputs from VTs. The Input 1 is assigned for current measurements, inputs 2 and 3 are for RTD sensors and inputs 4 to 8 are used for measuring input data from

VT.

2RTD/1mA/3SO card has one milliampere input, two inputs from RTD sensors and three signal outputs. The Input 1 is assigned for current measurements, inputs 2 and 3 are for RTD sensors and outputs 4 , 5 , 6 are used signal outputs.

RTD/mA input connections

The examples of 3-wire and 2-wire connections of resistance and temperature sensors to the 2RTD/1mA board are as shown:

Resistor sensor

X130

1

+

2

mA

8

3

4

+

-

5

6

7

+

mA

RTD1

RTD2

Figure 50: Two RTD and resistance sensors connected according to the 3-wire connection for RTD/mA card

127


Resistor sensor

X130

1

+

2

mA

3

+

4

-

5

6

+

7

-

8 mA

RTD1

RTD2

3.13.3

128

Figure 51: Two RTD and resistance sensors connected according to the 2-wire connection for RTD/mA card

Sensor

Transducer

X130

1

+

2

...

...

-

Shunt

(44 Ω )

8

Figure 52: mA wiring connection for RTD/mA card

Signals

Table 57: 6RTD/2mA analog output signals

Name

ALARM

WARNING

AI_VAL1

Type

BOOLEAN

BOOLEAN

FLOAT32

AI_VAL2 FLOAT32


Description

General alarm

General warning mA input, Connectors 1-2, instantaneous value mA input, Connectors 3-4, instantaneous value

620 series

Technical Manual


Name

AI_VAL3

AI_VAL4

AI_VAL5

AI_VAL6

AI_VAL7

AI_VAL8

Type

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

FLOAT32

Description

RTD input, Connectors

5-6-11c, instantaneous value











Table 58: 2RTD/1mA analog output signals

Name

ALARM

WARNING

AI_VAL1

Type

BOOLEAN

BOOLEAN

FLOAT32

AI_VAL2

AI_VAL3

FLOAT32

FLOAT32

3.13.4

RTD input settings

Table 59: RTD input settings

Parameter

Input mode

Values (Range)

1=Not in use

2=Resistance

10=Pt100

11=Pt250

20=Ni100

21=Ni120

22=Ni250

30=Cu10

Input maximum 0...2000

Unit

Ω

Step

1

Input minimum 0...2000


Ω 1

Description

General alarm

General warning mA input, Connectors 1-2, instantaneous value

RTD input, Connectors 3-5, instantaneous value

RTD input, Connectors 6-8, instantaneous value

Default

1=Not in use

Description

Analogue input mode

2000

0

Maximum analogue input value for mA or resistance scaling

Minimum analogue input value for mA or resistance scaling

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Technical Manual

129

Basic functions

Parameter

Value unit

Values (Range)

1=Dimensionless

5=Ampere

23=Degrees celsius

30=Ohm

Value maximum -10000.0...1000

0.0

Value minimum -10000.0...1000

0.0

Val high high limit

-10000.0...1000

0.0

Value high limit -10000.0...1000

0.0

Value low limit -10000.0...1000

0.0

Value low low limit

-10000.0...1000

0.0

Value deadband 100...100000

Unit

Table 60: mA input settings

Parameter

Input mode

Values (Range)

1=Not in use

5=0..20mA

Input maximum 0...20

Unit mA

Input minimum 0...20

Value unit

1=Dimensionless

5=Ampere

23=Degrees celsius

30=Ohm

Value maximum -10000.0...1000

0.0

Value minimum -10000.0...1000

0.0

Val high high limit

-10000.0...1000

0.0

Value high limit -10000.0...1000

0.0

Value low limit -10000.0...1000

0.0

Value low low limit

-10000.0...1000

0.0

Value deadband 100...100000

mA

1

1

1

1

1

1

1

Step

1MRS757644 H

Default

1=Dimensionless

Description

Selected unit for output value format

1

1

1

1

1

1

1

Step

1

1

10000.0

-10000.0

10000.0

10000.0

-10000.0

-10000.0

1000

Maximum output value for scaling and supervision

Minimum output value for scaling and supervision

Output value high alarm limit for supervision

Output value high warning limit for supervision

Output value low warning limit for supervision

Output value low alarm limit for supervision

Deadband configuration value for integral calculation. (percentage of difference between min and max as 0,001 % s)

Default

1=Not in use

Description

Analogue input mode

20

0

1=Dimensionless

Maximum analogue input value for mA or resistance scaling

Minimum analogue input value for mA or resistance scaling

Selected unit for output value format

10000.0

-10000.0

10000.0

10000.0

-10000.0

-10000.0

1000

Maximum output value for scaling and supervision

Minimum output value for scaling and supervision

Output value high alarm limit for supervision

Output value high warning limit for supervision

Output value low warning limit for supervision

Output value low alarm limit for supervision

Deadband configuration value for integral calculation. (percentage of difference between min and max as 0,001 % s)

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1MRS757644 H

3.13.5

Monitored data

Table 61: 6RTD/2mA monitored data

Name

AI_DB1

Type

FLOAT32


-10000.0...10000.

0

AI_RANGE1 Enum

AI_DB2 FLOAT32

0=normal

1=high

2=low

3=high-high

4=low-low

-10000.0...10000.

0

AI_RANGE2 Enum

AI_DB3 FLOAT32

0=normal

1=high

2=low

3=high-high

4=low-low

-10000.0...10000.

0

AI_RANGE3 Enum

AI_DB4 FLOAT32

0=normal

1=high

2=low

3=high-high

4=low-low

-10000.0...10000.

0

AI_RANGE4 Enum

AI_DB5 FLOAT32

0=normal

1=high

2=low

3=high-high

4=low-low

-10000.0...10000.

0


Basic functions

Description mA input, Connectors 1-2, reported value mA input, Connectors 1-2, range mA input, Connectors 3-4, reported value mA input, Connectors 3-4, range

RTD input, Connectors 5-6-11c, reported value

RTD input, Connectors 5-6-11c, range




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131

Basic functions

Name

AI_RANGE5

Type

Enum

AI_DB6 FLOAT32

AI_RANGE6 Enum

AI_DB7

AI_RANGE7

AI_DB8

AI_RANGE8

FLOAT32

Enum

FLOAT32

Enum


0=normal

1=high

2=low

3=high-high

4=low-low

-10000.0...10000.

0

0=normal

1=high

2=low

3=high-high

4=low-low

-10000.0...10000.

0

0=normal

1=high

2=low

3=high-high

4=low-low

-10000.0...10000.

0

0=normal

1=high

2=low

3=high-high

4=low-low

1MRS757644 H

Description


RTD input,

Connectors

13-14-12c, reported value

RTD input,

Connectors

13-14-12c, range

RTD input,

Connectors


RTD input,

Connectors

15-16-12c, range

RTD input,

Connectors


RTD input,

Connectors

17-18-12c, range

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Table 62: 2RTD/1mA monitored data

Name

AI_DB1

Type

FLOAT32


-10000.0...10000.

0

AI_RANGE1 Enum

AI_DB2 FLOAT32

0=normal

1=high

2=low

3=high-high

4=low-low

-10000.0...10000.

0

AI_RANGE2 Enum

AI_DB3 FLOAT32

0=normal

1=high

2=low

3=high-high

4=low-low

-10000.0...10000.

0

AI_RANGE3 Enum

0=normal

1=high

2=low

3=high-high

4=low-low

Description mA input, Connectors 1-2, reported value mA input, Connectors 1-2, range

RTD input, Connectors 3-5, reported value

RTD input, Connectors 3-5, range

RTD input, Connectors 6-8, reported value

RTD input, Connectors 6-8, range

3.14

3.14.1

3.14.1.1

SMV function blocks

SMV function blocks are used in the process bus applications with the sending of the sampled values of analog currents and voltages and with the receiving of the sampled values of voltages.

IEC 61850-9-2 LE sampled values sending SMVSENDER

Functionality

The SMVSENDER function block is used for activating the SMV sending functionality. It adds/removes the sampled value control block and the related data set into/from the sending device's configuration. It has no input or output signals.

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133


SMVSENDER can be disabled with the Operation setting value “off”. If the

SMVSENDER is disabled from the LHMI, it can only be enabled from the LHMI. When disabled, the sending of the samples values is disabled.

3.14.1.2

Settings

Table 63: SMVSENDER Settings

Parameter

Operation

Values (Range)

1=on

5=off

Unit Step Default

1=on

Description

Operation

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3.14.2

3.14.2.1

IEC 61850-9-2 LE sampled values receiving SMVRCV

Function block

3.14.2.2

3.14.2.3

3.14.3

3.14.3.1


Functionality

The SMVRCV function block is used for activating the SMV receiving functionality.

Signals

Table 64: SMVRCV Output signals

Name

UL1

UL2

UL3

U0

Type

INT32-UL1

INT32-UL2

INT32-UL3

INT32-Uo

Description

IEC61850-9-2 phase 1 voltage



IEC61850-9-2 residual voltage

ULTVTR function block

Function block

3.14.3.2


Functionality

The ULTVTR function is used in the receiver application to perform the supervision for the sampled values and to connect the received analog phase voltage inputs to the application. Synchronization accuracy, sampled value frame transfer delays and missing frames are being supervised.

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135


3.14.3.3

3.14.3.4

The typical additional operate time increase is +2 ms for all the receiver application functions (using either local or remote samples) when SMV is used.


The ALARM in the receiver is activated if the synchronization accuracy of the sender or the receiver is either unknown or worse than 8 ms. The output is held on for 10 seconds after the synchronization accuracy returns within limits.

ALARM is activated when two or more consecutive SMV frames are lost or late. A single loss of frame is corrected with a zero-order hold scheme. In this case the effect on protection is considered negligible and the WARNING or ALARM outputs are not activated. The output is held on for 10 seconds after the conditions return to normal.

The SMV Max Delay parameter defines how long the receiver waits for the SMV frames before activating the ALARM output. This parameter can be accessed via

Configuration > System > Common. Waiting of the SMV frames also delays the local measurements of the receiver to keep them correctly time aligned. The SMV Max

Delay values include sampling, processing and network delay.

The MINCB_OPEN input signal is supposed to be connected through a protection relay's binary input to the NC auxiliary contact of the miniature circuit breaker protecting the VT secondary circuit. The MINCB_OPEN signal sets the FUSEF_U output signal to block all the voltage-related functions when MCB is in the open state.

The WARNING output in the receiver is activated if the synchronization accuracy of the sender or the receiver is worse than 4 μs. The output is held on for 10 seconds after the synchronization accuracy returns within limits.

The WARNING output is always internally active whenever the ALARM output is active.

The receiver activates the WARNING and ALARM outputs if any of the quality bits, except for the derived bit, is activated. When the receiver is in the test mode, it accepts SMV frames with test bit without activating the WARNING and ALARM outputs.

Signals

Table 65: ULTVTR Input signals

Name

UL1

UL2

UL3

MINCB_OPEN

Type

INT32-UL1

INT32-UL2

INT32-UL3

BOOLEAN

Default

0

0

0

0

Description




Active when external MCB opens protected voltage circuit

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Table 66: ULTVTR Output signals

Name

ALARM

WARNING

Type

BOOLEAN

BOOLEAN

3.14.3.5

Settings

Table 67: ULTVTR Non group settings (Basic)

Parameter

Primary voltage

Values (Range)

0.100...440.000


VT connection

Amplitude Corr A

1=Wye

2=Delta

3=U12

4=UL1

0.9000...1.1000

Unit kV

V

Step

0.001

1

0.0001

Description

Alarm

Warning

Amplitude Corr B 0.9000...1.1000


Division ratio 1000...20000

Voltage input type

Angle Corr A

1=Voltage trafo

3=CVD sensor

-8.000 … 8.000

deg

Angle Corr B

Angle Corr C

-8.000 … 8.000

deg

-8.000 … 8.000

deg

0.0001

0.0001

1

0.0001

0.0001

0.0001

Default

20.000

100

2=Delta

Description

Primary rated voltage

Secondary rated voltage

Voltage transducer measurement connection

1.0000

1.0000

1.0000

10000

1=Voltage trafo

0.0000

0.0000

0.0000

Phase A Voltage phasor magnitude correction of an external voltage transformer

Phase B Voltage phasor magnitude correction of an external voltage transformer

Phase C Voltage phasor magnitude correction of an external voltage transformer

Voltage sensor division ratio

Type of the voltage input

Phase A Voltage phasor angle correction of an external voltage transformer

Phase B Voltage phasor angle correction of an external voltage transformer

Phase C Voltage phasor angle correction of an external voltage transformer

3.14.3.6

Monitored data

Monitored data is available in three locations.

• Monitoring > I/O status > Analog inputs

• Monitoring > IED status > SMV traffic

• Monitoring > IED status > SMV accuracy

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137


3.14.4

3.14.4.1

RESTVTR function block

Function block

3.14.4.2

3.14.4.3


Functionality

The RESTVTR function is used in the receiver application to perform the supervision for the sampled values of analog residual voltage and to connect the received analog residual voltage input to the application. Synchronization accuracy, sampled value frame transfer delays and missing frames are being supervised.

The typical additional operate time increase is +2 ms for all the receiver application functions (using either local or remote samples) when SMV is used.


The ALARM in the receiver is activated if the synchronization accuracy of the sender or the receiver is either unknown or worse than 8 ms. The output is held on for 10 seconds after the synchronization accuracy returns within limits.

ALARM is activated when two or more consecutive SMV frames are lost or late. A single loss of frame is corrected with a zero-order hold scheme. In this case, the effect on protection is considered negligible and the WARNING or ALARM outputs are not activated. The output is held on for 10 seconds after the conditions return to normal.

The SMV Max Delay parameter defines how long the receiver waits for the SMV frames before activating the ALARM output. This parameter can be accessed via

Configuration/System/Common. Waiting of the SMV frames also delays the local measurements of the receiver to keep them correctly time aligned. The SMV Max

Delay values include sampling, processing and network delay.

The WARNING output in the receiver is activated if the synchronization accuracy of the sender or the receiver is worse than 4 μs. The output is held on for 10 seconds after the synchronization accuracy returns within limits.

The WARNING output is always internally active whenever the ALARM output is active.

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3.14.4.4

Signals

Table 68: RESTVTR Input signals

Name

Uo

Type

INT32-UL0

Default

0

Description

IEC61850-9-2 residual voltage

Table 69: RESTVTR Output signals

Name

ALARM

WARNING

Type

BOOLEAN

BOOLEAN

3.14.4.5

Settings

Table 70: RESTVTR Non group settings (Basic)


Primary voltage 0.100...440.000


Amplitude Corr 0.9000...1.1000

Angle correction

Unit kV

V

-20.0000...20.0000 deg

Step

0.001

1

0.0001

0.0001

3.14.4.6

Monitored data

Monitored data is available in three locations.

• Monitoring > I/O status > Analog inputs

• Monitoring > IED status > SMV traffic

• Monitoring > IED status > SMV accuracy

Default

11.547

100

1.0000

0.0000

Description

Alarm

Warning

Description

Primary voltage

Secondary voltage



3.15

GOOSE function blocks

GOOSE function blocks are used for connecting incoming GOOSE data to application. They support BOOLEAN, Dbpos, Enum, FLOAT32, INT8 and INT32 data types.

Common signals

The VALID output indicates the validity of received GOOSE data, which means in case of valid, that the GOOSE communication is working and received data quality bits (if configured) indicate good process data. Invalid status is caused either by bad data quality bits or GOOSE communication failure. See IEC 61850 engineering guide for details.

620 series

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139

Basic functions

3.15.1

3.15.1.1

1MRS757644 H

The OUT output passes the received GOOSE value for the application. Default value

(0) is used if VALID output indicates invalid status. The IN input is defined in the

GOOSE configuration and can always be seen in SMT sheet.

Settings

The GOOSE function blocks do not have any parameters available in LHMI or

PCM600.

GOOSERCV_BIN function block

Function block

3.15.1.2

3.15.1.3

3.15.2

3.15.2.1


Functionality

The GOOSERCV_BIN function is used to connect the GOOSE binary inputs to the application.

Signals

Table 71: GOOSERCV_BIN Output signals

Name

OUT

VALID

Type

BOOLEAN

BOOLEAN

Description

Output signal

Output signal

GOOSERCV_DP function block

Function block

3.15.2.2

140


Functionality

The GOOSERCV_DP function is used to connect the GOOSE double binary inputs to the application.

620 series

Technical Manual


3.15.2.3

3.15.3

3.15.3.1

Signals

Table 72: GOOSERCV_DP Output signals

Name

OUT

VALID

Type

Dbpos

BOOLEAN

GOOSERCV_MV function block

Function block

Description

Output signal

Output signal

3.15.3.2

3.15.3.3


Functionality

The GOOSERCV_MV function is used to connect the GOOSE measured value inputs to the application.

Signals

Table 73: GOOSERCV_MV Output signals

Name

OUT

VALID

Type

FLOAT32

BOOLEAN

Description

Output signal

Output signal

620 series

Technical Manual

141


3.15.4

3.15.4.1

GOOSERCV_INT8 function block

Function block

3.15.4.2

3.15.4.3

3.15.5

3.15.5.1


Functionality

The GOOSERCV_INT8 function is used to connect the GOOSE 8 bit integer inputs to the application.

Signals

Table 74: GOOSERCV_INT8 Output signals

Name

OUT

VALID

Type

INT8

BOOLEAN

Description

Output signal

Output signal

GOOSERCV_INTL function block

Function block

3.15.5.2


Functionality

The GOOSERCV_INTL function is used to connect the GOOSE double binary input to the application and extracting single binary position signals from the double binary position signal.

The OP output signal indicates that the position is open. Default value (0) is used if

VALID output indicates invalid status.

142 620 series

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3.15.5.3

3.15.6

3.15.6.1

The CL output signal indicates that the position is closed. Default value (0) is used if

VALID output indicates invalid status.

The OK output signal indicates that the position is neither in faulty or intermediate state. The default value (0) is used if VALID output indicates invalid status.

Signals

Table 75: GOOSERCV_INTL Output signals

Name

POS_OP

POS_CL

POS_OK

VALID

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Description

Position open output signal

Position closed output signal

Position OK output signal

Output signal

GOOSERCV_CMV function block

Function block


3.15.6.2

3.15.6.3

620 series

Technical Manual

Functionality

The GOOSERCV_CMV function is used to connect GOOSE measured value inputs to the application. The MAG_IN (amplitude) and ANG_IN (angle) inputs are defined in the GOOSE configuration (PCM600).

The MAG output passes the received GOOSE (amplitude) value for the application.

Default value (0) is used if VALID output indicates invalid status.

The ANG output passes the received GOOSE (angle) value for the application.

Default value (0) is used if VALID output indicates invalid status.

Signals

Table 76: GOOSERCV_CMV Output signals

Name

MAG

ANG

VALID

Type

FLOAT32

FLOAT32

BOOLEAN

Description

Output signal (amplitude)

Output signal (angle)

Output signal

143


3.15.7

3.15.7.1

GOOSERCV_ENUM function block

Function block

3.15.7.2

3.15.7.3

3.15.8

3.15.8.1


Functionality

The GOOSERCV_ENUM function block is used to connect GOOSE enumerator inputs to the application.

Signals

Table 77: GOOSERCV_ENUM Output signals

Name

OUT

VALID

Type

Enum

BOOLEAN

Description

Output signal

Output signal

GOOSERCV_INT32 function block

Function block

3.15.8.2


Functionality

The GOOSERCV_INT32 function block is used to connect GOOSE 32 bit integer inputs to the application.

144 620 series

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3.15.8.3

Signals

Table 78: GOOSERCV_INT32 Output signals

Name

OUT

VALID

Type

INT32

BOOLEAN

3.16

3.16.1

3.16.1.1

Type conversion function blocks

QTY_GOOD function block

Function block

Description

Output signal

Output signal

Basic functions

3.16.1.2

3.16.1.3


Functionality

The good signal quality function QTY_GOOD evaluates the quality bits of the input signal and passes it as a Boolean signal for the application.

The IN input can be connected to any logic application signal (logic function output, binary input, application function output or received GOOSE signal). Due to application logic quality bit propagation, each (simple and even combined) signal has quality which can be evaluated.

The OUT output indicates quality good of the input signal. Input signals that have no quality bits set or only test bit is set, will indicate quality good status.

Signals

Table 79: QTY_GOOD Input signals

Name

IN

Type

Any

Table 80: QTY_GOOD Output signals

Name

OUT

Type

BOOLEAN

Default

0

Description

Input signal

Description

Output signal

620 series

Technical Manual

145

Basic functions

3.16.2

3.16.2.1

QTY_BAD function block

Function block

1MRS757644 H

3.16.2.2

3.16.2.3

3.16.3

3.16.3.1


Functionality

The bad signal quality function QTY_BAD evaluates the quality bits of the input signal and passes it as a Boolean signal for the application.

The IN input can be connected to any logic application signal (logic function output, binary input, application function output or received GOOSE signal). Due to application logic quality bit propagation, each (simple and even combined) signal has quality which can be evaluated.

The OUT output indicates quality bad of the input signal. Input signals that have any other than test bit set, will indicate quality bad status.

Signals

Table 81: QTY_BAD Input signals

Name

IN

Type

Any

Table 82: QTY_BAD Output signals

Name

OUT

Type

BOOLEAN

Default

0

Description

Input signal

Description

Output signal

QTY_GOOSE_COMM function block

Function block


146 620 series

Technical Manual


3.16.3.2

3.16.3.3

3.16.4

3.16.4.1

Functionality

The QTY_GOOSE_COMM function block evaluates the peer device communication status from the quality bits of the input signal and passes it as a Boolean signal to the application.

The IN input signal must be connected to the VALID signal of the GOOSE function block.

The OUT output indicates the communication status of the GOOSE function block.

When the output is in the true (1) state, the GOOSE communication is active. The value false (0) indicates communication timeout.

Signals

Table 83: QTY_GOOSE_COMM Input signals

Name

IN

Type

Any

Default

0

Table 84: QTY_GOOSE_COMM Output signals

Name

COMMVALID

Type

BOOLEAN

Description

Input signal

Description

Output signal

T_HEALTH function block

Function block

3.16.4.2


Functionality

The GOOSE data health function T_HEALTH evaluates enumerated data of “Health” data attribute. This function block can only be used with GOOSE.

The IN input can be connected to GOOSERCV_ENUM function block, which is receiving the LD0.LLN0.Health.stVal data attribute sent by another device.

The outputs OK , WARNING and ALARM are extracted from the enumerated input value. Only one of the outputs can be active at a time. In case the GOOSERCV_ENUM function block does not receive the value from the sending device or it is invalid, the default value (0) is used and the ALARM is activated in the T_HEALTH function block.

620 series

Technical Manual

147


3.16.4.3

3.16.5

3.16.5.1

Signals

Table 85: T_HEALTH Input signals

Name

IN1

Type

Any

Table 86: T_HEALTH Output signals

Name

OK

WARNING

ALARM

Type

BOOLEAN

BOOLEAN

BOOLEAN

Default

0

T_F32_INT8 function block

Function block

Description

Input signal

Description

Output signal

Output signal

Output signal

3.16.5.2

3.16.5.3

3.16.6


Functionality

The T_F32_INT8 function is used to convert 32-bit floating type values to 8-bit integer type. The rounding operation is included. Output value saturates if the input value is below the minimum or above the maximum value.

Signals

Table 87: T_F32_INT8 Input signals

Name

F32

Type

FLOAT32

Table 88: T_F32_INT8 Output signal

Name

INT8

Type

INT8

Default

0.0

Description

Input signal

Description

Output signal

T_DIR function block

148 620 series

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1MRS757644 H

3.16.6.1

Function block

Basic functions

3.16.6.2

3.16.6.3

3.16.7

3.16.7.1


Functionality

The T_DIR function evaluates enumerated data of the FAULT_DIR data attribute of the directional functions. T_DIR can only be used with GOOSE. The DIR input can be connected to the GOOSERCV_ENUM function block, which is receiving the

LD0.<function>.Str.dirGeneral or LD0.<function>.Dir.dirGeneral data attribute sent by another device.

In case the GOOSERCV_ENUM function block does not receive the value from the sending device or it is invalid, the default value (0) is used in function outputs.

The outputs FWD and REV are extracted from the enumerated input value.

Signals

Table 89: T_DIR Input signals

Name

DIR

Type

Enum

Table 90: T_DIR Output signals

Name

FWD

REV

Type

BOOLEAN

BOOLEAN

Default

0

Default

0

0

Description

Input signal

Description

Direction forward

Direction backward

T_TCMD function block

Function block


620 series

Technical Manual

149


3.16.7.2

3.16.7.3

3.16.8

3.16.8.1

IN

2 x

0

1

Functionality

The T_TCMD function is used to convert enumerated input signal to Boolean output signals.

Table 91: Conversion from enumerated to Boolean

RAISE

FALSE

FALSE

TRUE

FALSE

LOWER

FALSE

TRUE

FALSE

FALSE

Signals

Table 92: T_TCMD input signals

Name

IN

Type

Enum

Table 93: T_TCMD output signals

Name

RAISE

LOWER

Type

BOOLEAN

BOOLEAN

Default

0

Description

Input signal

Description

Raise command

Lower command

T_TCMD_BIN function block

Function block

3.16.8.2

150


Functionality

The T_TCMD_BIN function is used to convert 32 bit integer input signal to Boolean output signals.

Table 94: Conversion from integer to Boolean

IN

0

1


RAISE

FALSE

FALSE

LOWER

FALSE

TRUE

620 series

Technical Manual


3.16.8.3

3.16.9

3.16.9.1

IN

2 x

RAISE

TRUE

FALSE

Signals

Table 95: T_TCMD_BIN input signals

Name

IN

Type

INT32

Table 96: T_TCMD_BIN output signals

Name

RAISE

LOWER

Type

BOOLEAN

BOOLEAN

Default

0

T_BIN_TCMD function block

Function block

LOWER

FALSE

FALSE

Description

Input signal

Description

Raise command

Lower command

3.16.9.2


Functionality

The T_BIN_TCMD function is used to convert Boolean input signals to 32 bit integer output signals.

Table 97: Conversion from Boolean to integer

RAISE

FALSE

FALSE

TRUE

LOWER

FALSE

TRUE

FALSE

OUT

0

1

2

620 series

Technical Manual

151


3.16.9.3

Signals

Table 98: T_BIN_TCMD input signals

Name

RAISE

LOWER

Type

BOOLEAN

BOOLEAN

Table 99: T_BIN_TCMD output signals

Name

OUT

Type

INT32

Default

0

0

Description

Raise command

Lower command

Description

Output signal

3.17

3.17.1

3.17.1.1

Configurable logic blocks

Standard configurable logic blocks

OR function block

Function block

152


620 series

Technical Manual


620 series

Technical Manual

Functionality

OR, OR6 and OR20 are used to form general combinatory expressions with Boolean variables

The O output is activated when at least one input has the value TRUE. The default value of all inputs is FALSE, which makes it possible to use only the required number of inputs and leave the rest disconnected.

OR has two inputs, OR6 six and OR20 twenty inputs.

Signals

Table 100: OR Input signals

Name

B1

B2

Type

BOOLEAN

BOOLEAN

Default

0

0

Description

Input signal 1

Input signal 2

Table 101: OR6 Input signals

Name

B1

B2

B3

B4

B5

B6

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Table 102: OR20 Input signals

Name

B9

B10

B11

B12

B13

B14

B15

B5

B6

B7

B8

B1

B2

B3

B4


Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Default

0

0

0

0

0

0

Default

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

Description

Input signal 1

Input signal 2

Input signal 3

Input signal 4

Input signal 5

Input signal 6

Description

Input signal 1

Input signal 2

Input signal 3

Input signal 4

Input signal 5

Input signal 6

Input signal 7

Input signal 8

Input signal 9

Input signal 10

Input signal 11

Input signal 12

Input signal 13

Input signal 14

Input signal 15

153


3.17.1.2

Name

B16

B17

B18

B19

B20

Table 103: OR Output signal

Name

O

Type

BOOLEAN

Table 104: OR6 Output signal

Name

O

Type

BOOLEAN

Table 105: OR20 Output signal

Name

O

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Type

BOOLEAN

Default

0

0

0

0

0

Description

Input signal 16

Input signal 17

Input signal 18

Input signal 19

Input signal 20

Description

Output signal

Description

Output signal

Description

Output signal

Settings

The function does not have any parameters available in LHMI or PCM600.

AND Function block

154 620 series

Technical Manual

1MRS757644 H

AND Function block

Basic functions

620 series

Technical Manual


Functionality

AND, AND6 and AND20 are used to form general combinatory expressions with

Boolean variables.

The default value in all inputs is logical true, which makes it possible to use only the required number of inputs and leave the rest disconnected.

AND has two inputs, AND6 six inputs and AND20 twenty inputs.

Signals

Table 106: AND Input signals

Name

B1

B2

Type

BOOLEAN

BOOLEAN

Default

1

1

Description

Input signal 1

Input signal 2

Table 107: AND6 Input signals

Name

B1

B2

B3

B4

B5

B6

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Default

1

1

1

1

1

1

Description

Input signal 1

Input signal 2

Input signal 3

Input signal 4

Input signal 5

Input signal 6

155

Basic functions

3.17.1.3

156

1MRS757644 H

Table 108: AND20 Input signals

Name

B13

B14

B15

B16

B9

B10

B11

B12

B17

B18

B19

B20

B5

B6

B7

B8

B1

B2

B3

B4

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Table 109: AND Output signal

Name

O

Type

BOOLEAN

Table 110: AND6 Output signal

Name

O

Type

BOOLEAN

Table 111: AND20 Output signal

Name

O

Type

BOOLEAN

Default

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

0

Description

Output signal

Description

Output signal

Description

Output signal

Settings


Description

Input signal 1

Input signal 2

Input signal 3

Input signal 4

Input signal 5

Input signal 6

Input signal 7

Input signal 8

Input signal 9

Input signal 10

Input signal 11

Input signal 12

Input signal 13

Input signal 14

Input signal 15

Input signal 16

Input signal 17

Input signal 18

Input signal 19

Input signal 20

XOR function block

620 series

Technical Manual


Function block

3.17.1.4


Functionality

The exclusive OR function XOR is used to generate combinatory expressions with

Boolean variables.

The output signal is TRUE if the input signals are different and FALSE if they are equal.

Signals

Table 112: XOR Input signals

Name

B1

B2

Type

BOOLEAN

BOOLEAN

Table 113: XOR Output signals

Name

O

Type

BOOLEAN

Default

0

0

Description

Output signal

Description

Input signal 1

Input signal 2

Settings


NOT function block

Function block


Functionality

NOT is used to generate combinatory expressions with Boolean variables.

NOT inverts the input signal.

620 series

Technical Manual

157


3.17.1.5

Signals

Table 114: NOT Input signals

Name

1

Type

BOOLEAN

Table 115: NOT Output signals

Name

O

Type

BOOLEAN

Default

0

Description

Output signal

Description

Input signal

Settings


MAX3 function block

Function block

158


Functionality

The maximum function MAX3 selects the maximum value from three analog values.

Disconnected inputs and inputs whose quality is bad are ignored. If all inputs are disconnected or the quality is bad, MAX3 output value is set to -2^21.

Signals

Table 116: MAX3 Input signals

Name

IN1

IN2

IN3

Type

FLOAT32

FLOAT32

FLOAT32

Default

0

0

0

Description

Input signal 1

Input signal 2

Input signal 3

Table 117: MAX3 Output signal

Name

OUT

Type

FLOAT32

Description

Output signal

Settings


620 series

Technical Manual

1MRS757644 H

3.17.1.6

MIN3 function block

Function block

Basic functions

3.17.1.7


Functionality

The minimum function MIN3 selects the minimum value from three analog values.

Disconnected inputs and inputs whose quality is bad are ignored. If all inputs are disconnected or the quality is bad, MIN3 output value is set to 2^21.

Signals

Table 118: MIN3 Input signals

Name

IN1

IN2

IN3

Type

FLOAT32

FLOAT32

FLOAT32

Default

0

0

0

Description

Input signal 1

Input signal 2

Input signal 3

Table 119: MIN3 Output signal

Name

OUT

Type

FLOAT32

Description

Output signal

Settings


R_TRIG function block

Function block

620 series

Technical Manual


Functionality

R_TRIG is used as a rising edge detector.

159


3.17.1.8

R_TRIG detects the transition from FALSE to TRUE at the CLK input. When the rising edge is detected, the element assigns the output to TRUE. At the next execution round, the output is returned to FALSE despite the state of the input.

Signals

Table 120: R_TRIG Input signals

Name

CLK

Type

BOOLEAN

Table 121: R_TRIG Output signals

Name

Q

Type

BOOLEAN

Default

0

Description

Output signal

Description

Input signal

Settings


F_TRIG function block

Function block


Functionality

F_TRIG is used as a falling edge detector.

The function detects the transition from TRUE to FALSE at the CLK input. When the falling edge is detected, the element assigns the Q output to TRUE. At the next execution round, the output is returned to FALSE despite the state of the input.

Signals

Table 122: F_TRIG Input signals

Name

CLK

Type

BOOLEAN

Table 123: F_TRIG Output signals

Name

Q

Type

BOOLEAN

Default

0

Description

Output signal

Description

Input signal

160 620 series

Technical Manual


3.17.1.9

Settings


T_POS_XX function blocks

Function block


620 series

Technical Manual

Functionality

The circuit breaker position information can be communicated with the IEC 61850

GOOSE messages. The position information is a double binary data type which is fed to the POS input.

T_POS_CL and T_POS_OP are used for extracting the circuit breaker status information. Respectively, T_POS_OK is used to validate the intermediate or faulty breaker position.

Table 124: Cross reference between circuit breaker position and the output of the function block

Circuit breaker position

Intermediate '00'

Close '01'

Open '10'

Faulty '11'

Output of the function block

T_POS_CL

FALSE

TRUE

FALSE

TRUE

T_POS_OP

FALSE

FALSE

TRUE

TRUE

T_POS_OK

FALSE

TRUE

TRUE

FALSE

Signals

Table 125: T_POS_CL Input signals

Name

POS

Type

Double binary

Table 126: T_POS_OP Input signals

Name

POS

Type

Double binary

Table 127: T_POS_OK Input signals

Name

POS

Type

Double binary

Default

0

Default

0

Default

0

Description

Input signal

Description

Input signal

Description

Input signal

161


3.17.1.10

Table 128: T_POS_CL Output signal

Name

CLOSE

Type

BOOLEAN

Table 129: T_POS_OP Output signal

Name

OPEN

Type

BOOLEAN

Table 130: T_POS_OK Output signal

Name

OK

Type

BOOLEAN

Description

Output signal

Description

Output signal

Description

Output signal

Settings


SWITCHR function block

Function block

162


Functionality

SWITCHR switching block for REAL data type is operated by the CTL_SW input, selects the output value OUT between the IN1 and IN2 inputs.

CTL_SW

FALSE

TRUE

OUT

IN2

IN1

Signals

Table 131: SWITCHR Input signals

Name

CTL_SW

IN1

IN2

Type

BOOLEAN

REAL

REAL

Default

1

0.0

0.0

Description

Control Switch

Real input 1

Real input 2

620 series

Technical Manual

1MRS757644 H

3.17.1.11

Table 132: SWITCHR Output signals

Name

OUT

Type

REAL

SWITCHI32 function block

Function block

Description

Real switch output

Basic functions

3.17.1.12


Functionality

SWITCHI32 switching block for 32-bit integer data type is operated by the CTL_SW input, which selects the output value OUT between the IN1 and IN2 inputs.

Table 133: SWITCHI32

CTL_SW

FALSE

TRUE

OUT

IN2

IN1

Signals

Table 134: SWITCHI32 Input signals

Name

CTL_SW

IN1

IN2

Type

BOOLEAN

INT32

INT32

Table 135: SWITCHI32 Output signals

Name

OUT

Type

INT32

Default

1

0

0

Description

Output signal

Description

Control Switch

Input signal 1

Input signal 2

SR function block

Function block


620 series

Technical Manual

163


3.17.1.13

Functionality

The SR flip-flop output Q can be set or reset from the S or R inputs. S input has a higher priority over the R input. Output NOTQ is the negation of output Q .

The statuses of outputs Q and NOTQ are not retained in the nonvolatile memory.

Table 136: Truth table for SR flip-flop

S

1

1

0

0

R

0

1

0

1 0

1

1

Q

0 1

Signals

Table 137: SR Input signals

Name

S

Type

BOOLEAN

R BOOLEAN

Table 138: SR Output signals

Name

Q

NOTQ

Type

BOOLEAN

BOOLEAN

Default

0=False

0=False

Description

Q status

NOTQ status

Description

Set Q output when set

Resets Q output when set

RS function block

Function block


Functionality

The RS flip-flop output Q can be set or reset from the S or R inputs. R input has a higher priority over the S input. Output NOTQ is the negation of output Q .

1 Keep state/no change

164 620 series

Technical Manual

1MRS757644 H

3.17.2

3.17.2.1

Basic functions

The statuses of outputs Q and NOTQ are not retained in the nonvolatile memory.

Table 139: Truth table for RS flip-flop

S

1

1

0

0

R

0

1

0

1 0

1

0

Q

0 1

Signals

Table 140: RS Input signals

Name

S

Type

BOOLEAN

R BOOLEAN

Table 141: RS Output signals

Name

Q

NOTQ

Type

BOOLEAN

BOOLEAN

Default

0=False

0=False

Description

Set Q output when set

Resets Q output when set

Description

Q status

NOTQ status

Technical revision history

Table 142: RS Technical revision history

Technical revision

L

Change

The name of the function has been changed from SR to RS.

Minimum pulse timer

Minimum pulse timer TPGAPC


620 series

Technical Manual

165

Basic functions

Function block

1MRS757644 H


Functionality

The Minimum pulse timer function TPGAPC contains two independent timers. The function has a settable pulse length (in milliseconds). The timers are used for setting the minimum pulse length for example, the signal outputs. Once the input is activated, the output is set for a specific duration using the Pulse time setting. Both timers use the same setting parameter.

Figure 87: A = Trip pulse is shorter than Pulse time setting, B = Trip pulse is longer than Pulse time setting

Signals

Table 143: TPGAPC Input signals

Name

IN1

IN2

Type

BOOLEAN

BOOLEAN

Table 144: TPGAPC Output signals

Name

OUT1

OUT2

Type

BOOLEAN

BOOLEAN

Settings

Table 145: TPGAPC Non group settings

Parameter

Pulse time

Values (Range)

0...60000

Unit ms

Step

1

Default

0=False

0=False

Description

Output 1 status

Output 2 status

Default

150

Description

Input 1 status

Input 2 status

Description

Minimum pulse time

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3.17.2.2


Table 146: TPGAPC Technical revision history


B

C

Change

Outputs now visible in menu

Internal improvement

Minimum pulse timer TPSGAPC

Function block

Basic functions


Functionality

The Minimum second pulse timer function TPSGAPC contains two independent timers. The function has a settable pulse length (in seconds). The timers are used for setting the minimum pulse length for example, the signal outputs. Once the input is activated, the output is set for a specific duration using the Pulse time setting. Both timers use the same setting parameter.

620 series

Technical Manual


Signals

Table 147: TPSGAPC Input signals

Name

IN1

IN2

Type

BOOLEAN

BOOLEAN

Table 148: TPSGAPC Output signals

Name

OUT1

OUT2

Type

BOOLEAN

BOOLEAN

Settings

Default

0=False

0=False

Description

Output 1 status

Output 2 status

Description

Input 1

Input 2

167


Table 149: TPSGAPC Non group settings (Basic)

Parameter

Pulse time

Values (Range)

0...300

Unit s

Step

1

Default

0

Description

Minimum pulse time


Table 150: TPSGAPC Technical revision history


B

C

Change

Outputs now visible in menu


3.17.2.3

Minimum pulse timer TPMGAPC

Function block


Functionality

The Minimum minute pulse timer function TPMGAPC contains two independent timers. The function has a settable pulse length (in minutes). The timers are used for setting the minimum pulse length for example, the signal outputs. Once the input is activated, the output is set for a specific duration using the Pulse time setting. Both timers use the same setting parameter.

168


Signals

Table 151: TPMGAPC Input signals

Name

IN1

IN2

Type

BOOLEAN

BOOLEAN

Default

0=False

0=False

Description

Input 1

Input 2

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Table 152: TPMGAPC Output signals

Name

OUT1

OUT2

Type

BOOLEAN

BOOLEAN

Settings

Table 153: TPMGAPC Non group settings (Basic)

Parameter

Pulse time

Values (Range)

0...300

Unit min

Step

1

Description

Output 1 status

Output 2 status

Default

0

3.17.3

3.17.3.1

Pulse timer function block PTGAPC

Function block

Basic functions

Description

Minimum pulse time

3.17.3.2


Functionality

The pulse timer function PTGAPC contains eight independent timers. The function has a settable pulse length. Once the input is activated, the output is set for a specific duration using the Pulse delay time setting.

t

0 t

0

+dt t

1 t

1

+dt t

2 t

2

+dt dt = Pulse delay time

Figure 93: Timer operation

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3.17.3.3

Signals

Table 154: PTGAPC Input signals

Name

Q5

Q6

Q7

Q8

Q1

Q2

Q3

Q4

Name

IN5

IN6

IN7

IN8

IN1

IN2

IN3

IN4

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Table 155: PTGAPC Output signals

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Default

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

Description

Output 1 status

Output 2 status

Output 3 status

Output 4 status

Output 5 status

Output 6 status

Output 7 status

Output 8 status

3.17.3.4

Settings

Table 156: PTGAPC Non group settings (Basic)

Parameter

Pulse time 1

Pulse time 2

Pulse time 3

Pulse time 4

Pulse time 5

Pulse time 6

Pulse time 7

Pulse time 8

Values (Range)

0...3600000

0...3600000

0...3600000

0...3600000

0...3600000

0...3600000

0...3600000

0...3600000

Unit ms ms ms ms ms ms ms ms

Step

10

10

10

10

10

10

10

10

3.17.3.5

Technical data

Table 157: PTGAPC Technical data

Characteristic

Operate time accuracy

Default

0

0

0

0

0

0

0

0

Description

Pulse time

Pulse time

Pulse time

Pulse time

Pulse time

Pulse time

Pulse time

Pulse time

Value

±1.0% of the set value or ±20 ms

Description

Input 1 status

Input 2 status

Input 3 status

Input 4 status

Input 5 status

Input 6 status

Input 7 status

Input 8 status

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3.17.4

3.17.4.1

Time delay off (8 pcs) TOFGAPC

Function block

Basic functions

3.17.4.2


Functionality

The time delay off (8 pcs) function TOFGAPC can be used, for example, for a dropoff-delayed output related to the input signal. The function contains eight independent timers. There is a settable delay in the timer. Once the input is activated, the output is set immediately. When the input is cleared, the output stays on until the time set with the Off delay time setting has elapsed.

3.17.4.3

620 series

Technical Manual t

0 t

1 t

1

+dt t

2 t

3 t

4

Figure 95: Timer operation t

5 t

5

+dt dt = Off delay time

Signals

Table 158: TOFGAPC Input signals

Name

IN5

IN6

IN7

IN8

IN1

IN2

IN3

IN4

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Default

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

Description

Input 1 status

Input 2 status

Input 3 status

Input 4 status

Input 5 status

Input 6 status

Input 7 status

Input 8 status

171


Table 159: TOFGAPC Output signals

Name

Q5

Q6

Q7

Q8

Q1

Q2

Q3

Q4

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Description

Output 1 status

Output 2 status

Output 3 status

Output 4 status

Output 5 status

Output 6 status

Output 7 status

Output 8 status

3.17.4.4

Settings

Table 160: TOFGAPC Non group settings (Basic)

Parameter

Off delay time 1

Off delay time 2

Off delay time 3

Off delay time 4

Off delay time 5

Off delay time 6

Off delay time 7

Off delay time 8

Values (Range)

0...3600000

0...3600000

0...3600000

0...3600000

0...3600000

0...3600000

0...3600000

0...3600000


Step

10

10

10

10

10

10

10

10

3.17.4.5

Technical data

Table 161: TOFGAPC Technical data

Characteristic


Default

0

0

0

0

0

0

0

0

Description

Off delay time

Off delay time

Off delay time

Off delay time

Off delay time

Off delay time

Off delay time

Off delay time

Value


3.17.5

Time delay on (8 pcs) TONGAPC

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3.17.5.1

Function block

Basic functions

3.17.5.2


Functionality

The time delay on (8 pcs) function TONGAPC can be used, for example, for time delaying the output related to the input signal. TONGAPC contains eight independent timers. The timer has a settable time delay. Once the input is activated, the output is set after the time set by the On delay time setting has elapsed.

3.17.5.3

t

0 t

0

+dt t

1 t

2 t

3 t

4 t

4

+dt t

5 dt = On delay time

Figure 97: Timer operation

Signals

Table 162: TONGAPC Input signals

Name

IN5

IN6

IN7

IN8

IN1

IN2

IN3

IN4

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Default

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

Description

Input 1

Input 2

Input 3

Input 4

Input 5

Input 6

Input 7

Input 8

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Table 163: TONGAPC Output signals

Name

Q5

Q6

Q7

Q8

Q1

Q2

Q3

Q4

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Description

Output 1

Output 2

Output 3

Output 4

Output 5

Output 6

Output 7

Output 8

3.17.5.4

Settings

Table 164: TONGAPC Non group settings (Basic)

Parameter

On delay time 1

On delay time 2

On delay time 3

On delay time 4

On delay time 5

On delay time 6

On delay time 7

On delay time 8

Values (Range)

0...3600000

0...3600000

0...3600000

0...3600000

0...3600000

0...3600000

0...3600000

0...3600000


Step

10

10

10

10

10

10

10

10

3.17.5.5

Technical data

Table 165: TONGAPC Technical data

Characteristic


Default

0

0

0

0

0

0

0

0

Description

On delay time

On delay time

On delay time

On delay time

On delay time

On delay time

On delay time

On delay time

Value


3.17.6

Set-reset (8 pcs) SRGAPC

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3.17.6.1

Function block

Basic functions


3.17.6.2

S#

1

1

0

0

Functionality

The set-reset (8 pcs) function SRGAPC is a simple SR flip-flop with a memory that can be set or that can reset an output from the S# or R# inputs, respectively.

The function contains eight independent set-reset flip-flop latches where the SET input has the higher priority over the RESET input. The status of each Q# output is retained in the nonvolatile memory. The individual reset for each Q# output is available on the LHMI or through tool via communication.

Table 166: Truth table for SRGAPC

R#

0

1

0

1

Q#

0 1

0

1

1

3.17.6.3

Signals

Table 167: SRGAPC Input signals

Name

S1

Type

BOOLEAN

R1 BOOLEAN



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Technical Manual

Default

0=False

0=False

Description

Set Q1 output when set

Resets Q1 output when set

175


3.17.6.4

S8

R8

R6

S7

R7

R5

S6

R4

S5

R3

S4

Name

S2

R2

S3

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Table 168: SRGAPC Output signals

Name

Q5

Q6

Q7

Q8

Q1

Q2

Q3

Q4

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Settings

0=False

0=False

0=False

0=False

0=False

0=False

0=False

Default

0=False

0=False

0=False

0=False

0=False

0=False

0=False

Description

Q1 status

Q2 status

Q3 status

Q4 status

Q5 status

Q6 status

Q7 status

Q8 status

Description















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Table 169: SRGAPC Non group settings (Basic)

Parameter

Reset Q1

Reset Q2

Reset Q3

Reset Q4

Reset Q5

Reset Q6

Reset Q7

Reset Q8

Values (Range)

0=Cancel

1=Reset

0=Cancel

1=Reset

0=Cancel

1=Reset

0=Cancel

1=Reset

0=Cancel

1=Reset

0=Cancel

1=Reset

0=Cancel

1=Reset

0=Cancel

1=Reset

Unit Step

3.17.7

3.17.7.1

Move (8 pcs) MVGAPC

Function block

Basic functions

Default

0=Cancel

0=Cancel

0=Cancel

0=Cancel

0=Cancel

0=Cancel

0=Cancel

0=Cancel

Description










3.17.7.2

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Technical Manual

Functionality

The move (8 pcs) function MVGAPC is used for user logic bits. Each input state is directly copied to the output state. This allows the creating of events from advanced logic combinations.

MVGAPC can generate user defined events in LHMI when the output description setting is changed in Configuration > Generic logic > MVGAPC1 > Output x >

Description. MVGAPC can also be used to generate events for IEC 61850 client as well as Modbus, DNP3 and IEC 60870-5-103 procotols.

177


3.17.7.3

Signals

Table 170: MVGAPC Input signals

Name

Q5

Q6

Q7

Q8

Q1

Q2

Q3

Q4

Name

IN5

IN6

IN7

IN8

IN1

IN2

IN3

IN4

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Table 171: MVGAPC Output signals

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

3.17.7.4

Settings

Table 172: MVGAPC Non group settings (Basic)

Parameter

Description

Description

Description

Description

Description

Description

Description

Description

Values (Range) Unit Step Default

MVGAPC1 Q1

MVGAPC1 Q2

MVGAPC1 Q3

MVGAPC1 Q4

MVGAPC1 Q5

MVGAPC1 Q6

MVGAPC1 Q7

MVGAPC1 Q8

Default

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

Description

Q1 status

Q2 status

Q3 status

Q4 status

Q5 status

Q6 status

Q7 status

Q8 status

Description

IN1 status

IN2 status

IN3 status

IN4 status

IN5 status

IN6 status

IN7 status

IN8 status

Description

Output description

Output description

Output description

Output description

Output description

Output description

Output description

Output description

3.17.8

Integer value move MVI4GAPC

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3.17.8.1

3.17.8.2

Function block

MVI4GAPC

IN1

IN2

IN3

IN4

OUT1

OUT2

OUT3

OUT4


Functionality

The integer value move function MVI4GAPC is used for creation of the events from the integer values. The integer input value is received via IN1...4

input. The integer output value is available on OUT1...4

output.

The integer input range is from -2147483648 to 2147483647.

3.17.8.3

3.17.9

Signals

Table 173: MVI4GAPC Input signals

Name

IN1

IN2

IN3

IN4

Type

INT32

INT32

INT32

INT32

Table 174: MVI4GAPC Output signals

Name

OUT1

OUT2

OUT3

OUT4

Type

INT32

INT32

INT32

INT32

Default

0

0

0

0

Description

Integer output value 1




Description

Integer input value 1




Analog value scaling SCA4GAPC

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3.17.9.1

3.17.9.2

3.17.9.3

Function block

SCA4GAPC

AI1_VALUE AO1_VALUE

AI2_VALUE AO2_VALUE

AI3_VALUE

AI4_VALUE

AO3_VALUE

AO4_VALUE


Functionality

The analog value scaling function SCA4GAPC is used for scaling the analog value. It allows creating events from analog values.

The analog value received via the AIn_VALUE input is scaled with the Scale ratio n setting. The scaled value is available on the AOn_VALUE output.

Analog input range is from –10000.0 to 10000.0.

Analog output range is from –2000000.0 to 2000000.0.

If the value of the AIn_VALUE input exceeds the analog input range,

AOn_VALUE is set to 0.0.

If the result of AIn_VALUE multiplied by the Scale ratio n setting exceeds the analog output range, AOn_VALUE shows the minimum or maximum value, according to analog value range.

Signals

Table 175: SCA4GAPC Input signals

Name

AI1_VALUE

Type

FLOAT32

AI2_VALUE

AI3_VALUE

AI4_VALUE

FLOAT32

FLOAT32

FLOAT32

Default

0.0

0.0

0.0

0.0

Description

Analog input value of channel 1




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Table 176: SCA4GAPC Output signals

Name

AO1_VALUE

AO2_VALUE

AO3_VALUE

AO4_VALUE

Type

FLOAT32

FLOAT32

FLOAT32

FLOAT32

Description

Analog value 1 after scaling




3.17.9.4

Settings

Table 177: SCA4GAPC settings

Parameter

Scale ratio 1

Scale ratio 2

Scale ratio 3

Scale ratio 4

Values (Range)

0.001...1000.000

0.001...1000.000

0.001...1000.000

0.001...1000.000

Unit Step

0.001

0.001

0.001

0.001

Default

1.000

1.000

1.000

1.000

Description

Scale ratio for analog value 1




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Basic functions

3.17.10

3.17.10.1

Local/remote control function block CONTROL

Function block

1MRS757644 H


3.17.10.2

Functionality

Local/Remote control is by default realized through the R/L button on the front panel. The control via binary input can be enabled by setting the value of the

LR control setting to "Binary input". The binary input control requires that the

CONTROL function is instantiated in the product configuration.

Local/Remote control supports multilevel access for control operations in substations according to the IEC 61850 standard. Multilevel control access with separate station control access level is not supported by other protocols than IEC

61850.

The actual Local/Remote control state is evaluated by the priority scheme on the function block inputs. If more than one input is active, the input with the highest priority is selected.

The actual state is reflected on the CONTROL function outputs. Only one output is active at a time.

Table 178: Truth table for CONTROL

CTRL_OFF

TRUE

FALSE

FALSE

FALSE

FALSE

CTRL_LOC any

TRUE

FALSE

FALSE

FALSE

Input

CTRL_STA 1 any any

TRUE

FALSE

FALSE

CTRL_REM any any any

TRUE

FALSE

Output

OFF = TRUE

LOCAL = TRUE

STATION = TRUE

REMOTE = TRUE

OFF = TRUE

The station authority check based on the IEC 61850 command originator category in control command can be enabled by setting the value of the Station authority setting to "Station, Remote" (The command originator validation is performed only if the LR control setting is set to "Binary input"). The station authority check is not in use by default.

182

1 If station authority is not in use, the CTRL_STA input is interpreted as CTRL_REM .

620 series

Technical Manual


3.17.10.3

3.17.10.4

L/R control access

Four different Local/Remote control access scenarios are possible depending on the selected station authority level: “L,R”, “L,R,L+R”, “L,S,R” and “L, S, S+R, L+S,

L+S+R”. If control commands need to be allowed from multiple levels, multilevel access can be used. Multilevel access is possible only by using the station authority levels “L,R,L+R” and “L, S, S+R, L+S, L+S+R”. Multilevel access status is available from

IEC 61850 data object CTRL.LLN0.MltLev.

Control access selection is made with R/L button or CONTROL function block and IEC 61850 data object CTRL.LLN0.LocSta. When writing CTRL.LLN0.LocSta IEC

61850 data object, IEC 61850 command originator category station must be used by the client, and remote IEC 61850 control access must be allowed by the relay station authority. CTRL.LLN0.LocSta data object value is retained in the nonvolatile memory. The present control status can be monitored in the HMI or PCM600 via

Monitoring > Control command with the LR state parameter or from the IEC 61850 data object CTRL.LLN0. LocKeyHMI.

IEC 61850 command originator category is always set by the IEC 61850 client.

The relay supports station and remote IEC 61850 command originator categories, depending on the selected station authority level.

Station authority level “L,R"

Relay's default station authority level is “L,R”. In this scenario only local or remote control access is allowed. Control access with IEC 61850 command originator category station is interpreted as remote access. There is no multilevel access.

REMOTE LOCAL OFF

IEC 61850 remote

IEC 61850 remote

IEC 61850 remote

IEC 61850 remote

IEC 61850 remote

IEC 61850 remote

IED IED

Figure 103: Station authority is “L,R”

IED

When station authority level “L,R” is used, control access can be selected using R/L button or CONTROL function block. IEC 61850 data object CTRL.LLN0.LocSta and

CONTROL function block inputs CTRL_STA and CTRL_ALL are not applicable for this station authority level.

Table 179: Station authority level “L,R” using R/L button

L/R control

R/L button

Local

Remote

Off

L/R control status

CTRL.LLN0.LocSta CTRL.LLN0.MltLev L/R state

CTRL.LLN0.LocKey

HMI

N/A

N/A

N/A

FALSE

FALSE

FALSE

1

2

0

Control access

Local user x

IEC 61850 client 1 x

1 Client IEC 61850 command originator category check is not performed.

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Table 180: Station authority “L,R” using CONTROL function block

L/R control

Control FB input

CTRL_OFF

CTRL_LOC

CTRL_STA

CTRL_REM

CTRL_ALL

L/R control status



HMI

N/A

N/A

N/A

N/A

N/A

FALSE

FALSE

FALSE

FALSE

FALSE

0

1

0

2

0

Control access

Local user x

IEC 61850 client 1 x

3.17.10.5

Station authority level "L,R,L+R"

Station authority level "L,R, L+R" adds multilevel access support. Control access can also be simultaneously permitted from local or remote location. Simultaneous local or remote control operation is not allowed as one client and location at time can access controllable objects and they remain reserved until the previously started control operation is first completed by the client. Control access with IEC 61850 originator category station is interpreted as remote access.

REMOTE LOCAL OFF L+R

IEC 61850 remote

IEC 61850 remote

IEC 61850 remote

IEC 61850 remote

IEC 61850 remote

IEC 61850 remote

IEC 61850 remote

IEC 61850 remote

IED IED

Figure 104: Station authority is “L,R,L+R”

IED IED

When station authority level "L,R, L+R" is used, the control access can be selected using R/L button or CONTROL function block. IEC 61850 data object

CTRL.LLN0.LocSta and CONTROL function block input CTRL_STA are not applicable for this station authority level.

Table 181: Station authority level "L,R,L+R" using R/L button

L/R Control

R/L button IEC 61850 client 1

Local

Remote

Local + Remote

Off

L/R Control status



HMI

N/A

N/A

N/A

N/A

FALSE

FALSE

TRUE

FALSE

1

2

4

0

Control access

Local user x x x x

1 Client IEC 61850 command originator category check is not performed.

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Table 182: Station authority “L,R,L+R” using CONTROL function block

L/R Control


CTRL_OFF

CTRL_LOC

CTRL_STA

CTRL_REM

CTRL_ALL




HMI

N/A

N/A

N/A

N/A

N/A

FALSE

FALSE

FALSE

FALSE

TRUE

0

1

0

2

4

Control access

Local user x x

IEC 61850 client 1 x x

3.17.10.6

Station authority level "L,S,R"

Station authority level "L,S,R" adds station control access. In this level IEC 61850 command originator category validation is performed to distinguish control commands with IEC 61850 command originator category set to “Remote” or

“Station”. There is no multilevel access.

LOCAL REMOTE STATION OFF

IEC 61850 remote

IEC 61850 remote

IEC 61850 remote

IEC 61850 remote

IEC 61850 station

IEC 61850 station

IEC 61850 station

IEC 61850 station

IED IED

Figure 105: Station authority is "L,S,R"

IED IED

When the station authority level “L,S,R” is used, the control access can be selected using R/L button or CONTROL function block. IEC 61850 data object

CTRL.LLN0.LocSta and CONTROL function block input CTRL_STA are applicable for this station authority level.

Station control access can be reserved by using R/L button or CONTROL function block together with IEC 61850 data object CTRL.LLN0.LocSta.

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Table 183: Station authority level “L,S,R” using R/L button

L/R Control

R/L button

Local

Remote

Remote

Off

CTRL.LLN0.Loc

Sta 1

FALSE

FALSE

TRUE

FALSE


CTRL.LLN0.MltL

ev

FALSE

FALSE

FALSE

FALSE

3

0

1

2

L/R state

CTRL.LLN0.Loc

KeyHMI

Control access

Local user x

IEC 61850 client

2

IEC 61850 client 3 x x

Table 184: Station authority level “L,S,R” using CONTROL function block

L/R Control

Control FB input CTRL.LLN0.Lo

cSta 1

CTRL_OFF

CTRL_LOC

CTRL_STA

CTRL_REM 4

CTRL_REM

CTRL_ALL

FALSE

FALSE

TRUE

TRUE

FALSE

FALSE


CTRL.LLN0.MltL

ev

FALSE

FALSE

FALSE

FALSE

FALSE

FALSE

3

2

0

0

1

3

L/R state

CTRL.LLN0.Loc

KeyHMI

Control access

Local user x


2

IEC 61850 client 3 x x x

3.17.10.7

Station authority level “L,S,S+R,L+S,L+S+R”

Station authority level "L,S,S+R,L+S,L+S+R" adds station control access together with several different multilevel access scenarios. Control access can also be simultaneously permitted from local, station or remote location. Simultaneous local, station or remote control operation is not allowed as one client and location at time can access controllable objects and they remain reserved until the previously started control operation is first completed by the client.

LOCAL STATION S+R L+S L+S+R OFF

IEC 61850 remote

IEC 61850 remote

IEC 61850 remote

IEC 61850 remote

IEC 61850 remote

IEC 61850 remote

IEC 61850 station

IEC 61850 station

IEC 61850 station

IEC 61850 station

IEC 61850 station

IEC 61850 station

IED IED IED IED

Figure 106: Station authority is “L,S,S+R,L+S,L+S+R”

IED IED

When station authority level “L,S,S+R,L+S,L+S+R” is used, control access can be selected using R/L button or CONTROL function block. IEC 61850 data object

3

4

1

2

Station client reserves the control operating by writing controllable point LocSta.

Client IEC 61850 command originator category is remote.

Client IEC 61850 command originator category is station.

CTRL_STA unconnected in application configuration. Station client reserves the control operating by writing controllable point LocSta

186 620 series

Technical Manual


CTRL.LLN0.LocSta and CONTROL function block input CTRL_STA are applicable for this station authority level.

“Station” and “Local + Station” control access can be reserved by using R/L button or CONTROL function block in combination with IEC 61850 data object

CTRL.LLN0.LocSta.

Table 185: Station authority level “L,S,S+R,L+S,L+S+R” using R/L button

L/R Control

R/L button CTRL.LLN0.Loc

Sta 1

Local

Remote

Remote

FALSE

FALSE

TRUE

Local + Remote FALSE

Local + Remote TRUE

Off FALSE


CTRL.LLN0.MltL

ev

FALSE

TRUE

FALSE

TRUE

TRUE

FALSE

6

5

0

1

7

3

L/R state

CTRL.LLN0.Loc

KeyHMI

Control access

Local user x x x


2

IEC 61850 client 3 x x x x x x

Table 186: Station authority level “L,S,S+R,L+S,L+S+R” using CONTROL function block

L/R Control


CTRL_OFF

CTRL_LOC

CTRL_STA

CTRL_REM 4

CTRL_REM

CTRL_ALL

CTRL_ALL 4

CTRL.LLN0.Loc

Sta 1

FALSE

FALSE

FALSE

TRUE

FALSE

FALSE

TRUE

FALSE

FALSE

FALSE

TRUE

TRUE

TRUE

TRUE


CTRL.LLN0.MltL

ev

3

3

7

0

1

6

5

L/R state

CTRL.LLN0.Loc

KeyHMI

Control access

Local user x x x x x


2

IEC 61850 client 3 x x x x x

3.17.10.8

Signals

Table 187: CONTROL Input signals

Name

CTRL_OFF

CTRL_LOC

CTRL_STA

CTRL_REM

CTRL_ALL

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Default

0

0

0

0

0

Description

Control input OFF

Control input Local

Control input Station

Control input Remote

Control input All

3

4

1

2

Station client reserves the control operating by writing controllable point LocSta.

Client IEC 61850 command originator category is remote.

Client IEC 61850 command originator category is station.

CTRL_STA unconnected in application configuration. Station client reserves the control operating by writing controllable point LocSta.

620 series

Technical Manual

187


Table 188: CONTROL Output signals

Name

OFF

LOCAL

STATION

REMOTE

ALL

BEH_BLK

BEH_TST

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

3.17.10.9

Settings

Table 189: Non group settings

Parameter

LR control

Station authority

Control mode

Values (Range)

1=LR key

2=Binary input

1=L,R

2=L,S,R

3=L,R,L+R

4=L,S,S+R,L+S,L

+S+R

1=On

2=Blocked

5=Off


1=LR key

1=L,R

1=On

Description

Control output OFF

Control output Local

Control output Station

Control output Remote

Control output All

Logical device CTRL block status

Logical device CTRL test status

Description

LR control through LR key or binary input

Control command originator category usage

Enabling and disabling control

188 620 series

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3.17.10.10

Monitored data

Table 190: Monitored data

Name

Command response

Type

Enum

Values (Range)

0=No commands

1=Select open

2=Select close

3=Operate open

4=Operate close

5=Direct open

6=Direct close

7=Cancel

8=Position reached

9=Position timeout

10=Object status only

11=Object direct

12=Object select

13=RL local allowed

14=RL remote allowed

15=RL off

16=Function off

17=Function blocked

18=Command progress

19=Select timeout

20=Missing authority

21=Close not enabled

22=Open not enabled

23=Internal fault

24=Already close

25=Wrong client

26=RL station allowed

27=RL change

28=Abortion by trip


Unit Description

Latest command response

620 series

Technical Manual

189


3.17.11

3.17.11.1

Name

LR state

Type

Enum

Values (Range)

0=Off

1=Local

2=Remote

3=Station

4=L+R

5=L+S

6=L+S+R

7=S+R

Unit

Generic control point (16 pcs) SPCGAPC

Function block

Description

LR state monitoring

3.17.11.2


Functionality

The generic control point (16 pcs) function SPCGAPC can be used in combination with other function blocks such as FKEYGGIO. SPCGAPC offers the capability to activate its outputs through a local or remote control. The local control is provided through the buttons in the front panel and the remote control is provided through communications. SPCGAPC has two modes of operation. In the "Toggle" mode, the block toggles the output signal for every input pulse received. In the "Pulsed" mode, the block generates an output pulse of a preset duration.

For example, if the Operation mode is "Toggle", the output O# is initially “False”.

The rising edge in IN# sets O# to “True”. The falling edge of IN# has no effect. Next rising edge of IN# sets O# to “False”.

190 620 series

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3.17.11.3

Figure 108: Operation in "Toggle" mode

From the remote communication point of view SPCGAPC toggled operation mode is always working as persistent mode. The output O# follows the value written to the input IN# .

Signals

Table 191: SPCGAPC Input signals

Name

BLOCK

Type

BOOLEAN

IN9

IN10

IN11

IN5

IN6

IN7

IN8

IN1

IN2

IN3

IN4

IN12

IN13


BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Default

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

Description

Block signal for activating the blocking mode

Input of control point

1


2


3


4


5


6


7


8


9


10


11


12


13

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191


Name

IN14

IN15

IN16

Type

BOOLEAN

BOOLEAN

BOOLEAN

Table 192: SPCGAPC Output signals

Name

O13

O14

O15

O16

O9

O10

O11

O12

O5

O6

O7

O8

O1

O2

O3

O4

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Default

0=False

0=False

0=False

Description

Output 1 status

Output 2 status

Output 3 status

Output 4 status

Output 5 status

Output 6 status

Output 7 status

Output 8 status

Output 9 status

Output 10 status

Output 11 status

Output 12 status

Output 13 status

Output 14 status

Output 15 status

Output 16 status

Description


14


15


16

192 620 series

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3.17.11.4

Settings

Table 193: SPCGAPC Non group settings (Basic)

Step Parameter

Loc Rem restriction

Operation mode

Values (Range)

0=False

1=True

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

Unit ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description


10

10

10

10

10

10

10

Default

1=True

-1=Off

Description

Local remote switch restriction

Operation mode for generic control point

1000 Pulse length for pulsed operation mode

SPCGAPC1 Output 1 Generic control point description

-1=Off Operation mode for generic control point


















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193


Parameter

Operation mode

Values (Range)

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000


Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

Pulse length

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

Pulse length

Description

Table continues on the next page ms ms ms

Step

10

10

10

10

10

Default

-1=Off

Description

















10

10

10









194 620 series

Technical Manual


Parameter

Operation mode

Pulse length

Description

Values (Range)

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

Unit ms

Step

10

Default

-1=Off

Description




3.17.12

3.17.12.1

Remote generic control points SPCRGAPC

Function block


3.17.12.2

Functionality

The remote generic control points function SPCRGAPC is dedicated only for remote controlling, that is, SPCRGAPC cannot be controlled locally. The remote control is provided through communications.

3.17.12.3

620 series

Technical Manual


The function can be enabled and disabled with the Operation setting. The corresponding parameter values are "On" and "Off".

SPCRGAPC has the Operation mode, Pulse length and Description settings available to control all 16 outputs. By default, the Operation mode setting is set to "Off". This disables the controllable signal output. SPCRGAPC also has a general setting Loc

Rem restriction, which enables or disables the local or remote state functionality.

When the Operation mode is set to "Toggle", the corresponding output toggles between "True" and "False" for every input pulse received. The state of the output is stored in a nonvolatile memory and restored if the protection relay is restarted.

When the Operation mode is set to "Pulsed", the corresponding output can be used to produce the predefined length of pulses. Once activated, the output remains active for the duration of the set pulse length. When activated, the additional activation command does not extend the length of pulse. Thus, the pulse needs to be ended before the new activation can occur.

195


3.17.12.4

The Description setting can be used for storing signal names for each output.

Each control point or SPCRGAPC can only be accessed remotely through communication. SPCRGAPC follows the local or remote (L/R) state if the setting

Loc Rem restriction is "true". If the Loc Rem restriction setting is "false", local or remote (L/R) state is ignored, that is, all controls are allowed regardless of the local or remote state.

The BLOCK input can be used for blocking the output functionality. The BLOCK input operation depends on the Operation mode setting. If the Operation mode setting is set to "Toggle", the output state cannot be changed when the input BLOCK is TRUE.

If the Operation mode setting is set to "Pulsed", the activation of the

BLOCK input resets the output to the FALSE state.

Signals

Table 194: SPCRGAPC Input signals

Name

BLOCK

Type

BOOLEAN

Default

0=False

Description


Table 195: SPCRGAPC Output signals

Name

O13

O14

O15

O16

O9

O10

O11

O12

O5

O6

O7

O8

O1

O2

O3

O4

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Description

Output 1 status

Output 2 status

Output 3 status

Output 4 status

Output 5 status

Output 6 status

Output 7 status

Output 8 status

Output 9 status

Output 10 status

Output 11 status

Output 12 status

Output 13 status

Output 14 status

Output 15 status

Output 16 status

196 620 series

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3.17.12.5

Settings

Table 196: SPCRGAPC Non group settings (Basic)

Step Parameter

Loc Rem restriction

Operation mode

Values (Range)

0=False

1=True

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000


Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description


10

10

10

10

10

10

10

Default

1=True

-1=Off

Description




SPCRGAPC1 Output 1 Generic control point description



















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Parameter

Operation mode

Values (Range)

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000


Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

Pulse length

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000


198

Step

10

10

10

10

10

Default

-1=Off

Description








1000

SPCRGAPC1 Output

10

-1=Off

Pulse length for pulsed operation mode

Generic control point description


1000

SPCRGAPC1 Output

11

-1=Off




1000

SPCRGAPC1 Output

12

-1=Off




10

10

10

1000

SPCRGAPC1 Output

13

-1=Off




1000

SPCRGAPC1 Output

14

-1=Off





620 series

Technical Manual


Parameter

Description

Operation mode

Values (Range)

Pulse length

Description

Unit

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms

Step Default

SPCRGAPC1 Output

15

-1=Off

Description



10 1000

SPCRGAPC1 Output

16



3.17.13

3.17.13.1

Local generic control points SPCLGAPC

Function block


3.17.13.2

3.17.13.3

620 series

Technical Manual

Functionality

The local generic control points function SPCLGAPC is dedicated only for local controlling, that is, SPCLGAPC cannot be controlled remotely. The local control is done through the buttons in the front panel.



SPCLGAPC has the Operation mode, Pulse length and Description settings available to control all 16 outputs. By default, the Operation mode setting is set to "Off". This disables the controllable signal output. SPCLGAPC also has a general setting Loc

Rem restriction, which enables or disables the local or remote state functionality.

When the Operation mode is set to "Toggle", the corresponding output toggles between "True" and "False" for every input pulse received. The state of the output is stored in a nonvolatile memory and restored if the protection relay is restarted.

When the Operation mode is set to "Pulsed", the corresponding output can be used to produce the predefined length of pulses. Once activated, the output remains

199


3.17.13.4

active for the duration of the set pulse length. When activated, the additional activation command does not extend the length of pulse. Thus, the pulse needs to be ended before the new activation can occur.

The Description setting can be used for storing signal names for each output.

Each control point or SPCLGAPC can only be accessed through the LHMI control.

SPCLGAPC follows the local or remote (L/R) state if the Loc Rem restriction setting is "true". If the Loc Rem restriction setting is "false", local or remote (L/R) state is ignored, that is, all controls are allowed regardless of the local or remote state.

The BLOCK input can be used for blocking the output functionality. The BLOCK input operation depends on the Operation mode setting. If the Operation mode setting is set to "Toggle", the output state cannot be changed when the input BLOCK is TRUE.

If the Operation mode setting is set to "Pulsed", the activation of the

BLOCK input resets the output to the FALSE state.

Signals

Table 197: SPCLGAPC Input signals

Name

BLOCK

Type

BOOLEAN

Default

0=False

Description


Table 198: SPCLGAPC Output signals

Name

O13

O14

O15

O16

O9

O10

O11

O12

O5

O6

O7

O8

O1

O2

O3

O4

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Description

Output 1 status

Output 2 status

Output 3 status

Output 4 status

Output 5 status

Output 6 status

Output 7 status

Output 8 status

Output 9 status

Output 10 status

Output 11 status

Output 12 status

Output 13 status

Output 14 status

Output 15 status

Output 16 status

200 620 series

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3.17.13.5

Settings

Table 199: SPCLGAPC Non group settings (Basic)

Step Parameter

Loc Rem restriction

Operation mode

Values (Range)

0=False

1=True

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000


Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description


10

10

10

10

10

10

10

Default

1=True

-1=Off

Description




SPCLGAPC1 Output 1 Generic control point description



















620 series

Technical Manual

201


Parameter

Operation mode

Values (Range)

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000


Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms Pulse length

Description

Operation mode

Pulse length

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000


202

Step

10

10

10

10

10

Default

-1=Off

Description








1000

SPCLGAPC1 Output

10

-1=Off




1000

SPCLGAPC1 Output

11

-1=Off




1000

SPCLGAPC1 Output

12

-1=Off




10

10

10

1000

SPCLGAPC1 Output

13

-1=Off




1000

SPCLGAPC1 Output

14

-1=Off





620 series

Technical Manual


Parameter

Description

Operation mode

Values (Range)

Pulse length

Description

Unit

0=Pulsed

1=Toggle/Persistent

-1=Off

10...3600000

ms

Step Default

SPCLGAPC1 Output

15

-1=Off

Description



10 1000

SPCLGAPC1 Output

16



3.17.14

3.17.14.1

Programmable buttons FKEYGGIO

Function block

3.17.14.2

3.17.14.3


Functionality

The programmable buttons function FKEYGGIO is a simple interface between the panel and the application. The user input from the buttons available on the front panel is transferred to the assigned functionality and the corresponding LED is ON or OFF for indication. The behavior of each function key in the specific application is configured by connection with other application functions. This gives the maximum flexibility.


Inputs L1..L16

represent the LEDs on the protection relay's LHMI. When an input is set to TRUE, the corresponding LED is lit. When a function key on LHMI is pressed, the corresponding output K1..K16

is set to TRUE.

620 series

Technical Manual

203


3.17.14.4

Signals

Table 200: FKEYGGIO Input signals

Name

L13

L14

L15

L16

L9

L10

L11

L12

L5

L6

L7

L8

L1

L2

L3

L4

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Table 201: FKEYGGIO Output signals

Name

K12

K13

K14

K15

K16

K8

K9

K10

K11

K4

K5

K6

K7

K1

K2

K3

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Default

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

0=False

Description

KEY 8

KEY 9

KEY 10

KEY 11

KEY 12

KEY 13

KEY 14

KEY 15

KEY 16

KEY 1

KEY 2

KEY 3

KEY 4

KEY 5

KEY 6

KEY 7

Description

LED 9

LED 10

LED 11

LED 12

LED 13

LED 14

LED 15

LED 16

LED 1

LED 2

LED 3

LED 4

LED 5

LED 6

LED 7

LED 8

204 620 series

Technical Manual

1MRS757644 H

3.17.15

3.17.15.1

Generic up-down counter UDFCNT

Function block

Basic functions

3.17.15.2

3.17.15.3


Functionality

The generic up-down counter function UDFCNT counts up or down for each positive edge of the corresponding inputs. The counter value output can be reset to zero or preset to some other value if required.

The function provides up-count and down-count status outputs, which specify the relation of the counter value to a loaded preset value and to zero respectively.



The operation of UDFCNT can be described with a module diagram. All the modules in the diagram are explained in the next sections.

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Technical Manual

Figure 113: Functional module diagram

Up-down counter

Each rising edge of the UP_CNT input increments the counter value CNT_VAL by one and each rising edge of the DOWN_CNT input decrements the CNT_VAL by one. If there is a rising edge at both the inputs UP_CNT and DOWN_CNT , the counter value

CNT_VAL is unchanged. The CNT_VAL is available in the monitored data view.

The counter value CNT_VAL is stored in a nonvolatile memory. The range of the counter is 0...+2147483647. The count of CNT_VAL saturates at the final value of

2147483647, that is, no further increment is possible.

The value of the setting Counter load value is loaded into counter value CNT_VAL either when the LOAD input is set to "True" or when the Load Counter is set to

"Load" in the LHMI. Until the LOAD input is "True", it prevents all further counting.

205


3.17.15.4

3.17.15.5

3.17.15.6

206

The function also provides status outputs UPCNT_STS and DNCNT_STS . The

UPCNT_STS is set to "True" when the CNT_VAL is greater than or equal to the setting

Counter load value.

DNCNT_STS is set to "True" when the CNT_VAL is zero.

The RESET input is used for resetting the function. When this input is set to "True" or when Reset counter is set to "reset", the

CNT_VAL is forced to zero.

Application

When UDFCNT is connected to a relay binary input, two settings of binary input need to be checked to ensure the counter is working correctly.

• Input # filter time. All pulses that are shorter than the filter time are not detected.

• Binary input oscillation suppression threshold. The binary input is blocked if the number of valid state changes during one second is equal to or greater than the set oscillation level value.

With the correct settings, UDFCNT can record correctly up to 20 pulses per second.

For example, to constantly record 20 pulses per second from slot X110 binary input

1, when the pulse length is 25 ms pulse high and 25 ms pulse low time, the following settings are recommended.

• Input 1 filter time is set to “5...15 ms” via Configuration > I/O modules >

X110(BIO) > Input filtering

• Input osc. level is set to “45...50 events/s” via Configuration > I/O modules >

Common settings

• Input osc. hyst is set to “2 events/s” via Configuration > I/O modules > Common settings

Signals

Table 202: UDFCNT Input signals

Name

UP_CNT

DOWN_CNT

Type

BOOLEAN

BOOLEAN

RESET

LOAD

BOOLEAN

BOOLEAN

Default

0=False

0=False

0=False

0=False

Description

Input for up counting

Input for down counting

Reset input for counter

Load input for counter

Table 203: UDFCNT Output signals

Name

UPCNT_STS

DNCNT_STS

Type

BOOLEAN

BOOLEAN

Description

Status of the up counting

Status of the down counting

Settings

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Technical Manual


Table 204: UDFCNT Non group settings (Basic)

Parameter

Operation

Values (Range)

1=on

5=off

Counter load value 0...2147483647

Unit

Reset counter

Load counter

0=Cancel

1=Reset

0=Cancel

1=Load

Step

1

3.17.15.7

Monitored data

Table 205: UDFCNT Monitored data

Name

CNT_VAL

Type

INT64


0...2147483647

Default

1=on

10000

0=Cancel

0=Cancel

3.18

3.19

3.19.1

Description

Operation Off / On

Preset counter value

Resets counter value

Loads the counter to preset value

Description

Output counter value

Factory settings restoration

In case of configuration data loss or any other file system error that prevents the protection relay from working properly, the whole file system can be restored to the original factory state. All default settings and configuration files stored in the factory are restored. For further information on restoring factory settings, see the operation manual.

Load profile record LDPRLRC

Function block


3.19.2

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Technical Manual

Functionality

The protection relay is provided with a load profile recorder. The load profile feature stores the historical load data captured at a periodical time interval (demand interval). Up to 12 load quantities can be selected for recording and storing in a

207


3.19.2.1

3.19.2.2

208 nonvolatile memory. The value range for the recorded load quantities is about eight times the nominal value, and values larger than that saturate. The recording time depends on a settable demand interval parameter and the amount of quantities selected. The record output is in the COMTRADE format.

Quantities

Selectable quantities are product-dependent.

Table 206: Quantity Description

Quantity Sel x

S

P

Q

PF

U23

U31

UL1

UL2

UL3

UL1B

UL2B

UL3B

IL2B

IL3B

IoB

U12

Disabled

IL1

IL2

IL3

Io

IL1B

Description

Quantity not selected

Phase 1 current

Phase 2 current

Phase 3 current

Neutral/earth/residual current

Phase 1 current, B side



Neutral/earth/residual current, B side

Phase-to-phase 12 voltage



Phase-to-earth 1 voltage



Phase-to-earth 1 voltage, B side



Apparent power

Real power

Reactive power

Power factor

If the data source for the selected quantity is removed, for example, with

Application Configuration in PCM600, the load profile recorder stops recording it and the previously collected data are cleared.

Length of record

The recording capability is about 7.4 years when one quantity is recorded and the demand interval is set to 180 minutes. The recording time scales down proportionally when a shorter demand time is selected or more quantities are recorded. The recording lengths in days with different settings used are presented

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3.19.2.3

in Table 207 . When the recording buffer is fully occupied, the oldest data are

overwritten by the newest data.

Table 207: Recording capability in days with different settings

1

minute

Amount of quantities

7

8

9

10

3

4

1

2

5

6

11

12

5.1

4.5

4.1

3.8

15.2

11.4

9.1

7.6

6.5

5.7

3.5

3.2

25.3

22.7

20.7

19.0

75.8

56.9

45.5

37.9

32.5

28.4

17.5

16.2

5

minutes

10

minutes

Demand interval

15

minutes

30

minutes

50.5

45.5

41.4

37.9

35.0

32.5

Recording capability in days

151.6

113.7

227.4

170.6

454.9

341.1

91.0

75.8

65.0

56.9

136.5

113.7

97.5

85.3

272.9

227.4

194.9

170.6

75.8

68.2

62.0

56.9

52.5

48.7

151.6

136.5

124.1

113.7

105.0

97.5

60

minutes

909.7

682.3

545.8

454.9

389.9

341.1

303.2

272.9

248.1

227.4

209.9

194.9

180

minutes

2729.2

2046.9

1637.5

1364.6

1169.6

1023.4

909.7

818.8

744.3

682.3

629.8

584.8

Uploading of record

The protection relay stores the load profile COMTRADE files to the

C:\LDP\COMTRADE folder. The files can be uploaded with the PCM600 tool or any appropriate computer software that can access the C:\LDP\COMTRADE folder.

The load profile record consists of two COMTRADE file types: the configuration file

(.CFG) and the data file (.DAT). The file name is same for both file types.

To ensure that both the uploaded file types are generated from the same data content, the files need to be uploaded successively. Once either of the files is uploaded, the recording buffer is halted to give time to upload the other file.

Data content of the load profile record is sequentially updated.

Therefore, the size attribute for both COMTRADE files is "0".

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209

Basic functions

192 . 168 . 10 . 187 L D P 1

1MRS757644 H

3.19.2.4

3.19.3

210

0 A B B L D P 1 . C F G

0 A B B L D P 1 . D A T

Figure 115: Load profile record file naming

Clearing of record

The load profile record can be cleared with Reset load profile rec via HMI, communication or the ACT input in PCM600. Clearing of the record is allowed only on the engineer and administrator authorization levels.

The load profile record is automatically cleared if the quantity selection parameters are changed or any other parameter which affects the content of the COMTRADE configuration file is changed. Also, if data source for selected quantity is removed, for example, with ACT, the load profile recorder stops recording and previously collected data are cleared.

Configuration

The load profile record can be configured with the PCM600 tool or any tool supporting the IEC 61850 standard.

The load profile record can be enabled or disabled with the Operation setting under the Configuration/Load Profile Record menu.

Each protection relay can be mapped to each of the quantity channels of the load profile record. The mapping is done with the Quantity selection setting of the corresponding quantity channel.

The IP number of the protection relay and the content of the Bay name setting are both included in the COMTRADE configuration file for identification purposes.

The memory consumption of load profile record is supervised, and indicated with two signals MEM_WARN and MEM_ALARM , which could be used to notify the customer that recording should be backlogged by reading the recorded data from

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Technical Manual

1MRS757644 H

3.19.4

3.19.5

Basic functions the protection relay. The levels for MEM_WARN and MEM_ALARM are set by two parameters Mem.warn level and Mem. Alarm level.

Signals

Table 208: LDPRLRC Output signals

Name

MEM_WARN

Type

BOOLEAN

MEM_ALARM BOOLEAN

Description

Recording memory warning status

Recording memory alarm status

Settings

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211

Basic functions

Table 209: LDPRLRC Non group settings (Basic)

Parameter

Operation

Values (Range)

1=on

5=off

Quantity Sel 1

27=QB

28=PFB

29=SL1

30=SL2

31=SL3

32=PL1

33=PL2

34=PL3

35=QL1

36=QL2

17=U31B

18=UL1B

19=UL2B

20=UL3B

21=S

22=P

23=Q

24=PF

25=SB

26=PB

0=Disabled

1=IL1

2=IL2

3=IL3

4=Io

5=IL1B

6=IL2B

7=IL3B

8=IoB

9=U12

10=U23

11=U31

12=UL1

13=UL2

14=UL3

15=U12B

16=U23B

37=QL3

38=PFL1

39=PFL2

40=PFL3

41=SL1B

42=SL2B

43=SL3B

44=PL1B


Unit Step

212

1MRS757644 H

Default

1=on

0=Disabled

Description

Operation Off / On

Select quantity to be recorded

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1MRS757644 H


45=PL2B

46=PL3B

47=QL1B

48=QL2B

49=QL3B

50=PFL1B

51=PFL2B

52=PFL3B

53=IL1C

54=IL2C

55=IL3C



Basic functions

Description

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Basic functions

Parameter

Quantity Sel 2

Values (Range)

28=PFB

29=SL1

30=SL2

31=SL3

32=PL1

33=PL2

34=PL3

35=QL1

36=QL2

37=QL3

18=UL1B

19=UL2B

20=UL3B

21=S

22=P

23=Q

24=PF

25=SB

26=PB

27=QB

38=PFL1

39=PFL2

40=PFL3

41=SL1B

42=SL2B

43=SL3B

44=PL1B

45=PL2B

46=PL3B

47=QL1B

48=QL2B

49=QL3B

0=Disabled

1=IL1

2=IL2

3=IL3

4=Io

5=IL1B

6=IL2B

7=IL3B

8=IoB

9=U12

10=U23

11=U31

12=UL1

13=UL2

14=UL3

15=U12B

16=U23B

17=U31B


214

Unit Step

1MRS757644 H

Default

0=Disabled

Description


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1MRS757644 H


50=PFL1B

51=PFL2B

52=PFL3B

53=IL1C

54=IL2C

55=IL3C



Basic functions

Description

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215

Basic functions

Parameter

Quantity Sel 3

Values (Range)

28=PFB

29=SL1

30=SL2

31=SL3

32=PL1

33=PL2

34=PL3

35=QL1

36=QL2

37=QL3

18=UL1B

19=UL2B

20=UL3B

21=S

22=P

23=Q

24=PF

25=SB

26=PB

27=QB

38=PFL1

39=PFL2

40=PFL3

41=SL1B

42=SL2B

43=SL3B

44=PL1B

45=PL2B

46=PL3B

47=QL1B

48=QL2B

49=QL3B

0=Disabled

1=IL1

2=IL2

3=IL3

4=Io

5=IL1B

6=IL2B

7=IL3B

8=IoB

9=U12

10=U23

11=U31

12=UL1

13=UL2

14=UL3

15=U12B

16=U23B

17=U31B


216

Unit Step

1MRS757644 H

Default

0=Disabled

Description


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1MRS757644 H


50=PFL1B

51=PFL2B

52=PFL3B

53=IL1C

54=IL2C

55=IL3C



Basic functions

Description

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217

Basic functions

Parameter

Quantity Sel 4

Values (Range)

28=PFB

29=SL1

30=SL2

31=SL3

32=PL1

33=PL2

34=PL3

35=QL1

36=QL2

37=QL3

18=UL1B

19=UL2B

20=UL3B

21=S

22=P

23=Q

24=PF

25=SB

26=PB

27=QB

38=PFL1

39=PFL2

40=PFL3

41=SL1B

42=SL2B

43=SL3B

44=PL1B

45=PL2B

46=PL3B

47=QL1B

48=QL2B

49=QL3B

0=Disabled

1=IL1

2=IL2

3=IL3

4=Io

5=IL1B

6=IL2B

7=IL3B

8=IoB

9=U12

10=U23

11=U31

12=UL1

13=UL2

14=UL3

15=U12B

16=U23B

17=U31B


218

Unit Step

1MRS757644 H

Default

0=Disabled

Description


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1MRS757644 H


50=PFL1B

51=PFL2B

52=PFL3B

53=IL1C

54=IL2C

55=IL3C



Basic functions

Description

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219

Basic functions

Parameter

Quantity Sel 5

Values (Range)

28=PFB

29=SL1

30=SL2

31=SL3

32=PL1

33=PL2

34=PL3

35=QL1

36=QL2

37=QL3

18=UL1B

19=UL2B

20=UL3B

21=S

22=P

23=Q

24=PF

25=SB

26=PB

27=QB

38=PFL1

39=PFL2

40=PFL3

41=SL1B

42=SL2B

43=SL3B

44=PL1B

45=PL2B

46=PL3B

47=QL1B

48=QL2B

49=QL3B

0=Disabled

1=IL1

2=IL2

3=IL3

4=Io

5=IL1B

6=IL2B

7=IL3B

8=IoB

9=U12

10=U23

11=U31

12=UL1

13=UL2

14=UL3

15=U12B

16=U23B

17=U31B


220

Unit Step

1MRS757644 H

Default

0=Disabled

Description


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1MRS757644 H


50=PFL1B

51=PFL2B

52=PFL3B

53=IL1C

54=IL2C

55=IL3C



Basic functions

Description

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221

Basic functions

Parameter

Quantity Sel 6

Values (Range)

28=PFB

29=SL1

30=SL2

31=SL3

32=PL1

33=PL2

34=PL3

35=QL1

36=QL2

37=QL3

18=UL1B

19=UL2B

20=UL3B

21=S

22=P

23=Q

24=PF

25=SB

26=PB

27=QB

38=PFL1

39=PFL2

40=PFL3

41=SL1B

42=SL2B

43=SL3B

44=PL1B

45=PL2B

46=PL3B

47=QL1B

48=QL2B

49=QL3B

0=Disabled

1=IL1

2=IL2

3=IL3

4=Io

5=IL1B

6=IL2B

7=IL3B

8=IoB

9=U12

10=U23

11=U31

12=UL1

13=UL2

14=UL3

15=U12B

16=U23B

17=U31B


222

Unit Step

1MRS757644 H

Default

0=Disabled

Description


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1MRS757644 H


50=PFL1B

51=PFL2B

52=PFL3B

53=IL1C

54=IL2C

55=IL3C



Basic functions

Description

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223

Basic functions

Parameter

Quantity Sel 7

Values (Range)

28=PFB

29=SL1

30=SL2

31=SL3

32=PL1

33=PL2

34=PL3

35=QL1

36=QL2

37=QL3

18=UL1B

19=UL2B

20=UL3B

21=S

22=P

23=Q

24=PF

25=SB

26=PB

27=QB

38=PFL1

39=PFL2

40=PFL3

41=SL1B

42=SL2B

43=SL3B

44=PL1B

45=PL2B

46=PL3B

47=QL1B

48=QL2B

49=QL3B

0=Disabled

1=IL1

2=IL2

3=IL3

4=Io

5=IL1B

6=IL2B

7=IL3B

8=IoB

9=U12

10=U23

11=U31

12=UL1

13=UL2

14=UL3

15=U12B

16=U23B

17=U31B


224

Unit Step

1MRS757644 H

Default

0=Disabled

Description


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1MRS757644 H


50=PFL1B

51=PFL2B

52=PFL3B

53=IL1C

54=IL2C

55=IL3C



Basic functions

Description

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225

Basic functions

Parameter

Quantity Sel 8

Values (Range)

28=PFB

29=SL1

30=SL2

31=SL3

32=PL1

33=PL2

34=PL3

35=QL1

36=QL2

37=QL3

18=UL1B

19=UL2B

20=UL3B

21=S

22=P

23=Q

24=PF

25=SB

26=PB

27=QB

38=PFL1

39=PFL2

40=PFL3

41=SL1B

42=SL2B

43=SL3B

44=PL1B

45=PL2B

46=PL3B

47=QL1B

48=QL2B

49=QL3B

0=Disabled

1=IL1

2=IL2

3=IL3

4=Io

5=IL1B

6=IL2B

7=IL3B

8=IoB

9=U12

10=U23

11=U31

12=UL1

13=UL2

14=UL3

15=U12B

16=U23B

17=U31B


226

Unit Step

1MRS757644 H

Default

0=Disabled

Description


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1MRS757644 H


50=PFL1B

51=PFL2B

52=PFL3B

53=IL1C

54=IL2C

55=IL3C



Basic functions

Description

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227

Basic functions

Parameter

Quantity Sel 9

Values (Range)

28=PFB

29=SL1

30=SL2

31=SL3

32=PL1

33=PL2

34=PL3

35=QL1

36=QL2

37=QL3

18=UL1B

19=UL2B

20=UL3B

21=S

22=P

23=Q

24=PF

25=SB

26=PB

27=QB

38=PFL1

39=PFL2

40=PFL3

41=SL1B

42=SL2B

43=SL3B

44=PL1B

45=PL2B

46=PL3B

47=QL1B

48=QL2B

49=QL3B

0=Disabled

1=IL1

2=IL2

3=IL3

4=Io

5=IL1B

6=IL2B

7=IL3B

8=IoB

9=U12

10=U23

11=U31

12=UL1

13=UL2

14=UL3

15=U12B

16=U23B

17=U31B


228

Unit Step

1MRS757644 H

Default

0=Disabled

Description


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1MRS757644 H


50=PFL1B

51=PFL2B

52=PFL3B

53=IL1C

54=IL2C

55=IL3C



Basic functions

Description

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229

Basic functions

Parameter

Quantity Sel 10

Values (Range)

28=PFB

29=SL1

30=SL2

31=SL3

32=PL1

33=PL2

34=PL3

35=QL1

36=QL2

37=QL3

18=UL1B

19=UL2B

20=UL3B

21=S

22=P

23=Q

24=PF

25=SB

26=PB

27=QB

38=PFL1

39=PFL2

40=PFL3

41=SL1B

42=SL2B

43=SL3B

44=PL1B

45=PL2B

46=PL3B

47=QL1B

48=QL2B

49=QL3B

0=Disabled

1=IL1

2=IL2

3=IL3

4=Io

5=IL1B

6=IL2B

7=IL3B

8=IoB

9=U12

10=U23

11=U31

12=UL1

13=UL2

14=UL3

15=U12B

16=U23B

17=U31B


230

Unit Step

1MRS757644 H

Default

0=Disabled

Description


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1MRS757644 H


50=PFL1B

51=PFL2B

52=PFL3B

53=IL1C

54=IL2C

55=IL3C



Basic functions

Description

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231

Basic functions

Parameter

Quantity Sel 11

Values (Range)

28=PFB

29=SL1

30=SL2

31=SL3

32=PL1

33=PL2

34=PL3

35=QL1

36=QL2

37=QL3

18=UL1B

19=UL2B

20=UL3B

21=S

22=P

23=Q

24=PF

25=SB

26=PB

27=QB

38=PFL1

39=PFL2

40=PFL3

41=SL1B

42=SL2B

43=SL3B

44=PL1B

45=PL2B

46=PL3B

47=QL1B

48=QL2B

49=QL3B

0=Disabled

1=IL1

2=IL2

3=IL3

4=Io

5=IL1B

6=IL2B

7=IL3B

8=IoB

9=U12

10=U23

11=U31

12=UL1

13=UL2

14=UL3

15=U12B

16=U23B

17=U31B


232

Unit Step

1MRS757644 H

Default

0=Disabled

Description


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1MRS757644 H


50=PFL1B

51=PFL2B

52=PFL3B

53=IL1C

54=IL2C

55=IL3C



Basic functions

Description

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233

Basic functions

Parameter

Quantity Sel 12

Values (Range)

28=PFB

29=SL1

30=SL2

31=SL3

32=PL1

33=PL2

34=PL3

35=QL1

36=QL2

37=QL3

18=UL1B

19=UL2B

20=UL3B

21=S

22=P

23=Q

24=PF

25=SB

26=PB

27=QB

38=PFL1

39=PFL2

40=PFL3

41=SL1B

42=SL2B

43=SL3B

44=PL1B

45=PL2B

46=PL3B

47=QL1B

48=QL2B

49=QL3B

0=Disabled

1=IL1

2=IL2

3=IL3

4=Io

5=IL1B

6=IL2B

7=IL3B

8=IoB

9=U12

10=U23

11=U31

12=UL1

13=UL2

14=UL3

15=U12B

16=U23B

17=U31B


234

Unit Step

1MRS757644 H

Default

0=Disabled

Description


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50=PFL1B

51=PFL2B

52=PFL3B

53=IL1C

54=IL2C

55=IL3C

Mem. warning level 0...100

Mem. alarm level 0...100

Unit

%

%

3.19.6

Step Default

1

1

0

0

Monitored data

Table 210: LDPRLRC Monitored data

Name

Rec. memory used

Type

INT32


0...100

%

Description

Set memory warning level

Set memory alarm level

Description

How much recording memory is currently used

3.20

3.20.1

3.20.1.1

ETHERNET channel supervision function blocks

Redundant Ethernet channel supervision RCHLCCH

Function block

3.20.1.2


Functionality

Redundant Ethernet channel supervision RCHLCCH represents LAN A and LAN B redundant Ethernet channels.

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3.20.1.3

3.20.1.4

3.20.1.5

3.20.2

Signals

Table 211: RCHLCCH output signals

Parameter

CHLIV

REDCHLIV

LNKLIV

REDLNKLIV

Values

(Range)

True

False

True

False

Up

Down

Up

Down

Unit Step Defaul t

Description

Status of redundant Ethernet channel LAN A. When Redundant mode is set to "HSR" or "PRP", value is

"True" if the protection relay is receiving redundancy supervision frames. Otherwise value is "False".

Status of redundant Ethernet channel LAN B. When Redundant mode is set to "HSR" or "PRP", value is

"True" if the protection relay is receiving redundancy supervision frames. Otherwise value is "False".

Link status of redundant port LAN

A. Valid only when Redundant mode is set to "HSR" or "PRP".

Link status of redundant port LAN

B. Valid only when Redundant mode is set to "HSR" or "PRP".

Settings

Table 212: Redundancy settings

Parameter

Redundant mode

Values

(Range)

None

PRP

HSR


Description

None Mode selection for Ethernet switch on redundant communication modules. The "None" mode is used with normal and Self-healing Ethernet topologies.

Monitored data

Monitored data is available in four locations.

• Monitoring > Communication > Ethernet > Activity > CHLIV_A

• Monitoring > Communication/ > Ethernet > Activity > REDCHLIV_B

• Monitoring > Communication > Ethernet > Link statuses > LNKLIV_A

• Monitoring > Communication > Ethernet > Link statuses > REDLNKLIV_B

Ethernet channel supervision SCHLCCH

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3.20.2.1

Function block

Basic functions

3.20.2.2

3.20.2.3


Functionality

Ethernet channel supervision SCHLCCH represents X1/LAN, X2/LAN and X3/LAN

Ethernet channels.

An unused Ethernet port can be set "Off" with the setting Configuration >

Communication > Ethernet > Rear port(s) > Port x Mode. This setting closes the port from software, disabling the Ethernet communication in that port. Closing an unused Ethernet port enhances the cyber security of the relay.

Signals

Table 213: SCHLCCH1 output signals

Parameter

CH1LIV

LNK1LIV

Values

(Range)

True

False


Description

Status of Ethernet channel X1/LAN.

Value is "True" if the port is receiving Ethernet frames. Valid only when

Redundant mode is set to "None" or port is not one of the redundant ports (LAN A or LAN B).

Link status of Ethernet port X1/LAN.

Up

Down


Parameter

CH2LIV

LNK2LIV

Values

(Range)

True

False

Up

Down


Description





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Parameter

CH3LIV

LNK3LIV

Values

(Range)

True

False


Description





Up

Down

3.20.2.4

Settings

Table 216: Port mode settings

Parameter

Port 1 Mode

Values (Range)

Off

On

Unit

Port 2 Mode

Port 3 Mode

3.20.2.5

Off

On

Off

On

Step Default

On

On

On

Description

Mode selection for rear port(s). If port is not used, it can be set to “Off”. Port cannot be set to “Off” when Redundant mode is “HSR” or “PRP” and port is one of the redundant ports (LAN A or LAN B) or when port is used for line differential communication.

Mode selection for rear port(s). If port is not used, it can be set to “Off”. Port cannot be set to “Off” when Redundant mode is “HSR” or “PRP” and port is one of the redundant ports (LAN A or LAN B).

Mode selection for rear port(s). If port is not used, it can be set to “Off”. Port cannot be set to “Off” when Redundant mode is “HSR” or “PRP” and port is one of the redundant ports (LAN A or LAN B).

Monitored data

Monitored data is available in six locations.

• Monitoring > Communication > Ethernet > Activity > CH1LIV

• Monitoring > Communication > Ethernet > Activity > CH2LIV

• Monitoring/ > Communication > Ethernet > Activity > CH3LIV

• Monitoring/ > Communication > Ethernet > Link statuses > LNK1LIV

• Monitoring > Communication > Ethernet > Link statuses > LNK2LIV

• Monitoring > Communication > Ethernet > Link statuses > LNK3LIV

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1MRS757644 H Protection functions

4

4.1

4.1.1

4.1.1.1

4.1.1.2

Protection functions

Three-phase current protection

Three-phase non-directional overcurrent protection

PHxPTOC

Identification

Function description

Three-phase non-directional overcurrent protection, low stage

Three-phase non-directional overcurrent protection, high stage

Three-phase non-directional overcurrent protection, instantaneous stage

IEC 61850 identification

PHLPTOC

PHHPTOC

PHIPTOC


3I>

3I>>

3I>>>

ANSI/IEEE C37.2

device number

51P-1

51P-2

50P/51P

Function block

4.1.1.3


Functionality

The three-phase non-directional overcurrent protection function PHxPTOC is used as one-phase, two-phase or three-phase non-directional overcurrent and shortcircuit protection.

The function starts when the current exceeds the set limit. The operate time characteristics for low stage PHLPTOC and high stage PHHPTOC can be selected to be either definite time ( DT) or inverse definite minimum time ( IDMT). The instantaneous stage PHIPTOC always operates with the DT characteristic.

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Protection functions

4.1.1.4

1MRS757644 H

In the DT mode, the function operates after a predefined operate time and resets when the fault current disappears. The IDMT mode provides current-dependent timer characteristics.

The function contains a blocking functionality. It is possible to block function outputs, timers or the function itself, if desired.



The operation of PHxPTOC can be described by using a module diagram. All the modules in the diagram are explained in the next sections.


Level detector

The measured phase currents are compared phasewise to the set Start value. If the measured value exceeds the set Start value, the level detector reports the exceeding of the value to the phase selection logic. If the ENA_MULT input is active, the Start value setting is multiplied by the Start value Mult setting.

The protection relay does not accept the Start value or Start value Mult setting if the product of these settings exceeds the Start value setting range.

The start value multiplication is normally done when the inrush detection function

(INRPHAR) is connected to the ENA_MULT input.

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Figure 120: Start value behavior with ENA_MULT input activated

Phase selection logic

If the fault criteria are fulfilled in the level detector, the phase selection logic detects the phase or phases in which the measured current exceeds the setting. If the phase information matches the Num of start phases setting, the phase selection logic activates the timer module.

Timer

Once activated, the timer activates the START output. Depending on the value of the Operating curve type setting, the time characteristics are according to DT or

IDMT. When the operation timer has reached the value of Operate delay time in the

DT mode or the maximum value defined by the inverse time curve, the OPERATE output is activated.

When the user-programmable IDMT curve is selected, the operation time characteristics are defined by the parameters Curve parameter A, Curve parameter

B, Curve parameter C, Curve parameter D and Curve parameter E.

If a drop-off situation happens, that is, a fault suddenly disappears before the operate delay is exceeded, the timer reset state is activated. The functionality of the timer in the reset state depends on the combination of the Operating curve type, Type of reset curve and Reset delay time settings. When the DT characteristic is selected, the reset timer runs until the set Reset delay time value is exceeded.

When the IDMT curves are selected, the Type of reset curve setting can be set to

"Immediate", "Def time reset" or "Inverse reset". The reset curve type "Immediate" causes an immediate reset. With the reset curve type "Def time reset", the reset time depends on the Reset delay time setting. With the reset curve type "Inverse

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4.1.1.5

1MRS757644 H reset", the reset time depends on the current during the drop-off situation. The

START output is deactivated when the reset timer has elapsed.

The "Inverse reset" selection is only supported with ANSI or user programmable types of the IDMT operating curves. If another operating curve type is selected, an immediate reset occurs during the drop-off situation.

The setting Time multiplier is used for scaling the IDMT operate and reset times.

The setting parameter Minimum operate time defines the minimum desired operate time for IDMT. The setting is applicable only when the IDMT curves are used.

The Minimum operate time setting should be used with great care because the operation time is according to the IDMT curve, but always at least the value of the Minimum operate time setting. For more

information, see Chapter 11.2.1 IDMT curves for overcurrent protection

in this manual.

The timer calculates the start duration value START_DUR, which indicates the percentage ratio of the start situation and the set operating time. The value is available in the monitored data view.

Blocking logic

There are three operation modes in the blocking function. The operation modes are controlled by the BLOCK input and the global setting in Configuration >

System > Blocking mode which selects the blocking mode. The BLOCK input can be controlled by a binary input, a horizontal communication input or an internal signal of the protection relay's program. The influence of the BLOCK signal activation is preselected with the global setting Blocking mode.

The Blocking mode setting has three blocking methods. In the "Freeze timers" mode, the operation timer is frozen to the prevailing value, but the OPERATE output is not deactivated when blocking is activated. In the "Block all" mode, the whole function is blocked and the timers are reset. In the "Block OPERATE output" mode, the function operates normally but the OPERATE output is not activated.

Measurement modes

The function operates on four alternative measurement modes: "RMS", "DFT",

"Peak-to-Peak" and "P-to-P + backup". The measurement mode is selected with the setting Measurement mode.

Table 217: Measurement modes supported by PHxPTOC stages

Measurement mode PHLPTOC

RMS

DFT

Peak-to-Peak

P-to-P + backup x x x

PHHPTOC x x x

PHIPTOC x

For a detailed description of the measurement modes, see

Chapter 11.5

Measurement modes in this manual.

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4.1.1.6

Timer characteristics

PHxPTOC supports both DT and IDMT characteristics. The user can select the timer characteristics with the Operating curve type and Type of reset curve settings.

When the DT characteristic is selected, it is only affected by the Operate delay time and Reset delay time settings.

The protection relay provides 16 IDMT characteristics curves, of which seven comply with the IEEE C37.112 and six with the IEC 60255-3 standard. Two curves follow the special characteristics of ABB praxis and are referred to as RI and RD. In addition to this, a user programmable curve can be used if none of the standard curves are applicable. The DT characteristics can be chosen by selecting the Operating curve type values "ANSI Def. Time" or "IEC Def. Time". The functionality is identical in both cases.

The timer characteristics supported by different stages comply with the list in the IEC 61850-7-4 specification, indicate the characteristics supported by different stages:

Table 218: Timer characteristics supported by different stages

PHHPTOC x

Operating curve type

(1) ANSI Extremely Inverse

(2) ANSI Very Inverse

(3) ANSI Normal Inverse

(4) ANSI Moderately Inverse

(5) ANSI Definite Time

(6) Long Time Extremely Inverse

(7) Long Time Very Inverse

(8) Long Time Inverse

(9) IEC Normal Inverse

(10) IEC Very Inverse

(11) IEC Inverse

(12) IEC Extremely Inverse

(13) IEC Short Time Inverse

(14) IEC Long Time Inverse

(15) IEC Definite Time

(17) User programmable

(18) RI type

(19) RD type

PHIPTOC supports only definite time characteristic.

PHLPTOC x x x x x x x x x x x x x x x x x x x x x x x x x

For a detailed description of timers, see Chapter 11 General function block features

in this manual.

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4.1.1.7

244

1MRS757644 H

Table 219: Reset time characteristics supported by different stages

Reset curve type

(1) Immediate

(2) Def time reset

(3) Inverse reset

PHLPTOC x x

PHHPTOC x x

Note

Available for all operate time curves

Available for all operate time curves x x Available only for ANSI and user programmable curves

The Type of reset curve setting does not apply to PHIPTOC or when the

DT operation is selected. The reset is purely defined by the Reset delay time setting.

Application

PHxPTOC is used in several applications in the power system. The applications include but are not limited to:

• Selective overcurrent and short-circuit protection of feeders in distribution and subtransmission systems

• Backup overcurrent and short-circuit protection of power transformers and generators

• Overcurrent and short-circuit protection of various devices connected to the power system, for example shunt capacitor banks, shunt reactors and motors

• General backup protection

PHxPTOC is used for single-phase, two-phase and three-phase non-directional overcurrent and short-circuit protection. Typically, overcurrent protection is used for clearing two and three-phase short circuits. Therefore, the user can choose how many phases, at minimum, must have currents above the start level for the function to operate. When the number of start-phase settings is set to "1 out of 3", the operation of PHxPTOC is enabled with the presence of high current in one-phase.

When the setting is "2 out of 3" or "3 out of 3", single-phase faults are not detected. The setting "3 out of 3" requires the fault to be present in all three phases.

Many applications require several steps using different current start levels and time delays. PHxPTOC consists of three protection stages.

• Low PHLPTOC

• High PHHPTOC

• Instantaneous PHIPTOC

PHLPTOC is used for overcurrent protection. The function contains several types of time-delay characteristics. PHHPTOC and PHIPTOC are used for fast clearance of very high overcurrent situations.

Transformer overcurrent protection

The purpose of transformer overcurrent protection is to operate as main protection, when differential protection is not used. It can also be used as coarse back-up protection for differential protection in faults inside the zone of protection, that is, faults occurring in incoming or outgoing feeders, in the region of transformer terminals and tank cover. This means that the magnitude range of the fault current can be very wide. The range varies from 6xI n

to several hundred times I

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1MRS757644 H Protection functions n

, depending on the impedance of the transformer and the source impedance of the feeding network. From this point of view, it is clear that the operation must be both very fast and selective, which is usually achieved by using coarse current settings.

The purpose is also to protect the transformer from short circuits occurring outside the protection zone, that is through-faults. Transformer overcurrent protection also provides protection for the LV-side busbars. In this case the magnitude of the fault current is typically lower than 12xI n

depending on the fault location and transformer impedance. Consequently, the protection must operate as fast as possible taking into account the selectivity requirements, switching-in currents, and the thermal and mechanical withstand of the transformer and outgoing feeders.

Traditionally, overcurrent protection of the transformer has been arranged as shown in

Figure 121

. The low-set stage PHLPTOC operates time-selectively both in transformer and LV-side busbar faults. The high-set stage PHHPTOC operates instantaneously making use of current selectivity only in transformer HV-side faults. If there is a possibility, that the fault current can also be fed from the

LV-side up to the HV-side, the transformer must also be equipped with LV-side overcurrent protection. Inrush current detectors are used in start-up situations to multiply the current start value setting in each particular protection relay where the inrush current can occur. The overcurrent and contact based circuit breaker failure protection CCBRBRF is used to confirm the protection scheme in case of circuit breaker malfunction.

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Figure 121: Example of traditional time selective transformer overcurrent protection

The operating times of the main and backup overcurrent protection of the above scheme become quite long, this applies especially in the busbar faults and also in the transformer LV-terminal faults. In order to improve the performance of the above scheme, a multiple-stage overcurrent protection with reverse blocking is proposed.

Figure 122 shows this arrangement.

245

Protection functions 1MRS757644 H

Transformer and busbar overcurrent protection with reverse blocking principle

By implementing a full set of overcurrent protection stages and blocking channels between the protection stages of the incoming feeders, bus-tie and outgoing feeders, it is possible to speed up the operation of overcurrent protection in the busbar and transformer LV-side faults without impairing the selectivity. Also, the security degree of busbar protection is increased, because there is now a dedicated, selective and fast busbar protection functionality which is based on the blockable overcurrent protection principle. The additional time selective stages on the transformer HV and LV-sides provide increased security degree of backup protection for the transformer, busbar and also for the outgoing feeders.

Depending on the overcurrent stage in question, the selectivity of the scheme in

Figure 122 is based on the operating current, operating time or blockings between

successive overcurrent stages. With blocking channels, the operating time of the protection can be drastically shortened if compared to the simple time selective protection. In addition to the busbar protection, this blocking principle is applicable for the protection of transformer LV terminals and short lines. The functionality and performance of the proposed overcurrent protections can be summarized as seen in the table.

Table 220: Proposed functionality of numerical transformer and busbar overcurrent protection. DT = definite time, IDMT = inverse definite minimum time

O/C-stage

HV/3I>

HV/3I>>

HV/3I>>>

LV/3I>

LV/3I>>

LV/3I>>>

Operating char.

Selectivity mode Operation speed

DT/IDMT

DT

DT

DT/IDMT

DT

DT time selective blockable/time selective current selective time selective time selective blockable low high/low very high low low high

Sensitivity very high high low very high high high

In case the bus-tie breaker is open, the operating time of the blockable overcurrent protection is approximately 100 ms (relaying time). When the bus-tie breaker is closed, that is, the fault current flows to the faulted section of the busbar from two directions, the operation time becomes as follows: first the bus-tie relay unit trips the tie breaker in the above 100 ms, which reduces the fault current to a half. After this the incoming feeder relay unit of the faulted bus section trips the breaker in approximately 250 ms (relaying time), which becomes the total fault clearing time in this case.

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Figure 122: Numerical overcurrent protection functionality for a typical subtransmission/distribution substation (feeder protection not shown). Blocking output = digital output signal from the start of a protection stage, Blocking in = digital input signal to block the operation of a protection stage

The operating times of the time selective stages are very short, because the grading margins between successive protection stages can be kept short. This is mainly due to the advanced measuring principle allowing a certain degree of CT saturation, good operating accuracy and short retardation times of the numerical units. So, for example, a grading margin of 150 ms in the DT mode of operation can be used, provided that the circuit breaker interrupting time is shorter than 60 ms.

The sensitivity and speed of the current-selective stages become as good as possible due to the fact that the transient overreach is very low. Also, the effects of switching inrush currents on the setting values can be reduced by using the protection relay's logic, which recognizes the transformer energizing inrush current and blocks the operation or multiplies the current start value setting of the selected overcurrent stage with a predefined multiplier setting.

Finally, a dependable trip of the overcurrent protection is secured by both a proper selection of the settings and an adequate ability of the measuring transformers to reproduce the fault current. This is important in order to maintain selectivity and also for the protection to operate without additional time delays. For additional information about available measuring modes and current transformer requirements, see

Chapter 11.5 Measurement modes

in this manual.

Radial outgoing feeder overcurrent protection

The basic requirements for feeder overcurrent protection are adequate sensitivity and operation speed taking into account the minimum and maximum fault current levels along the protected line, selectivity requirements, inrush currents and the thermal and mechanical withstand of the lines to be protected.

247


In many cases the above requirements can be best fulfilled by using multiple-stage

overcurrent units. Figure 123

shows an example of this. A brief coordination study has been carried out between the incoming and outgoing feeders.

The protection scheme is implemented with three-stage numerical overcurrent protection, where the low-set stage PHLPTOC operates in IDMT-mode and the two higher stages PHHPTOC and PHIPTOC in DT-mode. Also the thermal withstand of the line types along the feeder and maximum expected inrush currents of the feeders are shown. Faults occurring near the station where the fault current levels are the highest are cleared rapidly by the instantaneous stage in order to minimize the effects of severe short circuit faults. The influence of the inrush current is taken into consideration by connecting the inrush current detector to the start value multiplying input of the instantaneous stage. In this way the start value is multiplied with a predefined setting during the inrush situation and nuisance tripping can be avoided.

248

Figure 123: Functionality of numerical multiple-stage overcurrent protection

The coordination plan is an effective tool to study the operation of time selective operation characteristics. All the points mentioned earlier, required to define the overcurrent protection parameters, can be expressed simultaneously in a

coordination plan. In Figure 124

, the coordination plan shows an example of operation characteristics in the LV-side incoming feeder and radial outgoing feeder.

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Figure 124: Example coordination of numerical multiple-stage overcurrent protection

4.1.1.8

Signals

Table 221: PHLPTOC Input signals

Name

I_A

I_B

I_C

BLOCK

Type

SIGNAL

SIGNAL

SIGNAL

BOOLEAN

ENA_MULT BOOLEAN

Default

0

0

0

0=False

0=False

Description

Phase A current

Phase B current

Phase C current


Enable signal for current multiplier

Table 222: PHHPTOC Input signals

Name

I_A

I_B

I_C

BLOCK

Type

SIGNAL

SIGNAL

SIGNAL

BOOLEAN

ENA_MULT BOOLEAN

Default

0

0

0

0=False

0=False

Description

Phase A current

Phase B current

Phase C current



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Table 223: PHIPTOC Input signals

Name

I_A

I_B

I_C

BLOCK

Type

SIGNAL

SIGNAL

SIGNAL

BOOLEAN

Default

0

0

0

0=False

ENA_MULT BOOLEAN

Table 224: PHLPTOC Output signals

Name

OPERATE

START

Type

BOOLEAN

BOOLEAN

Table 225: PHHPTOC Output signals

Name

OPERATE

START

Type

BOOLEAN

BOOLEAN

Table 226: PHIPTOC Output signals

Name

OPERATE

START

Type

BOOLEAN

BOOLEAN

0=False

4.1.1.9

Settings

Table 227: PHLPTOC Group settings (Basic)

Parameter

Start value

Start value Mult

Values (Range)

0.05...5.00

0.8...10.0

Unit xIn

Time multiplier 0.05...15.00


Step

0.01

0.1

0.01

Default

0.05

1.0

1.00

Description

Operate

Start

Description

Operate

Start

Description

Operate

Start

Description

Phase A current

Phase B current

Phase C current



Description

Start value

Multiplier for scaling the start value

Time multiplier in IEC/ANSI IDMT curves

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Operate delay time 40...200000

Operating curve type

1=ANSI Ext. inv.

2=ANSI Very inv.

3=ANSI Norm. inv.

4=ANSI Mod. inv.

5=ANSI Def. Time

6=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. inv.

15=IEC Def. Time

17=Programmable

18=RI type

19=RD type

Unit ms

Step

10

Table 228: PHLPTOC Group settings (Advanced)

Unit Parameter Values (Range)

Type of reset curve 1=Immediate

2=Def time reset

3=Inverse reset

Step

Table 229: PHLPTOC Non group settings (Basic)

Parameter

Operation

Values (Range)

1=on

5=off

Num of start phases

1=1 out of 3

2=2 out of 3

3=3 out of 3

Curve parameter A 0.0086...120.0000

Unit Step

1

Curve parameter B 0.0000...0.7120

1

Curve parameter C 0.02...2.00

Curve parameter D 0.46...30.00

Curve parameter E 0.0...1.0

1

1

1

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Default

40

15=IEC Def. Time

Description

Operate delay time

Selection of time delay curve type

Default

1=Immediate

Description

Selection of reset curve type

Default

1=on

1=1 out of 3

28.2000

0.1217

2.00

29.10

1.0

Description

Operation Off / On

Number of phases required for operate activation

Parameter A for customer programmable curve

Parameter B for customer programmable curve

Parameter C for customer programmable curve

Parameter D for customer programmable curve

Parameter E for customer programmable curve

251


Table 230: PHLPTOC Non group settings (Advanced)

Parameter

Minimum operate time

Reset delay time

Measurement mode

Values (Range)

20...60000

0...60000

1=RMS

2=DFT

3=Peak-to-Peak

5=Wide P-to-P

Unit ms ms

Step

1

1

Table 231: PHHPTOC Group settings (Basic)

Parameter

Start value

Start value Mult

Values (Range)

0.10...40.00

0.8...10.0

Unit xIn




1=ANSI Ext. inv.

3=ANSI Norm. inv.

5=ANSI Def. Time

9=IEC Norm. inv.

10=IEC Very inv.

12=IEC Ext. inv.

15=IEC Def. Time

17=Programmable ms

Table 232: PHHPTOC Group settings (Advanced)



2=Def time reset

3=Inverse reset

Unit Step

Step

0.01

0.1

0.01

10

Table 233: PHHPTOC Non group settings (Basic)

Parameter

Operation

Values (Range)

1=on

5=off

Num of start phases

1=1 out of 3

2=2 out of 3

3=3 out of 3


Unit Step

1


1


252

1MRS757644 H

Default

20

20

2=DFT

Description

Minimum operate time for IDMT curves

Reset delay time

Selects used measurement mode

Default

0.10

1.0

1.00

40

15=IEC Def. Time

Description

Start value



Operate delay time


Default

1=Immediate

Description


Default

1=on

1=1 out of 3

28.2000

0.1217

Description

Operation Off / On




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Unit Step

1

1

1

Default

2.00

29.10

1.0

Description




Table 234: PHHPTOC Non group settings (Advanced)

Parameter


Reset delay time

Measurement mode

Values (Range)

20...60000

0...60000

1=RMS

2=DFT

3=Peak-to-Peak

Unit ms ms

Step

1

1

Table 235: PHIPTOC Group settings (Basic)

Parameter

Start value

Start value Mult

Values (Range)

0.2...40.00 1

0.8...10.0

Unit xIn

Operate delay time 20...200000 2

40...200000 3 ms

Step

0.01

0.1

10

Table 236: PHIPTOC Non group settings (Basic)

Parameter

Operation

Num of start phases

Values (Range)

1=on

5=off

1=1 out of 3

2=2 out of 3

3=3 out of 3

Unit Step

Table 237: PHIPTOC Non group settings (Advanced)

Parameter

Reset delay time

Values (Range)

0...60000

Unit ms

Step

1

Default

20

20

2=DFT

Default

1.00

1.0

20 2

40 3

Default

1=on

1=1 out of 3

Description


Reset delay time


Description

Start value


Operate delay time

Description

Operation Off / On


Default

20

Description

Reset delay time

1

2

3

In relay patch software 2.1.2, the Start value setting range has been extended to start from 0.2

xIn. There is a limitation to the new extended setting range 0.2…1.0 xIn. Firstly, the extended setting range is settable only from the LHMI. New range values cannot be set from the relay tools. Secondly, when Start value is set below 1.0 xIn, the Operate delay time setting must be ≥40 ms to avoid degrading the relay surge immunity, and to avoid relay faulty operations due to high surge spikes.

REF620 and REM620

RET620

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253


4.1.1.10

Monitored data

Table 238: PHLPTOC Monitored data

Name

START_DUR

PHLPTOC

Type

FLOAT32

Enum

Values (Range)

0.00...100.00

1=on

2=blocked

3=test

4=test/blocked

5=off

Table 239: PHHPTOC Monitored data

Name

START_DUR

Type

FLOAT32

PHHPTOC Enum

Values (Range)

0.00...100.00

1=on

2=blocked

3=test

4=test/blocked

5=off

Table 240: PHIPTOC Monitored data

Name

START_DUR

Type

FLOAT32

PHIPTOC Enum

Values (Range)

0.00...100.00

1=on

2=blocked

3=test

4=test/blocked

5=off

4.1.1.11

Technical data

Table 241: PHxPTOC Technical data

Characteristic

Operation accuracy

PHLPTOC

PHHPTOC and

PHIPTOC

Start time ,


Unit

%

Unit

%

Unit

%

Description

Ratio of start time / operate time

Status

Description


Status

Description


Status

Value

Depending on the frequency of the measured current: f

Hz n

±2

±1.5% of the set value or ±0.002 × I n

±1.5% of set value or ±0.002 × I n

(at currents in the range of 0.1…10 × I n

)

±5.0% of the set value

(at currents in the range of 10…40 × I n

)

Minimum Typical Maximum

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Characteristic

PHIPTOC:

I

Fault

= 2 × set Start value

I

Fault


PHHPTOC and PHLPTOC:

I

Fault


Reset time

Reset ratio

Retardation time

Operate time accuracy in definite time mode

Operate time accuracy in inverse time mode

Suppression of harmonics

Value

16 ms

11 ms

19 ms

12 ms

23 ms

14 ms

23 ms 26 ms 29 ms

Typically 40 ms

Typically 0.96

<40 ms


±5.0% of the theoretical value or ±20 ms

RMS: No suppression

DFT: -50 dB at f = n × f n

, where n = 2, 3, 4, 5,…

Peak-to-Peak: No suppression

P-to-P+backup: No suppression

4.1.1.12


Table 242: PHIPTOC Technical revision history

E

F


B

C

D

E

Change

Minimum and default values changed to 40 ms for the Operate delay time setting


Minimum value changed to 1.00 x In for the

Start value setting



Table 243: PHHPTOC Technical revision history


C

D

Change

Measurement mode "P-to-P + backup" replaced with "Peak-to-Peak"

Step value changed from 0.05 to 0.01 for the

Time multiplier setting



1

2

3

Measurement mode = default (depends on stage), current before fault = 0.0 × I on statistical distribution of 1000 measurements

Includes the delay of the signal output contact

Maximum Start value = 2.5 × I n

, Start value multiples in range of 1.5...20

n

, f n

= 50 Hz, fault current in one phase with nominal frequency injected from random phase angle, results based

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255


4.1.2

4.1.2.1

4.1.2.2

1MRS757644 H

Table 244: PHLPTOC Technical revision history

D

E


B

C

Change






Three-independent-phase non-directional overcurrent protection PH3xPTOC

Identification

Function description IEC 61850 identification

PH3LPTOC Three-independent-phase non-directional overcurrent protection, low stage

Three-independent-phase non-directional overcurrent protection, high stage

Three-independent-phase non-directional overcurrent protection, instantaneous stage

PH3HPTOC

PH3IPTOC


3I_3>

ANSI/IEEE C37.2

device number

51P-1_3

3I_3>>

3I_3>>>

51P-2_3

50P/51P_3

Function block

4.1.2.3

256


Functionality

The three-independent-phase non-directional overcurrent protection function

PH3xPTOC is used as one-phase, two-phase or three-phase non-directional overcurrent and short circuit protection for feeders.

The function starts when the current exceeds the set limit. Each phase has its own timer. The operating time characteristics for low-stage PH3LPTOC and highstage PH3HPTOC can be selected to be either definite time (DT) or inverse definite minimum time (IDMT). The instantaneous stage PH3IPTOC always operates with the

DT characteristic.

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1MRS757644 H

4.1.2.4






PH3xPTOC is used as single-phase and three-phase non-directional overcurrent and short circuit protection. The phase operation mode is selected with the Operation curve type setting. The operation is further specified with the Num of start phases setting, which sets the number of phases in which the current must exceed the set current start value before the corresponding start and operating signals can be activated.

The operation of PH3xPTOC can be described by using a module diagram. All the modules in the diagram are explained in the next sections.

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Technical Manual


Level detector

The measured phase currents are compared phasewise to the set Start value. If the measured value exceeds the set Start value, the level detector reports the exceeding

257

Protection functions 1MRS757644 H of the value to the phase selection logic. If the ENA_MULT input is active, the Start value setting is multiplied by the Start value Mult setting.

The IED does not accept the Start value or Start value Mult setting if the product of these settings exceeds the Start value setting range.



258



The phase selection logic detects the faulty phase or phases and controls the timers according to the set value of the Num of start phases setting.

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620 series

Technical Manual

Figure 128: Logic diagram for phase selection module

When the Number of start phases setting is set to "1 out of 3" and the fault is in one or several phases, the phase selection logic sends an enabling signal to the faulty phase timers. In case the fault disappears, the related timer-enabling signal is removed.

When the setting is "2 out of 3" or "3 out of 3", the single-phase faults are not detected. The setting "3 out of 3" requires the fault to be present in all three phases.

Timer A, Timer B, Timer C

The function design contains three independent phase-segregated timers that are controlled by common settings. This design allows true three-phase overcurrent protection which is useful in some applications.

Common START and OPERATE outputs are created by ORing the phase-specific start and operating outputs.

Each phase has its own phase-specific start and operating outputs: ST_A , ST_B ,

ST_C , OPR_A , OPR_B and OPR_C .


259


260

1MRS757644 H



When the programmable IDMT curve is selected, the operating time characteristics are defined with the parameters Curve parameter A, Curve parameter B, Curve parameter C, Curve parameter D and Curve parameter E.

The shortest IDMT operation time is adjustable. It can be set up with the global parameter in the HMI menu: Configuration > System > IDMT

Sat point. More information can be found in

Chapter 11 General function block features

.



"Immediate", "Def time reset" or "Inverse reset". The reset curve type "Immediate" causes an immediate reset. With the reset curve type "Def time reset", the reset time depends on the Reset delay time setting. With the reset curve type "Inverse reset", the reset time depends on the current during the drop-off situation. The


The "Inverse reset" selection is only supported with ANSI or programmable types of the IDMT operating curves. If another operating curve type is selected, an immediate reset occurs during the drop-off situation.

The setting Time multiplier is used for scaling the IDMT operation and reset times.

The setting parameter Minimum operate time defines the minimum desired operation time for IDMT. The setting is applicable only when the IDMT curves are used.


information, see Chapter 11 General function block features in this

manual.


Blocking logic

There are three operation modes in the blocking function. The operation modes are controlled by the BLOCK input and the global setting in Configuration > System >

Blocking mode, which selects the blocking mode. The BLOCK input can be controlled by a binary input, a horizontal communication input or an internal signal of the IED program. The influence of the BLOCK signal activation is preselected with the global setting Blocking mode.

The Blocking mode setting has three blocking methods. In the "Freeze timers" mode, the operation timer is frozen to the prevailing value. In the "Block all" mode, the whole function is blocked and the timers are reset. In the "Block OPERATE output" mode, the function operates normally but the OPERATE , OPR_A , OPR_B and

OPR_C outputs are not activated.

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4.1.2.5


PH3xPTOC supports both DT and IDMT characteristics. The timer characteristics can be selected with the Operating curve type and Type of reset curve settings.


The IED provides 16 IDMT characteristics curves, of which seven comply with the

IEEE C37.112 and six with the IEC 60255-3 standard. Two curves follow the special characteristics of ABB praxis and are referred to as RI and RD. In addition, a programmable curve can be used if none of the standard curves are applicable.

The DT characteristic can be chosen by selecting the Operating curve type values

"ANSI Def. Time" or "IEC Def. Time". The functionality is identical in both cases.

The following characteristics, which comply with the list in the IEC 61850-7-4 specification, indicate the characteristics supported by different stages:

Table 245: IDMT curves supported by different stages

Operating curve type Supported by










(11) IEC Inverse




(17) Programmable

PH3LPTOC x x x x x x x x x x x x x x

PH3IPTOC supports only definite time characteristic.

PH3HPTOC x x x x x x


in this manual.

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4.1.2.6

262

1MRS757644 H



(1) Immediate

(2) Def time reset

(3) Inverse reset

PH3LPTOC x x x

PH3HPTOC x x x

Note

Available for all operating time curves


Available only for ANSI and user programmable curves

The Type of reset curve setting does not apply to PH3IPTOC or when the


Application

PH3xPTOC is used in several applications in the power system. The applications include different protections, for example.

• Selective overcurrent and short-circuit protection of feeders in distribution and subtransmission systems

• Backup overcurrent and short-circuit protection of power transformers and generators

• Overcurrent and short-circuit protection of various devices connected to the power system, for example shunt capacitor banks, shunt reactors and motors

• General backup protection

PH3xPTOC is used for single-phase, two-phase and three-phase non-directional overcurrent and short circuit protection. Typically, overcurrent protection is used for clearing two-phase and three-phase short circuits. Therefore, it can be chosen how many phases, at minimum, must have currents above the start level for the function to operate.

Many applications require several steps using different current start levels and time delays. PH3xPTOC consists of three protection stages:

• Low PH3LPTOC

• High PH3HPTOC

• Instantaneous PH3IPTOC

PH3LPTOC is used for overcurrent protection. The function contains several types of time delay characteristics. PH3HPTOC and PH3IPTOC are used for the fast clearing of very high overcurrent situations.

Transformer overcurrent protection

The purpose of the transformer overcurrent protection is to operate as the main protection when differential protection is not used. It can also be used as a coarse backup protection for differential protection in the faults inside the zone of protection, that is, faults occurring in incoming or outgoing feeders, in the region of transformer terminals and in the tank cover. This means that the magnitude range of the fault current can be very wide. The range varies from 6xIn to several hundred times In, depending on the impedance of the transformer and the source impedance of the feeding network. From this point of view, it is clear that the

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Technical Manual

1MRS757644 H Protection functions operation must be both very fast and selective, which is usually achieved by using coarse current settings.

The purpose is also to protect the transformer from short circuits occurring outside the protection zone, that is, from through-faults. Transformer overcurrent protection also provides protection for the LV-side busbars. In this case, the magnitude of the fault current is typically lower than 12xIn, depending on the fault location and transformer impedance. Consequently, the protection must operate as fast as possible, taking into account the selectivity requirements, switchingin currents and the thermal and mechanical withstand of the transformer and outgoing feeders.

Traditionally, overcurrent protection of the transformer has been arranged as shown in

Figure 129

. The low-set stage PH3LPTOC operates time-selectively both in transformer and LV-side busbar faults. The high-set stage PH3HPTOC operates instantaneously, making use of current selectivity only in the transformer HV-side faults. If there is a possibility that the fault current can also be fed from the LVside up to the HV-side, the transformer must also be equipped with an LV-side overcurrent protection. Inrush current detectors are used in startup situations to multiply the current start value setting in each particular IED where the inrush current can occur. The overcurrent- and contact-based circuit breaker failure protection CCBRBRF is used to confirm the protection scheme in case of circuit breaker malfunction.

MF

PH3LPTOC

PH3HPTOC

INRPHAR

PH3LPTOC

PH3HPTOC

INRPHAR

MF

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Technical Manual

PH3LPTOC

PH3HPTOC

CCBRBRF

INRPHAR

MF

MEASUREMENT

INCOMING

O U T G O I N G O U T G O I N G B U S T I E

MF MF MF

PH3LPTOC

PH3HPTOC

CCBRBRF

PH3LPTOC

PH3HPTOC

CCBRBRF

INRPHAR MF

B U S _ T I E O U T G O I N G O U T G O I N G

INCOMING

MEASUREMENT

MF MF

Figure 129: Example of traditional time selective transformer overcurrent protection

The operating times of the main and backup overcurrent protection of the above scheme become quite long. This applies especially in the busbar faults and also in the transformer LV-terminal faults. To improve the performance of the above scheme, a multiple-stage overcurrent protection with a reverse blocking is proposed.

Figure 130

shows this arrangement.

263


Transformer and busbar overcurrent protection with reverse blocking principle

By implementing a full set of overcurrent protection stages and blocking channels between the protection stages of the incoming feeders, bus-tie and outgoing feeders, it is possible to accelerate the operation of the overcurrent protection in the busbar and transformer LV-side faults without impairing the selectivity. Also, the security degree of the busbar protection is increased, because there is now a dedicated, selective and fast busbar protection functionality which is based on the blockable overcurrent protection principle. The additional time-selective stages on the transformer HV- and LV-sides provide increased security degree of backup protection for the transformer, busbar and also for the outgoing feeders.

Depending on the overcurrent stage in question, the selectivity of the scheme in

Figure 130

is based on the operating current, operating time or blockings between successive overcurrent stages. With blocking channels, the operating time of the protection can be drastically shortened if compared to the simple time-selective protection. In addition to the busbar protection, this blocking principle is applicable for the protection of transformer LV-terminals and short lines. The functionality and performance of the proposed overcurrent protections can be summarized.

Table 247: Proposed functionality of numerical transformer and busbar overcurrent protection. DT = definite time, IDMT = inverse definite minimum time

O/C-stage

HV/3I>

HV/3I>>

HV/3I>>>

LV/3I>

LV/3I>>

LV/3I>>>

Operating char.

Selectivity mode Operation speed

DT/IDMT

DT

DT

DT/IDMT

DT

DT time selective blockable/time selective current selective time selective time selective blockable low high/low very high low low high

Sensitivity very high high low very high high high

If the bus-tie breaker is open, the operating time of the blockable overcurrent protection is approximately 100 ms (relaying time). When the bus-tie breaker is closed, that is, the fault current flows to the faulted section of the busbar from two directions, the operation time becomes as follows: first the bus-tie relay unit trips the tie breaker in the above 100 ms, which reduces the fault current to a half. After this the incoming feeder relay unit of the faulted bus section trips the breaker in approximately 250 ms (relaying time), which becomes the total fault-clearing time in this case.

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Technical Manual

MF

HV-side

PH3LPTOC

PH3HPTOC

PH3IPTOC

CCBRBRF

INRPHAR

Blocking output

(PH3HPTOC

START)

LV-side

PH3LPTOC

PH3HPTOC

PH3IPTOC

CCBRBRF

MF

MEASUREMENT

INCOMING

O U T G O I N G O U T G O I N G B U S T I E

MF MF MF

PH3LPTOC

PH3HPTOC

PH3IPTOC

CCBRBRF

Blocking output

(PH3HPTOC

START)

PH3LPTOC

PH3HPTOC

PH3IPTOC

CCBRBRF

INRPHAR

PH3LPTOC

PH3HPTOC

PH3IPTOC

CCBRBRF

B U S _ T I E O U T G O I N G O U T G O I N G

MF MF

MF

HV-side

LV-side

MF

MEASUREMENT

INCOMING

Blocking output

(Outgoing feeder

PH3HPTOC START)

Blocking output

(Outgoing feeder

PH3HPTOC START)

Figure 130: Numerical overcurrent protection functionality for a typical subtransmission/distribution substation (feeder protection not shown). Blocking output = digital output signal from the start of a protection stage, Blocking in = digital input signal to block the operation of a protection stage

The operating times of the time-selective stages are very short, because the grading margins between successive protection stages can be kept short. This is mainly due to the advanced measuring principle allowing a certain degree of CT saturation, good operating accuracy and short retardation times of the numerical units. So, for example, a grading margin of 150 ms in the DT mode of operation can be used, provided that the circuit breaker interrupting time is shorter than 60 ms.

The sensitivity and speed of the current-selective stages become as good as possible due to the fact that the transient overreach is very low. Also, the effects of switching inrush currents on the setting values can be reduced using the IED logic which recognizes the transformer-energizing inrush current and blocks the operation or multiplies the current start value setting of the selected overcurrent stage with a predefined multiplier setting.

Finally, a dependable trip of the overcurrent protection is secured by both a proper selection of the settings and an adequate ability of the measuring transformers to reproduce the fault current. This is important in maintaining selectivity and also for the protection to operate without additional time delays. For additional information about available measuring modes and current transformer requirements, see

Chapter 11.5 Measurement modes

in this manual.

Radial outgoing feeder overcurrent protection

The basic requirements for feeder overcurrent protection are adequate sensitivity and operation speed taking into account the minimum and maximum fault current

265

Protection functions 1MRS757644 H levels along the protected line, selectivity requirements, inrush currents and the thermal and mechanical withstand of the lines to be protected.

Often the above requirements can be best fulfilled using multiple-stage overcurrent units.

Figure 131 shows an example of this. A brief coordination study has been

carried out between the incoming and outgoing feeders.

The protection scheme is implemented with three-stage numerical overcurrent protection where the low-set stage PH3LPTOC operates in the IDMT-mode and the two higher stages, PH3HPTOC and PH3IPTOC, in the DT-mode. Also the thermal withstand of the line types along the feeder and the maximum expected inrush currents of the feeders are shown. Faults occurring near the station where the fault current levels are the highest are cleared rapidly by the instantaneous stage to minimize the effects of severe short circuit faults. The influence of the inrush current is taken into consideration by connecting the inrush current detector to the start value-multiplying input of the instantaneous stage. This way, the start value is multiplied with a predefined setting during the inrush situation, and nuisance tripping can be avoided.

266

I k

I k max min

7

OUTGOING

MF

INCOMING

PH3LPTOC

PH3HPTOC

PH3IPTOC

CCBRBRF

INRPHAR

OUTGOING

MF MF

PH3LPTOC

PH3HPTOC

PH3IPTOC

CCBRBRF

INRPHAR

Line type 2

I k max

I k min

8

Line type 1

I k max

I k min

9

Figure 131: Functionality of numerical multiple-stage overcurrent protection

The coordination plan is an effective tool to study the operation of time-selective operation characteristics. All the points mentioned earlier, required to define the overcurrent protection parameters, can be expressed simultaneously in a

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Technical Manual


coordination plan. In Figure 132

, the coordination plan shows an example of operation characteristics in the LV-side incoming feeder and radial outgoing feeder.

4.1.2.7

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Technical Manual

Figure 132: Example coordination of numerical multiple-stage overcurrent protection

Signals

Table 248: PH3LPTOC Input signals

Name

I_A

I_B

I_C

BLOCK

Type

SIGNAL

SIGNAL

SIGNAL

BOOLEAN

ENA_MULT BOOLEAN

Default

0

0

0

0=False

0=False

Description

Phase A current

Phase B current

Phase C current



Table 249: PH3HPTOC Input signals

Name

I_A

I_B

I_C

BLOCK

Type

SIGNAL

SIGNAL

SIGNAL

BOOLEAN

ENA_MULT BOOLEAN

Default

0

0

0

0=False

0=False

Description

Phase A current

Phase B current

Phase C current



267


268

1MRS757644 H

Table 250: PH3IPTOC Input signals

Name

I_A

I_B

I_C

BLOCK

Type

SIGNAL

SIGNAL

SIGNAL

BOOLEAN

Default

0

0

0

0=False

ENA_MULT BOOLEAN

Table 251: PH3LPTOC Output signals

Name

OPERATE

OPR_A

OPR_B

OPR_C

START

ST_A

ST_B

ST_C

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Table 252: PH3HPTOC Output signals

Name

OPERATE

OPR_A

OPR_B

OPR_C

START

ST_A

ST_B

ST_C

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Table 253: PH3IPTOC Output signals

Name Type

OPERATE

OPR_A

OPR_B


BOOLEAN

BOOLEAN

BOOLEAN

0=False

Description

Operate

Operate phase A

Operate phase B

Operate phase C

Start

Start phase A

Start phase B

Start phase C

Description

Operate

Operate phase A

Operate phase B

Operate phase C

Start

Start phase A

Start phase B

Start phase C

Description

Operate

Operate phase A

Operate phase B

Description

Phase A current

Phase B current

Phase C current



620 series

Technical Manual

1MRS757644 H

Name

OPR_C

START

ST_A

ST_B

ST_C

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

4.1.2.8

Settings

Table 254: PH3LPTOC Group settings (Basic)

Parameter

Start value

Start value Mult

Values (Range)

0.05...5.00

0.8...10.0

Unit xIn




1=ANSI Ext. inv.

2=ANSI Very inv.

3=ANSI Norm. inv.

4=ANSI Mod. inv.

5=ANSI Def. Time

6=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. inv.

15=IEC Def. Time

17=Programmable

18=RI type

19=RD type ms

Table 255: PH3LPTOC Group settings (Advanced)



2=Def time reset

3=Inverse reset

Unit Step

Step

0.01

0.1

0.01

10


Description

Operate phase C

Start

Start phase A

Start phase B

Start phase C

Default

0.05

1.0

1.00

40

15=IEC Def. Time

Description

Start value



Operate delay time


Default

1=Immediate

Description


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269


Table 256: PH3LPTOC Non group settings (Basic)

Parameter

Operation

Values (Range)

1=on

5=off

Num of start phases

1=1 out of 3

2=2 out of 3

3=3 out of 3


Unit Step

1


1




1

1

1

Table 257: PH3LPTOC Non group settings (Advanced)

Parameter


Values (Range)

20...60000

Unit ms

Step

10

Reset delay time

Measurement mode

0...60000

1=RMS

2=DFT

3=Peak-to-Peak ms 10

Table 258: PH3HPTOC Group settings (Basic)

Parameter

Start value

Start value Mult

Values (Range)

0.10...40.00

0.8...10.0

Unit xIn




1=ANSI Ext. inv.

3=ANSI Norm. inv.

5=ANSI Def. Time

9=IEC Norm. inv.

10=IEC Very inv.

12=IEC Ext. inv.

15=IEC Def. Time

17=Programmable ms

Step

0.01

0.1

0.01

10

1MRS757644 H

Default

1=on

1=1 out of 3

28.2000

0.1217

2.00

29.10

1.0

Description

Operation Off / On







Default

20

20

2=DFT

Description


Reset delay time


Default

0.10

1.0

1.00

40

15=IEC Def. Time

Description

Start value



Operate delay time


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1MRS757644 H

Table 259: PH3HPTOC Group settings (Advanced)



2=Def time reset

3=Inverse reset

Unit Step

Table 260: PH3HPTOC Non group settings (Basic)

Parameter

Operation

Values (Range)

1=on

5=off

Num of start phases

1=1 out of 3

2=2 out of 3

3=3 out of 3


Unit Step

1





1

1

1

1

Table 261: PH3HPTOC Non group settings (Advanced)

Parameter


Values (Range)

20...60000

Unit ms

Step

10

Reset delay time

Measurement mode

0...60000

1=RMS

2=DFT

3=Peak-to-Peak ms 10

Table 262: PH3IPTOC Group settings (Basic)

Parameter

Start value

Start value Mult

Values (Range)

1.00...40.00

0.8...10.0

Unit xIn


ms

Step

0.01

0.1

10


Default

1=Immediate

Description


Default

1=on

1=1 out of 3

28.2000

0.1217

2.00

29.10

1.0

Description

Operation Off / On







Default

20

20

2=DFT

Description


Reset delay time


Default

1.00

1.0

20

Description

Start value


Operate delay time

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271


Table 263: PH3IPTOC Non group settings (Basic)

Parameter

Operation

Num of start phases

Values (Range)

1=on

5=off

1=1 out of 3

2=2 out of 3

3=3 out of 3

Unit Step

Table 264: PH3IPTOC Non group settings (Advanced)

Parameter

Reset delay time

Values (Range)

0...60000

Unit ms

Step

10

4.1.2.9

Monitored data

Table 265: PH3LPTOC Monitored data

Name

START_DUR

PH3LPTOC

Type

FLOAT32

Enum

Values (Range)

0.00...100.00

1=on

2=blocked

3=test

4=test/blocked

5=off

Table 266: PH3HPTOC Monitored data

Name

START_DUR

PH3HPTOC

Type

FLOAT32

Enum

Values (Range)

0.00...100.00

1=on

2=blocked

3=test

4=test/blocked

5=off

Table 267: PH3IPTOC Monitored data

Name

START_DUR

PH3IPTOC

Type

FLOAT32

Enum

Values (Range)

0.00...100.00

1=on

2=blocked

3=test

4=test/blocked

5=off

Unit

%

Unit

%

Unit

%

Default

1=on

1=1 out of 3

Default

20

Description

Operation Off / On


Description

Reset delay time

Description


Status

Description


Status

Description


Status

272 620 series

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4.1.2.10

Technical data

Table 268: PH3xPTOC Technical data

Characteristic

Operation accuracy

PH3LPTOC

PH3HPTOC and PH3IPTOC

Start time ,

PH3IPTOC:

I

Fault


I

Fault


PH3HPTOC and PH3LPTOC:

I

Fault


Reset time

Reset ratio

Retardation time




Value


Hz n

±2



0.1…10 × I n

)

(at currents in the range of

±5.0% of the set value (at currents in the range of 10…40 × I n

)


15 ms

11 ms

16 ms

14 ms

17 ms

17 ms

23 ms 25 ms

<40 ms

Typically 0.96

<30 ms



28 ms

RMS: No suppression


, where n = 2, 3, 4, 5,…


Peak-to-Peak + backup: No suppression

4.1.3

4.1.3.1

Three-phase directional overcurrent protection

DPHxPDOC

Identification


Three-phase directional overcurrent protection, low stage

Three-phase directional overcurrent protection, high stage



3I> ->

ANSI/IEEE

C37.2 device number

67-1

DPHLPDOC

DPHHPDOC 3I>> -> 67-2

1

2

3

Measurement mode = default (depends on stage), current before fault = 0.0 × I on statistical distribution of 1000 measurements




n

, f n

= 50 Hz, fault current in one phase with nominal frequency injected from random phase angle, results based

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273


4.1.3.2

Function block

1MRS757644 H

4.1.3.3

4.1.3.4


Functionality

The three-phase directional overcurrent protection function DPHxPDOC is used as one-phase, two-phase or three-phase directional overcurrent and short-circuit protection for feeders.

DPHxPDOC starts up when the value of the current exceeds the set limit and directional criterion is fulfilled. The operate time characteristics for low stage

DPHLPDOC and high stage DPHHPDOC can be selected to be either definite time

(DT) or inverse definite minimum time (IDMT).





The operation of DPHxPDOC can be described using a module diagram. All the modules in the diagram are explained in the next sections.

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Directional calculation

The directional calculation compares the current phasors to the polarizing phasor.

A suitable polarization quantity can be selected from the different polarization quantities, which are the positive sequence voltage, negative sequence voltage, self-polarizing (faulted) voltage and cross-polarizing voltages (healthy voltages).

The polarizing method is defined with the Pol quantity setting.

Table 269: Polarizing quantities

Polarizing quantity

Pos. seq. volt

Neg. seq. volt

Self pol

Cross pol

Description



Self polarization

Cross polarization

The directional operation can be selected with the Directional mode setting.

The user can select either "Non-directional", "Forward" or "Reverse" operation. By setting the value of Allow Non Dir to "True", the non-directional operation is allowed when the directional information is invalid.

The Characteristic angle setting is used to turn the directional characteristic. The value of Characteristic angle should be chosen in such a way that all the faults in the operating direction are seen in the operating zone and all the faults in the

275

Protection functions 1MRS757644 H opposite direction are seen in the non-operating zone. The value of Characteristic angle depends on the network configuration.

Reliable operation requires both the operating and polarizing quantities to exceed certain minimum amplitude levels. The minimum amplitude level for the operating quantity (current) is set with the Min operate current setting. The minimum amplitude level for the polarizing quantity (voltage) is set with the Min operate voltage setting. If the amplitude level of the operating quantity or polarizing quantity is below the set level, the direction information of the corresponding phase is set to "Unknown".

The polarizing quantity validity can remain valid even if the amplitude of the polarizing quantity falls below the value of the Min operate voltage setting. In this case, the directional information is provided by a special memory function for a time defined with the Voltage Mem time setting.

DPHxPDOC is provided with a memory function to secure a reliable and correct directional protection relay operation in case of a close short circuit or an earth fault characterized by an extremely low voltage. At sudden loss of the polarization quantity, the angle difference is calculated on the basis of a fictive voltage. The fictive voltage is calculated using the positive phase sequence voltage measured before the fault occurred, assuming that the voltage is not affected by the fault.

The memory function enables the function to operate up to a maximum of three seconds after a total loss of voltage. This time can be set with the Voltage Mem time setting. The voltage memory cannot be used for the "Negative sequence voltage" polarization because it is not possible to substitute the positive sequence voltage for negative sequence voltage without knowing the network unsymmetry level. This is the reason why the fictive voltage angle and corresponding direction information are frozen immediately for this polarization mode when the need for a voltage memory arises and these are kept frozen until the time set with Voltage

Mem time elapses.

The value for the Min operate voltage setting should be carefully selected since the accuracy in low signal levels is strongly affected by the measuring device accuracy.

When the voltage falls below Min operate voltage at a close fault, the fictive voltage is used to determine the phase angle. The measured voltage is applied again as soon as the voltage rises above Min operate voltage and hysteresis. The fictive voltage is also discarded if the measured voltage stays below Min operate voltage and hysteresis for longer than Voltage Mem time or if the fault current disappears while the fictive voltage is in use. When the voltage is below Min operate voltage and hysteresis and the fictive voltage is unusable, the fault direction cannot be determined. The fictive voltage can be unusable for two reasons:

• The fictive voltage is discarded after Voltage Mem time

• The phase angle cannot be reliably measured before the fault situation.

DPHxPDOC can be forced to the non-directional operation with the NON_DIR input. When the NON_DIR input is active, DPHxPDOC operates as a non-directional overcurrent protection, regardless of the Directional mode setting.

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Technical Manual

Figure 135: Operating zones at minimum magnitude levels

Level detector

The measured phase currents are compared phasewise to the set Start value. If the measured value exceeds the set Start value, the level detector reports the exceeding of the value to the phase selection logic. If the ENA_MULT input is active, the Start value setting is multiplied by the Start value Mult setting.




277


278



If the fault criteria are fulfilled in the level detector and the directional calculation, the phase selection logic detects the phase or phases in which the measured current exceeds the setting. If the phase information matches the Num of start phases setting, the phase selection logic activates the timer module.

Timer








"Immediate", "Def time reset" or "Inverse reset". The reset curve type "Immediate" causes an immediate reset. With the reset curve type "Def time reset", the reset time depends on the Reset delay time setting. With the reset curve type "Inverse

620 series

Technical Manual

1MRS757644 H

4.1.3.5

Protection functions reset", the reset time depends on the current during the drop-off situation. The







in this manual.


Blocking logic





The function operates on three alternative measurement modes: “RMS”, “DFT” and

“Peak-to-Peak” . The measurement mode is selected with the Measurement mode setting.

Table 270: Measurement modes supported by DPHxPDOC stages

Measurement mode

RMS

DFT

Peak-to-Peak

DPHLPDOC x x x

DPHHPDOC x x x

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4.1.3.6

1MRS757644 H

Directional overcurrent characteristics

The forward and reverse sectors are defined separately. The forward operation area is limited with the Min forward angle and Max forward angle settings. The reverse operation area is limited with the Min reverse angle and Max reverse angle settings.

The sector limits are always given as positive degree values.

In the forward operation area, the Max forward angle setting gives the counterclockwise sector and the Min forward angle setting gives the corresponding clockwise sector, measured from the Characteristic angle setting.

In the backward operation area, the Max reverse angle setting gives the counterclockwise sector and the Min reverse angle setting gives the corresponding clockwise sector, a measurement from the Characteristic angle setting that has been rotated 180 degrees.

Relay characteristic angle (RCA) is set positive if the operating current lags the polarizing quantity and negative if the operating current leads the polarizing quantity.

280

Figure 137: Configurable operating sectors

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Technical Manual


Table 271: Momentary per phase direction value for monitored data view

Criterion for per phase direction information

The ANGLE_X is not in any of the defined sectors, or the direction cannot be defined due too low amplitude

The ANGLE_X is in the forward sector

The ANGLE_X is in the reverse sector

(The ANGLE_X is in both forward and reverse sectors, that is, when the sectors are overlapping)

The value for DIR_A/_B/_C

0 = unknown

1 = forward

2 = backward

3 = both

Table 272: Momentary phase combined direction value for monitored data view

Criterion for phase combined direction information

The direction information (DIR_X) for all phases is unknown

The direction information (DIR_X) for at least one phase is forward, none being in reverse

The direction information (DIR_X) for at least one phase is reverse, none being in forward

The direction information (DIR_X) for some phase is forward and for some phase is reverse

The value for DIRECTION

0 = unknown

1 = forward

2 = backward

3 = both

FAULT_DIR gives the detected direction of the fault during fault situations, that is, when the START output is active.

Self-polarizing as polarizing method

Table 273: Equations for calculating angle difference for self-polarizing method

Angle difference Faulted phases

A

Used fault current

I

A

Used polarizing voltage

U

A

B I

B

U

B

C

A - B

B - C

C - A

I

C

I

A

- I

B

I

B

- I

C

I

C

- I

A

U

C

U

AB

U

BC

U

CA

ANGLE

ANGLE

ANGLE

ANGLE

ANGLE

ANGLE

_

_

_

_

_

_

A

B

C

A

B

C

= ϕ

= ϕ

= ϕ

( U

A

) ϕ ( I

A

) ϕ

RCA

( U

B

) ϕ

( I

B

) ϕ

RCA

( U

C

) ϕ ( I

C

) ϕ

= ϕ ( U

= ϕ ( U

BC

RCA

AB

) ϕ ( I

A

I

B

) ϕ

RCA

) ϕ ( I

B

I

C

) ϕ

RCA

= ϕ

( U

CA

) ϕ

( I

C

I

A

) ϕ

RCA

In an example case of the phasors in a single-phase earth fault where the faulted phase is phase A, the angle difference between the polarizing quantity U

A

and operating quantity I

A

is marked as φ. In the self-polarization method, there is no need to rotate the polarizing quantity.

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Figure 138: Single-phase earth fault, phase A

In an example case of a two-phase short-circuit failure where the fault is between phases B and C, the angle difference is measured between the polarizing quantity U

BC


B

- I

C

in the self-polarizing method.

282

Figure 139: Two-phase short circuit, short circuit is between phases B and C

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Cross-polarizing as polarizing quantity

Table 274: Equations for calculating angle difference for cross-polarizing method

Faulted phases

A

B

C

A - B

B - C

C - A


I

A


U

BC

I

B

I

C

I

A

- I

B

I

B

- I

C

I

C

- I

A

U

CA

U

AB

U

BC

- U

CA

U

CA

- U

AB

U

AB

- U

BC

Angle difference

ANGLE

ANGLE

ANGLE

ANGLE

ANGLE

ANGLE

_

_

_

_

_

_

A

B

C

A

B

C

=

=

=

=

=

= ϕ ϕ ϕ ϕ ϕ ϕ

(

(

( U

BC

) ϕ ( I

A

) ϕ

RCA

( U

CA

) ϕ ( I

B

) -

(

( U

U

U

U

AB

BC

CA

AB

) ϕ ( I

C

) ϕ ϕ

RCA

RCA

+ 90 o

+

+

90 o

90 o

U

CA

) ϕ

( I

A

I

B

) ϕ

RCA

-

-

U

U

AB

BC

) ϕ ( I

B

I

C

) ϕ

RCA

) ϕ ( I

C

I

A

) ϕ

RCA

+ 90 o

+

+

90 o

90 o

The angle difference between the polarizing quantity U

A

BC


is marked as φ in an example of the phasors in a single-phase earth fault where the faulted phase is phase A. The polarizing quantity is rotated with 90 degrees. The characteristic angle is assumed to be ~ 0 degrees.

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In an example of the phasors in a two-phase short-circuit failure where the fault is between the phases B and C, the angle difference is measured between the polarizing quantity U

AB


B

- I

C

marked as φ.

283


284


The equations are valid when network rotating direction is counterclockwise, that is, ABC. If the network rotating direction is reversed,

180 degrees is added to the calculated angle difference. This is done automatically with a system parameter Phase rotation.

Negative sequence voltage as polarizing quantity

When the negative voltage is used as the polarizing quantity, the angle difference between the operating and polarizing quantity is calculated with the same formula for all fault types:

ANGLE _ X

= ϕ (

−

U

2

)

− ϕ ( I

2

)

− ϕ

RCA

(Equation 6)

This means that the actuating polarizing quantity is - U

2

.

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Technical Manual


U

A

I

A

U

A

I

A U

2

I

2

U

CA

I

B

U

AB

I

C

I

C U

2

I

2

U

B

U

C

U

B

U

C

U

BC

A B

Figure 142: Phasors in a single-phase earth fault, phases A-N, and two-phase short circuit, phases B and C, when the actuating polarizing quantity is the negativesequence voltage -U2

I

B

Positive sequence voltage as polarizing quantity

Table 275: Equations for calculating angle difference for positive-sequence quantity polarizing method


A


I

A

B I

B


U

1

U

1

ANGLE

ANGLE

_

_

A

B

=

= ϕ ϕ

(

( U

U

1

1

)

)

−

− ϕ ϕ

(

(

I

I

A

B

)

)

−

− ϕ

RCA ϕ

RCA −

120 o

C I

C

U

1

ANGLE _ C = ϕ ( U

1

) − ϕ ( I

C

) − ϕ

RCA

+ 120 o

A - B I

A

- I

B

U

1

ANGLE _ A = ϕ ( U

1

) − ϕ ( I

A

− I

B

) − ϕ

RCA

+ 30 o

B - C I

B

- I

C

U

1

ANGLE _ B

= ϕ ( U

1

)

− ϕ ( I

B

−

I

C

)

− ϕ

RCA

−

90 o

C - A I

C

- I

A

U

1

ANGLE _ C

= ϕ

( U

1

)

− ϕ

( I

C

−

I

A

)

− ϕ

RCA

+

150 o

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285


I

A

U

1

U

A

I

A

U

A

U

1

-90°

I

B

I

B

- I c

-I

C

I

C

I

B

I

C

U

C

U

B

U

C

U

B

A B

Figure 143: Phasors in a single-phase earth fault, phase A to ground, and a twophase short circuit, phases B-C, are short-circuited when the polarizing quantity is the positive-sequence voltage U 1

Network rotation direction

Typically, the network rotating direction is counter-clockwise and defined as "ABC".

If the network rotating direction is reversed, meaning clockwise, that is, "ACB", the equations for calculating the angle difference needs to be changed. The network rotating direction is defined with a system parameter Phase rotation.

The change in the network rotating direction affects the phase-to-phase voltages polarization method where the calculated angle difference needs to be rotated 180 degrees. Also, when the sequence components are used, which are, the positive sequence voltage or negative sequence voltage components, the calculation of the components are affected but the angle difference calculation remains the same.

When the phase-to-ground voltages are used as the polarizing method, the network rotating direction change has no effect on the direction calculation.

The network rotating direction is set in the protection relay using the parameter in the HMI menu Configuration > System > Phase rotation.

The default parameter value is "ABC".

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4.1.3.7

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Technical Manual

NETWORK ROTATION ABC

U

A

I

A

NETWORK ROTATION ACB

U

A

I

A

U

CA

U

AB

U

AB

I

B

I

C

U

C

U

BC

U

B

U

B

Figure 144: Examples of network rotating direction

I

B

U

BC

U

CA

I

C

U

C

Application

DPHxPDOC is used as short-circuit protection in three-phase distribution or sub transmission networks operating at 50 or 60 Hz.

In radial networks, phase overcurrent protection relays are often sufficient for the short circuit protection of lines, transformers and other equipment. The current-time characteristic should be chosen according to the common practice in the network. It is recommended to use the same current-time characteristic for all overcurrent protection relays in the network. This includes the overcurrent protection of transformers and other equipment.

The phase overcurrent protection can also be used in closed ring systems as short circuit protection. Because the setting of a phase overcurrent protection system in closed ring networks can be complicated, a large number of fault current calculations are needed. There are situations with no possibility to have the selectivity with a protection system based on overcurrent protection relays in a closed ring system.

In some applications, the possibility of obtaining the selectivity can be improved significantly if DPHxPDOC is used. This can also be done in the closed ring networks and radial networks with the generation connected to the remote in the system thus giving fault current infeed in reverse direction. Directional overcurrent protection relays are also used to have a selective protection scheme, for example in case of parallel distribution lines or power transformers fed by the same single source. In ring connected supply feeders between substations or feeders with two feeding sources, DPHxPDOC is also used.

Parallel lines or transformers

When the lines are connected in parallel and if a fault occurs in one of the lines, it is practical to have DPHxPDOC to detect the direction of the fault. Otherwise, there is a risk that the fault situation in one part of the feeding system can de-energize the whole system connected to the LV side.

287


Figure 145: Overcurrent protection of parallel lines using directional protection relays

DPHxPDOC can be used for parallel operating transformer applications. In these applications, there is a possibility that the fault current can also be fed from the LVside up to the HV-side. Therefore, the transformer is also equipped with directional overcurrent protection.

288

Figure 146: Overcurrent protection of parallel operating transformers

Closed ring network topology

The closed ring network topology is used in applications where electricity distribution for the consumers is secured during network fault situations. The power is fed at least from two directions which means that the current direction can be varied. The time grading between the network level stages is challenging without unnecessary delays in the time settings. In this case, it is practical to use the directional overcurrent protection relays to achieve a selective protection scheme. Directional overcurrent functions can be used in closed ring applications.

The arrows define the operating direction of the directional functionality. The double arrows define the non-directional functionality where faults can be detected in both directions.

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4.1.3.8

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Technical Manual

Figure 147: Closed ring network topology where feeding lines are protected with directional overcurrent protection relays

Signals

Table 276: DPHLPDOC Input signals

Name

I_A

I_B

I_C

I

2

Type

SIGNAL

SIGNAL

SIGNAL

SIGNAL

U_A_AB SIGNAL

U_B_BC SIGNAL

U_C_CA SIGNAL

U

1

SIGNAL


0

0

Default

0

0

0

0

0

0

Description

Phase A current

Phase B current

Phase C current

Negative phase sequence current

Phase-to-earth voltage A or phase-tophase voltage AB

Phase-to-earth voltage B or phase-tophase voltage BC

Phase-to-earth voltage C or phase-tophase voltage CA

Positive phase sequence voltage

289


Name

U

2

BLOCK

ENA_MULT

NON_DIR

Type

SIGNAL

BOOLEAN

BOOLEAN

BOOLEAN

Default

0

0=False

0=False

0=False

Description

Negative phase sequence voltage


Enabling signal for current multiplier

Forces protection to non-directional

U_B_BC

U_C_CA

U

1

U

2

BLOCK

Table 277: DPHHPDOC Input signals

Name

I_A

I_B

I_C

I

2

Type

SIGNAL

SIGNAL

SIGNAL

SIGNAL

U_A_AB SIGNAL

SIGNAL

SIGNAL

SIGNAL

SIGNAL

BOOLEAN

ENA_MULT

NON_DIR

BOOLEAN

BOOLEAN

Table 278: DPHLPDOC Output signals

Name

OPERATE

START

Type

BOOLEAN

BOOLEAN

0=False

0=False

0

0

Default

0

0

0

0

0

0

0

0=False

Description

Operate

Start

Description

Phase A current

Phase B current

Phase C current


Phase to earth voltage A or phase to phase voltage AB

Phase to earth voltage B or phase to phase voltage BC

Phase to earth voltage C or phase to phase voltage CA






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1MRS757644 H

Table 279: DPHHPDOC Output signals

Name

START

OPERATE

Type

BOOLEAN

BOOLEAN

4.1.3.9

Settings

Table 280: DPHLPDOC Group settings (Basic)

Parameter

Start value

Start value Mult

Time multiplier

Values (Range)

0.05...5.00

0.8...10.0

0.05...15.00

Unit xIn



1=ANSI Ext. inv.

2=ANSI Very inv.

3=ANSI Norm. inv.

4=ANSI Mod. inv.

5=ANSI Def. Time

6=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. inv.

15=IEC Def. Time

17=Programmable

18=RI type

19=RD type

Directional mode

1=Non-directional

2=Forward

3=Reverse

Characteristic angle

-179...180

Max forward angle 0...90

ms deg deg

Max reverse angle 0...90

deg

Min forward angle 0...90

Min reverse angle 0...90

deg deg

Step

0.01

0.1

0.01

10

1

1

1

1

1

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Technical Manual


Description

Start

Operate

Default

0.05

1.0

1.00

40

15=IEC Def. Time

Description

Start value



Operate delay time


2=Forward

80

80

60

80

80

Directional mode


Maximum phase angle in forward direction

Maximum phase angle in reverse direction

Minimum phase angle in forward direction

Minimum phase angle in reverse direction

291


Table 281: DPHLPDOC Group settings (Advanced)



2=Def time reset

3=Inverse reset

Voltage Mem time 0...3000

Unit ms

Step

1

Pol quantity

1=Self pol

4=Neg. seq. volt.

5=Cross pol

7=Pos. seq. volt.

Table 282: DPHLPDOC Non group settings (Basic)

Parameter

Operation

Values (Range)

1=on

5=off

Num of start phases

1=1 out of 3

2=2 out of 3

3=3 out of 3


Unit Step

1





1

1

1

1

Table 283: DPHLPDOC Non group settings (Advanced)

Parameter


Values (Range)

20...60000

Unit ms

Step

1

Reset delay time

Measurement mode

Allow Non Dir

0...60000

1=RMS

2=DFT

3=Peak-to-Peak

0=False

1=True ms 1


1MRS757644 H

Default

1=Immediate

40

5=Cross pol

Description


Voltage memory time

Reference quantity used to determine fault direction

Default

20

20

2=DFT

0=False

Default

1=on

1=1 out of 3

28.2000

0.1217

2.00

29.10

1.0

Description

Operation Off / On







Description


Reset delay time


Allows prot activation as non-dir when dir info is invalid

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1MRS757644 H

Parameter

Min operate current

Min operate voltage

Values (Range)

0.01...1.00

0.01...1.00

Unit xIn xUn

Table 284: DPHHPDOC Group settings (Basic)

Parameter

Start value

Start value Mult

Values (Range)

0.10...40.00

0.8...10.0

Unit xIn

Directional mode

Time multiplier

1=Non-directional

2=Forward

3=Reverse

0.05...15.00


1=ANSI Ext. inv.

3=ANSI Norm. inv.

5=ANSI Def. Time

9=IEC Norm. inv.

10=IEC Very inv.

12=IEC Ext. inv.

15=IEC Def. Time

17=Programmable



-179...180


ms deg deg




deg deg deg

Step

0.01

0.01

Step

0.01

0.1

0.01

1

1

10

1

1

1

Table 285: DPHHPDOC Group settings (Advanced)



2=Def time reset

3=Inverse reset

Voltage Mem time 0...3000

Pol quantity

1=Self pol

4=Neg. seq. volt.

5=Cross pol

7=Pos. seq. volt.

ms

Step

1


Default

0.01

0.01

Default

0.10

1.0

2=Forward

Description

Minimum operating current

Minimum operating voltage

Description

Start value


Directional mode

1.00

15=IEC Def. Time



80

80

40

60

80

80

Operate delay time






Default

1=Immediate

40

5=Cross pol

Description


Voltage memory time


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Technical Manual

293


Table 286: DPHHPDOC Non group settings (Basic)

Parameter

Operation

Values (Range)

1=on

5=off


Unit Step

1





Num of start phases

1=1 out of 3

2=2 out of 3

3=3 out of 3

1

1

1

1

Table 287: DPHHPDOC Non group settings (Advanced)

Parameter

Reset delay time


Values (Range)

0...60000

20...60000

Unit ms ms

Step

1

1

Allow Non Dir

0=False

1=True

Measurement mode

Min operate current

Min operate voltage

1=RMS

2=DFT

3=Peak-to-Peak

0.01...1.00

0.01...1.00

xIn xUn

0.01

0.01

1MRS757644 H

Default

1=on

28.2000

0.1217

2.00

29.10

1.0

1=1 out of 3

Description

Operation Off / On







Default

20

20

0=False

2=DFT

0.01

0.01

Description

Reset delay time






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1MRS757644 H

4.1.3.10

Monitored data

Table 288: DPHLPDOC Monitored data

Name

START_DUR

Type

FLOAT32


0.00...100.00

%

FAULT_DIR

DIRECTION

DIR_A

DIR_B

DIR_C

Enum

Enum

Enum

Enum

Enum

ANGLE_A

ANGLE_B

ANGLE_C

FLOAT32

FLOAT32

FLOAT32


0=unknown

1=forward

2=backward

3=both

0=unknown

1=forward

2=backward

3=both

0=unknown

1=forward

2=backward

-1=both

0=unknown

1=forward

2=backward

-1=both

0=unknown

1=forward

2=backward

-1=both

-180.00...180.00

deg

-180.00...180.00

deg

-180.00...180.00

deg


Description


Detected fault direction

Direction information

Direction phase

A

Direction phase

B

Direction phase

C

Calculated angle difference, Phase

A


B


C

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Name

VMEM_USED

DPHLPDOC

Type

BOOLEAN

Enum


0=False

1=True

1=on

2=blocked

3=test

4=test/blocked

5=off

Table 289: DPHHPDOC Monitored data

Name

START_DUR

Type

FLOAT32


0.00...100.00

%

FAULT_DIR

DIRECTION

DIR_A

DIR_B

DIR_C

Enum

Enum

Enum

Enum

Enum


0=unknown

1=forward

2=backward

3=both

0=unknown

1=forward

2=backward

3=both

0=unknown

1=forward

2=backward

-1=both

0=unknown

1=forward

2=backward

-1=both

0=unknown

1=forward

2=backward

-1=both

296

1MRS757644 H

Description

Voltage memory in use status

Status

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Description




Direction phase

A

Direction phase

B

Direction phase

C


Name

ANGLE_A

ANGLE_B

Type

FLOAT32

FLOAT32

ANGLE_C FLOAT32

VMEM_USED BOOLEAN

DPHHPDOC Enum


-180.00...180.00

deg

-180.00...180.00

deg

-180.00...180.00

deg

Description


A


B


C

Voltage memory in use status

Status

0=False

1=True

1=on

2=blocked

3=test

4=test/blocked

5=off

4.1.3.11

Technical data

Table 290: DPHxPDOC Technical data

Characteristic

Operation accuracy

Start time ,

DPHLPDOC

DPHHPDOC

I value

= 2.0 x set Start

Value

Depending on the frequency of the current/voltage measured: f n

±2 Hz

Current:


Voltage:

±1.5% of the set value or ±0.002 × U n

Phase angle: ±2°

Current:



)



)

Voltage:


Phase angle: ±2°

Minimum Typical

43 ms 39 ms

Typically 40 ms

Typically 0.96

Maximum

47 ms

Reset time

Reset ratio


1

2

Measurement mode and Pol quantity = default, current before fault = 0.0 × I n fault = 1.0 × U n

, f n

, voltage before

= 50 Hz, fault current in one phase with nominal frequency injected from random phase angle, results based on statistical distribution of 1000 measurements


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Characteristic

Retardation time




4.1.3.12

Value

<35 ms




, where n = 2, 3, 4, 5,…


Table 291: DPHHPDOC Technical revision history


B

C

D

E

Change

Added a new input NON_DIR


Time multiplier setting.

Monitored data VMEM_USED indicating voltage memory use.

Internal improvement.

Table 292: DPHLPDOC Technical revision history


B

C

D

E

Change

Added a new input NON_DIR



Monitored data VMEM_USED indicating voltage memory use.


4.1.4

4.1.4.1

Directional three-independent-phase directional overcurrent protection DPH3xPDOC

Identification



DPH3LPDOC

3_3I> ->

ANSI/IEEE

C37.2 device number

67-1_3 Directional three-independentphase directional overcurrent protection, low stage

Directional three-independentphase directional overcurrent protection, high stage

DPH3HPDOC 3I_3>> -> 67-2_3

3 Maximum Start value = 2.5 × I n


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1MRS757644 H

4.1.4.2

Function block


4.1.4.3

4.1.4.4


Functionality

Directional three-independent-phase directional overcurrent protection function

DPH3xPDOC is used as one-phase, two-phase or three-phase directional overcurrent and short circuit protection for feeders.

DPH3xPDOC starts when the value of the current exceeds the set limit and directional criterion is fulfilled. Each phase has its own timer. The operation time characteristics for the low stage, DPH3LPDOC, and the high stage, DPH3HPDOC, can be selected to be either definite time (DT) or inverse definite minimum time

(IDMT).

In the DT mode, the function operates after a predefined operation time and resets when the fault current disappears. The IDMT mode provides current-dependent timer characteristics.




The operation of DPH3xPDOC can be described using a module diagram. All the modules in the diagram are explained in the next sections.

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300



The directional calculation compares the current phasors to the polarizing phasor.

A suitable polarization quantity can be selected from the different polarization quantities, which are the positive-sequence voltage, negative-sequence voltage, self-polarizing (faulted) voltage and cross-polarizing voltages (healthy voltages).

The polarizing method is defined with the Pol quantity setting.

Table 293: Polarizing quantities

Polarizing quantity

Pos. seq. volt

Neg. seq. volt

Self pol

Cross pol

Description



Self polarization

Cross polarization


The user can select either "Non-directional", "Forward" or "Reverse" operation. By setting the value of Allow Non Dir to "True", the non-directional operation is allowed when the directional information is invalid.

The Characteristic angle setting is used to turn the directional characteristic. The value of Characteristic angle should be chosen in such a way that all the faults in the operating direction are seen in the operating zone and all the faults in the

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1MRS757644 H Protection functions opposite direction are seen in the non-operating zone. The value of Characteristic angle depends on the network configuration.

Reliable operation requires both the operating and polarizing quantities to exceed certain minimum amplitude levels. The minimum amplitude level for the operating quantity (current) is set with the Min operate current setting. The minimum amplitude level for the polarizing quantity (voltage) is set with the Min operate voltage setting. If the amplitude level of the operating quantity or polarizing quantity is below the set level, the direction information of the corresponding phase is set to "Unknown".

The polarizing quantity validity can remain valid even if the amplitude of the polarizing quantity falls below the value of the Min operate voltage setting. In this case, the directional information is provided by a special memory function for a time defined with the Voltage Mem time setting.

DPH3xPDOC is provided with a memory function to secure a reliable and correct directional IED operation in case of a close short circuit or an earth fault characterized by an extremely low voltage. At the sudden loss of the polarization quantity, the angle difference is calculated on the basis of a fictive voltage. The fictive voltage is calculated using the positive-phase sequence voltage measured before the fault occurred, assuming that the voltage is not affected by the fault.

The memory function enables the function to operate up to a maximum of three seconds after a total loss of voltage. This time can be set with the Voltage

Mem time setting. The voltage memory cannot be used for the negative-sequence voltage polarization because it is not possible to substitute the positive-sequence voltage for negative-sequence voltage without knowing the network asymmetry level. This is the reason why the fictive voltage angle and corresponding direction information are frozen immediately for this polarization mode when the need for a voltage memory arises, and these are kept frozen until the time set with Voltage

Mem time elapses.

The value for the Min operate voltage setting should be carefully selected since the accuracy in low signal levels is strongly affected by the measuring device accuracy.

When the voltage falls below Min operate voltage at a close fault, the fictive voltage is used to determine the phase angle. The measured voltage is applied again as soon as the voltage rises above Min operate voltage and hysteresis. The fictive voltage is discarded if the fault current disappears while the fictive voltage is in use. When the voltage is below Min operate voltage and hysteresis and the fictive voltage is unusable, the fault direction cannot be determined.. The fictive voltage can be unusable for two reasons:

• The fictive voltage is discarded if the fault current disappears while the fictive voltage is in use

• The phase angle cannot be reliably measured before the fault situation.

DPH3xPDOC can be forced to non-directional operation with the NON_DIR input.

When the NON_DIR input is active, DPH3xPDOC operates as a non-directional overcurrent protection regardless of the Directional mode setting.

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302

Figure 150: Operating zones at minimum magnitude levels

Level detector

The measured phase currents are compared phasewise to the set Start value. If the measured value exceeds the set Start value,the level detector reports the exceeding of the value, together with the directional results of that phase, to the phase selection logic. If the ENA_MULT input is active, the Start value setting is multiplied by the Start value Mult setting.

The IED does not accept the Start value or Start value Mult setting if the product of these settings exceeds the Start value setting range.



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The phase selection logic detects the faulty phase or phases and controls the timers according to the set value of the Num of start phases setting.

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304

Figure 152: Logic diagram for phase selection module

When the Number of start phase setting is set to "1 out of 3" and the fault is in one or several phases, the phase selection logic sends an enabling signal to the faulty phase timers. If the fault disappears, the related timer-enabling signal is removed.

When the Number of start phase setting is "2 out of 3" or "3 out of 3", single-phase faults are not detected. The value "3 out of 3" requires the fault to be present in all three phases.

Timer A, Timer B, Timer C

The function design contains three independent phase-segregated timers which are controlled by common settings. This design allows a true three-phase overcurrent protection which is useful in some applications.

The common START and OPERATE outputs are created by "ORing" the phasespecific starting and operating outputs.

Each phase has its own phase-specific starting and operating outputs: ST_A , ST_B ,

ST_C , OPR_A , OPR_B and OPR_C .

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Once activated, each timer activates its START output. Depending on the value of the Operating curve type setting, the time characteristics are according to DT or



When the programmable IDMT curve is selected, the operation time characteristics are defined by the parameters Curve parameter A, Curve parameter B, Curve parameter C, Curve parameter D and Curve parameter E.

The shortest IDMT operation time is adjustable. The setup can be done with a global parameter in the HMI menu: Configuration > System >

IDMT Sat point. More information can be found in Chapter 11 General function block features in this manual.

If a drop-off situation happens, that is, a fault suddenly disappears before the operation delay is exceeded, the timer reset state is activated. The functionality of the timer in the reset state depends on the combination of the Operating curve type, Type of reset curve and Reset delay time settings. When the DT characteristic is selected, the reset timer runs until the set Reset delay time value is exceeded.


"Immediate", "Def time reset" or "Inverse reset". The reset curve type "Immediate" causes an immediate reset. With the reset curve type "Def time reset", the reset time depends on the Reset delay time setting. With the reset curve type "Inverse reset", the reset time depends on the current during the drop-off situation. If the drop-off situation continues, the reset timer is reset and the START output is deactivated.

The "Inverse reset" selection is only supported with ANSI or programmable IDMT operating curves. If another operating curve type is selected, an immediate reset occurs during the drop-off situation.

The Time multiplier setting is used for scaling the IDMT operating and reset times.

The setting parameter Minimum operate time defines the minimum desired operating time for IDMT. The setting is applicable only when the IDMT curves are used.


information, see Chapter 11 General function block features in this

manual.


Blocking logic

There are three operation modes in the blocking function. The operation modes are controlled by the BLOCK input and the global setting in Configuration > System >

Blocking mode which selects the blocking mode. The BLOCK input can be controlled by a binary input, a horizontal communication input or an internal signal of the IED program. The influence of the BLOCK signal activation is preselected with the global setting Blocking mode.

The Blocking mode setting has three blocking methods. In the "Freeze timers" mode, the operation timer is frozen to the prevailing value. In the "Block all" mode, the whole function is blocked and the timers are reset. In the "Block OPERATE

305


4.1.4.5

1MRS757644 H output" mode, the function operates normally but the OPERATE , OPR_A , OPR_B and

OPR_C outputs are not activated.


DPH3xPDOC supports both DT and IDMT characteristics. The timer characteristics can be selected with the Operating curve type and Type of reset curve settings.


The IED provides 16 IDMT characteristics curves, of which seven comply with the

IEEE C37.112 and six with the IEC 60255-3 standard. Two curves follow the special characteristics of the ABB praxis and are referred to as RI and RD. In addition to this, a programmable curve can be used if none of the standard curves are applicable. The DT characteristic can be chosen by selecting the Operating curve type values "ANSI Def. Time" or "IEC Def. Time". The functionality is identical in both cases.

The list of characteristics, which matches the list in the IEC 61850-7-4 specification, indicates the characteristics supported by different stages.

Table 294: IDMT curves supported by different stages

Operating curve type Supported by










(11) IEC Inverse




(17) Programmable

DPH3LPDOC x x x x x x x x x x x x x x

DPH3HPDOC x x x x x x

For a detailed description of the timers, see Chapter 11 General function block features

in this manual.

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4.1.4.6


(1) Immediate

(2) Def time reset

(3) Inverse reset

Supported by

DPH3LPDOC x

DPH3HPDOC x x x x x

Note



Available only for AN-

SI and user programmable curves

Directional overcurrent characteristics



In the forward operation area, the Max forward angle setting gives the counterclockwise sector and the Min forward angle setting gives the corresponding clockwise sector, measured from the Characteristic angle setting.

In the backward operation area, the Max reverse angle setting gives the counterclockwise sector and the Min reverse angle setting gives the corresponding clockwise sector, a measurement from the Characteristic angle setting that has been rotated 180 degrees.

Relay characteristic angle (RCA) is set positive if the operating current lags the polarizing quantity and negative if the operating current leads the polarizing quantity.

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308

Figure 153: Configurable operating sectors

Table 295: Momentary per phase direction value for monitored data view

Criterion for per phase direction information

The ANGLE_X is not in any of the defined sectors, or the direction cannot be defined due too low amplitude

The ANGLE_X is in the forward sector

The ANGLE_X is in the reverse sector

The ANGLE_X is in both forward and reverse sectors, that is, when the sectors are overlapping

The value for DIR_A/_B/_C

0 = unknown

1 = forward

2 = backward

3 = both

Table 296: Momentary phase combined direction value for monitored data view

Criterion for phase combined direction information

The direction information (DIR_X) for all phases is unknown

The direction information (DIR_X) for at least one phase is forward, none being in reverse

The direction information (DIR_X) for at least one phase is reverse, none being in forward

The direction information (DIR_X) for some phase is forward and for some phase is reverse


0 = unknown

1 = forward

2 = backward

3 = both

FAULT_DIR gives the detected direction of the fault during fault situations, that is, when the START output is active.

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Self-polarizing as polarizing method

Table 297: Equations for calculating angle difference for self-polarizing method


A


I

A


U

A

B I

B

U

B

C

A - B

I

C

I

A

- I

B

U

C

U

AB

B - C

C - A

I

B

- I

C

I

C

- I

A

U

BC

U

CA

ANGLE

ANGLE

ANGLE

ANGLE

ANGLE

ANGLE

_

_

_

_

_

_

A

B

C

A

B

C

= ϕ

= ϕ

= ϕ

( U

A

) ϕ ( I

A

) ϕ

RCA

( U

B

) ϕ ( I

B

) ϕ

RCA

( U

C

) ϕ ( I

C

) ϕ

= ϕ

( U

= ϕ ( U

BC

RCA

AB

) ϕ

( I

A

I

B

) ϕ

RCA

) ϕ ( I

B

I

C

) ϕ

RCA

= ϕ ( U

CA

) ϕ ( I

C

I

A

) ϕ

RCA

In an example case of the phasors in a single-phase earth fault where the faulted phase is phase A, the angle difference between the polarizing quantity U

A


A

is marked as φ. In the self-polarization method, there is no need to rotate the polarizing quantity.

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In an example case of a two-phase short-circuit failure where the fault is between phases B and C, the angle difference is measured between the polarizing quantity U

BC


B

- I

C

in the self-polarizing method.

309


310


Cross-polarizing as polarizing quantity

Table 298: Equations for calculating angle difference for cross-polarizing method

Faulted phases

A

B

C

A - B

B - C

C - A


I

A


U

BC

I

B

I

C

I

A

- I

B

I

B

- I

C

I

C

- I

A

U

CA

U

AB

U

BC

- U

CA

U

CA

- U

AB

U

AB

- U

BC

Angle difference

ANGLE

ANGLE

ANGLE

ANGLE

ANGLE

ANGLE

_

_

_

_

_

_

A

B

C

A

B

C

=

=

=

=

=

= ϕ ϕ ϕ ϕ ϕ ϕ

(

(

( U

BC

) ϕ ( I

A

) ϕ

RCA

( U

CA

) ϕ ( I

B

) -

(

( U

U

U

U

AB

BC

CA

AB

) ϕ ( I

C

) ϕ ϕ

RCA

RCA

+ 90 o

+

+

90 o

90 o

U

CA

) ϕ

( I

A

I

B

) ϕ

RCA

-

-

U

U

AB

BC

) ϕ ( I

B

I

C

) ϕ

RCA

) ϕ ( I

C

I

A

) ϕ

RCA

+

90 o

+

+

90 o

90 o

The angle difference between the polarizing quantity U

A

BC


is marked as φ in an example of the phasors in a single-phase earth fault where the faulted phase is phase A. The polarizing quantity is rotated with 90 degrees. The characteristic angle is assumed to be ~ 0 degrees.

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In an example of the phasors in a two-phase short-circuit failure where the fault is between the phases B and C, the angle difference is measured between the polarizing quantity U

AB


B

- I

C

marked as φ.

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312


The equations are valid when network rotating direction is counterclockwise, that is, ABC. If the network rotating direction is reversed,

180 degrees is added to the calculated angle difference. This is done automatically with a system parameter Phase rotation.

Negative sequence voltage as polarizing quantity

When the negative voltage is used as the polarizing quantity, the angle difference between the operating and polarizing quantity is calculated with the same formula for all fault types:

ANGLE _ X

= ϕ (

−

U

2

)

− ϕ ( I

2

)

− ϕ

RCA

(Equation 7)

This means that the actuating polarizing quantity is -U

2

.

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U

A

I

A

U

A

I

A U

2

I

2

U

CA

I

B

U

AB

I

C

I

C U

2

I

2

U

B

U

C

U

B

U

C

U

BC

A B

Figure 158: Phasors in a single-phase earth fault, phases A-N, and two-phase short circuit, phases B and C, when the actuating polarizing quantity is the negativesequence voltage -U2

I

B

Positive sequence voltage as polarizing quantity

Table 299: Equations for calculating angle difference for positive-sequence quantity polarizing method


A


I

A

B I

B


U

1

U

1

ANGLE

ANGLE

_

_

A

B

=

= ϕ ϕ

(

( U

U

1

1

)

)

−

− ϕ ϕ

(

(

I

I

A

B

)

)

−

− ϕ

RCA ϕ

RCA −

120 o

C I

C

U

1

ANGLE _ C = ϕ ( U

1

) − ϕ ( I

C

) − ϕ

RCA

+ 120 o

A - B I

A

- I

B

U

1

ANGLE _ A = ϕ ( U

1

) − ϕ ( I

A

− I

B

) − ϕ

RCA

+ 30 o

B - C I

B

- I

C

U

1

ANGLE _ B

= ϕ ( U

1

)

− ϕ ( I

B

−

I

C

)

− ϕ

RCA

−

90 o

C - A I

C

- I

A

U

1

ANGLE _ C

= ϕ

( U

1

)

− ϕ

( I

C

−

I

A

)

− ϕ

RCA

+

150 o

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I

A

U

1

U

A

I

A

U

A

U

1

-90°

I

B

I

B

- I c

-I

C

I

C

I

B

I

C

U

C

U

B

U

C

U

B

A B

Figure 159: Phasors in a single-phase earth fault, phase A to ground, and a twophase short circuit, phases B-C, are short-circuited when the polarizing quantity is the positive-sequence voltage U 1

Network rotation direction

Typically, the network rotatiion direction is counterclockwise and defined as "ABC".

If the network rotation direction is reversed, meaning clockwise, that is, "ACB", the equations for calculating the angle difference need to be changed. The network rotation direction is defined with a system parameter Phase rotation. The change in the network rotation direction affects the polarization method of the phase-tophase voltages where the calculated angle difference needs to be rotated 180 degrees. Also, when the sequence components are used, the calculation of the components is affected but the angle difference calculation remains the same.

The sequence components are the positive-sequence voltage or negative-sequence voltage components. When the phase-to-ground voltages are used as the polarizing method, the network rotation direction change has no effect on the direction calculation.

The network rotation direction is set in the IED using the parameter in the HMI menu Configuration > System > Phase rotation. The default parameter value is "ABC".

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4.1.4.7

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NETWORK ROTATION ABC

U

A

I

A

NETWORK ROTATION ACB

U

A

I

A

U

CA

U

AB

U

AB

I

B

I

C

U

C

U

BC

U

B

U

B

Figure 160: Examples of network rotating direction

I

B

U

BC

U

CA

I

C

U

C

Application

DPH3xPDOC is used as short circuit protection in three-phase distribution or sub transmission networks operating at 50 Hz.

In radial networks, phase overcurrent IEDs are often sufficient for the short circuit protection of lines, transformers and other equipment. The current-time characteristic should be chosen according to the common practice in the network.

It is recommended to use the same current-time characteristic for all overcurrent

IEDs in the network. This includes the overcurrent protection of transformers and other equipment.

The phase overcurrent protection can also be used in closed ring systems as short circuit protection. Because the setting of a phase overcurrent protection system in closed ring networks can be complicated, a large number of fault current calculations are needed. There are situations with no possibility to have the selectivity with a protection system based on overcurrent IEDs in a closed ring system.

In some applications, the possibility of obtaining the selectivity can be improved significantly if DPH3xPDOC is used. This can also be done in the closed ring networks and radial networks with the generation connected to the remote in the system, thus giving fault current infeed in the reverse direction. Directional overcurrent IEDs are also used to have a selective protection scheme, for example in case of parallel distribution lines or power transformers fed by the same single source. DPH3xPDOC is also used in the ring-connected supply feeders between substations or feeders with two feeding sources.

Parallel lines or transformers

When the lines are connected in parallel and a fault occurs in one of the lines, it is practical to have DPH3xPDOC to detect the direction of the fault. Otherwise, there is a risk that the fault situation in one part of the feeding system can de-energize the whole system connected to the LV-side.

315


Figure 161: Overcurrent protection of parallel lines using directional protection relays

DPH3xPDOC can be used for parallel operating transformer applications. In these applications, there is a possibility that the fault current can also be fed from the LVside up to the HV-side. Therefore, the transformer is also equipped with directional overcurrent protection.

316

Figure 162: Overcurrent protection of parallel operating transformers

Closed ring network topology

The closed-ring network topology is used in applications where electricity distribution for the consumers is secured during network fault situations. The power is fed from at least two directions, which means that the current direction can be varied. The time-grading between the network level stages is challenging without unnecessary delays in the time settings. In this case, it is practical to use the directional overcurrent IEDs to achieve a selective protection scheme.

Directional overcurrent functions can be used in closed-ring applications. The arrows define the operating direction of the directional functionality. The double arrows define the nondirectional functionality where faults can be detected in both directions.

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4.1.4.8

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Figure 163: Closed-ring network topology where feeding lines are protected with directional overcurrent IEDs

Signals

Table 300: DPH3LPDOC Input signals

Name

I_A

I_B

I_C

I

2

Type

SIGNAL

SIGNAL

SIGNAL

SIGNAL

U_A_AB SIGNAL

Default

0

0

0

0

0

U_B_BC SIGNAL 0

U_C_CA SIGNAL

U

1

SIGNAL


0

0

Description

Phase A current

Phase B current

Phase C current


Phase-to-earth voltage A or phase-tophase voltage AB

Phase-to-earth voltage B or phase-tophase voltage BC

Phase-to-earth voltage C or phase-tophase voltage CA


317


318

1MRS757644 H

Name

U

2

BLOCK

ENA_MULT

NON_DIR

Type

SIGNAL

BOOLEAN

BOOLEAN

BOOLEAN

Default

0

0=False

0=False

0=False

Description





U_B_BC

U_C_CA

U

1

U

2

BLOCK

Table 301: DPH3HPDOC Input signals

Name

I_A

I_B

I_C

I

2

Type

SIGNAL

SIGNAL

SIGNAL

SIGNAL

U_A_AB SIGNAL

Default

0

0

0

0

0

SIGNAL

SIGNAL

SIGNAL

SIGNAL

BOOLEAN

ENA_MULT

NON_DIR

BOOLEAN

BOOLEAN

Table 302: DPH3LPDOC Output signals

Name Type

OPERATE

START

BOOLEAN

BOOLEAN


0=False

0=False

0

0

0

0

0=False

Description

Operate

Start

Description

Phase A current

Phase B current

Phase C current


Phase to earth voltage A or phase to phase voltage AB

Phase to earth voltage B or phase to phase voltage BC

Phase to earth voltage C or phase to phase voltage CA






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1MRS757644 H

Name

OPR_A

OPR_B

OPR_C

ST_A

ST_B

ST_C

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Table 303: DPH3HPDOC Output signals

Name

OPERATE

START

OPR_A

OPR_B

OPR_C

ST_A

ST_B

ST_C

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

4.1.4.9

Settings

Table 304: DPH3LPDOC Group settings (Basic)

Parameter

Start value

Start value Mult

Values (Range)

0.05...5.00

0.8...10.0

Unit xIn




Step

0.01

0.1

0.01

10


Description

Operate phase A

Operate phase B

Operate phase C

Start phase A

Start phase B

Start phase C

Description

Operate

Start

Operate phase A

Operate phase B

Operate phase C

Start phase A

Start phase B

Start phase C

Default

0.05

1.0

1.00

40

Description

Start value



Operate delay time

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Parameter


Values (Range)

1=ANSI Ext. inv.

2=ANSI Very inv.

3=ANSI Norm. inv.

4=ANSI Mod. inv.

5=ANSI Def. Time

6=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. inv.

15=IEC Def. Time

17=Programmable

18=RI type

19=RD type

Directional mode

1=Non-directional

2=Forward

3=Reverse


-179...180


Unit deg deg


deg



deg deg

Step

Table 305: DPH3LPDOC Group settings (Advanced)



2=Def time reset

3=Inverse reset

Pol quantity

1=Self pol

4=Neg. seq. volt.

5=Cross pol

7=Pos. seq. volt.

Unit Step

1

1

1

1

1

1MRS757644 H

Default

15=IEC Def. Time

Description


2=Forward

80

80

60

80

80

Directional mode






Default

1=Immediate

5=Cross pol

Description



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Table 306: DPH3LPDOC Non group settings (Basic)

Parameter

Operation

Values (Range)

1=on

5=off

Num of start phases

1=1 out of 3

2=2 out of 3

3=3 out of 3


Unit Step

1


1




1

1

1

Table 307: DPH3LPDOC Non group settings (Advanced)

Parameter


Values (Range)

20...60000

Unit ms

Step

1

1 Reset delay time

Measurement mode

Allow Non Dir

Parameter

Start value

Start value Mult

Directional mode

0...60000

1=RMS

2=DFT

3=Peak-to-Peak

0=False

1=True ms

Min operate current

Min operate voltage

0.01...1.00

0.01...1.00

xIn xUn

Table 308: DPH3HPDOC Group settings (Basic)

Values (Range)

0.10...40.00

0.8...10.0

Unit xIn

Time multiplier

1=Non-directional

2=Forward

3=Reverse

0.05...15.00

0.01

0.01

Step

0.01

0.1

0.01


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Default

1=on

1=1 out of 3

28.2000

0.1217

2.00

29.10

1.0

Description

Operation Off / On







Default

20

20

2=DFT

0=False

0.01

0.01

Default

0.10

1.0

2=Forward

1.00

Description


Reset delay time





Description

Start value


Directional mode


321


Parameter


Values (Range)

1=ANSI Ext. inv.

3=ANSI Norm. inv.

5=ANSI Def. Time

9=IEC Norm. inv.

10=IEC Very inv.

12=IEC Ext. inv.

15=IEC Def. Time

17=Programmable



-179...180


Unit ms deg deg




deg deg deg

Step

Table 309: DPH3HPDOC Group settings (Advanced)



2=Def time reset

3=Inverse reset

Pol quantity

1=Self pol

4=Neg. seq. volt.

5=Cross pol

7=Pos. seq. volt.

Unit Step

Table 310: DPH3HPDOC Non group settings (Basic)

Parameter

Operation

Values (Range)

1=on

5=off


Unit Step

1


1




1

1

1

1

10

1

1

1

322

1MRS757644 H

Default

15=IEC Def. Time

Description


80

80

40

60

80

80

Operate delay time






Default

1=Immediate

5=Cross pol

Description



Default

1=on

28.2000

0.1217

2.00

29.10

Description

Operation Off / On





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Num of start phases

1=1 out of 3

2=2 out of 3

3=3 out of 3

Unit Step

1

Table 311: DPH3HPDOC Non group settings (Advanced)

Parameter

Reset delay time


Allow Non Dir

Values (Range)

0...60000

20...60000

0=False

1=True

Unit ms ms

Step

1

1

Measurement mode

Min operate current

Min operate voltage

1=RMS

2=DFT

3=Peak-to-Peak

0.01...1.00

0.01...1.00

xIn xUn

0.01

0.01

4.1.4.10

Default

1.0

1=1 out of 3

Default

20

20

0=False

2=DFT

0.01

0.01

Monitored data

Table 312: DPH3LPDOC Monitored data

Name

START_DUR

Type

FLOAT32


0.00...100.00

%

FAULT_DIR

DIRECTION

Enum

Enum


0=unknown

1=forward

2=backward

3=both

0=unknown

1=forward

2=backward

3=both

Description



Description

Reset delay time






Description




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Name

DIR_A

DIR_B

DIR_C

Type

Enum

Enum

Enum

ANGLE_A

ANGLE_B

ANGLE_C

FLOAT32

FLOAT32

FLOAT32

DPH3LPDOC Enum

1=on

2=blocked

3=test

4=test/blocked

5=off

Table 313: DPH3HPDOC Monitored data

Name

START_DUR

Type

FLOAT32


0.00...100.00

%

FAULT_DIR Enum


0=unknown

1=forward

2=backward

3=both


0=unknown

1=forward

2=backward

3=both

0=unknown

1=forward

2=backward

3=both

0=unknown

1=forward

2=backward

3=both

-180.00...180.00

deg

-180.00...180.00

deg

-180.00...180.00

deg

324

Description



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1MRS757644 H

Description

Direction phase

A

Direction phase

B

Direction phase

C


A


B


C

Status

1MRS757644 H

Name

DIRECTION

DIR_A

DIR_B

DIR_C

Type

Enum

Enum

Enum

Enum

ANGLE_A

ANGLE_B

FLOAT32

FLOAT32

ANGLE_C FLOAT32

DPH3HPDOC Enum


0=unknown

1=forward

2=backward

3=both

0=unknown

1=forward

2=backward

3=both

0=unknown

1=forward

2=backward

3=both

0=unknown

1=forward

2=backward

3=both

-180.00...180.00

deg

-180.00...180.00

deg

-180.00...180.00

deg

1=on

2=blocked

3=test

4=test/blocked

5=off


Description


Direction phase

A

Direction phase

B

Direction phase

C


A


B


C

Status

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4.1.4.11

Technical data

Table 314: DPH3xPDOC Technical data

Characteristic

Operation accuracy

Start time ,

Reset time

Reset ratio

Retardation time




DPH3LPDOC

DPH3HPDOC

I value

= 2.0 x set Start

Value

Depending on the frequency of the current/voltage measured: f n

±2 Hz

Current:


Voltage:


Phase angle: ±2°

Current:

±1.5% of the set value or ±0.002 × I

× I n

) n

(at currents in the range of 0.1…10

±5.0% of the set value (at currents in the range of 10…40 × I n

)

Voltage:


Phase angle: ±2°

Minimum

38 ms

Typical

40 ms

<40 ms

Typically 0.96

<35 ms


Maximum

43 ms


RMS: No suppression


, where n = 2, 3, 4, 5,…


Peak-to-Peak + backup: No suppression

1

2

3

Measurement mode and Pol quantity = default, current before fault = 0.0 × I fault = 1.0 × U n

, f n n

, voltage before

= 50 Hz, fault current in one phase with nominal frequency injected from random phase angle, results based on statistical distribution of 1000 measurements




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4.1.5

4.1.5.1

4.1.5.2

Three-phase voltage-dependent overcurrent protection

PHPVOC

Identification


Three-phase voltage-dependent overcurrent protection


PHPVOC


3I(U)>

ANSI/IEEE C37.2

device number

51V

Function block

4.1.5.3

4.1.5.4


Functionality

The three-phase voltage-dependent overcurrent protection function PHPVOC is used for single-phase, two-phase or three-phase voltage-dependent time overcurrent protection of generators against overcurrent and short circuit conditions.

PHPVOC starts when the input phase current exceeds a limit which is dynamically calculated based on the measured terminal voltages. The operating characteristics can be selected to be either inverse definite minimum time IDMT or definite time

DT.

PHPVOC contains a blocking functionality. It is possible to block function outputs, timers or the function itself, if desired.



The operation of PHPVOC can be described by using a module diagram. All the modules in the diagram are explained in the next sections.

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328


Effective start value calculator

The normal starting current above which the overcurrent protection starts is set through the Start value setting. The Effective start value of the current may need to be changed during certain conditions like magnetizing inrush or when the terminal voltages drop due to a fault. Hence, the effective start value calculator module dynamically calculates the effective start value above which the overcurrent protection starts.

Four methods of calculating the effective start value are provided in PHPVOC. These can be chosen with the Control mode setting to be either "Voltage control", "Input control", "Volt & Input Ctrl" or "No Volt dependency".

The calculated effective start value per phase, EFF_ST_VAL_A , EFF_ST_VAL_B ,

EFF_ST_VAL_C , is available in the Monitored data view and is used by the Level detector module.

All three phase-to-phase voltages should be available for the function to operate properly.

Voltage control mode

In the Voltage control mode, the Effective start value is calculated based on the magnitude of input voltages U_AB , U_BC and U_CA . The voltage dependency is phase sensitive, which means that the magnitude of one input voltage controls the start value of only the corresponding phase, that is, the magnitude of voltage inputs U_AB , U_BC and U_CA independently control the current start values of phases A, B and C.

Two voltage control characteristics, voltage step and voltage slope, can be achieved with the Voltage high limit and Voltage low limit settings.

The voltage step characteristic is achieved when the Voltage high limit setting is equal to the Voltage low limit setting. The effective start value is calculated based on the equations.

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Voltage level

U < Voltage high limit

U ≥ Voltage high limit

Effective start value (I> effective)

Start value low

Start value

In this example, U represents the measured input voltage. This voltage step characteristic is graphically represented in

Figure 166

.

620 series

Technical Manual

C

D

A

I>

Figure 166: Effective start value for voltage step characteristic

The voltage slope characteristic is achieved by assigning different values to Voltage high limit and Voltage low limit. The effective start value calculation is based on the equations.

Voltage level

U < Voltage low limit

U ≥ Voltage high limit

Effective start value (I> effective)

Start value low

Start value

If Voltage low limit ≤ U < Voltage high limit,

I > (effective)=A -









A- I >

C - D





(C -U)



(Equation 8) set Start value low set Start value set Voltage high limit set Voltage low limit

329


Here U represents the measured input voltage. The voltage slope characteristic is graphically represented.

330

Figure 167: Effective start value or voltage slope characteristic

To achieve the voltage slope characteristics, Voltage high limit must always be set to a value greater than Voltage low limit.

If Voltage high limit is lower than Voltage low limit, the voltage step characteristic is active with Voltage low limit being the cutoff value.

The value of the setting Start value should always be greater than the setting Start value low. Otherwise, Start value low is used as the effective start value.

External input control mode

The External input control mode is used to enable voltage control from an external application. If Control mode is set to the "Input Control" mode, the effective start value for all phases is influenced by the status of the binary input ENA_U_MULT .

If ENA

_

U

_

MULT isTRUE

:

Effective start value

=

Start value low

(Equation 9)

If ENA

_

U

_

MULT is FALSE

:

Effective start value

=

Start value

(Equation 10)

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Technical Manual

Voltage and input control mode

If Control mode is set to "Voltage and input Ctrl", both the "Voltage control" and "Input control" modes are used. However, the “Input control” functionality is dominant over the “Voltage control” mode when ENA_U_MULT is active.

No voltage dependency mode

When Control mode is set to "No Volt dependency", the effective start value has no voltage dependency and the function acts as a normal time overcurrent function with effective start value being equal to the Start value setting.

Level detector

The measured phase currents are compared phasewise to the calculated effective start value. If the measured value exceeds the calculated effective start value, the

Level detector reports the exceeding value to the phase selection logic. If the

ENA_MULT input is active, the effective start value is multiplied by the Start value

Mult setting.

Do not set the multiplier Start value Mult setting higher than necessary.

If the value is too high, the function may not operate at all during an inrush followed by a fault, no matter how severe the fault is.


INRPHAR is connected to the ENA_MULT input.


If the fault criteria are fulfilled in the level detector, the phase selection logic detects the phase or phases in which the measured current exceeds the setting. If the phase information matches the Num of start phases setting, the phase selection logic activates the Timer module.

Timer

Once activated, the Timer module activates the START output.

Depending on the value of the Operating curve type setting, the time characteristics are according to DT or IDMT. When the operation timer has reached the value of Operate delay time in the DT mode or the maximum value defined by the inverse time curve, the OPERATE output is activated.

When the user programmable IDMT curve is selected, the operation time characteristics are defined by the settings Curve parameter A, Curve parameter B,

Curve parameter C, Curve parameter D and Curve parameter E.

In a drop-off situation, that is, when a fault suddenly disappears before the operating delay is exceeded, the timer reset state is activated. The functionality of the Timer in the reset state depends on the combination of the Operating curve type, Type of reset curve and Reset delay time settings. When the DT characteristic is selected, the reset timer runs until the set Reset delay time value is exceeded.




331


4.1.5.5

332

1MRS757644 H


The Time multiplier is used for scaling the IDMT trip and reset times.

The Minimum operate time setting defines the minimum desired operating time for

IDMT operation. The setting is applicable only when the IDMT curves are used.

Though the Time multiplier and Minimum operate time settings are common for different IDMT curves, the operating time essentially depends upon the type of IDMT curve chosen.

The Timer calculates the start duration value START_DUR which indicates the percentage ratio of the start situation and the set operating time. This output is available in the Monitored data view.

Blocking logic

There are three operation modes in the blocking function. The operation modes are controlled by the BLOCK input and the global setting Configuration > System >

Blocking mode which selects the blocking mode. The BLOCK input can be controlled by a binary input, a horizontal communication input or an internal signal of the protection relay's program. The influence of the BLOCK signal activation is preselected with the global setting Blocking mode.

The Blocking mode setting has three blocking methods. In the "Freeze timers" mode, the operation timer is frozen to the prevailing value. In the "Block all" mode, the whole function is blocked and the timers are reset. In the "Block OPERATE output" mode, the function operates normally but the OPERATE output is not activated.

Application

The three-phase voltage-dependent overcurrent protection is used as a backup protection for the generators and system from damage due to the phase faults which are not cleared by primary protection and associated breakers.

In case of a short circuit, the sustained fault current of the generator, determined by the machine synchronous reactance, could be below the full-load current. If the generator excitation power is fed from the generator terminals, a voltage drop caused by a short circuit also leads to low fault current. The primary protection, like normal overcurrent protection, might not detect this kind of fault situation. In some cases, the automatic voltage regulator AVR can help to maintain high fault currents by controlling the generator excitation system. If the AVR is out of service or if there is an internal fault in the operation of AVR, the low fault currents can go unnoticed and therefore a voltage-depended overcurrent protection should be used for backup.

Two voltage control characteristics, voltage step and voltage slope, are available in PHPVOC. The choice is made based on the system conditions and the level of protection to be provided.

Voltage step characteristic is applied to generators used in industrial systems.

Under close-up fault conditions when the generator terminal voltages drop below the settable threshold value, a new start value of the current, well below the normal load current, is selected. The control voltage setting should ensure that PHPVOC does not trip under the highest loading conditions to which the system can be

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1MRS757644 H

4.1.5.6

Protection functions subjected. Choosing too high a value for the control voltage may allow an undesired operation of the function during wide-area disturbances. When the terminal voltage of the generator is above the control voltage value, the normal start value is used.

This ensures that PHPVOC does not operate during normal overloads when the generator terminal voltages are maintained near the normal levels.

Voltage slope characteristic is often used as an alternative to impedance protection on small to medium (5...150 MVA) size generators to provide backup to the differential protection. Other applications of the voltage slope characteristic protection exist in networks to provide better coordination and fault detection than plain overcurrent protection. The voltage slope method provides an improved sensitivity of overcurrent operation by making the overcurrent start value proportional to the terminal voltage. The current start value varies correspondingly with the generator terminal voltages between the set voltage high limit and voltage low limit, ensuring the operation of PHPVOC despite the drop in fault current value.

The operation of PHPVOC should be time-graded with respect to the main protection scheme to ensure that PHPVOC does not operate before the main protection.

Signals

Table 315: PHPVOC Input signals

Name

I_A

I_B

I_C

U_AB

Type

SIGNAL

SIGNAL

SIGNAL

SIGNAL

U_BC

U_CA

BLOCK

SIGNAL

SIGNAL

BOOLEAN

ENA_MULT

ENA_LOW_LIM

BOOLEAN

BOOLEAN

0

0

Default

0

0

0

0

0=False

0=False

0=False

Description

Phase A current

Phase B current

Phase C current

Phase-to-phase voltage AB

Phase-to-phase voltage BC

Phase-to-phase voltage CA



Enable signal for voltage dependent lower start value

Table 316: PHPVOC Output signals

Name

OPERATE

START

Type

BOOLEAN

BOOLEAN

Description

Operate

Start

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4.1.5.7

Settings

Table 317: PHPVOC Group settings (Basic)

Parameter

Start value

Start value low

Values (Range)

0.05...5.00

0.05...1.00

Unit xIn xIn

Voltage high limit 0.01...1.00

Voltage low limit

Start value Mult

Time multiplier

0.01...1.00

0.8...10.0

0.05...15.00

xUn xUn


1=ANSI Ext. inv.

2=ANSI Very inv.

3=ANSI Norm. inv.

4=ANSI Mod. inv.

5=ANSI Def. Time

6=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. inv.

15=IEC Def. Time

17=Programmable

18=RI type

19=RD type


ms

Table 318: PHPVOC Group settings (Advanced)



2=Def time reset

3=Inverse reset

Unit

Step

0.01

0.01

0.01

0.01

0.1

0.01

10

Step

Table 319: PHPVOC Non group settings (Basic)

Parameter

Operation

Values (Range)

1=on

5=off

Num of start phases

1=1 out of 3

2=2 out of 3

3=3 out of 3


Unit

334

Step

1MRS757644 H

1.00

1.00

1.0

1.00

Default

0.05

0.05

15=IEC Def. Time

Description

Start value

Lower start value based on voltage control

Voltage high limit for voltage control

Voltage low limit for voltage control




40 Operate delay time

Default

1=Immediate

Description


Default

1=on

1=1 out of 3

Description

Operation Off / On


620 series

Technical Manual




Unit





1

1

Step

1

1

1

Default

28.2000

0.1217

2.00

29.10

1.0

Description






Table 320: PHPVOC Non group settings (Advanced)

Parameter

Measurement mode

Control mode

Values (Range)

1=RMS

2=DFT

3=Peak-to-Peak

1=Voltage control

2=Input control

3=Voltage and input Ctl

4=No Volt dependency

40...60000

Unit ms

Step

1 Minimum operate time

Reset delay time 0...60000

ms 1

4.1.5.8

EFF_ST_VAL_A FLOAT32

EFF_ST_VAL_B FLOAT32


0.00...50.00

0.00...50.00

Default

2=DFT

1=Voltage control Type of control

40

20

Monitored data

Table 321: PHPVOC Monitored data

Name

START_DUR

Type

FLOAT32


0.00...100.00

% xIn xIn

Description



Reset delay time

Description


Effective start value for phase A

Effective start value for phase B

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Name

EFF_ST_VAL_C

PHPVOC

Type

FLOAT32

Enum


0.00...50.00

xIn

1=on

2=blocked

3=test

4=test/blocked

5=off

Description

Effective start value for phase C

Status

4.1.5.9

Technical data

Table 322: PHPVOC Technical data

Characteristic

Operation accuracy

Start time , 2

Reset time

Reset ratio




4.1.6

4.1.6.1

Value

Depending on the frequency of the measured current and voltage: f n

±2 Hz

Current:

±1.5% of the set value or ± 0.002 × I n

Voltage:


Typically 26 ms

Typically 40 ms

Typically 0.96



-50 dB at f = n × f n

, where n = 2, 3, 4, 5,…

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

Identification


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


T1PTTR


3Ith>F

ANSI/IEEE C37.2

device number

49F

336

1

2

Measurement mode = default, current before fault = 0.0 × I distribution of 1000 measurements

Includes the delay of the signal output contact n

, f n

= 50 Hz, fault current in one phase with nominal frequency injected from random phase angle, results based on statistical

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1MRS757644 H

4.1.6.2

Function block


4.1.6.3

4.1.6.4


Functionality

The increased utilization of power systems closer to the thermal limits has generated a need for a thermal overload function for power lines as well.

A thermal overload is in some cases not detected by other protection functions, and the introduction of the three-phase thermal protection for feeders, cables and distribution transformers function T1PTTR allows the protected circuit to operate closer to the thermal limits.

An alarm level gives an early warning to allow operators to take action before the line trips. The early warning is based on the three-phase current measuring function using a thermal model with first order thermal loss with the settable time constant.

If the temperature rise continues the function operates based on the thermal model of the line.

Re-energizing of the line after the thermal overload operation can be inhibited during the time the cooling of the line is in progress. The cooling of the line is estimated by the thermal model.



The operation of T1PTTR can be described using a module diagram. All the modules in the diagram are explained in the next sections.

The function uses ambient temperature which can be measured locally or remotely.

Local measurement is done by the protection relay. Remote measurement uses analog GOOSE to connect AMB_TEMP input.

If the quality of remotely measured temperature is invalid or communication channel fails the function uses ambient temperature set in Env temperature Set.

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337


I_A

I_B

I_C

ENA_MULT

BLK_OPR

AMB_TEMP

Max current selector

Temperature estimator


Thermal counter

START

OPERATE

ALARM

BLK_CLOSE

Max current selector

The max current selector of the function continuously checks the highest measured TRMS phase current value. The selector reports the highest value to the temperature estimator.

Temperature estimator

The final temperature rise is calculated from the highest of the three-phase currents according to the expression:

Θ final

=





I

I ref





2

T ref

(Equation 11)

I

I ref

T ref the largest phase current set Current reference set Temperature rise

The ambient temperature is added to the calculated final temperature rise estimation, and the ambient temperature value used in the calculation is also available in the monitored data as TEMP_AMB in degrees. If the final temperature estimation is larger than the set Maximum temperature, the

START output is activated.

Current reference and Temperature rise setting values are used in the final temperature estimation together with the ambient temperature. It is suggested to set these values to the maximum steady state current allowed for the line or cable under emergency operation for a few hours per years. Current values with the corresponding conductor temperatures are given in cable manuals. These values are given for conditions such as ground temperatures, ambient air temperature, the way of cable laying and ground thermal resistivity.

Thermal counter

The actual temperature at the actual execution cycle is calculated as:

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Technical Manual

Θ n

= Θ n

−

1

+

(

Θ final

− Θ n

−

1

)



⋅ − e

−

∆ t

τ





(Equation 12)

Θ n

Θ n-1

Θ final

Δt t calculated present temperature calculated temperature at previous time step calculated final temperature with actual current time step between calculation of actual temperature thermal time constant for the protected device (line or cable), set Time constant

The actual temperature of the protected component (line or cable) is calculated by adding the ambient temperature to the calculated temperature, as shown above.

The ambient temperature can be given a constant value or it can be measured. The calculated component temperature can be monitored as it is exported from the function as a real figure.

When the component temperature reaches the set alarm level Alarm value, the output signal ALARM is set. When the component temperature reaches the set trip level Maximum temperature, the

OPERATE output is activated. The OPERATE signal pulse length is fixed to 100 ms.

There is also a calculation of the present time to operation with the present current.

This calculation is only performed if the final temperature is calculated to be above the operation temperature: t operate

= − ⋅ ln





Θ final

Θ

− final

Θ operate

− Θ n





(Equation 13)

Caused by the thermal overload protection function, there can be a lockout to reconnect the tripped circuit after operating. The lockout output BLK_CLOSE is activated at the same time when the OPERATE output is activated and is not reset until the device temperature has cooled down below the set value of the Reclose temperature setting. The Maximum temperature value must be set at least two degrees above the set value of Reclose temperature.

The time to lockout release is calculated, that is, the calculation of the cooling time to a set value. The calculated temperature can be reset to its initial value (the Initial temperature setting) via a control parameter that is located under the clear menu.

This is useful during testing when secondary injected current has given a calculated false temperature level.

t lockout _ release ln





Θ final

− Θ lockout _ release

Θ final

− Θ n





(Equation 14)

Here the final temperature is equal to the set or measured ambient temperature.

339


In some applications, the measured current can involve a number of parallel lines.

This is often used for cable lines where one bay connects several parallel cables.

By setting the Current multiplier parameter to the number of parallel lines (cables), the actual current on one line is used in the protection algorithm. To activate this option, the ENA_MULT input must be activated.

The ambient temperature can be measured with the RTD measurement. The measured temperature value is then connected, for example, from the AI_VAL3 output of the X130 (RTD) function to the AMB_TEMP input of T1PTTR.

The Env temperature Set setting is used to define the ambient temperature if the ambient temperature measurement value is not connected to the AMB_TEMP input. The Env temperature Set setting is also used when the ambient temperature measurement connected to T1PTTR is set to “Not in use” in the X130 (RTD) function.

The temperature calculation is initiated from the value defined with the Initial temperature setting parameter. This is done in case the protection relay is powered up, the function is turned "Off" and back "On" or reset through the Clear menu.

The temperature is also stored in the nonvolatile memory and restored in case the protection relay is restarted.

The thermal time constant of the protected circuit is given in seconds with the Time constant setting. Please see cable manufacturers manuals for further details.

T1PTTR thermal model complies with the IEC 60255-149 standard.

4.1.6.5

Application

The lines and cables in the power system are constructed for a certain maximum load current level. If the current exceeds this level, the losses will be higher than expected. As a consequence, the temperature of the conductors will increase. If the temperature of the lines and cables reaches too high values, it can cause a risk of damages by, for example, the following ways:

• The sag of overhead lines can reach an unacceptable value.

• If the temperature of conductors, for example aluminium conductors, becomes too high, the material will be destroyed.

• Overheating can damage the insulation on cables which in turn increases the risk of phase-to-phase or phase-to-earth faults.

In stressed situations in the power system, the lines and cables may be required to be overloaded for a limited time. This should be done without any risk for the above-mentioned risks.

The thermal overload protection provides information that makes temporary overloading of cables and lines possible. The thermal overload protection estimates the conductor temperature continuously. This estimation is made by using a thermal model of the line/cable that is based on the current measurement.

If the temperature of the protected object reaches a set warning level, a signal is given to the operator. This enables actions in the power system to be done before dangerous temperatures are reached. If the temperature continues to increase to the maximum allowed temperature value, the protection initiates a trip of the protected line.

340 620 series

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1MRS757644 H

4.1.6.6

Signals

Table 323: T1PTTR Input signals

Name

I_A

I_B

I_C

BLK_OPR

Type

SIGNAL

SIGNAL

SIGNAL

BOOLEAN

ENA_MULT

AMB_TEMP

BOOLEAN

FLOAT32

Table 324: T1PTTR Output signals

Name

OPERATE

START

ALARM

BLK_CLOSE

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

4.1.6.7

Settings

Table 325: T1PTTR Group settings (Basic)

Parameter

Env temperature

Set

Values (Range)

-50...100

Unit

°C

Current reference 0.05...4.00

Temperature rise 0.0...200.0

Time constant 60...60000

Maximum temperature

Alarm value

20.0...200.0

20.0...150.0

Reclose temperature

20.0...150.0

xIn

°C

°C

°C

°C s

Step

1

0.01

0.1

1

0.1

0.1

0.1

Default

0

0

0

0=False

0=False

0

Default

40

1.00

75.0

2700

90.0

80.0

70.0


Description

Phase A current

Phase B current

Phase C current

Block signal for operate outputs

Enable Current multiplier

The ambient temperature used in the calculation

Description

Operate

Start

Thermal Alarm

Thermal overload indicator.

To inhibit reclose.

Description

Ambient temperature used when no external temperature measurement available

The load current leading to Temperature raise temperature

End temperature rise above ambient

Time constant of the line in seconds.

Temperature level for operate

Temperature level for start (alarm)

Temperature for reset of block reclose after operate

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Technical Manual

341


Table 326: T1PTTR Group settings (Advanced)


Current multiplier 1...5

Unit Step

1

Table 327: T1PTTR Non group settings (Basic)

Parameter

Operation

Values (Range)

1=on

5=off

Unit Step

Table 328: T1PTTR Non group settings (Advanced)


Initial temperature -50.0...100.0

Unit

°C

Step

0.1

4.1.6.8

Monitored data

Table 329: T1PTTR Monitored data

Name

TEMP

Type

FLOAT32

TEMP_RL FLOAT32

Values (Range)

-100.0...9999.9

0.00...99.99

T_OPERATE

T_ENA_CLOSE

TEMP_AMB

T1PTTR

INT32

INT32

FLOAT32

Enum

0...60000

0...60000

-99...999

1=on

2=blocked

3=test

4=test/blocked

5=off

Unit

°C s s

°C

Default

1

Default

1=on

Default

0.0

Description

Current multiplier when function is used for parallel lines

Description

Operation Off / On

Description

Temperature raise above ambient temperature at startup

Description

The calculated temperature of the protected object

The calculated temperature of the protected object relative to the operate level

Estimated time to operate

Estimated time to deactivate BLK_CLOSE


Status

342 620 series

Technical Manual


4.1.6.9

4.1.6.10

4.1.7

4.1.7.1

4.1.7.2

Technical data

Table 330: T1PTTR Technical data

Characteristic

Operation accuracy


Value

Depending on the frequency of the measured current: f n

±2 Hz

Current measurement: ±1.5% of the set value or ±0.002 × I n

(at currents in the range of

0.01...4.00 × I n

)

±2.0% of the theoretical value or ±0.50 s

D

E

F


Table 331: T1PTTR Technical revision history


C

Change

Removed the Sensor available setting parameter

Added the AMB_TEMP input



Three-phase thermal overload protection, two time constants T2PTTR

Identification


Three-phase thermal overload protection, two time constants


T2PTTR


3Ith>T/G/C

ANSI/IEEE C37.2

device number

49T/G/C

Function block


1 Overload current > 1.2 × Operate level temperature

620 series

Technical Manual

343


4.1.7.3

4.1.7.4

344

1MRS757644 H

Functionality

The three-phase thermal overload, two time constants, protection function T2PTTR protects the transformer mainly from short-time overloads. The transformer is protected from long-time overloads with the oil temperature detector included in its equipment.

The alarm signal gives an early warning to allow the operators to take action before the transformer trips. The early warning is based on the three-phase current measuring function using a thermal model with two settable time constants. If the temperature rise continues, T2PTTR operates based on the thermal model of the transformer.

After a thermal overload operation, the re-energizing of the transformer is inhibited during the transformer cooling time. The transformer cooling is estimated with a thermal model.



The operation of T2PTTR can be described using a module diagram. All the modules in the diagram are explained in the next sections.




I_A

I_B

I_C


Temperature estimator

Thermal counter

START

OPERATE

ALARM

BLK_CLOSE

BLOCK

AMB_TEMP



The max current selector of the function continuously checks the highest measured

TRMS phase current value. The selector reports the highest value to the thermal counter.

Temperature estimator

The final temperature rise is calculated from the highest of the three-phase currents according to the expression:

620 series

Technical Manual


620 series

Technical Manual

Θ final

=





I

I ref





2

T ref

(Equation 15)

I

I ref

T ref highest measured phase current the set value of the Current reference setting the set value of the Temperature rise setting (temperature rise (°C) with the steady-state current I ref

The ambient temperature value is added to the calculated final temperature rise estimation. If the total value of temperature is higher than the set operate temperature level, the START output is activated.

The Current reference setting is a steady-state current that gives the steady-state end temperature value Temperature rise. It gives a setting value corresponding to the rated power of the transformer.

The Temperature rise setting is used when the value of the reference temperature rise corresponds to the Current reference value. The temperature values with the corresponding transformer load currents are usually given by transformer manufacturers.

Thermal counter

T2PTTR applies the thermal model of two time constants for temperature measurement. The temperature rise in degrees Celsius (°C) is calculated from the highest of the three-phase currents according to the expression:

∆Θ =



 p *





I

I ref





2

* T ref







⋅ − e

−

τ

∆ t

1





+



 (

1

− p

) ⋅





II

I ref





2

T ref







⋅ − e

−

τ

∆ t

2





(Equation 16)

I

ΔΘ

I ref

T ref p

Δt t

1 t

2 calculated temperature rise (°C) in transformer measured phase current with the highest TRMS value the set value of the Current reference setting (rated current of the protected object) the set value of the Temperature rise setting (temperature rise setting (°C) with the steady-state current I ref

) the set value of the Weighting factor p setting (weighting factor for the short time constant) time step between the calculation of the actual temperature the set value of the Short time constant setting (the short heating / cooling time constant) the set value of the Long time constant setting (the long heating / cooling time constant)

The warming and cooling following the two time-constant thermal curve is a characteristic of transformers. The thermal time constants of the protected transformer are given in seconds with the Short time constant and Long time

345

Protection functions 1MRS757644 H constant settings. The Short time constant setting describes the warming of the transformer with respect to windings. The Long time constant setting describes the warming of the transformer with respect to the oil. Using the two time-constant model, the protection relay is able to follow both fast and slow changes in the temperature of the protected object.

The Weighting factor p setting is the weighting factor between Short time constant

τ

1

and Long time constant τ

2

. The higher the value of the Weighting factor p setting, the larger is the share of the steep part of the heating curve. When

Weighting factor p =1, only Short-time constant is used. When Weighting factor p =

0, only Long time constant is used.

346

Figure 172: Effect of the Weighting factor p factor and the difference between the two time constants and one time constant models

The actual temperature of the transformer is calculated by adding the ambient temperature to the calculated temperature.

Θ = ∆ Θ + Θ amb

(Equation 17)

Θ

ΔΘ

Θ amb temperature in transformer (°C) calculated temperature rise (°C) in transformer set value of the Env temperature Set setting or measured ambient temperature

The ambient temperature can be measured with RTD measurement. The measured temperature value is connected, for example, from the AI_VAL3 output of the X130

(RTD) function to the AMB_TEMP input of T2PTTR.

The Env temperature Set setting is used to define the ambient temperature if the ambient temperature measurement value is not connected to the AMB_TEMP

620 series

Technical Manual


4.1.7.5

620 series

Technical Manual input. The Env temperature Set setting is also used when the ambient temperature measurement connected to T2PTTR is set to “Not in use” in the X130 (RTD) function.

The temperature calculation is initiated from the value defined with the Initial temperature and Max temperature setting parameters. The initial value is a percentage of Max temperature defined by Initial temperature. This is done when the protection relay is powered up or the function is turned off and back on or reset through the Clear menu. The temperature is stored in a nonvolatile memory and restored if the protection relay is restarted.

The Max temperature setting defines the maximum temperature of the transformer in degrees Celsius (°C). The value of the Max temperature setting is usually given by transformer manufacturers. The actual alarm, operating and lockout temperatures for T2PTTR are given as a percentage value of the Max temperature setting.

When the transformer temperature reaches the alarm level defined with the

Alarm temperature setting, the

ALARM output signal is set. When the transformer temperature reaches the trip level value defined with the Operate temperature setting, the OPERATE output is activated. The OPERATE output is deactivated when the value of the measured current falls below 10 percent of the Current Reference value or the calculated temperature value falls below Operate temperature.

There is also a calculation of the present time to operation with the present current.

T_OPERATE is only calculated if the final temperature is calculated to be above the operation temperature. The value is available in the monitored data view.

After operating, there can be a lockout to reconnect the tripped circuit due to the thermal overload protection function. The BLK_CLOSE lockout output is activated when the device temperature is above the Reclose temperature lockout release temperature setting value. The time to lockout release T_ENA_CLOSE is also calculated. The value is available in the monitored data view.

Application

The transformers in a power system are constructed for a certain maximum load current level. If the current exceeds this level, the losses are higher than expected.

This results in a rise in transformer temperature. If the temperature rise is too high, the equipment is damaged:

• Insulation within the transformer ages faster, which in turn increases the risk of internal phase-to-phase or phase-to-earth faults.

• Possible hotspots forming within the transformer degrade the quality of the transformer oil.

During stressed situations in power systems, it is required to overload the transformers for a limited time without any risks. The thermal overload protection provides information and makes temporary overloading of transformers possible.

The permissible load level of a power transformer is highly dependent on the transformer cooling system. The two main principles are:

• ONAN: The air is naturally circulated to the coolers without fans, and the oil is naturally circulated without pumps.

• OFAF: The coolers have fans to force air for cooling, and pumps to force the circulation of the transformer oil.

The protection has several parameter sets located in the setting groups, for example one for a non-forced cooling and one for a forced cooling situation. Both the permissive steady-state loading level as well as the thermal time constant are

347


348

1MRS757644 H influenced by the transformer cooling system. The active setting group can be changed by a parameter, or through a binary input if the binary input is enabled for it. This feature can be used for transformers where forced cooling is taken out of operation or extra cooling is switched on. The parameters can also be changed when a fan or pump fails to operate.

The thermal overload protection continuously estimates the internal heat content, that is, the temperature of the transformer. This estimation is made by using a thermal model of the transformer which is based on the current measurement.

If the heat content of the protected transformer reaches the set alarm level, a signal is given to the operator. This enables the action that needs to be taken in the power systems before the temperature reaches a high value. If the temperature continues to rise to the trip value, the protection initiates the trip of the protected transformer.

After the trip, the transformer needs to cool down to a temperature level where the transformer can be taken into service again. T2PTTR continues to estimate the heat content of the transformer during this cooling period using a set cooling time constant. The energizing of the transformer is blocked until the heat content is reduced to the set level.

The thermal curve of two time constants is typical for a transformer. The thermal time constants of the protected transformer are given in seconds with the Short time constant and Long time constant settings. If the manufacturer does not state any other value, the Long time constant can be set to 4920 s (82 minutes) for a distribution transformer and 7260 s (121 minutes) for a supply transformer. The corresponding Short time constants are 306 s (5.1 minutes) and 456 s (7.6 minutes).

If the manufacturer of the power transformer has stated only one, that is, a single time constant, it can be converted to two time constants. The single time constant is also used by itself if the p-factor Weighting factor p setting is set to zero and the time constant value is set to the value of the Long time constant setting. The thermal image corresponds to the one time constant model in that case.

Table 332: Conversion table between one and two time constants

Weighting factor p Single time constant

(min)

50

55

60

65

70

75

30

35

40

45

10

15

20

25

Short time constant

(min)

5.1

5.6

6.1

6.7

7.2

7.8

3.1

3.6

4.1

4.8

1.1

1.6

2.1

2.6

Long time constant

(min)

82

90

98

107

115

124

49

58

60

75

17

25

33

41

0.4

0.4

0.4

0.4

0.4

0.4

0.4

0.4

0.4

0.4

0.4

0.4

0.4

0.4

620 series

Technical Manual


4.1.7.6

The default Max temperature setting is 105°C. This value is chosen since even though the IEC 60076-7 standard recommends 98°C as the maximum allowable temperature in long-time loading, the standard also states that a transformer can withstand the emergency loading for weeks or even months, which may produce the winding temperature of 140°C. Therefore, 105°C is a safe maximum temperature value for a transformer if the Max temperature setting value is not given by the transformer manufacturer.

Signals

Table 333: T2PTTR Input signals

Name

I_A

I_B

I_C

BLOCK

Type

SIGNAL

SIGNAL

SIGNAL

BOOLEAN

AMB_TEMP FLOAT32

Default

0

0

0

0=False

0

Description

Phase A current

Phase B current

Phase C current



Table 334: T2PTTR Output signals

Name

OPERATE

START

ALARM

BLK_CLOSE

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

Description

Operate

Start

Thermal Alarm

Thermal overload indicator.

To inhibite reclose.

4.1.7.7

Settings

Table 335: T2PTTR Group settings (Basic)

Parameter

Env temperature

Set

Values (Range)

-50...100

Unit

°C

Temperature rise 0.0...200.0

Max temperature 0.0...200.0

Operate temperature

80.0...120.0

Alarm temperature 40.0...100.0


%

%

°C

°C

Step

1

0.1

0.1

0.1

0.1

Default

40

78.0

105.0

100.0

90.0

Description


End temperature rise above ambient

Maximum temperature allowed for the transformer

Operate temperature, percent value

Alarm temperature, percent value

620 series

Technical Manual

349


Parameter

Reclose temperature

Values (Range)

40.0...100.0

Short time constant

6...60000

Long time constant 60...60000

Weighting factor p 0.00...1.00

s s

Unit

%

Step

0.1

1

1

0.01

Table 336: T2PTTR Group settings (Advanced)



Unit xIn

Step

0.01

Default

60.0

450

7200

0.40

Description

Temperature for reset of block reclose after operate

Short time constant in seconds

Long time constant in seconds

Weighting factor of the short time constant

Default

1.00

Description

The load current leading to Temperature raise temperature

Table 337: T2PTTR Non group settings (Basic)

Parameter

Operation

Values (Range)

1=on

5=off

Unit Step

Table 338: T2PTTR Non group settings (Advanced)


Initial temperature 0.0...100.0

Unit

%

Step

0.1

4.1.7.8

Monitored data

Table 339: T2PTTR Monitored data

Name

TEMP

Type

FLOAT32

TEMP_RL FLOAT32

Values (Range)

-100.0...9999.9

0.00...99.99

T_OPERATE

T_ENA_CLOSE

TEMP_AMB

T2PTTR

INT32

INT32

FLOAT32

Enum

0...60000

0...60000

-99...999

1=on

2=blocked

3=test

4=test/blocked

5=off

Unit

°C s s

°C

Default

1=on

Default

80.0

Description

Operation Off / On

Description

Initial temperature, percent value

Description

The calculated temperature of the protected object


Estimated time to operate

Estimated time to deactivate BLK_CLOSE in seconds


Status

350 620 series

Technical Manual


4.1.7.9

Technical data

Table 340: T2PTTR Technical data

Characteristic

Operation accuracy


4.1.7.10

4.1.8

4.1.8.1

4.1.8.2

Value


Hz n

±2

Current measurement: ±1.5% of the set value or ±0.002 x I

(at currents in the range of 0.01...4.00 x I n

) n

±2.0% of the theoretical value or ±0.50 s


Table 341: T2PTTR Technical revision history

C

D


B

Change

Added the AMB_TEMP input



Motor load jam protection JAMPTOC

Identification


Motor load jam protection


JAMPTOC


Ist>

ANSI/IEEE C37.2

device number

51LR

Function block


4.1.8.3

Functionality

The motor load jam protection function JAMPTOC is used for protecting the motor in stall or mechanical jam situations during the running state.

When the motor is started, a separate function is used for the startup protection, and JAMPTOC is normally blocked during the startup period. When the motor has

1 Overload current > 1.2 x Operate level temperature

620 series

Technical Manual

351


4.1.8.4

1MRS757644 H passed the starting phase, JAMPTOC monitors the magnitude of phase currents.

The function starts when the measured current exceeds the breakdown torque level, that is, above the set limit. The operation characteristic is definite time.

The function contains a blocking functionality. It is possible to block the function outputs.



The operation of JAMPTOC can be described with a module diagram. All the modules in the diagram are explained in the next sections.

352


Level detector

The measured phase currents are compared to the set Start value. The TRMS values of the phase currents are considered for the level detection. The timer module is enabled if at least two of the measured phase currents exceed the set Start value.

Timer

Once activated, the internal START signal is activated. The value is available only through the Monitored data view. The time characteristic is according to DT. When the operation timer has reached the Operate delay time value, the OPERATE output is activated.

When the timer has elapsed but the motor stall condition still exists, the OPERATE output remains active until the phase currents values drop below the Start value, that is, until the stall condition persists. If the drop-off situation occurs while the operating time is still counting, the reset timer is activated. If the drop-off time exceeds the set Reset delay time, the operating timer is reset.


Blocking logic



620 series

Technical Manual

1MRS757644 H

4.1.8.5

4.1.8.6


The Blocking mode setting has three blocking methods. In the "Freeze timers" mode, the operation timer is frozen to the prevailing value. In the "Block all" mode, the whole function is blocked and the timers are reset. In the "Block OPERATE output" mode, the function operates normally but the OPERATE output is not activated.

Application

The motor protection during stall is primarily needed to protect the motor from excessive temperature rise, as the motor draws large currents during the stall phase. This condition causes a temperature rise in the stator windings. Due to reduced speed, the temperature also rises in the rotor. The rotor temperature rise is more critical when the motor stops.

The physical and dielectric insulations of the system deteriorate with age and the deterioration is accelerated by the temperature increase. Insulation life is related to the time interval during which the insulation is maintained at a given temperature.

An induction motor stalls when the load torque value exceeds the breakdown torque value, causing the speed to decrease to zero or to some stable operating point well below the rated speed. This occurs, for example, when the applied shaft load is suddenly increased and is greater than the producing motor torque due to the bearing failures. This condition develops a motor current almost equal to the value of the locked-rotor current.

JAMPTOC is designed to protect the motor in stall or mechanical jam situations during the running state. To provide a good and reliable protection for motors in a stall situation, the temperature effects on the motor have to be kept within the allowed limits.

Signals

Table 342: JAMPTOC Input signals

Name

I_A

I_B

I_C

BLOCK

Type

SIGNAL

SIGNAL

SIGNAL

BOOLEAN

Default

0

0

0

0=False

Description

Phase A current

Phase B current

Phase C current


Table 343: JAMPTOC Output signals

Name

OPERATE

Type

BOOLEAN

Description

Operate

620 series

Technical Manual

353


4.1.8.7

Settings

Table 344: JAMPTOC Non group settings (Basic)

Parameter

Operation

Values (Range)

1=on

5=off

Start value 0.10...10.00


Unit xIn ms

Step

0.01

10

Table 345: JAMPTOC Non group settings (Advanced)

Parameter

Reset delay time

Values (Range)

0...60000

Unit ms

Step

1

4.1.8.8

Monitored data

Table 346: JAMPTOC Monitored data

Name

START

Type

BOOLEAN

START_DUR

JAMPTOC

FLOAT32

Enum

Values (Range)

0=False

1=True

0.00...100.00

1=on

2=blocked

3=test

4=test/blocked

5=off

Unit

%

Default

1=on

2.50

2000

Default

100

Description

Operation Off / On

Start value

Operate delay time

Description

Reset delay time

Description

Start


Status

4.1.8.9

Technical data

Table 347: JAMPTOC Technical data

Characteristic

Operation accuracy

Reset time

Reset ratio

Retardation time


4.1.8.10

Value


Hz

±2


Typically 40 ms

Typically 0.96

<35 ms



Table 348: JAMPTOC Technical revision history


B

C

Change



354 620 series

Technical Manual


4.1.9

4.1.9.1

4.1.9.2

Loss of load supervision LOFLPTUC

Identification


Loss of load supervision


LOFLPTUC


3I<

ANSI/IEEE C37.2

device number

37

Function block

4.1.9.3

4.1.9.4


Functionality

The loss of load supervision function LOFLPTUC is used to detect a sudden load loss which is considered as a fault condition.

LOFLPTUC starts when the current is less than the set limit. It operates with the definite time (DT) characteristics, which means that the function operates after a predefined operate time and resets when the fault current disappears.

The function contains a blocking functionality. It is possible to block function outputs, the definite timer or the function itself, if desired.



The operation of LOFLPTUC can be described using a module diagram. All the modules in the diagram are explained in the next sections.

620 series

Technical Manual


355


4.1.9.5

1MRS757644 H

Level detector 1

This module compares the phase currents (RMS value) to the set Start value high setting. If all the phase current values are less than the set Start value high value, the loss of load condition is detected and an enable signal is sent to the timer. This signal is disabled after one or several phase currents have exceeded the set Start value high value of the element.


This is a low-current detection module, which monitors the de-energized condition of the motor. It compares the phase currents (RMS value) to the set Start value low setting. If any of the phase current values is less than the set Start value low, a signal is sent to block the operation of the timer.

Timer

Once activated, the timer activates the START output. The time characteristic is according to DT. When the operation timer has reached the value set by Operate delay time, the OPERATE output is activated. If the fault disappears before the module operates, the reset timer is activated. If the reset timer reaches the value set by Reset delay time, the operate timer resets and the

START output is deactivated.


The BLOCK signal blocks the operation of the function and resets the timer.

Application

When a motor runs with a load connected, it draws a current equal to a value between the no-load value and the rated current of the motor. The minimum load current can be determined by studying the characteristics of the connected load.

When the current drawn by the motor is less than the minimum load current drawn, it can be inferred that the motor is either disconnected from the load or the coupling mechanism is faulty. If the motor is allowed to run in this condition, it may aggravate the fault in the coupling mechanism or harm the personnel handling the machine. Therefore, the motor has to be disconnected from the power supply as soon as the above condition is detected.

LOFLPTUC detects the condition by monitoring the current values and helps disconnect the motor from the power supply instantaneously or after a delay according to the requirement.

When the motor is at standstill, the current will be zero and it is not recommended to activate the trip during this time. The minimum current drawn by the motor when it is connected to the power supply is the no load current, that is, the higher start value current. If the current drawn is below the lower start value current, the motor is disconnected from the power supply. LOFLPTUC detects this condition and interprets that the motor is de-energized and disables the function to prevent unnecessary trip events.

356 620 series

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4.1.9.6

Signals

Table 349: LOFLPTUC Input signals

Name

I_A

I_B

I_C

BLOCK

Type

SIGNAL

SIGNAL

SIGNAL

BOOLEAN

Default

0

0

0

0=False

Table 350: LOFLPTUC Output signals

Name

OPERATE

START

Type

BOOLEAN

BOOLEAN

4.1.9.7

Settings

Table 351: LOFLPTUC Group settings (Basic)

Parameter

Start value low

Values (Range)

0.01...0.50

Unit xIn

Start value high 0.01...1.00


xIn ms

Table 352: LOFLPTUC Non group settings (Basic)

Parameter

Operation

Values (Range)

1=on

5=off

Unit Step

Step

0.01

0.01

10

Table 353: LOFLPTUC Non group settings (Advanced)

Parameter

Reset delay time

Values (Range)

0...60000

Unit ms

Step

1

Default

0.10

0.50

2000

Default

1=on

Default

20

Description

Operate

Start

Description

Phase A current

Phase B current

Phase C current

Block all binary outputs by resetting timers

Description

Current setting/Start value low

Current setting/Start value high

Operate delay time

Description

Operation Off / On

Description

Reset delay time

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Technical Manual

357


4.1.9.8

Monitored data

Table 354: LOFLPTUC Monitored data

Name

START_DUR

Type

FLOAT32

LOFLPTUC Enum

Values (Range)

0.00...100.00

1=on

2=blocked

3=test

4=test/blocked

5=off

Unit

%

Description


Status

4.1.9.9

Technical data

Table 355: LOFLPTUC Technical data

Characteristic

Operation accuracy

Start time

Reset time

Reset ratio

Retardation time


4.1.9.10

Value


Hz n

±2


Typically 300 ms

Typically 40 ms

Typically 1.04

<35 ms



Table 356: LOFLPTUC Technical revision history


B

C

Change



4.1.10

4.1.10.1

Loss of phase, undercurrent PHPTUC

Identification


Loss of phase, undercurrent


PHPTUC1


3I<

ANSI/IEEE C37.2

device number

37

358 620 series

Technical Manual

1MRS757644 H

4.1.10.2

Function block


4.1.10.3

4.1.10.4


Functionality

The loss of phase, undercurrent, protection function PHPTUC is used to detect an undercurrent that is considered as a fault condition.

PHPTUC starts when the current is less than the set limit. Operation time characteristics are according to definite time (DT).

The function contains a blocking functionality. It is possible to block function outputs and reset the definite timer, if desired..



The operation of PHPTUC can be described with a module diagram. All the modules in the diagram are explained in the next sections.

620 series

Technical Manual



This module compares the phase currents (RMS value) to the Start value setting.

The Operation modesetting can be used to select the "Three Phase" or "Single

Phase" mode.

If in the "Three Phase" mode all the phase current values are less than the value of the Start value setting, the condition is detected and an enable signal is sent to the

359


4.1.10.5

timer. This signal is disabled after one or several phase currents have exceeded the set Start value value of the element.

If in the "Single Phase" mode any of the phase current values are less than the value of the Start value setting, the condition is detected and an enable signal is sent to the timer. This signal is disabled after all the phase currents have exceeded the set

Start value value of the element.

The protection relay does not accept the Start value to be smaller than

Current block value.


This is a low-current detection module that monitors the de-energized condition of the protected object. The module compares the phase currents (RMS value) to the

Start value low setting. If all the phase current values are less than the Start value low setting, a signal is sent to block the operation of the timer.

Timer

Once activated, the timer activates the START output and the phase-specific ST_X output . The time characteristic is according to DT. When the operation timer has reached the value set by Operate delay time, the

OPERATE output and the phasespecific OPR_X output are activated. If the fault disappears before the module operates, the reset timer is activated. If the reset timer reaches the value set by

Reset delay time, the operate timer resets and the

START output is deactivated.

The timer calculates the start duration value START_DUR , which indicates the percentage ratio of the start situation and the set operating time. The value is available through the monitored data view.

The BLOCK signal blocks the operation of the function and resets the timer.

Application

In some cases, smaller distribution power transformers are used where the highside protection involves only power fuses. When one of the high-side fuses blows in a single-phase condition, knowledge of it on the secondary side is lacking. The resulting negative-sequence current leads to a premature failure due to excessive heating and breakdown of the transformer insulation. Knowledge of this condition when it occurs allows for a quick fuse replacement and saves the asset.

The Current block value setting can be set to zero to not block PHPTUC with a low three-phase current. However, this results in an unnecessary event sending when the transformer or protected object is disconnected.

Phase-specific start and operate can give a better picture about the evolving faults when one phase has started first and another follows.

PHPTUC is meant to be a general protection function, so that it could be used in other cases too

In case of undercurrent-based motor protection, see the Loss of load protection.

360 620 series

Technical Manual

1MRS757644 H

4.1.10.6

Signals

Table 357: PHPTUC Input signals

Name

I_A

I_B

I_C

BLOCK

Type

SIGNAL

SIGNAL

SIGNAL

BOOLEAN

Table 358: PHPTUC Output signals

Name

OPERATE

OPR_A

OPR_B

OPR_C

START

ST_A

ST_B

ST_C

Type

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

BOOLEAN

4.1.10.7

Settings

Table 359: PHPTUC Group settings (Basic)


Current block value 0.00...0.50

Unit xIn

Start value 0.01...1.00


xIn ms

Table 360: PHPTUC Non group settings (Basic)

Parameter

Operation

Operation mode

Values (Range)

1=on

5=off

1=Three Phase

2=Single Phase

Unit

Step

0.01

0.01

10

Step

Table 361: PHPTUC Non group settings (Advanced)

Parameter

Reset delay time

Values (Range)

0...60000

Unit ms

Step

1

620 series

Technical Manual

Default

0

0

0

0=False

Default

20


Description

Operate

Operate phase A

Operate phase B

Operate phase C

Start

Start phase A

Start phase B

Start phase C

Description

Phase A current

Phase B current

Phase C current

Block all binary outputs by resetting timers

Default

0.10

0.50

2000

Description

Low current setting to block internally

Current setting to start

Operate delay time

Default

1=on

1=Three Phase

Description

Operation Off / On

Number of phases needed to start

Description

Reset delay time

361


4.1.10.8

Monitored data

Table 362: PHPTUC Monitored data

Name

START_DUR

PHPTUC

Type

FLOAT32

Enum

Values (Range)

0.00...100.00

1=on

2=blocked

3=test

4=test/blocked

5=off

4.1.10.9

Technical data

Table 363: PHPTUC Technical data

Characteristic

Operation accuracy

Start time

Reset time

Reset ratio

Retardation time


Unit

%

Description


Status

Value

Depending on the frequency of the measured current and voltages: f n

±2 Hz

±1.5% of the set value or ± 0.002 × I n

Typically <55 ms

<40 ms

Typically 1.04

<35 ms mode ±1.0% of the set value or ±20 ms

4.1.11

4.1.11.1

4.1.11.2

Thermal overload protection for motors MPTTR

Identification


Thermal overload protection for motors


MPTTR


3Ith>M

ANSI/IEEE C37.2

device number

49M

Function block


362 620 series

Technical Manual


4.1.11.3

4.1.11.4

620 series

Technical Manual

Functionality

The thermal overload protection for motors function MPTTR protects the electric motors from overheating. MPTTR models the thermal behavior of motor on the basis of the measured load current and disconnects the motor when the thermal content reaches 100 percent.

Thermal overload conditions are the most often encountered abnormal conditions in industrial motor applications. The thermal overload conditions are typically the result of an abnormal rise in the motor running current, which produces an increase in the thermal dissipation of the motor and temperature or reduces cooling. MPTTR prevents an electric motor from drawing excessive current and overheating, which causes the premature insulation failures of the windings and, in worst cases, burning out of the motors.



The operation of MPTTR can be described using a module diagram. All the modules in the diagram are explained in the next sections.




I_A

I_B

I_C

I

2


AMB_TEMP

Internal

FLC calculator

START_EMERG

BLOCK


Thermal level calculator

Alarm and tripping logic

OPERATE

ALARM

BLK_RESTART


Max current selector selects the highest measured TRMS phase current and reports it to Thermal level calculator.

Internal FLC calculator

Full load current ( FLC) of the motor is defined by the manufacturer at an ambient temperature of 40°C. Special considerations are required with an application where

363


364

1MRS757644 H the ambient temperature of a motor exceeds or remains below 40°C. A motor operating at a higher temperature, even if at or below rated load, can subject the motor windings to excessive temperature similar to that resulting from overload operation at normal ambient temperature. The motor rating has to be appropriately reduced for operation in such high ambient temperatures. Similarly, when the ambient temperature is considerably lower than the nominal 40°C, the motor can be slightly overloaded. For calculating thermal level it is better that the FLC values are scaled for different temperatures. The scaled currents are known as internal FLC.

An internal FLC is calculated based on the ambient temperature shown in the table.

The Env temperature mode setting defines whether the thermal level calculations are based on FLC or internal FLC.

When the value of the Env temperature mode setting is set to the "FLC Only" mode, no internal FLC is calculated. Instead, the FLC given in the data sheet of the manufacturer is used. When the value of the Env temperature mode setting is set to "Set Amb Temp" mode, the internal FLC is calculated based on the ambient temperature taken as an input through the Env temperature Set setting. When the

Env temperature mode setting is on "Use input" mode, the internal FLC is calculated from temperature data available through resistance temperature detectors ( RTDs) using the AMB_TEMP input.

Table 364: Modification of internal FLC

Ambient Temperature T amb

<20°C

20 to <40°C

40°C

>40 to 65°C

>65°C

Internal FLC

FLC x 1.09

FLC x (1.18 - T amb

x 0.09/20)

FLC

FLC x (1 –[(T amb

-40)/100])

FLC x 0.75

The ambient temperature is used for calculating thermal level and it is available in the monitored data view from the TEMP_AMB output. The activation of the BLOCK input does not affect the TEMP_AMB output.

The Env temperature Set setting is used:

• If the ambient temperature measurement value is not connected to the

AMB_TEMP input in ACT.

• When the ambient temperature measurement connected to 49M is set to "Not in use" in the RTD function.

• In case of any errors or malfunctioning in the RTD output.

Thermal level calculator

The module calculates the thermal load considering the TRMS and negativesequence currents. The heating up of the motor is determined by the square value of the load current.

However, in case of unbalanced phase currents, the negative-sequence current also causes additional heating. By deploying a protection based on both current components, abnormal heating of the motor is avoided.

The thermal load is calculated based on different situations or operations and it also depends on the phase current level. The equations used for the heating calculations are:

620 series

Technical Manual


θ

B

=











I k × I r



2

 + K ×



2







I

2 k × I r







2





( e

− t / τ

)

× p %

(Equation 18)

θ

A

=









I k

×

I r



2



K

2

×





I

2 k

×

I r





2





( e

− t / τ

)

×

100 %

θ

02

(Equation 19)

K

2 p t

I

I r

I

2 k

TRMS value of the measured max of phase currents set Current reference , FLC or internal FLC measured negative sequence current set value of Overload factor set value of Negative Seq factor set value of Weighting factor time constant

The equation θ

B

is used when the values of all the phase currents are below the overload limit, that is, k x I r

. The equation θ

A

is used when the value of any one of the phase currents exceeds the overload limit.

During overload condition, the thermal level calculator calculates the value of θ

B

in background, and when the overload ends the thermal level is brought linearly from θ

A

to θ

B

with a speed of 1.66 percent per second. For the motor at standstill, that is, when the current is below the value of 0.12 x I r

, the cooling is expressed as:

θ

=

θ

02

×

− t e

τ

(Equation 20) initial thermal level when cooling begins

620 series

Technical Manual

Figure 181: Thermal behavior

365


366

1MRS757644 H

The required overload factor and negative sequence current heating effect factor are set by the values of the Overload factor and Negative Seq factor settings.

In order to accurately calculate the motor thermal condition, different time constants are used in the above equations. These time constants are employed based on different motor running conditions, for example starting, normal or stop, and are set through the Time constant start, Time constant normal and Time constant stop settings. Only one time constant is valid at a time.

Table 365: Time constant and the respective phase current values

Time constant (tau) in use

Time constant start

Time constant normal

Time constant stop

Phase current

Any current whose value is over 2.5 x I r

Any current whose value is over 0.12 x I r

and all currents are below 2.5 x I r

All the currents whose values are below 0.12 x

I r

The Weighting factor p setting determines the ratio of the thermal increase of the two curves θ

A

and θ

B

.

The thermal level at the power-up of the protection relay is defined by the Initial thermal Val setting.

The temperature calculation is initiated from the value defined in the Initial thermal

Val setting. This is done if the protection relay is powered up or the function is turned off and back on or reset through the Clear menu.

The calculated temperature of the protected object relative to the operate level, the

TEMP_RL output, is available through the monitored data view. The activation of the

BLOCK input does not affect the calculated temperature.

The thermal level at the beginning of the start-up condition of a motor and at the end of the start-up condition is available in the monitored data view at the

THERMLEV_ST and THERMLEV_END outputs respectively. The activation of the BLOCK input does not have any effect on these outputs.

Alarm and tripping logic

The module generates alarm, restart inhibit and tripping signals.

When the thermal level exceeds the set value of the Alarm thermal value setting, the ALARM output is activated. Sometimes a condition arises when it becomes necessary to inhibit the restarting of a motor, for example in case of some extreme starting condition like long starting time. If the thermal content exceeds the set value of the Restart thermal val setting, the

BLK_RESTART output is activated. The time for the next possible motor start-up is available through the monitored data view from the T_ENARESTART output. The T_ENARESTART output estimates the time for the BLK_RESTART deactivation considering as if the motor is stopped.

When the emergency start signal START_EMERG is set high, the thermal level is set to a value below the thermal restart inhibit level. This allows at least one motor start-up, even though the thermal level has exceeded the restart inhibit level.

When the thermal content reaches 100 percent, the OPERATE output is activated.

The OPERATE output is deactivated when the value of the measured current falls below 12 percent of Current reference or the thermal content drops below 100 percent.

620 series

Technical Manual


The activation of the BLOCK input blocks the ALARM , BLK_RESTART and OPERATE outputs.

620 series

Technical Manual

Tau [s]

3840

1920

960

640

480

320

160

80

Figure 182: Trip curves when no prior load and p=20...100 %. Overload factor = 1.05.

367


368

Tau [s]

3840

1920

80 160 320 480 640 960

Figure 183: Trip curves at prior load 1 x FLC and p=100 %, Overload factor = 1.05.

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Technical Manual


Tau [s]

3840

1920

960

640

480

320

80 160

Figure 184: Trip curves at prior load 1 x FLC and p=50 %. Overload factor = 1.05.

4.1.11.5

620 series

Technical Manual

Application

MPTTR is intended to limit the motor thermal level to predetermined values during the abnormal motor operating conditions. This prevents a premature motor insulation failure.

The abnormal conditions result in overheating and include overload, stalling, failure to start, high ambient temperature, restricted motor ventilation, reduced speed operation, frequent starting or jogging, high or low line voltage or frequency, mechanical failure of the driven load, improper installation and unbalanced

369

Protection functions 1MRS757644 H line voltage or single phasing. The protection of insulation failure by the implementation of current sensing cannot detect some of these conditions, such as restricted ventilation. Similarly, the protection by sensing temperature alone can be inadequate in cases like frequent starting or jogging. The thermal overload protection addresses these deficiencies to a larger extent by deploying a motor thermal model based on load current.

The thermal load is calculated using the true RMS phase value and negative sequence value of the current. The heating up of the motor is determined by the square value of the load current. However, while calculating the thermal level, the rated current should be re-rated or de-rated depending on the value of the ambient temperature. Apart from current, the rate at which motor heats up or cools is governed by the time constant of the motor.

Setting the weighting factor

There are two thermal curves: one which characterizes the short-time loads and long-time overloads and which is also used for tripping and another which is used for monitoring the thermal condition of the motor. The value of the Weighting factor p setting determines the ratio of the thermal increase of the two curves.

When the Weighting factor p setting is 100 percent, a pure single time constant thermal unit is produced which is used for application with the cables. As presented

in Figure 185 , the hot curve with the value of

Weighting factor p being 100 percent only allows an operate time which is about 10 percent of that with no prior load.

For example, when the set time constant is 640 seconds, the operate time with the prior load 1 x FLC (full Load Current) and overload factor 1.05 is only 2 seconds, even if the motor could withstand at least 5 to 6 seconds. To allow the use of the full capacity of the motor, a lower value of Weighting factor p should be used.

Normally, an approximate value of half of the thermal capacity is used when the motor is running at full load. Thus by setting Weighting factor p to 50 percent, the protection relay notifies a 45 to 50 percent thermal capacity use at full load.

For direct-on-line started motors with hot spot tendencies, the value of Weighting factor p is typically set to 50 percent, which will properly distinguish between shorttime thermal stress and long-time thermal history. After a short period of thermal stress, for example a motor start-up, the thermal level starts to decrease quite sharply, simulating the leveling out of the hot spots. Consequently, the probability of successive allowed start-ups increases.

When protecting the objects without hot spot tendencies, for example motors started with soft starters, and cables, the value of Weighting factor p is set to 100 percent. With the value of Weighting factor p set to 100 percent, the thermal level decreases slowly after a heavy load condition. This makes the protection suitable for applications where no hot spots are expected. Only in special cases where the thermal overload protection is required to follow the characteristics of the object to be protected more closely and the thermal capacity of the object is very well known, a value between 50 and 100 percent is required.

For motor applications where, for example, two hot starts are allowed instead of three cold starts, the value of the setting Weighting factor p being 40 percent has proven to be useful. Setting the value of Weighting factor p significantly below

50 percent should be handled carefully as there is a possibility to overload the protected object as a thermal unit might allow too many hot starts or the thermal history of the motor has not been taken into account sufficiently.

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620 series

Technical Manual t/s

4000

3000

2000

1000 x

500

400

300

200

100

50

40

30

20

Cold curve

10

20

5

4

3

50

75

2

p

[%]

1.05

1

1 2 3 4 5 6 8

100

10 I/I q

Figure 185: The influence of Weighting factor p at prior load 1xFLC, timeconstant =

640 s, and Overload factor = 1.05

Setting the overload factor

The value of Overload factor defines the highest permissible continuous load. The recommended value is 1.05.

Setting the negative sequence factor

During the unbalance condition, the symmetry of the stator currents is disturbed and a counter-rotating negative sequence component current is set up. An increased stator current causes additional heating in the stator and the negative sequence component current excessive heating in the rotor. Also mechanical problems like rotor vibration can occur.

The most common cause of unbalance for three-phase motors is the loss of phase resulting in an open fuse, connector or conductor. Often mechanical problems

371

Protection functions 1MRS757644 H can be more severe than the heating effects and therefore a separate unbalance protection is used.

Unbalances in other connected loads in the same busbar can also affect the motor.

A voltage unbalance typically produces 5 to 7 times higher current unbalance.

Because the thermal overload protection is based on the highest TRMS value of the phase current, the additional heating in stator winding is automatically taken into account. For more accurate thermal modeling, the Negative Seq factor setting is used for taking account of the rotor heating effect.

Negative Seq factor

=

R

R 2

R

R 1

(Equation 21)

R

R2

R

R1

Rotor negative sequence resistance

Rotor positive sequence resistance

A conservative estimate for the setting can be calculated:


=

175

2

I

LR

(Equation 22)

I

LR

Locked rotor current (multiple of set Rated current ). The same as the start-up current at the beginning of the motor start-up.

For example, if the rated current of a motor is 230 A, start-up current is 5.7 x I r

,


=

175

2

=

(Equation 23)

Setting the thermal restart level

The restart disable level can be calculated as follows:

θ i

=

100 %

− 



 startup time of the motor operate time when no prior load

×

10 0

+ margin







(Equation 24)

For example, the motor start-up time is 11 seconds, start-up current 6 x rated and

Time constant start is set for 800 seconds. Using the trip curve with no prior load, the operation time at 6 x rated current is 25 seconds, one motor start-up uses 11/25

≈ 45 percent of the thermal capacity of the motor. Therefore, the restart disable level must be set to below 100 percent - 45 percent = 55 percent, for example to 50 percent (100 percent - (45 percent + margin), where margin is 5 percent).

Setting the thermal alarm level

Tripping due to high overload is avoided by reducing the load of the motor on a prior alarm.

372 620 series

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4.1.11.6

The value of Alarm thermal value is set to a level which allows the use of the full thermal capacity of the motor without causing a trip due to a long overload time.

Generally, the prior alarm level is set to a value of 80 to 90 percent of the trip level.

Signals

Table 366: MPTTR Input signals

Name

I_A

I_B

I_C

I

2

Type

SIGNAL

SIGNAL

SIGNAL

SIGNAL

BLOCK BOOLEAN

START_EMERG

AMB_TEMP

BOOLEAN

FLOAT32

Default

0

0

0

0

0=False

0=False

0

Description

Phase A current

Phase B current

Phase C current

Negative sequence current


Signal for indicating the need for emergency start


Table 367: MPTTR Output signals

Name

OPERATE

ALARM

BLK_RESTART

Type

BOOLEAN

BOOLEAN

BOOLEAN

Description

Operate

Thermal Alarm

Thermal overload indicator, to inhibit restart

4.1.11.7

Settings

Table 368: MPTTR Group settings (Basic)

Parameter

Overload factor

Alarm thermal value

Values (Range)

1.00...1.20

50.0...100.0

Unit

%

Restart thermal Val 20.0...80.0

%

Negative Seq factor

0.0...10.0

Weighting factor p 20.0...100.0


%

0.1

0.1

Step

0.01

0.1

0.1

Default

1.05

95.0

40.0

0.0

50.0

Description

Overload factor (k)

Thermal level above which function gives an alarm

Thermal level above which function inhibits motor restarting

Heating effect factor for negative sequence current

Weighting factor

(p)

620 series

Technical Manual

373


Parameter

Time constant normal

Values (Range)

80...4000

Time constant start

80...4000

Time constant stop 80...60000

Unit s s s

Env temperature mode

Env temperature

Set

1=FLC Only

2=Use input

3=Set Amb Temp

-20.0...70.0

°C

TEMP_AMB FLOAT32

1

1

Step

1

0.1

Table 369: MPTTR Non group settings (Basic)

Parameter

Operation

Values (Range)

1=on

5=off

Unit Step

Table 370: MPTTR Non group settings (Advanced)



Initial thermal Val 0.0...100.0

Unit xIn

%

Step

0.01

0.1

4.1.11.8

Default

1=on

Default

1.00

74.0

Monitored data

Table 371: MPTTR Monitored data

Name

TEMP_RL

Type

FLOAT32


0.00...9.99

-99...999

THERMLEV_ST FLOAT32


0.00...9.99

Default

320

320

500

1=FLC Only

40.0

Description

Motor time constant during the normal operation of motor

Motor time constant during the start of motor

Motor time constant during the standstill condition of motor

Mode of measuring ambient temperature


°C

Description

Operation Off / On

Description

Rated current (FLC) of the motor

Initial thermal level of the motor

Description



Thermal level at beginning of motor startup

374 620 series

Technical Manual


Name Type

THERMLEV_END FLOAT32

T_ENARESTART INT32


0.00...9.99

0...99999

s

Description

Thermal level at the end of motor startup situation

Estimated time to reset of block restart

Status MPTTR Enum

1=on

2=blocked

3=test

4=test/blocked

5=off

0.00...9.99

Therm-Lev FLOAT32 Thermal level of protected object

(1.00 is the operate level)

4.1.11.9

Technical data

Table 372: MPTTR Technical data

Characteristic

Operation accuracy

Value


Hz n

±2

Current measurement: ±1.5% of the set value or ±0.002 × I

(at currents in the range of 0.01...4.00 × I n

) n

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

4.1.11.10


Table 373: MPTTR Technical revision history

C

D


B

E

Change

Added a new input AMB_TEMP .

Added a new selection for the Env temperature mode setting "Use input".


Time constant stop range maximum value changed from 8000 s to 60000 s.


1 Overload current > 1.2 × Operate level temperature

620 series

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375


4.2

4.2.1

4.2.1.1

4.2.1.2

4.2.1.3

4.2.1.4

376

1MRS757644 H

Earth-fault protection

Non-directional earth-fault protection EFxPTOC

Identification


EFLPTOC Non-directional earth-fault protection, low stage

Non-directional earth-fault protection, high stage

Non-directional earth-fault protection, instantaneous stage

EFHPTOC

EFIPTOC


Io>

Io>>

Io>>>

ANSI/IEEE C37.2

device number

51N-1

51N-2

50N/51N

Function block

EFLPTOC

Io

BLOCK

ENA_MULT

OPERATE

START


EFHPTOC

Io

BLOCK

ENA_MULT

OPERATE

START

EFIPTOC

Io

BLOCK

ENA_MULT

OPERATE

START

Functionality

The non-directional earth-fault protection function EFxPTOC is used as nondirectional earth-fault protection for feeders.

The function starts and operates when the residual current exceeds the set limit.

The operate time characteristic for low stage EFLPTOC and high stage EFHPTOC can be selected to be either definite time (DT) or inverse definite minimum time (IDMT). The instantaneous stage EFIPTOC always operates with the DT characteristic.





The operation of EFxPTOC can be described by using a module diagram. All the modules in the diagram are explained in the next sections.

620 series

Technical Manual


620 series

Technical Manual


Level detector

The operating quantity can be selected with the setting Io signal Sel. The selectable options are "Measured Io" and "Calculated Io". The operating quantity is compared to the set Start value. If the measured value exceeds the set Start value, the level detector sends an enable-signal to the timer module. If the ENA_MULT input is active, the Start value setting is multiplied by the Start value Mult setting.




Timer












377


4.2.1.5

4.2.1.6

378

1MRS757644 H




in this manual.


Blocking logic





The function operates on three alternative measurement modes: "RMS", "DFT" and

"Peak-to-Peak". The measurement mode is selected with the Measurement mode setting.

Table 374: Measurement modes supported by EFxPTOC stages

Measurement mode EFLPTOC

RMS

DFT

Peak-to-Peak x x x

EFHPTOC x x x

EFIPTOC x


Chapter 11.5



EFxPTOC supports both DT and IDMT characteristics. The user can select the timer characteristics with the Operating curve type and Type of reset curve settings.


The protection relay provides 16 IDMT characteristics curves, of which seven comply with the IEEE C37.112 and six with the IEC 60255-3 standard. Two curves follow the

620 series

Technical Manual


620 series

Technical Manual special characteristics of ABB praxis and are referred to as RI and RD. In addition to this, a user programmable curve can be used if none of the standard curves are applicable. The user can choose the DT characteristic by selecting the Operating curve type values "ANSI Def. Time" or "IEC Def. Time". The functionality is identical in both cases.

The following characteristics, which comply with the list in the IEC 61850-7-4 specification, indicate the characteristics supported by different stages:


EFHPTOC x












(11) IEC Inverse





(17) User programmable curve

(18) RI type

(19) RD type

EFIPTOC supports only definite time characteristics.

EFLPTOC x x x x x x x x x x x x x x x x x x x x x x x x x


in this manual.



(1) Immediate

(2) Def time reset

(3) Inverse reset

EFLPTOC x x x

EFHPTOC x x x

Note




379


4.2.1.7

4.2.1.8

1MRS757644 H

The Type of reset curve setting does not apply to EFIPTOC or when the


Application

EFxPTOC is designed for protection and clearance of earth faults in distribution and sub-transmission networks where the neutral point is isolated or earthed via a resonance coil or through low resistance. It also applies to solidly earthed networks and earth-fault protection of different equipment connected to the power systems, such as shunt capacitor bank or shunt reactors and for backup earth-fault protection of power transformers.

Many applications require several steps using different current start levels and time delays. EFxPTOC consists of three different protection stages.

• Low EFLPTOC

• High EFHPTOC

• Instantaneous EFIPTOC

EFLPTOC contains several types of time-delay characteristics. EFHPTOC and

EFIPTOC are used for fast clearance of serious earth faults.

Signals

EFLPTOC Input signals

Table 377: EFLPTOC Input signals

Name

Io

BLOCK

Type

SIGNAL

BOOLEAN

ENA_MULT BOOLEAN

Default

0

0=False

0=False

Description

Residual current



EFHPTOC Input signals

Table 378: EFHPTOC Input signals

Name

Io

BLOCK

Type

SIGNAL

BOOLEAN

ENA_MULT BOOLEAN

Default

0

0=False

0=False

Description

Residual current



380 620 series

Technical Manual


EFIPTOC Input signals

Table 379: EFIPTOC Input signals

Name

Io

BLOCK

Type

SIGNAL

BOOLEAN

ENA_MULT BOOLEAN

EFLPTOC Output signals

Table 380: EFLPTOC Output signals

Name

OPERATE

START

Type

BOOLEAN

BOOLEAN

EFHPTOC Output signals

Table 381: EFHPTOC Output signals

Name

OPERATE

START

Type

BOOLEAN

BOOLEAN

EFIPTOC Output signals

Table 382: EFIPTOC Output signals

Name

OPERATE

START

Type

BOOLEAN

BOOLEAN

4.2.1.9

Settings

EFLPTOC Group settings

Table 383: EFLPTOC Group settings (Basic)

Parameter

Start value

Start value Mult

Values (Range)

0.010...5.000

0.8...10.0

Unit xIn


Step

0.005

0.1

Default

0

0=False

0=False

Default

0.010

1.0

Description

Operate

Start

Description

Operate

Start

Description

Operate

Start

Description

Residual current



Description

Start value


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381


Parameter

Time multiplier

Values (Range)

0.05...15.00

Unit



1=ANSI Ext. inv.

2=ANSI Very inv.

3=ANSI Norm. inv.

4=ANSI Mod. inv.

5=ANSI Def. Time

6=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. inv.

15=IEC Def. Time

17=Programmable

18=RI type

19=RD type ms

Step

0.01

10

Table 384: EFLPTOC Group settings (Advanced)



2=Def time reset

3=Inverse reset

Unit Step

Table 385: EFLPTOC Non group settings (Basic)

Parameter

Operation

Values (Range)

1=on

5=off


Unit Step

1





1

1

1

1

1MRS757644 H

Default

1.00

40

15=IEC Def. Time

Description


Operate delay time


Default

1=Immediate

Description


Default

1=on

28.2000

0.1217

2.00

29.10

1.0

Description

Operation Off / On






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1MRS757644 H

Table 386: EFLPTOC Non group settings (Advanced)

Parameter


Reset delay time

Measurement mode

Io signal Sel

Values (Range)

20...60000

0...60000

1=RMS

2=DFT

3=Peak-to-Peak

1=Measured Io

2=Calculated Io

Unit ms ms

Step

1

1

EFHPTOC Group settings

Table 387: EFHPTOC Group settings (Basic)

Parameter

Start value

Start value Mult

Time multiplier

Values (Range)

0.10...40.00

0.8...10.0

0.05...15.00

Unit xIn



1=ANSI Ext. inv.

3=ANSI Norm. inv.

5=ANSI Def. Time

9=IEC Norm. inv.

10=IEC Very inv.

12=IEC Ext. inv.

15=IEC Def. Time

17=Programmable ms

Table 388: EFHPTOC Group settings (Advanced)



2=Def time reset

3=Inverse reset

Step

Step

0.01

0.1

0.01

10

Table 389: EFHPTOC Non group settings (Basic)

Parameter

Operation

Values (Range)

1=on

5=off


Unit Step

1

1 Curve parameter B 0.0000...0.7120


620 series

Technical Manual


Default

20

20

2=DFT

Description


Reset delay time


1=Measured Io Selection for used

Io signal

Default

0.10

1.0

1.00

40

15=IEC Def. Time

Description

Start value



Operate delay time


Default

1=Immediate

Description


Default

1=on

28.2000

0.1217

Description

Operation Off / On



383






Unit

Table 390: EFHPTOC Non group settings (Advanced)

Parameter


Reset delay time

Measurement mode

Io signal Sel

Values (Range)

20...60000

0...60000

1=RMS

2=DFT

3=Peak-to-Peak

1=Measured Io

2=Calculated Io

Unit ms ms

Step

1

1

EFIPTOC Group settings

Table 391: EFIPTOC Group settings (Basic)

Parameter

Start value

Start value Mult

Values (Range)

1.00...40.00

0.8...10.0

Unit xIn


ms

Table 392: EFIPTOC Non group settings (Basic)

Parameter

Operation

Values (Range)

1=on

5=off

Unit

Step

0.01

0.1

10

Step

Table 393: EFIPTOC Non group settings (Advanced)

Parameter

Reset delay time

Io signal Sel

Values (Range)

0...60000

1=Measured Io

2=Calculated Io

Unit ms

Step

1

Step

1

1

1

1MRS757644 H

Default

2.00

29.10

1.0

Description




Default

20

20

2=DFT

Description


Reset delay time


1=Measured Io Selection for used

Io signal

Default

1.00

1.0

20

Default

1=on

Description

Start value


Operate delay time

Description

Operation Off / On

Default

20

1=Measured Io

Description

Reset delay time

Selection for used

Io signal

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1MRS757644 H

4.2.1.10

Monitored data

Table 394: EFLPTOC Monitored data

Name

START_DUR

Type

FLOAT32

EFLPTOC Enum

Values (Range)

0.00...100.00

1=on

2=blocked

3=test

4=test/blocked

5=off

Table 395: EFHPTOC Monitored data

Name

START_DUR

EFHPTOC

Type

FLOAT32

Enum

Values (Range)

0.00...100.00

1=on

2=blocked

3=test

4=test/blocked

5=off

Table 396: EFIPTOC Monitored data

Name

START_DUR

EFIPTOC

Type

FLOAT32

Enum

Values (Range)

0.00...100.00

1=on

2=blocked

3=test

4=test/blocked

5=off

Unit

%

Unit

%

Unit

%


Description


Status

Description


Status

Description


Status

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385


4.2.1.11

Technical data

Table 397: EFxPTOC Technical data

Characteristic

Operation accuracy

EFLPTOC

EFHPTOC and

EFIPTOC

Start time ,

EFIPTOC:

I

Fault


I

Fault


EFHPTOC and EFLPTOC:

I

Fault


Reset time

Reset ratio

Retardation time




Value


Hz

±2




)



)


16 ms

11 ms

19 ms

12 ms

23 ms

14 ms

23 ms 26 ms 29 ms

Typically 40 ms

Typically 0.96

<30 ms



RMS: No suppression


, where n = 2, 3, 4, 5,…


4.2.1.12


Table 398: EFIPTOC Technical revision history


B

C

D

Change

The minimum and default values changed to

40 ms for the Operate delay time setting


Minimum value changed to 1.00 x In for the

Start value setting

Added a setting parameter for the "Measured Io" or "Calculated Io" selection


1

2

3

Measurement mode = default (depends on stage), current before fault = 0.0 × I statistical distribution of 1000 measurements




n

, f n

= 50 Hz, earth-fault current with nominal frequency injected from random phase angle, results based on

386 620 series

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1MRS757644 H

4.2.2

4.2.2.1



E

F

Change



Table 399: EFHPTOC Technical revision history


B

C

D

E

F

Change







Table 400: EFLPTOC Technical revision history

F

G

C

D


B

E

Change

The minimum and default values changed to

40 ms for the Operate delay time setting

Start value step changed to 0.005






Directional earth-fault protection DEFxPDEF

Identification


DEFLPDEF Directional earth-fault protection, low stage

Directional earth-fault protection, high stage

DEFHPDEF


Io> ->

Io>> ->

ANSI/IEEE C37.2

device number

67N-1

67N-2

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Technical Manual

387


4.2.2.2

Function block

1MRS757644 H

4.2.2.3

4.2.2.4


Functionality

The directional earth-fault protection function DEFxPDEF is used as directional earth-fault protection for feeders.

The function starts and operates when the operating quantity (current) and polarizing quantity (voltage) exceed the set limits and the angle between them is inside the set operating sector. The operate time characteristic for low stage

(DEFLPDEF) and high stage (DEFHPDEF) can be selected to be either definite time

(DT) or inverse definite minimum time (IDMT).





The operation of DEFxPDEF can be described using a module diagram. All the modules in the diagram are explained in the next sections.

388


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Level detector

The magnitude of the operating quantity is compared to the set Start value and the magnitude of the polarizing quantity is compared to the set Voltage start value. If both the limits are exceeded, the level detector sends an enabling signal to the timer module. When the Enable voltage limit setting is set to "False", Voltage start value has no effect and the level detection is purely based on the operating quantity. If the ENA_MULT input is active, the Start value setting is multiplied by the

Start value Mult setting.

The operating quantity (residual current) can be selected with the setting Io signal

Sel. The options are "Measured Io" and "Calculated Io". If "Measured Io" is selected, the current ratio for Io-channel is given in Configuration > Analog inputs > Current

(Io,CT). If "Calculated Io" is selected, the current ratio is obtained from the phasecurrent channels given in Configuration > Analog inputs > Current (3I,CT).

The operating quantity (residual voltage) can be selected with the setting Uo signal Sel. The options are "Measured Uo" and "Calculated Uo". If "Measured Uo" is selected, the voltage ratio for Uo-channel is given in Configuration > Analog

inputs > Voltage (Uo,VT). If "Calculated Uo" is selected, the voltage ratio is obtained from the phase-voltage channels given in Configuration > Analog inputs >

Voltage (3U,VT).

Example 1: Io is measured with cable core CT (100/1 A) and Uo is measured from open-delta connected VTs (20/sqrt(3) kV : 100/sqrt(3) V : 100/3 V). In this case,

"Measured Io" and "Measured Uo" are selected. The nominal values for residual current and residual voltage are obtained from CT and VT ratios entered in Residual current Io: Configuration > Analog inputs > Current (Io,CT): 100 A : 1 A. The Residual voltage Uo: Configuration > Analog inputs > Voltage (Uo,VT): 11.547 kV : 100 V. The

Start value of 1.0 × In corresponds to 1.0 * 100 A = 100 A in the primary. The Voltage start value of 1.0 × Un corresponds to 1.0 * 11.547 kV = 11.547 kV in the primary.

Example 2: Both Io and Uo are calculated from the phase quantities. Phase CTratio is 100 : 1 A and phase VT-ratio is 20/sqrt(3) kV : 100/sqrt(3) V. In this case,

"Calculated Io" and "Calculated Uo" are selected. The nominal values for residual current and residual voltage are obtained from CT and VT ratios entered in Residual current Io: Configuration > Analog inputs > Current (3I,CT): 100 A : 1 A. The residual voltage Uo: Configuration > Analog inputs > Voltage (3U,VT): 20.000 kV : 100 V. The

Start value of 1.0 × In corresponds to 1.0 * 100 A = 100 A in the primary. The Voltage start value of 1.0 × Un corresponds to 1.0 * 20.000 kV = 20.000 kV in the primary.

If "Calculated Uo" is selected, the residual voltage nominal value is always phase-to-phase voltage. Thus, the valid maximum setting for residual

Voltage start value is 0.577 x Un. The calculated Uo requires that all the three phase-to-earth voltages are connected to the protection relay. Uo cannot be calculated from the phase-to-phase voltages.

If the Enable voltage limit setting is set to "True", the magnitude of the polarizing quantity is checked even if the Directional mode was set to

"Non-directional" or Allow Non Dir to "True". The protection relay does not accept the Start value or Start value Mult setting if the product of these settings exceeds the Start value setting range.

Typically, the ENA_MULT input is connected to the inrush detection function

INRHPAR. In case of inrush, INRPHAR activates the ENA_MULT input, which multiplies

Start value by the Start value Mult setting.

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390

1MRS757644 H


The directional calculation module monitors the angle between the polarizing quantity and operating quantity. Depending on the Pol quantity setting, the polarizing quantity can be the residual voltage (measured or calculated) or the negative sequence voltage. When the angle is in the operation sector, the module sends the enabling signal to the timer module.

The minimum signal level which allows the directional operation can be set with the

Min operate current and Min operate voltage settings.

If Pol quantity is set to "Zero. seq. volt", the residual current and residual voltage are used for directional calculation.

If Pol quantity is set to "Neg. seq. volt", the negative sequence current and negative sequence voltage are used for directional calculation.

In the phasor diagrams representing the operation of DEFxPDEF, the polarity of the polarizing quantity (Uo or U2) is reversed, that is, the polarizing quantity in the phasor diagrams is either -Uo or -U2. Reversing is done by switching the polarity of the residual current measuring channel (see the connection diagram in the application manual). Similarly the polarity of the calculated Io and I

2 switched.

is also

For defining the operation sector, there are five modes available through the

Operation mode setting.

Table 401: Operation modes

Operation mode

Phase angle

IoSin

IoCos

Phase angle 80

Phase angle 88

Description

The operating sectors for forward and reverse are defined with the settings Min forward angle , Max forward angle , Min reverse angle and Max reverse angle .

The operating sectors are defined as "forward" when |Io| x sin

(ANGLE) has a positive value and "reverse" when the value is negative. ANGLE is the angle difference between -Uo and Io.

As "IoSin" mode. Only cosine is used for calculating the operation current.

The sector maximum values are frozen to 80 degrees respectively. Only Min forward angle and Min reverse angle are settable.

The sector maximum values are frozen to 88 degrees. Otherwise as "Phase angle 80" mode.

Polarizing quantity selection "Neg. seq. volt." is available only in the

"Phase angle" operation mode.


The alternatives are "Non-directional", "Forward" and "Reverse" operation. The operation criterion is selected with the Operation mode setting. By setting Allow

Non Dir to "True", non-directional operation is allowed when the directional information is invalid, that is, when the magnitude of the polarizing quantity is less than the value of the Min operate voltage setting.

Typically, the network rotating direction is counter-clockwise and defined as "ABC".

If the network rotating direction is reversed, meaning clockwise, that is, "ACB", the equation for calculating the negative sequence voltage component need to be

620 series

Technical Manual

1MRS757644 H Protection functions changed. The network rotating direction is defined with a system parameter Phase rotation. The calculation of the component is affected but the angle difference calculation remains the same. When the residual voltage is used as the polarizing method, the network rotating direction change has no effect on the direction calculation.

The network rotating direction is set in the protection relay using the parameter in the HMI menu: Configuration > System > Phase rotation.

The default parameter value is "ABC".

If the Enable voltage limit setting is set to "True", the magnitude of the polarizing quantity is checked even if Directional mode is set to

"Non-directional" or Allow Non Dir to "True".

The Characteristic angle setting is used in the "Phase angle" mode to adjust the operation according to the method of neutral point earthing so that in an isolated network the

RCA

Characteristic angle (φ

RCA

) = -90° and in a compensated network φ

= 0°. In addition, the characteristic angle can be changed via the control signal

RCA_CTL. RCA_CTL affects the Characteristic angle setting.

The Correction angle setting can be used to improve selectivity due the inaccuracies in the measurement transformers. The setting decreases the operation sector. The correction can only be used with the "IoCos" or "IoSin" modes.

The polarity of the polarizing quantity can be reversed by setting the Pol reversal to

"True", which turns the polarizing quantity by 180 degrees.

For definitions of different directional earth-fault characteristics, see

Chapter 4.2.2.8 Directional earth-fault characteristics

in this manual.

For definitions of different directional earth-fault characteristics, refer to general function block features information.

The directional calculation module calculates several values which are presented in the monitored data.

Table 402: Monitored data values

Monitored data values

FAULT_DIR

DIRECTION

ANGLE

Description

The detected direction of fault during fault situations, that is, when START output is active.

The momentary operating direction indication output.

Also called operating angle, shows the angle difference between the polarizing quantity

(Uo, U2) and operating quantity (Io, I2).


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Technical Manual

391


392

1MRS757644 H

Monitored data values

ANGLE_RCA

I_OPER

Description

The angle difference between the operating angle and Characteristic angle, that is, AN-

GLE_RCA = ANGLE – Characteristic angle.

The current that is used for fault detection. If the Operation mode setting is "Phase angle",

"Phase angle 80" or "Phase angle 88", I_OP-

ER is the measured or calculated residual current. If the Operation mode setting is "IoSin",

I_OPER is calculated as follows I_OPER = Io x sin(ANGLE). If the Operation mode setting is

"IoCos", I_OPER is calculated as follows I_OP-

ER = Io x cos(ANGLE).

Monitored data values are accessible on the LHMI or through tools via communications.

Timer















in this manual.

620 series

Technical Manual

1MRS757644 H

4.2.2.5



Blocking logic




Directional earth-fault principles

In many cases it is difficult to achieve selective earth-fault protection based on the magnitude of residual current only. To obtain a selective earth-fault protection scheme, it is necessary to take the phase angle of Io into account. This is done by comparing the phase angle of the operating and polarizing quantity.

Relay characteristic angle

The Characteristic angle setting, also known as Relay Characteristic Angle (RCA),

Relay Base Angle or Maximum Torque Angle (MTA), is used in the "Phase angle" mode to turn the directional characteristic if the expected fault current angle does not coincide with the polarizing quantity to produce the maximum torque. That is,

RCA is the angle between the maximum torque line and polarizing quantity. If the polarizing quantity is in phase with the maximum torque line, RCA is 0 degrees. The angle is positive if the operating current lags the polarizing quantity and negative if it leads the polarizing quantity.

Example 1

The "Phase angle" mode is selected, compensated network (φRCA = 0 deg)

=> Characteristic angle = 0 deg

620 series

Technical Manual

393


394

Figure 190: Definition of the relay characteristic angle, RCA=0 degrees in a compensated network

Example 2

The "Phase angle" mode is selected, solidly earthed network (φRCA = +60 deg)

=> Characteristic angle = +60 deg

620 series

Technical Manual


620 series

Technical Manual

Figure 191: Definition of the relay characteristic angle, RCA=+60 degrees in a solidly earthed network

Example 3

The "Phase angle" mode is selected, isolated network (φRCA = -90 deg)

=> Characteristic angle = -90 deg

395


396

Figure 192: Definition of the relay characteristic angle, RCA=–90 degrees in an isolated network

Directional earth-fault protection in an isolated neutral network

In isolated networks, there is no intentional connection between the system neutral point and earth. The only connection is through the phase-to-earth capacitances (C

0

) of phases and leakage resistances (R

0

). This means that the residual current is mainly capacitive and has a phase shift of -90 degrees compared to the polarizing voltage. Consequently, the relay characteristic angle (RCA) should be set to -90 degrees and the operation criteria to "IoSin" or "Phase angle". The width of the operating sector in the phase angle criteria can be selected with the settings Min forward angle, Max forward angle, Min reverse angle or Max reverse angle.

Figure

193 illustrates a simplified equivalent circuit for an unearthed network with an earth

fault in phase C.

For definitions of different directional earth-fault characteristics, see

Chapter 4.2.2.8 Directional earth-fault characteristics

.

620 series

Technical Manual


620 series

Technical Manual

Figure 193: Earth-fault situation in an isolated network

Directional earth-fault protection in a compensated network

In compensated networks, the capacitive fault current and the inductive resonance coil current compensate each other. The protection cannot be based on the reactive current measurement, since the current of the compensation coil would disturb the operation of the protection relays. In this case, the selectivity is based on the measurement of the active current component. The magnitude of this component is often small and must be increased by means of a parallel resistor in the compensation equipment. When measuring the resistive part of the residual current, the relay characteristic angle (RCA) should be set to 0 degrees and the operation criteria to "IoCos" or "Phase angle".

Figure 194

illustrates a simplified equivalent circuit for a compensated network with an earth fault in phase C.

397


398

Figure 194: Earth-fault situation in a compensated network

The Petersen coil or the earthing resistor may be temporarily out of operation. To keep the protection scheme selective, it is necessary to update the Characteristic angle setting accordingly. This can be done with an auxiliary input in the protection relay which receives a signal from an auxiliary switch of the disconnector of the

Petersen coil in compensated networks. As a result the characteristic angle is set automatically to suit the earthing method used. The RCA_CTL input can be used to change the operation criteria as described in

Table 403 and Table 404 .

Table 403: Relay characteristic angle control in Iosin(φ) and Iocos(φ) operation criteria

Operation mode setting:

Iosin

Iocos

RCA_CTL = FALSE RCA_CTL = TRUE

Actual operation mode: Iosin Actual operation mode: Iocos

Actual operation mode: Iocos Actual operation mode: Iosin

Table 404: Characteristic angle control in phase angle operation mode

Characteristic angle setting

-90°

0°

RCA_CTL = FALSE

φ

RCA

= -90°

φ

RCA

= 0°

RCA_CTL = TRUE

φ

RCA

= 0°

φ

RCA

= -90°

Use of the extended phase angle characteristic

The traditional method of adapting the directional earth-fault protection function to the prevailing neutral earthing conditions is done with the Characteristic angle setting. In an unearthed network, Characteristic angle is set to -90 degrees and in a compensated network Characteristic angle is set to 0 degrees. In case the earthing method of the network is temporarily changed from compensated to unearthed due to the disconnection of the arc suppression coil, the Characteristic angle setting should be modified correspondingly. This can be done using the setting

620 series

Technical Manual

1MRS757644 H Protection functions groups or the RCA_CTL input. Alternatively, the operating sector of the directional earth-fault protection function can be extended to cover the operating sectors of both neutral earthing principles. Such characteristic is valid for both unearthed and compensated network and does not require any modification in case the neutral earthing changes temporarily from the unearthed to compensated network or vice versa.

The extended phase angle characteristic is created by entering a value of over 90 degrees for the Min forward angle setting; a typical value is 170 degrees ( Min reverse angle in case Directional mode is set to "Reverse"). The Max forward angle setting should be set to cover the possible measurement inaccuracies of current and voltage transformers; a typical value is 80 degrees ( Max reverse angle in case

Directional mode is set to "Reverse").

Figure 195: Extended operation area in directional earth-fault protection

4.2.2.6

620 series

Technical Manual




Table 405: Measurement modes supported by DEFxPDEF stages

Measurement mode DEFLPDEF

RMS

DFT

Peak-to-Peak x x x

DEFHPDEF x x x

399


4.2.2.7

1MRS757644 H


Chapter 11.5



DEFxPDEF supports both DT and IDMT characteristics. The user can select the timer characteristics with the Operating curve type setting.

The protection relay provides 16 IDMT characteristics curves, of which seven comply with the IEEE C37.112 and six with the IEC 60255-3 standard. Two curves follow the special characteristics of ABB praxis and are referred to as RI and RD. In addition to this, a user programmable curve can be used if none of the standard curves are applicable. The user can choose the DT characteristic by selecting the Operating curve type values "ANSI Def. Time" or "IEC Def. Time". The functionality is identical in both cases.

The following characteristics, which comply with the list in the IEC 61850-7-4 specification, indicate the characteristics supported by different stages.













(11) IEC Inverse





(17) User programmable curve

(18) RI type

(19) RD type

DEFLPDEF x x x x x x x x x x x x x x x x x x

DEFHPDEF x x x x x

For a detailed description of the timers, see Chapter 11 General function block features

in this manual.

400 620 series

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1MRS757644 H

4.2.2.8




(1) Immediate

(2) Def time reset

(3) Inverse reset

DEFLPDEF x x x

DEFHPDEF x x x

Note




Directional earth-fault characteristics

Phase angle characteristic

The operation criterion phase angle is selected with the Operation mode setting using the value "Phase angle".

When the phase angle criterion is used, the function indicates with the DIRECTION output whether the operating quantity is within the forward or reverse operation sector or within the non-directional sector.



In the forward operation area, the Max forward angle setting gives the clockwise sector and the Min forward angle setting correspondingly the counterclockwise sector, measured from the Characteristic angle setting.

In the reverse operation area, the Max reverse angle setting gives the clockwise sector and the Min reverse angle setting correspondingly the counterclockwise sector, measured from the complement of the Characteristic angle setting (180 degrees phase shift) .

The relay characteristic angle (RCA) is set to positive if the operating current lags the polarizing quantity. It is set to negative if it leads the polarizing quantity.

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401


402

Figure 196: Configurable operating sectors in phase angle characteristic

Table 408: Momentary operating direction

Fault direction

Angle between the polarizing and operating quantity is not in any of the defined sectors.

Angle between the polarizing and operating quantity is in the forward sector.

Angle between the polarizing and operating quantity is in the reverse sector.

Angle between the polarizing and operating quantity is in both the forward and the reverse sectors, that is, the sectors are overlapping.


0 = unknown

1= forward

2 = backward

3 = both

If the Allow Non Dir setting is "False", the directional operation (forward, reverse) is not allowed when the measured polarizing or operating quantities are invalid, that is, their magnitude is below the set minimum values. The minimum values can be defined with the settings Min operate current and Min operate voltage.

In case of low magnitudes, the FAULT_DIR and DIRECTION outputs are set to

0 = unknown, except when the Allow non dir setting is "True". In that case, the function is allowed to operate in the directional mode as non-directional, since the directional information is invalid.

620 series

Technical Manual


Iosin(φ) and Iocos(φ) criteria

A more modern approach to directional protection is the active or reactive current measurement. The operating characteristic of the directional operation depends on the earthing principle of the network. The Iosin(φ) characteristics is used in an isolated network, measuring the reactive component of the fault current caused by the earth capacitance. The Iocos(φ) characteristics is used in a compensated network, measuring the active component of the fault current.

The operation criteria Iosin(φ) and Iocos(φ) are selected with the Operation mode setting using the values "IoSin" or "IoCos" respectively.

The angle correction setting can be used to improve selectivity. The setting decreases the operation sector. The correction can only be used with the Iosin(φ) or

Iocos(φ) criterion. The RCA_CTL input is used to change the Io characteristic:

Table 409: Relay characteristic angle control in the IoSin and IoCos operation criteria

Operation mode:

IoSin

IoCos

RCA_CTL = "False"

Actual operation criterion: Iosin(φ)

Actual operation criterion: Iocos(φ)

RCA_CTL = "True"

Actual operation criterion: Iocos(φ)

Actual operation criterion: Iosin(φ)

When the Iosin(φ) or Iocos(φ) criterion is used, the component indicates a forwardor reverse-type fault through the FAULT_DIR and DIRECTION outputs, in which 1 equals a forward fault and 2 equals a reverse fault. Directional operation is not allowed (the Allow non dir setting is "False") when the measured polarizing or operating quantities are not valid, that is, when their magnitude is below the set minimum values. The minimum values can be defined with the Min operate current and Min operate voltage settings. In case of low magnitude, the FAULT_DIR and

DIRECTION outputs are set to 0 = unknown, except when the Allow non dir setting is "True". In that case, the function is allowed to operate in the directional mode as non-directional, since the directional information is invalid.

The calculated Iosin(φ) or Iocos(φ) current used in direction determination can be read through the I_OPER monitored data. The value can be passed directly to a decisive element, which provides the final start and operate signals.

The I_OPER monitored data gives an absolute value of the calculated current.

The following examples show the characteristics of the different operation criteria:

Example 1.

Iosin(φ) criterion selected, forward-type fault

=> FAULT_DIR = 1

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Figure 197: Operating characteristic Iosin(φ) in forward fault

The operating sector is limited by angle correction, that is, the operating sector is

180 degrees - 2*(angle correction).

Example 2.

Iosin(φ) criterion selected, reverse-type fault

=> FAULT_DIR = 2

404

Figure 198: Operating characteristic Iosin(φ) in reverse fault

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1MRS757644 H

Example 3.

Iocos(φ) criterion selected, forward-type fault

=> FAULT_DIR = 1


Figure 199: Operating characteristic Iocos(φ) in forward fault

Example 4.

Iocos(φ) criterion selected, reverse-type fault

=> FAULT_DIR = 2

620 series

Technical Manual

Figure 200: Operating characteristic Iocos(φ) in reverse fault

405


Phase angle 80

The operation criterion phase angle 80 is selected with the Operation mode setting by using the value "Phase angle 80".

Phase angle 80 implements the same functionality as the phase angle but with the following differences:

• The Max forward angle and Max reverse angle settings cannot be set but they have a fixed value of 80 degrees

• The sector limits of the fixed sectors are rounded.

The sector rounding is used for cancelling the CT measurement errors at low current amplitudes. When the current amplitude falls below three percent of the nominal current, the sector is reduced to 70 degrees at the fixed sector side.

This makes the protection more selective, which means that the phase angle measurement errors do not cause faulty operation.

There is no sector rounding on the other side of the sector.

406

Figure 201: Operating characteristic for phase angle 80

620 series

Technical Manual


Io / % of I n

Min forward angle

10

9

8

7

6

Operating zone

4

3

2

1

80 deg

70 deg

Nonoperating zone

-90 -75 -60 -45 -30 -15 0 15 30 45 60 75 90

Figure 202: Phase angle 80 amplitude ( Directional mode = Forward)

3% of In

1% of In

Phase angle 88

The operation criterion phase angle 88 is selected with the Operation mode setting using the value "Phase angle 88".

Phase angle 88 implements the same functionality as the phase angle but with the following differences:

• The Max forward angle and Max reverse angle settings cannot be set but they have a fixed value of 88 degrees

• The sector limits of the fixed sectors are rounded.

Sector rounding in the phase angle 88 consists of three parts:

• If the current amplitude is between 1...20 percent of the nominal current, the sector limit increases linearly from 73 degrees to 85 degrees

• If the current amplitude is between 20...100 percent of the nominal current, the sector limit increases linearly from 85 degrees to 88 degrees

• If the current amplitude is more than 100 percent of the nominal current, the sector limit is 88 degrees.

There is no sector rounding on the other side of the sector.

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408

Figure 203: Operating characteristic for phase angle 88

Io / % of I n

Min forward angle

100

90

80

70

88 deg

100% of In

50

40

30

20

10

85 deg

73 deg

20% of In

-90 -75 -60 -45 -30 -15 0 15 30 45 60 75 90

Figure 204: Phase angle 88 amplitude ( Directional mode = Forward)

1% of In

620 series

Technical Manual


4.2.2.9

620 series

Technical Manual

Application

The directional earth-fault protection DEFxPDEF is designed for protection and clearance of earth faults and for earth-fault protection of different equipment connected to the power systems, such as shunt capacitor banks or shunt reactors, and for backup earth-fault protection of power transformers.

Many applications require several steps using different current start levels and time delays. DEFxPDEF consists of two different stages.

• Low DEFLPDEF

• High DEFHPDEF

DEFLPDEF contains several types of time delay characteristics. DEFHPDEF is used for fast clearance of serious earth faults.

The protection can be based on the phase angle criterion with extended operating sector. It can also be based on measuring either the reactive part Iosin(φ) or the active part Iocos(φ) of the residual current. In isolated networks or in networks with high impedance earthing, the phase-to-earth fault current is significantly smaller than the short-circuit currents. In addition, the magnitude of the fault current is almost independent of the fault location in the network.

The function uses the residual current components Iocos(φ) or Iosin(φ) according to the earthing method, where φ is the angle between the residual current and the reference residual voltage (-Uo). In compensated networks, the phase angle criterion with extended operating sector can also be used. When the relay characteristic angle RCA is 0 degrees, the negative quadrant of the operation sector can be extended with the Min forward angle setting. The operation sector can be set between 0 and -180 degrees, so that the total operation sector is from +90 to

-180 degrees. In other words, the sector can be up to 270 degrees wide. This allows the protection settings to stay the same when the resonance coil is disconnected from between the neutral point and earth.

System neutral earthing is meant to protect personnel and equipment and to reduce interference for example in telecommunication systems. The neutral earthing sets challenges for protection systems, especially for earth-fault protection.

In isolated networks, there is no intentional connection between the system neutral point and earth. The only connection is through the line-to-earth capacitances (C

0

) of phases and leakage resistances (R

0

). This means that the residual current is mainly capacitive and has -90 degrees phase shift compared to the residual voltage

(-Uo). The characteristic angle is -90 degrees.

In resonance-earthed networks, the capacitive fault current and the inductive resonance coil current compensate each other. The protection cannot be based on the reactive current measurement, since the current of the compensation coil would disturb the operation of the relays. In this case, the selectivity is based on the measurement of the active current component. This means that the residual current is mainly resistive and has zero phase shift compared to the residual voltage (-Uo) and the characteristic angle is 0 degrees. Often the magnitude of this component is small, and must be increased by means of a parallel resistor in the compensation equipment.

In networks where the neutral point is earthed through low resistance, the characteristic angle is also 0 degrees (for phase angle). Alternatively, Iocos(φ) operation can be used.

In solidly earthed networks, the Characteristic angle is typically set to +60 degrees for the phase angle. Alternatively, Iosin(φ) operation can be used with a reversal

409

Protection functions 1MRS757644 H polarizing quantity. The polarizing quantity can be rotated 180 degrees by setting the Pol reversal parameter to "True" or by switching the polarity of the residual voltage measurement wires. Although the Iosin(φ) operation can be used in solidly earthed networks, the phase angle is recommended.

Connection of measuring transformers in directional earth fault applications

The residual current Io can be measured with a core balance current transformer or the residual connection of the phase current signals. If the neutral of the network is either isolated or earthed with high impedance, a core balance current transformer is recommended to be used in earth-fault protection. To ensure sufficient accuracy of residual current measurements and consequently the selectivity of the scheme, the core balance current transformers should have a transformation ratio of at least

70:1. Lower transformation ratios such as 50:1 or 50:5 are not recommended.

Attention should be paid to make sure the measuring transformers are connected correctly so that DEFxPDEF is able to detect the fault current direction without failure. As directional earth fault uses residual current and residual voltage (-Uo), the poles of the measuring transformers must match each other and also the fault current direction. Also the earthing of the cable sheath must be taken into notice when using core balance current transformers. The following figure describes how measuring transformers can be connected to the protection relay.

4.2.2.10

Figure 205: Connection of measuring transformers

Signals

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Technical Manual


DEFLPDEF Input signals

Table 410: DEFLPDEF Input signals

Name

Io

Uo

BLOCK

Type

SIGNAL

SIGNAL

BOOLEAN

ENA_MULT

RCA_CTL

BOOLEAN

BOOLEAN

Default

0

0

0=False

0=False

0=False

DEFHPDEF Input signals

Table 411: DEFHPDEF Input signals

Name

Io

Uo

BLOCK

Type

SIGNAL

SIGNAL

BOOLEAN

ENA_MULT

RCA_CTL

BOOLEAN

BOOLEAN

Default

0

0

0=False

0=False

0=False

DEFLPDEF Output signals

Table 412: DEFLPDEF Output signals

Name

OPERATE

START

Type

BOOLEAN

BOOLEAN

DEFHPDEF Output signals

Table 413: DEFHPDEF Output signals

Name

OPERATE

START

Type

BOOLEAN

BOOLEAN

Description

Operate

Start

Description

Operate

Start

Description

Residual current

Residual voltage



Relay characteristic angle control

Description

Residual current

Residual voltage




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4.2.2.11

Settings

DEFLPDEF Group settings

Table 414: DEFLPDEF Group settings (Basic)

Parameter

Start value

Start value Mult

Values (Range)

0.010...5.000

0.8...10.0

Unit xIn

Directional mode

Time multiplier

1=Non-directional

2=Forward

3=Reverse

0.05...15.00


1=ANSI Ext. inv.

2=ANSI Very inv.

3=ANSI Norm. inv.

4=ANSI Mod. inv.

5=ANSI Def. Time

6=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. inv.

15=IEC Def. Time

17=Programmable

18=RI type

19=RD type



-179...180


ms deg deg


deg



Voltage start value 0.010...1.000

deg deg xUn

Step

0.005

0.1

0.01

10

1

1

1

1

1

0.001

1MRS757644 H

Default

0.010

1.0

2=Forward

Description

Start value


Directional mode

1.00

15=IEC Def. Time



50

-90

80

80

80

80

0.010

Operate delay time






Voltage start value

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1MRS757644 H

Table 415: DEFLPDEF Group settings (Advanced)



2=Def time reset

3=Inverse reset

Operation mode

1=Phase angle

2=IoSin

3=IoCos

4=Phase angle 80

5=Phase angle 88

Enable voltage limit 0=False

1=True

Unit Step

Table 416: DEFLPDEF Non group settings (Basic)

Parameter

Operation

Values (Range)

1=on

5=off


Unit Step

1


1




1

1

1

Table 417: DEFLPDEF Non group settings (Advanced)

Parameter

Reset delay time


Allow Non Dir

Values (Range)

0...60000

50...60000

0=False

1=True

Measurement mode

1=RMS

2=DFT

3=Peak-to-Peak

Min operate current

Min operate voltage

Correction angle

0.005...1.000

0.01...1.00

0.0...10.0


Unit ms ms xIn xUn deg

Step

1

1

0.001

0.01

0.1

620 series

Technical Manual


Default

1=Immediate

1=Phase angle

Description


Operation criteria

1=True Enable voltage limit

Default

20

50

0=False

2=DFT

0.005

0.01

0.0

Default

1=on

28.2000

0.1217

2.00

29.10

1.0

Description

Operation Off / On






Description

Reset delay time






Angle correction

413


Parameter

Pol reversal

Io signal Sel

Uo signal Sel

Pol quantity

Values (Range)

0=False

1=True

1=Measured Io

2=Calculated Io

1=Measured Uo

2=Calculated Uo

3=Zero seq. volt.

4=Neg. seq. volt.

Unit

DEFHPDEF Group settings

Table 418: DEFHPDEF Group settings (Basic)

Parameter

Start value

Start value Mult

Directional mode

Values (Range)

0.10...40.00

0.8...10.0

Unit xIn

Time multiplier

1=Non-directional

2=Forward

3=Reverse

0.05...15.00


1=ANSI Ext. inv.

3=ANSI Norm. inv.

5=ANSI Def. Time

15=IEC Def. Time

17=Programmable



-179...180


ms deg deg



Table continues on the next page deg deg

Step

Step

0.01

0.1

0.01

1

1

10

1

1

1MRS757644 H

Default

0=False

1=Measured Io

1=Measured Uo

3=Zero seq. volt.

Description

Rotate polarizing quantity

Selection for used

Io signal

Selection for used

Uo signal


80

80

40

-90

80

Default

0.10

1.0

2=Forward

Description

Start value


Directional mode

1.00

15=IEC Def. Time



Operate delay time





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1MRS757644 H



Unit deg

Step

1


xUn

Table 419: DEFHPDEF Group settings (Advanced)

0.001



2=Def time reset

3=Inverse reset

Operation mode

1=Phase angle

2=IoSin

3=IoCos

4=Phase angle 80

5=Phase angle 88

Enable voltage limit 0=False

1=True

Unit Step

Table 420: DEFHPDEF Non group settings (Basic)

Parameter

Operation

Values (Range)

1=on

5=off


Unit Step

1


1




1

1

1

Table 421: DEFHPDEF Non group settings (Advanced)

Parameter

Reset delay time


Values (Range)

0...60000

40...60000

Unit ms ms

Step

1

1

Allow Non Dir

0=False

1=True

Measurement mode

1=RMS

2=DFT

3=Peak-to-Peak

Min operate current

0.005...1.000

Table continues on the next page xIn 0.001

620 series

Technical Manual


Default

80

0.010

Description


Voltage start value

Default

1=Immediate

1=Phase angle

Description


Operation criteria

1=True Enable voltage limit

Default

20

40

0=False

2=DFT

0.005

Default

1=on

28.2000

0.1217

2.00

29.10

1.0

Description

Operation Off / On






Description

Reset delay time





415


Parameter

Min operate voltage

Correction angle

Pol reversal

Io signal Sel

Uo signal Sel

Pol quantity

Values (Range)

0.01...1.00

0.0...10.0

0=False

1=True

1=Measured Io

2=Calculated Io

1=Measured Uo

2=Calculated Uo

3=Zero seq. volt.

4=Neg. seq. volt.

Unit xUn deg

4.2.2.12

Step

0.01

0.1

Monitored data

Table 422: DEFLPDEF Monitored data

Name

FAULT_DIR

START_DUR

Type

Enum

FLOAT32


0=unknown

1=forward

2=backward

3=both

0.00...100.00

%

DIRECTION

ANGLE_RCA

ANGLE

Enum

FLOAT32

FLOAT32

0=unknown

1=forward

2=backward

3=both

-180.00...180.00

deg

Default

0.01

0.0

0=False

1=Measured Io

1=Measured Uo

3=Zero seq. volt.

Description


Angle correction


Selection for used

Io signal

Selection for used

Uo signal


-180.00...180.00

deg

Description




Angle between operating angle and characteristic angle

Angle between polarizing and operating quantity


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1MRS757644 H

Name

I_OPER

Type

FLOAT32


0.00...40.00

xIn

DEFLPDEF Enum

1=on

2=blocked

3=test

4=test/blocked

5=off

Table 423: DEFHPDEF Monitored data

Name

FAULT_DIR

START_DUR

Type

Enum

FLOAT32


0=unknown

1=forward

2=backward

3=both

0.00...100.00

%

DIRECTION Enum

ANGLE_RCA FLOAT32

0=unknown

1=forward

2=backward

3=both

-180.00...180.00

deg

ANGLE FLOAT32 -180.00...180.00

deg

I_OPER

DEFHPDEF

FLOAT32

Enum

0.00...40.00

1=on

2=blocked

3=test

4=test/blocked

5=off xIn


Description

Calculated operating current

Status

Description






Calculated operating current

Status

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4.2.2.13

Technical data

Table 424: DEFxPDEF Technical data

Characteristic

Operation accuracy

DEFLPDEF

DEFHPDEF

Start time ,

DEFHPDEF

I

Fault


DEFLPDEF

I

Fault


Reset time

Reset ratio

Retardation time




Value


Hz n

±2

Current:


Voltage


Phase angle:

±2°

Current:



)



)

Voltage:


Phase angle:

±2°


42 ms 46 ms 49 ms

58 ms 62 ms 66 ms

Typically 40 ms

Typically 0.96

<30 ms



RMS: No suppression


, where n = 2, 3, 4, 5,…


1

2

3

Measurement mode = default (depends on stage), current before fault = 0.0 × I statistical distribution of 1000 measurements.

Includes the delay of the signal output contact.


, Start value multiples in range of 1.5...20.

n

, f n

= 50 Hz, earth-fault current with nominal frequency injected from random phase angle, results based on

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Technical Manual


4.2.2.14

4.2.3


Table 425: DEFHPDEF Technical revision history


B

C

D

E

F

Change

Maximum value changed to 180 deg for the

Max forward angle setting

Added a setting parameter for the "Measured Io" or "Calculated Io" selection and setting parameter for the "Measured Uo", "Calculated Uo" or "Neg. seq. volt." selection for polarization. Operate delay time and Minimum operate time changed from 60 ms to

40 ms. The sector default setting values are changed from 88 degrees to 80 degrees.



Unit added to calculated operating current output (I_OPER).

Added setting Pol quantity .

Table 426: DEFLPDEF Technical revision history


B

C

D

E

F

Change

Maximum value changed to 180 deg for the

Max forward angle setting.

Start value step changed to 0.005

Added a setting parameter for the "Measured Io" or "Calculated Io" selection and setting parameter for the "Measured Uo", "Calculated Uo" or "Neg. seq. volt." selection for polarization. The sector default setting values are changed from 88 degrees to 80 degrees.



Unit added to calculated operating current output (I_OPER).

Added setting for

Pol quantity . Minimum value

Operate delay time and Minimum operate time changed from “60 ms” to “50 ms”. Default value for

“50 ms”.

Operate delay time and Minimum operate time changed from “60 ms” to

Transient-intermittent earth-fault protection INTRPTEF

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4.2.3.1

4.2.3.2

1MRS757644 H

Identification


Transient/intermittent earth-fault protection


INTRPTEF


Io> -> IEF

ANSI/IEEE C37.2

device number

67NIEF

Function block

4.2.3.3

4.2.3.4


Functionality

The transient/intermittent earth-fault protection function INTRPTEF is a function designed for the protection and clearance of permanent and intermittent earth faults in distribution and sub-transmission networks. Fault detection is done from the residual current and residual voltage signals by monitoring the transients.

The operating time characteristics are according to definite time (DT).




The operation of INTRPTEF can be described with a module diagram. All the modules in the diagram are explained in the next sections.

420 620 series

Technical Manual


Io

Uo

Transient detector

Fault indication logic

Level detector

Timer 1 t

Timer 2

OPERATE

START

BLK_EF

BLOCK

Blocking logic

620 series

Technical Manual


Level detector

The residual voltage can be selected from the Uo signal Sel setting. The options are "Measured Uo" and "Calculated Uo". If "Measured Uo" is selected, the voltage ratio for Uo-channel is given in the global setting Configuration > Analog inputs >

Voltage (Uo,VT). If "Calculated Uo" is selected, the voltage ratio is obtained from phase-voltage channels given in the global setting Configuration > Analog inputs >


Example 1: Uo is measured from open-delta connected VTs (20/sqrt(3) kV : 100/ sqrt(3) V : 100/3 V). In this case, "Measured Uo" is selected. The nominal values for residual voltage is obtained from VT ratios entered in Residual voltage Uo:

Configuration > Analog inputs > Voltage (Uo,VT): 11.547 kV :100 V. The residual voltage start value of 1.0 × Un corresponds to 1.0 × 11.547 kV = 11.547 kV in the primary.

Example 2: Uo is calculated from phase quantities. The phase VT-ratio is 20/sqrt(3) kV : 100/sqrt(3) V. In this case, "Calculated Uo" is selected. The nominal values for residual current and residual voltage are obtained from VT ratios entered in

Residual voltage Uo: Configuration > Analog inputs > Voltage (3U,VT): 20.000 kV :

100 V. The residual voltage start value of 1.0 × Un corresponds to 1.0 × 20.000 kV =

20.000 kV in the primary.

If "Calculated Uo" is selected, the residual voltage nominal value is always phase-to-phase voltage. Thus, the valid maximum setting for residual voltage start value is 0.577 × Un. Calculated Uo requires that all three phase-to-earth voltages are connected to the protection relay. Uo cannot be calculated from the phase-to-phase voltages.

Transient detector

The Transient detector module is used for detecting transients in the residual current and residual voltage signals.

The transient detection is supervised with a settable current threshold. With a special filtering technique, the setting Min operate current is based on the fundamental frequency current. This setting should be set based on the value of

421

Protection functions 1MRS757644 H the parallel resistor of the coil, with security margin. For example, if the resistive current of the parallel resistor is 10 A, then a value of 0.7×10 A = 7 A could be used.

The same setting is also applicable in case the coil is disconnected and the network becomes unearthed. Generally, a smaller value should be used and it must never exceed the value of the parallel resistor in order to allow operation of the faulted feeder.

Fault indication logic

Depending on the set Operation mode, INTRPTEF has two independent modes for detecting earth faults. The "Transient EF" mode is intended to detect all kinds of earth faults. The "Intermittent EF" mode is dedicated for detecting intermittent earth faults in cable networks.

To satisfy the sensitivity requirements, basic earth-fault protection

(based on fundamental frequency phasors) should always be used in parallel with the INTRPTEF function.

The Fault indication logic module determines the direction of the fault. The fault direction determination is secured by multi-frequency neutral admittance measurement and special filtering techniques. This enables fault direction determination which is not sensitive to disturbances in measured Io and Uo signals, for example, switching transients.

When Directional mode setting "Forward" is used, the protection operates when the fault is in the protected feeder. When Directional mode setting "Reverse" is used, the protection operates when the fault is outside the protected feeder

(in the background network). If the direction has no importance, the value "Nondirectional" can be selected. The detected fault direction (FAULT_DIR) is available in the monitored data view.

In the "Transient EF" mode, when the start transient of the fault is detected and the Uo level exceeds the set "Voltage start value", Timer 1 is activated. Timer 1 is kept activated until the Uo level exceeds the set value or in case of a drop-off, the drop-off duration is shorter than the set Reset delay time.

In the "Intermittent EF" mode, when the start transient of the fault is detected and the Uo level exceeds the set Voltage start value, the Timer 1 is activated. When a required number of intermittent earth-fault transients set with the Peak counter limit setting are detected without the function being reset (depends on the dropoff time set with the Reset delay time setting), the START output is activated. The

Timer 1 is kept activated as long as transients are occurring during the drop-off time defined by setting Reset delay time.

Timer 1

The time characteristic is according to DT.

In the "Transient EF" mode, the OPERATE output is activated after Operate delay time if the residual voltage exceeds the set "Voltage start value". The Reset delay time starts to elapse when residual voltage falls below Voltage start value. If there is no OPERATE activation, for example, the fault disappears momentarily, START stays activated until the the Reset delay time elapses. After OPERATE activation, START and OPERATE signals are reset as soon as Uo falls below Voltage start value.

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Figure 208: Example of INTRPTEF operation in ”Transient EF” mode in the faulty feeder

In the "Intermittent EF" mode the OPERATE output is activated when the following conditions are fulfilled:

• the number of transients that have been detected exceeds the Peak counter limit setting

• the timer has reached the time set with the Operate delay time

• and one additional transient is detected during the drop-off cycle

The Reset delay time starts to elapse from each detected transient (peak). In case there is no OPERATE activation, for example, the fault disappears momentarily

START stays activated until the Reset delay time elapses, that is, reset takes place if time between transients is more than Reset delay time. After

OPERATE activation, a fixed pulse length of 100 ms for OPERATE is given, whereas START is reset after

Reset delay time elapses

423


424

Figure 209: Example of INTRPTEF operation in ”Intermittent EF” mode in the faulty feeder, Peak counter limit=3

The timer calculates the start duration value START_DUR which indicates the percentage ratio of the start situation and the set operating time. The value is available in the monitored data view.

Timer 2

If the function is used in the directional mode and an opposite direction transient is detected, the BLK_EF output is activated for the fixed delay time of 25 ms. If the

START output is activated when the BLK_EF output is active, the BLK_EF output is deactivated.

Blocking logic

There are three operation modes in the blocking function. The operation modes are controlled by the BLOCK input and the global setting Configuration > System >

Blocking mode which selects the blocking mode. The BLOCK input can be controlled by a binary input, a horizontal communication input or an internal signal of the protection relay's program. The influence of the BLOCK signal activation is preselected with the global setting Blocking mode.

The Blocking mode setting has three blocking methods. In the "Freeze timers" mode, the operation timer is frozen to the prevailing value. In the "Block all" mode, the whole function is blocked and the timers are reset. In the "Block OPERATE

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4.2.3.5

620 series

Technical Manual output" mode, the function operates normally but the OPERATE output is not activated.

Application

INTRPTEF is an earth-fault function dedicated to operate in intermittent and permanent earth faults occurring in distribution and sub-transmission networks.

Fault detection is done from the residual current and residual voltage signals by monitoring the transients with predefined criteria. As the function has a dedicated purpose for the fault types, fast detection and clearance of the faults can be achieved.

Intermittent earth fault

Intermittent earth fault is a special type of fault that is encountered especially in compensated networks with underground cables. A typical reason for this type of fault is the deterioration of cable insulation either due to mechanical stress or due to insulation material aging process where water or moisture gradually penetrates the cable insulation. This eventually reduces the voltage withstand of the insulation, leading to a series of cable insulation breakdowns. The fault is initiated as the phaseto- earth voltage exceeds the reduced insulation level of the fault point and mostly extinguishes itself as the fault current drops to zero for the first time, as shown in

Figure 210 . As a result, very short transients, that is, rapid changes in the

form of spikes in residual current (Io) and in residual voltage (Uo), can be repeatedly measured. Typically, the fault resistance in case of an intermittent earth fault is only a few ohms.

Residual current Io and residual voltage Uo

COMP. COIL

0.1

(Healthy

Feeder)

FEEDER FEEDER MEAS

INCOMER

0

I ctot

Ioj Iov

Uo

-0.1

Uo

Pulse width

400 - 800 s

Rf

-0.2

-0.3

Ioj

(Faulty

Feeder)

Peak value

~0.1 ... 5 kA

Figure 210: Typical intermittent earth-fault characteristics

Earth-fault transients

In general, earth faults generate transients in currents and voltages. There are several factors that affect the magnitude and frequency of these transients, such

425

Protection functions 1MRS757644 H as the fault moment on the voltage wave, fault location, fault resistance and the parameters of the feeders and the supplying transformers. In the fault initiation, the voltage of the faulty phase decreases and the corresponding capacitance is discharged to earth (→ discharge transients). At the same time, the voltages of the healthy phases increase and the related capacitances are charged (→ charge transient).

If the fault is permanent (non-transient) in nature, only the initial fault transient in current and voltage can be measured, whereas the intermittent fault creates repetitive transients.

4.2.3.6

Figure 211: Example of earth-fault transients, including discharge and charge transient components, when a permanent fault occurs in a 20 kV network in phase C

Signals

Table 427: INTRPTEF Input signals

Name

Io

Uo

BLOCK

Type

SIGNAL

SIGNAL

BOOLEAN

Default

0

0

0=False

Description

Residual current

Residual voltage


Table 428: INTRPTEF Output signals

Name

OPERATE

START

BLK_EF

Type

BOOLEAN

BOOLEAN

BOOLEAN

Description

Operate

Start

Block signal for EF to indicate opposite direction peaks

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4.2.3.7

Settings

Table 429: INTRPTEF Group settings (Basic)

Parameter

Directional mode

Values (Range)

1=Non-directional

2=Forward

3=Reverse



Unit ms xUn

Step

10

0.01

Table 430: INTRPTEF Non group settings (Basic)

Parameter

Operation

Operation mode

Uo signal Sel

Values (Range)

1=on

5=off

1=Intermittent EF

2=Transient EF

1=Measured Uo

2=Calculated Uo

Unit Step

Table 431: INTRPTEF Non group settings (Advanced)


Reset delay time 40...60000

Peak counter limit 2...20

Unit ms

Step

1

1

Min operate current

0.01...1.00

xIn 0.01

4.2.3.8

Monitored data

Table 432: INTRPTEF Monitored data

Name

FAULT_DIR

Type

Enum

START_DUR

INTRPTEF

FLOAT32

Enum

Values (Range)

0=unknown

1=forward

2=backward

3=both

0.00...100.00

1=on

2=blocked

3=test

4=test/blocked

5=off

Unit

%

Default

2=Forward

500

0.20

Description

Directional mode

Operate delay time

Voltage start value

Default

1=on

Description

Operation Off / On

1=Intermittent EF Operation criteria

1=Measured Uo Selection for used

Uo signal

Default

500

2

0.01

Description

Reset delay time

Min requirement for peak counter before start in IEF mode

Minimum operating current for transient detector

Description



Status

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4.2.3.9

Technical data

Table 433: INTRPTEF Technical data

Characteristic

Operation accuracy (Uo criteria with transient protection)



Value


±2 Hz

±1.5% of the set value or ±0.002 × Uo



, where n = 2, 3, 4, 5

4.2.3.10


Table 434: INTRPTEF Technical revision history


B

C

D

E

Change


The Minimum operate current ed. Correction in IEC 61850 mapping: DO

BlkEF renamed to InhEF. Minimum value changed from 0.01 to 0.10 (default changed from 0.01 to 0.20) for the setting. Minimum value changed from 0 ms to 40 ms for the

setting is add-

Voltage start value

Reset delay time setting.

Voltage start value description changed from

"Voltage start value for transient EF" to "Voltage start value" since the start value is effective in both operation modes. Added support for calculated Uo. Uo source (measured/calculated) can be selected with "Uo signal

Sel". Voltage start value setting minimum changed from 0.10 to 0.05.

Min operate current setting scaling corrected to RMS level from peak level.

4.2.4

4.2.4.1

Admittance-based earth-fault protection EFPADM

Identification


Admittance-based earth-fault protection


EFPADM


Yo> ->

ANSI/IEEE C37.2

device number

21YN

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1MRS757644 H

4.2.4.2

Function block


4.2.4.3

4.2.4.4


Functionality

The admittance-based earth-fault protection function EFPADM provides a selective earth-fault protection function for high-resistance earthed, unearthed and compensated networks. It can be applied for the protection of overhead lines as well as with underground cables. It can be used as an alternative solution to traditional residual current-based earth-fault protection functions, such as the IoCos mode in DEFxPDEF. Main advantages of EFPADM include a versatile applicability, good sensitivity and easy setting principles.

EFPADM is based on evaluating the neutral admittance of the network, that is, the quotient:

Yo

=

Io /

−

Uo

(Equation 25)

The measured admittance is compared to the admittance characteristic boundaries in the admittance plane. The supported characteristics include overadmittance, oversusceptance, overconductance or any combination of the three. The directionality of the oversusceptance and overconductance criteria can be defined as forward, reverse or non-directional, and the boundary lines can be tilted if required by the application. This allows the optimization of the shape of the admittance characteristics for any given application.

The function supports two calculation algorithms for admittance. The admittance calculation can be set to include or exclude the prefault zero-sequence values of Io and Uo. Furthermore, the calculated admittance is recorded at the time of the trip and it can be monitored for post-fault analysis purposes.

To ensure the security of the protection, the admittance calculation is supervised by a residual overvoltage condition which releases the admittance protection during a fault condition. Alternatively, the release signal can be provided by an external binary signal.




The operation of EFPADM can be described using a module diagram. All the modules in the diagram are explained in the next sections.

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429


430

1MRS757644 H

Io

Uo

RELEASE

BLOCK

Neutral admittance calculation

Operation characteristics

Timer t

OPERATE

START

Blocking logic


Neutral admittance calculation

The residual current can be selected from the Io signal Sel setting. The setting options are "Measured Io" and "Calculated Io". If "Measured Io" is selected, the current ratio for Io-channel is given in Configuration > Analog inputs > Current

(Io,CT). If "Calculated Io" is selected, the current ratio is obtained from phasecurrent channels given in Configuration > Analog inputs > Current (3I,CT).

Respectively, the residual voltage can be selected from the Uo signal Sel setting.

The setting options are "Measured Uo" and "Calculated Uo". If "Measured Uo" is selected, the voltage ratio for Uo-channel is given in Configuration > Analog

inputs > Voltage (Uo,VT). If "Calculated Uo" is selected, the voltage ratio is obtained from phase-voltage channels given in Configuration > Analog inputs >


Example 1: Uo is measured from open-delta connected VTs (20/sqrt(3) kV : 100/ sqrt(3) V:100/3 V). In this case, "Measured Uo" is selected. The nominal values for residual voltage is obtained from the VT ratios entered in Residual voltage Uo :

Configuration > Analog inputs > Voltage (Uo,VT): 11.547 kV : 100 V. The residual voltage start value of 1.0 × Un corresponds to 1.0 × 11.547 kV = 11.547 kV in the primary.

Example 2: Uo is calculated from phase quantities. The phase VT-ratio is 20/sqrt(3) kV : 100/sqrt(3) V. In this case, "Calculated Uo" is selected. The nominal value for residual voltage is obtained from the VT ratios entered in Residual voltage Uo :

Configuration > Analog inputs > Voltage (3U,VT) : 20.000kV : 100V. The residual voltage start value of 1.0 × Un corresponds to 1.0 × 20.000 kV = 20.000 kV in the primary.

In case, if "Calculated Uo" is selected, the residual voltage nominal value is always phase-to-phase voltage. Thus, the valid maximum setting for residual voltage start value is 0.577 × Un. The calculated Uo requires that all three phase-to-earth voltages are connected to the protection relay.

Uo cannot be calculated from the phase-to-phase voltages.

When the residual voltage exceeds the set threshold Voltage start value, an earth fault is detected and the neutral admittance calculation is released.

To ensure a sufficient accuracy for the Io and Uo measurements, it is required that the residual voltage exceeds the value set by Min operate voltage. If the admittance calculation mode is "Delta", the minimum change in the residual voltage due to a fault must be 0.01 × Un to enable the operation. Similarly, the residual current must exceed the value set by Min operate current.

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The polarity of the polarizing quantity Uo can be changed, that is, rotated by 180 degrees, by setting the Pol reversal parameter to "True" or by switching the polarity of the residual voltage measurement wires.

As an alternative for the internal residual overvoltage-based start condition, the neutral admittance protection can also be externally released by utilizing the

RELEASE input.

When Admittance Clc mode is set to "Delta", the external logic used must be able to give RELEASE in less than 0.1 s from fault initiation. Otherwise the collected pre-fault values are overwritten with fault time values. If it is slower, Admittance Clc mode must be set to “Normal”.

Neutral admittance is calculated as the quotient between the residual current and residual voltage (polarity reversed) fundamental frequency phasors. The

Admittance Clc mode setting defines the calculation mode.

Admittance Clc mode = "Normal"

Io fault

Yo

=

−

Uo fault

(Equation 26)

Admittance Clc mode = "Delta"

Yo =

Io fault

− Io prefault

− ( Uo fault

− Uo prefault

)

∆ Io

=

− ∆ Uo

(Equation 27)

Yo

Io fault

Uo fault

Io prefault

Uo prefault

Δ Io

Δ Uo

Calculated neutral admittance [Siemens]

Residual current during the fault [Amperes]

Residual voltage during the fault [Volts]

Prefault residual current [Amperes]

Prefault residual voltage [Volts]

Change in the residual current due to fault [Amperes]

Change in the residual voltage due to fault [Volts]

Traditionally, admittance calculation is done with the calculation mode "Normal", that is, with the current and voltage values directly measured during the fault.

As an alternative, by selecting the calculation mode "Delta", the prefault zerosequence asymmetry of the network can be removed from the admittance calculation. Theoretically, this makes the admittance calculation totally immune to fault resistance, that is, the estimated admittance value is not affected by fault resistance. Utilization of the change in Uo and Io due to a fault in the admittance calculation also mitigates the effects of the VT and CT measurement errors, thus improving the measuring accuracy, the sensitivity and the selectivity of the protection.

Calculation mode "Delta" is recommended in case a high sensitivity of the protection is required, if the network has a high degree of asymmetry during the healthy state or if the residual current measurement is based on sum connection, that is, the Holmgren connection.

431


Neutral admittance calculation produces certain values during forward and reverse faults.

Fault in reverse direction, that is, outside the protected feeder.

Yo

= −

Y

Fdtot

(Equation 28)

I eFd

U ph

(Equation 29)

Y

Fdtot

I eFd

Sum of the phase-to-earth admittances ( Y

FdA feeder

, Y

FdB

, Y

FdC

) of the protected

Magnitude of the earth-fault current of the protected feeder when the fault resistance is zero ohm

Magnitude of the nominal phase-to-earth voltage of the system U ph

Equation 28

shows that in case of outside faults, the measured admittance equals the admittance of the protected feeder with a negative sign. The measured admittance is dominantly reactive; the small resistive part of the measured admittance is due to the leakage losses of the feeder. Theoretically, the measured admittance is located in the third quadrant in the admittance plane close to the im( Yo) axis, see

Figure 214

.

The result of Equation 28 is valid regardless of the neutral earthing

method. In compensated networks the compensation degree does not affect the result. This enables a straightforward setting principle for the neutral admittance protection: admittance characteristic is set to cover the value Yo = – Y

Fdtot

with a suitable margin.

Due to inaccuracies in voltage and current measurement, the small real part of the calculated neutral admittance may appear as positive, which brings the measured admittance in the fourth quadrant in the admittance plane. This should be considered when setting the admittance characteristic.

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L cc

E

A

~

E

B

E

C

~

~

R cc

A B C

Io

Protected feeder

Y

Fd

Background network

Y

Bg

Reverse

Fault

(I eTot

- I eFd

) I eFd

Im(Yo)

Re(Yo)

Reverse fault:

Yo ≈ -j*I eFd

/U ph

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Figure 214: Admittance calculation during a reverse fault

R

CC

L

CC

R n

Y

Fd

Y

Bg

Resistance of the parallel resistor

Inductance of the compensation coil

Resistance of the neutral earthing resistor

Phase-to-earth admittance of the protected feeder

Phase-to-earth admittance of the background network

For example, in a 15 kV compensated network with the magnitude of the earth-fault current in the protected feeder being 10 A (Rf = 0 Ω), the theoretical value for the measured admittance during an earth fault in the reverse direction, that is, outside the protected feeder, can be calculated.

Yo j

I eFd

U ph

10 A

15 3 kV

1 15 milliSiemens

(Equation 30)

The result is valid regardless of the neutral earthing method.

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434

1MRS757644 H

In this case, the resistive part of the measured admittance is due to leakage losses of the protected feeder. As they are typically very small, the resistive part is close to zero. Due to inaccuracies in the voltage and current measurement, the small real part of the apparent neutral admittance may appear positive. This should be considered in the setting of the admittance characteristic.

Fault in the forward direction, that is, inside the protected feeder.

Unearthed network:

Yo

=

Y

Bgtot

(Equation 31)





I eTot

−

I eFd

U ph





(Equation 32)

Compensated network:

Yo = Y

Bgtot

+ Y

CC

(Equation 33)

≈

I

Rcc

+ ⋅ ( I eTot

⋅ ( 1 − K ) − I eFd

)

U ph

(Equation 34)

High-resistance earthed network:

Yo = Y

Bgtot

+ Y

Rn

(Equation 35)

≈

I

Rn

+ ⋅ ( I eTot

U ph

− I eFd

)

(Equation 36)

Y

Bgtot

Y

CC

I

Rcc

I eFd

I eTot

K

I

Rn

Sum of the phase-to-earth admittances ( Y

BgA network

, Y

BgB

, Y

BgC

) of the background

Admittance of the earthing arrangement (compensation coil and parallel resistor)

Rated current of the parallel resistor

Magnitude of the earth-fault current of the protected feeder when the fault resistance is zero ohm

Magnitude of the uncompensated earth-fault current of the network when Rf is zero ohm

Compensation degree, K = 1 full resonance, K<1 undercompensated, K>1 overcompensated

Rated current of the neutral earthing resistor

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Equation 31 shows that in case of a fault inside the protected feeder in unearthed

networks, the measured admittance equals the admittance of the background network. The admittance is dominantly reactive; the small resistive part of the measured admittance is due to the leakage losses of the background network.

Theoretically, the measured admittance is located in the first quadrant in the

admittance plane, close to the im(Yo) axis, see Figure 215 .

Equation 33 shows that in case of a fault inside the protected feeder in

compensated networks, the measured admittance equals the admittance of the background network and the coil including the parallel resistor. Basically, the compensation degree determines the imaginary part of the measured admittance and the resistive part is due to the parallel resistor of the coil and the leakage losses of the background network and the losses of the coil. Theoretically, the measured admittance is located in the first or fourth quadrant in the admittance plane, depending on the compensation degree, see

Figure 215

.

Before the parallel resistor is connected, the resistive part of the measured admittance is due to the leakage losses of the background network and the losses of the coil. As they are typically small, the resistive part may not be sufficiently large to secure the discrimination of the fault and its direction based on the measured conductance. This and the rating and the operation logic of the parallel resistor should be considered when setting the admittance characteristic in compensated networks.

Equation 35

shows that in case of a fault inside the protected feeder in highresistance earthed systems, the measured admittance equals the admittance of the background network and the neutral earthing resistor. Basically, the imaginary part of the measured admittance is due to the phase-to-earth capacitances of the background network, and the resistive part is due to the neutral earthing resistor and the leakage losses of the background network. Theoretically, the measured admittance is located in the first quadrant in the admittance plane, see

Figure 215

.

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435


L cc

E

A

~

E

B

E

C

~

~

A B C

Io

Protected feeder

Forward

Fault

Y

Fd

I eFd

Background network

I eTot

R cc

Y

Bg

(I eTot

- I eFd

)

436

Forward fault, high resistance earthed network:

Yo ≈ (I

Rn

+j*(I eTot

-I eFd

))/U ph

Forward fault, unearthed network:

Yo ≈ j*(I eTot

-I eFd

)/U ph

Im(Yo)

Reverse fault:

Yo ≈ -j*I eFd

/U ph

Under-comp. (K<1)

Re(Yo)

Resonance (K=1)

Over-comp. (K>1)

Forward fault, compensated network:

Yo ≈ (I rcc

+ j*(I eTot

*(1-K) - I eFd

))/U ph

Figure 215: Admittance calculation during a forward fault

When the network is fully compensated in compensated networks, theoretically during a forward fault, the imaginary part of the measured admittance equals the susceptance of the protected feeder with a negative sign. The discrimination between a forward and reverse fault

620 series

Technical Manual

1MRS757644 H Protection functions must therefore be based on the real part of the measured admittance, that is, conductance. Thus, the best selectivity is achieved when the compensated network is operated either in the undercompensated or overcompensated mode.

For example, in a 15 kV compensated network, the magnitude of the earth-fault current of the protected feeder is 10 A (Rf = 0 Ω) and the magnitude of the network is 100 A (Rf = 0 Ω). During an earth fault, a 15 A resistor is connected in parallel to the coil after a 1.0 second delay. Compensation degree is overcompensated, K = 1.1.

During an earth fault in the forward direction, that is, inside the protected feeder, the theoretical value for the measured admittance after the connection of the parallel resistor can be calculated.

Yo ≈

I

Rcc

+ ⋅

( I eTot

⋅ ( 1 − K ) − I eFd

)

U ph

=

15 A j

(

100 A ⋅ ( − .

) − 10 A

)

15 kkV 3

≈ ( .

− ⋅ .

) milliSiemens

(Equation 37)

Before the parallel resistor is connected, the resistive part of the measured admittance is due to the leakage losses of the background network and the losses of the coil. As they are typically small, the resistive part may not be sufficiently large to secure the discrimination of the fault and its direction based on the measured conductance. This and the rating and the operation logic of the parallel resistor should be considered when setting the admittance characteristic.

When a high sensitivity of the protection is required, the residual current should be measured with a cable/ring core CT, that is, the Ferranti CT.

Also the use of the sensitive Io input should be considered. The residual voltage measurement should be done with an open delta connection of the three single pole-insulated voltage transformers.

The sign of the admittance characteristic settings should be considered based on the location of characteristic boundary in the admittance plane. All forward-settings are given with positive sign and reversesettings with negative sign.

Operation characteristic

After the admittance calculation is released, the calculated neutral admittance is compared to the admittance characteristic boundaries in the admittance plane. If the calculated neutral admittance Yo moves outside the characteristic, the enabling signal is sent to the timer.

EFPADM supports a wide range of different characteristics to achieve the maximum flexibility and sensitivity in different applications. The basic characteristic shape is selected with the Operation mode and Directional mode settings. Operation mode defines which operation criterion or criteria are enabled and Directional mode defines if the forward, reverse or non-directional boundary lines for that particular operation mode are activated.

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Table 435: Operation criteria

Operation mode

Yo

Bo

Go

Yo, Go

Yo, Bo

Go, Bo

Yo, Go, Bo

Description

Admittance criterion

Susceptance criterion

Conductance criterion

Admittance criterion combined with the conductance criterion

Admittance criterion combined with the susceptance criterion

Conductance criterion combined with the susceptance criterion

Admittance criterion combined with the conductance and susceptance criterion

The options for the Directional mode setting are "Non-directional", "Forward" and

"Reverse".

Figure 216

,

Figure 217 and

Figure 218

illustrate the admittance characteristics supported by EFPADM and the settings relevant to that particular characteristic.

The most typical characteristics are highlighted and explained in details in

Chapter 4.2.4.5 Neutral admittance characteristics . Operation is achieved when the

calculated neutral admittance Yo moves outside the characteristic (the operation area is marked with gray).

The settings defining the admittance characteristics are given in primary milliSiemens (mS). The conversion equation for the admittance from secondary to primary is:

Y pri =

Y sec ⋅ ni

CT nu

VT

(Equation 38) ni

CT nu

VT

CT ratio for the residual current Io

VT ratio for the residual voltage Uo

Example: Admittance setting in the secondary is 5.00 milliSiemens. The CT ratio is

100/1 A and the VT ratio is 11547/100 V. The admittance setting in the primary can be calculated.

Y pri = milliSiemens

100 1 A

⋅

11547 100 V

= milliSiemens

(Equation 39)

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Figure 216: Admittance characteristic with different operation modes when

Directional mode = "Non-directional"

439


440


Directional mode = "Forward"

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Directional mode = "Reverse"

441


4.2.4.5

1MRS757644 H

Timer

Once activated, the timer activates the START output. The time characteristic is according to DT. When the operation timer has reached the value set with the

Operate delay time setting, the OPERATE output is activated. If the fault disappears before the module operates, the reset timer is activated. If the reset timer reaches the value set with the Reset delay time setting, the operation timer resets and the START output is deactivated. The timer calculates the start duration value

START_DUR, which indicates the percentage ratio of the start situation and the set operation time. The value is available in the monitored data view.

Blocking logic



The Blocking mode setting has three blocking methods. In the "Freeze timers" mode, the operate timer is frozen to the prevailing value, but the OPERATE output is not deactivated when blocking is activated. In the "Block all" mode, the whole function is blocked and the timers are reset. In the "Block OPERATE output" mode, the function operates normally but the OPERATE output is not activated.

Neutral admittance characteristics

The applied characteristic should always be set to cover the total admittance of the protected feeder with a suitable margin. However, more detailed setting value selection principles depend on the characteristic in question.

The settings defining the admittance characteristics are given in primary milliSiemens.

The forward and reverse boundary settings should be set so that the forward setting is always larger than the reverse setting and that there is space between them.

Overadmittance characteristic

The overadmittance criterion is enabled with the setting Operation mode set to

"Yo". The characteristic is a circle with the radius defined with the Circle radius setting. For the sake of application flexibility, the midpoint of the circle can be moved away from the origin with the Circle conductance and Circle susceptance settings. Default values for Circle conductance and Circle susceptance are 0.0 mS, that is, the characteristic is an origin-centered circle.

Operation is achieved when the measured admittance moves outside the circle.

The overadmittance criterion is typically applied in unearthed networks, but it can also be used in compensated networks, especially if the circle is set off from the origin.

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Figure 219: Overadmittance characteristic. Left figure: classical origin-centered admittance circle. Right figure: admittance circle is set off from the origin.

Non-directional overconductance characteristic

The non-directional overconductance criterion is enabled with the Operation mode setting set to "Go" and Directional mode to "Non-directional". The characteristic is defined with two overconductance boundary lines with the Conductance forward and Conductance reverse settings. For the sake of application flexibility, the boundary lines can be tilted by the angle defined with the Conductance tilt Ang setting. By default, the tilt angle is zero degrees, that is, the boundary line is a vertical line in the admittance plane. A positive tilt value rotates the boundary line counterclockwise from the vertical axis.

In case of non-directional conductance criterion, the Conductance reverse setting must be set to a smaller value than Conductance forward.

Operation is achieved when the measured admittance moves over either of the boundary lines.

The non-directional overconductance criterion is applicable in highresistance earthed and compensated networks. It must not be applied in unearthed networks.

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Figure 220: Non-directional overconductance characteristic. Left figure: classical non-directional overconductance criterion. Middle figure: characteristic is tilted with negative tilt angle. Right figure: characteristic is tilted with positive tilt angle.

443


Forward directional overconductance characteristic

The forward directional overconductance criterion is enabled with the Operation mode setting set to "Go" and Directional mode set to "Forward". The characteristic is defined by one overconductance boundary line with the Conductance forward setting. For the sake of application flexibility, the boundary line can be tilted with the angle defined with the Conductance tilt Ang setting. By default, the tilt angle is zero degrees, that is, the boundary line is a vertical line in the admittance plane. A positive tilt value rotates the boundary line counterclockwise from the vertical axis.

Operation is achieved when the measured admittance moves over the boundary line.

The forward directional overconductance criterion is applicable in highresistance earthed and compensated networks. It must not be applied in unearthed networks.

444

Figure 221: Forward directional overconductance characteristic. Left figure: classical forward directional overconductance criterion. Middle figure: characteristic is tilted with negative tilt angle. Right figure: characteristic is tilted with positive tilt angle.

Forward directional oversusceptance characteristic

The forward directional oversusceptance criterion is enabled with the Operation mode setting set to "Bo" and Directional mode to "Forward". The characteristic is defined by one oversusceptance boundary line with the Susceptance forward setting. For the sake of application flexibility, the boundary line can be tilted by the angle defined with the Susceptance tilt Ang setting. By default, the tilt angle is zero degrees, that is, the boundary line is a horizontal line in the admittance plane. A positive tilt value rotates the boundary line counterclockwise from the horizontal axis.

Operation is achieved when the measured admittance moves over the boundary line.

The forward directional oversusceptance criterion is applicable in unearthed networks. It must not be applied to compensated networks.

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Technical Manual

Figure 222: Forward directional oversusceptance characteristic. Left figure: classical forward directional oversusceptance criterion. Middle figure: characteristic is tilted with negative tilt angle. Right figure: characteristic is tilted with positive tilt angle.

Combined overadmittance and overconductance characteristic

The combined overadmittance and overconductance criterion is enabled with the

Operation mode setting set to "Yo, Go" and Directional mode to "Non-directional".

The characteristic is a combination of a circle with the radius defined with the

Circle radius setting and two overconductance boundary lines with the settings

Conductance forward and Conductance reverse. For the sake of application flexibility, the midpoint of the circle can be moved from the origin with the Circle conductance and Circle susceptance settings. Also the boundary lines can be tilted by the angle defined with the Conductance tilt Ang setting. By default, the Circle conductance and Circle susceptance are 0.0 mS and Conductance tilt Ang equals zero degrees, that is, the characteristic is a combination of an origin-centered circle with two vertical overconductance boundary lines. A positive tilt value for the Conductance tilt Ang setting rotates boundary lines counterclockwise from the vertical axis.

In case of the non-directional conductance criterion, the Conductance reverse setting must be set to a smaller value than Conductance forward.

Operation is achieved when the measured admittance moves outside the characteristic.

The combined overadmittance and overconductance criterion is applicable in unearthed, high-resistance earthed and compensated networks or in systems where the system earthing may temporarily change during normal operation from compensated network to unearthed system.

Compared to the overadmittance criterion, the combined characteristic improves sensitivity in high-resistance earthed and compensated networks. Compared to the non-directional overconductance criterion, the combined characteristic enables the protection to be applied also in unearthed systems.

445


446

Figure 223: Combined overadmittance and overconductance characteristic.

Left figure: classical origin-centered admittance circle combined with two overconductance boundary lines. Right figure: admittance circle is set off from the origin.

Combined overconductance and oversusceptance characteristic

The combined overconductance and oversusceptance criterion is enabled with the

Operation mode setting set to "Go, Bo".

By setting Directional mode to "Forward", the characteristic is a combination of two boundary lines with the settings Conductance forward and Susceptance forward.

See

Figure 224 .

By setting Directional mode to "Non-directional", the characteristic is a combination of four boundary lines with the settings Conductance forward, Conductance

reverse, Susceptance forward and Susceptance reverse. See Figure 225 .

For the sake of application flexibility, the boundary lines can be tilted by the angle defined with the Conductance tilt Ang and Susceptance tilt Ang settings. By default, the tilt angles are zero degrees, that is, the boundary lines are straight lines in the admittance plane. A positive Conductance tilt Ang value rotates the overconductance boundary line counterclockwise from the vertical axis. A positive Susceptance tilt Ang value rotates the oversusceptance boundary line counterclockwise from the horizontal axis.

In case of the non-directional conductance and susceptance criteria, the

Conductance reverse setting must be set to a smaller value than Conductance forward and the Susceptance reverse setting must be set to a smaller value than

Susceptance forward.

Operation is achieved when the measured admittance moves outside the characteristic.

The combined overconductance and oversusceptance criterion is applicable in high-resistance earthed, unearthed and compensated networks or in the systems where the system earthing may temporarily change during normal operation from compensated to unearthed system.

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Figure 224: Combined forward directional overconductance and forward directional oversusceptance characteristic. Left figure: the Conductance tilt Ang and

Susceptance tilt Ang settings equal zero degrees. Right figure: the setting

Conductance tilt Ang > 0 degrees and the setting Susceptance tilt Ang < 0 degrees.

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Figure 225: Combined non-directional overconductance and non-directional oversusceptance characteristic

The non-directional overconductance and non-directional oversusceptance characteristic provides a good sensitivity and selectivity when the characteristic is set to cover the total admittance of the protected feeder with a proper margin.

The sign of the admittance characteristic settings should be considered based on the location of characteristic boundary in the admittance plane. All forward-settings are given with positive sign and reversesettings with negative sign.

447


4.2.4.6

1MRS757644 H

Application

Admittance-based earth-fault protection provides a selective earth-fault protection for high-resistance earthed, unearthed and compensated networks. It can be applied for the protection of overhead lines as well as with underground cables.

It can be used as an alternative solution to traditional residual current-based earth-fault protection functions, for example the IoCos mode in DEFxPDEF. Main advantages of EFPADM include versatile applicability, good sensitivity and easy setting principles.

Residual overvoltage condition is used as a start condition for the admittancebased earth-fault protection. When the residual voltage exceeds the set threshold

Voltage start value, an earth fault is detected and the neutral admittance calculation is released. In order to guarantee a high security of protection, that is, avoid false starts, the Voltage start value setting must be set above the highest possible value of Uo during normal operation with a proper margin. It should consider all possible operation conditions and configuration changes in the network. In unearthed systems, the healthy-state Uo is typically less than

1%×Uph (Uph = nominal phase-to-earth voltage). In compensated networks, the healthy-state Uo may reach values even up to 30%×Uph if the network includes large parts of overheadlines without a phase transposition. Generally, the highest

Uo is achieved when the compensation coil is tuned to the full resonance and when the parallel resistor of the coil is not connected.

The residual overvoltage-based start condition for the admittance protection enables a multistage protection principle. For example, one instance of EFPADM could be used for alarming to detect faults with a high fault resistance using a relatively low value for the Voltage start value setting. Another instance of EFPADM could then be set to trip with a lower sensitivity by selecting a higher value of the

Voltage start value setting than in the alarming instance (stage).

To apply the admittance-based earth-fault protection, at least the following network data are required:

• System earthing method

• Maximum value for Uo during the healthy state

• Maximum earth-fault current of the protected feeder when the fault resistance

Rf is zero ohm

• Maximum uncompensated earth-fault current of the system (Rf = 0 Ω)

• Rated current of the parallel resistor of the coil (active current forcing scheme) in the case of a compensated neutral network

• Rated current of the neutral earthing resistor in the case of a high-resistance earthed system

• Knowledge of the magnitude of Uo as a function of the fault resistance to verify the sensitivity of the protection in terms of fault resistance

Figure 226

shows the influence of fault resistance on the residual voltage magnitude in unearthed and compensated networks. Such information should be available to verify the correct Voltage start value setting, which helps fulfill the requirements for the sensitivity of the protection in terms of fault resistance.

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100

90

80

70

60

50

Unearthed

Rf = 500 ohm

Rf = 2500 ohm

Rf = 5000 ohm

Rf = 10000 ohm

40

30

20

10

0

0 10 20 30 40 50 60 70 80 90 100

Total earth fault current (A), Rf = 0 ohm

Resonance, K = 1

100

90

80

70

60

50

40

30

20

10

0

0 10 20 30 40 50 60 70 80 90 100


Over/Under-Compensated, K = 1.2/0.8

100

90

80

70

60

50

40

30

20

10

0

0 10 20 30 40 50 60 70 80 90 100


Figure 226: Influence of fault resistance on the residual voltage magnitude in 10 kV unearthed and compensated networks. The leakage resistance is assumed to be

30 times larger than the absolute value of the capacitive reactance of the network.

Parallel resistor of the compensation coil is assumed to be disconnected.

Unearthed

100

90

80

70

60

Rf = 500 ohm

Rf = 2500 ohm

Rf = 5000 ohm

Rf = 10000 ohm

50

40

30

20

10

0

0 10 20 30 40 50 60 70 80 90 100


Resonance, K = 1

100

90

80

70

60

50

40

30

20

10

0

0 10 20 30 40 50 60 70 80 90100



100

90

80

70

60

50

40

30

20

10

0

0 10 20 30 40 50 60 70 80 90100





Unearthed

100

90

80

70

60

50

40

30

Rf = 500 ohm

Rf = 2500 ohm

Rf = 5000 ohm

Rf = 10000 ohm

20

10

0

0 10 20 30 40 50 60 70 80 90100


Resonance, K = 1

100

90

80

70

60

50

40

30

20

10

0

0 10 20 30 40 50 60 70 80 90 100



100

90

80

70

60

50

40

30

20

10

0

0 10 20 30 40 50 60 70 80 90 100





Example

In a 15 kV, 50 Hz compensated network, the maximum value for Uo during the healthy state is 10%×Uph. Maximum earth-fault current of the system is

100 A. The maximum earth-fault current of the protected feeder is 10 A (Rf

= 0 Ω). The applied active current forcing scheme uses a 15 A resistor (at

15 kV), which is connected in parallel to the coil during the fault after a 1.0

second delay.

Solution: As a start condition for the admittance-based earth-fault protection, the internal residual overvoltage condition of EFPADM is used.

The Voltage start value setting must be set above the maximum healthystate Uo of 10%×Uph with a suitable margin.

449


450

1MRS757644 H

Voltage start value = 0.15 × Un

According to Figure 227 , this selection ensures at least a sensitivity

corresponding to a 2000 ohm fault resistance when the compensation degree varies between 80% and 120%. The greatest sensitivity is achieved when the compensation degree is close to full resonance.

An earth-fault current of 10 A can be converted into admittance.

Y

Fdtot

10 A

=

15 kV 3

≈ j

⋅

1 15 mS

(Equation 40)

A parallel resistor current of 15 A can be converted into admittance.

G cc

15 A

=

15 kV 3

≈

1 73 mS

(Equation 41)

According to Equation 28 , during an outside fault EFPADM measures the

following admittance:

Yo

= −

Y

Fdtot ≈ − ⋅

.

mS

(Equation 42)

According to Equation 31

, during an inside fault EFPADM measures the admittance after the connection of the parallel resistor:

Yo = Y

Bgtot

+ Y

CC

≈ ( ) mS

(Equation 43)

Where the imaginary part of the admittance, B, depends on the tuning of the coil (compensation degree).

The admittance characteristic is selected to be the combined overconductance and oversusceptance characteristic ("Box"-characteristics) with four boundary lines:

Operation mode = "Go, Bo"

Directional mode = "Non-directional"

The admittance characteristic is set to cover the total admittance of the

protected feeder with a proper margin, see Figure 229

. Different setting groups can be used to allow adaptation of protection settings to different feeder and network configurations.

Conductance forward

This setting should be set based on the parallel resistor value of the coil. It must be set to a lower value than the conductance of the parallel resistor, in order to enable dependable operation. The selected value should move the boundary line

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1MRS757644 H Protection functions from origin to include some margin for the admittance operation point due to

CT/VT-errors, when fault is located outside the feeder.

Conductance forward: 15 A/(15 kV/sqrt(3)) * 0.2 = +0.35 mS corresponding to 3.0

A (at 15 kV). The selected value provides margin considering also the effect of

CT/VT-errors in case of outside faults.

In case of smaller rated value of the parallel resistor, for example, 5 A (at 15 kV), the recommended security margin should be larger, for example 0.7, so that sufficient margin for CT/VT-errors can be achieved.

Susceptance forward

By default, this setting should be based on the minimum operate current of 1 A.

Susceptance forward: 1 A/(15 kV/sqrt(3)) = +0.1 mS

Susceptance reverse

This setting should be set based on the value of the maximum earth-fault current produced by the feeder (considering possible feeder topology changes) with a security margin. This ensures that the admittance operating point stays inside the "Box"-characteristics during outside fault. The recommended security margin should not be lower than 1.5.

Susceptance reverse: - (10 A * 1.5)/ (15 kV/sqrt(3)) = -1.73 mS

Conductance reverse

This setting is used to complete the non-directional characteristics by closing the

"Box"-characteristic. In order to keep the shape of the characteristic reasonable and to allow sufficient margin for the admittance operating point during outside fault, it is recommended to use the same value as for setting Susceptance reverse.

Conductance reverse = -1.73 mS

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Figure 229: Admittances of the example

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4.2.4.7

Signals

Table 436: EFPADM Input signals

Name

Io

Uo

BLOCK

Type

SIGNAL

SIGNAL

BOOLEAN

RELEASE BOOLEAN

Table 437: EFPADM Output signals

Name

OPERATE

START

Type

BOOLEAN

BOOLEAN

4.2.4.8

Settings

Table 438: EFPADM Group settings (Basic)



Directional mode

1=Non-directional

2=Forward

3=Reverse

Operation mode

1=Yo

2=Go

3=Bo

4=Yo, Go

5=Yo, Bo

6=Go, Bo

7=Yo, Go, Bo


Circle radius 0.05...500.00

Circle conductance -500.00...500.00

Unit xUn ms mS mS

Circle susceptance -500.00...500.00

mS

Conductance forward

Conductance reverse

-500.00...500.00

-500.00...500.00

Table continues on the next page mS mS

Step

0.01

10

0.01

0.01

0.01

0.01

0.01

452

Default

0

0

0=False

0=False

60

1.00

0.00

0.00

1.00

-1.00

Default

0.15

2=Forward

1=Yo

Description

Operate

Start

Description

Residual current

Residual voltage


External trigger to release neutral admittance protection

Description

Voltage start value

Directional mode

Operation criteria

Operate delay time

Admittance circle radius

Admittance circle midpoint, conductance

Admittance circle midpoint, susceptance

Conductance threshold in forward direction

Conductance threshold in reverse direction

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1MRS757644 H

Parameter

Susceptance forward

Susceptance reverse

Values (Range)

-500.00...500.00

-500.00...500.00

Unit mS mS

Step

0.01

0.01

Table 439: EFPADM Group settings (Advanced)

Parameter

Conductance tilt

Ang

Values (Range)

-30...30

Unit deg

Susceptance tilt

Ang

-30...30

deg

Step

1

1

Table 440: EFPADM Non group settings (Basic)

Parameter

Operation

Values (Range)

1=on

5=off

Unit Step

Table 441: EFPADM Non group settings (Advanced)

Parameter

Admittance Clc mode

Reset delay time

Pol reversal

Values (Range)

1=Normal

2=Delta

0...60000

0=False

1=True

0.01...1.00

Unit ms xIn

Step

1

0.01

Min operate current

Min operate voltage

Io signal Sel

0.01...1.00

xUn 0.01

Uo signal Sel

1=Measured Io

2=Calculated Io

1=Measured Uo

2=Calculated Uo

Default

1.00

-1.00

Default

0

0

Default

1=on


Description

Susceptance threshold in forward direction

Susceptance threshold in reverse direction

Description

Tilt angle of conductance boundary line

Tilt angle of susceptance boundary line

Description

Operation Off / On

Default

1=Normal

20

0=False

0.01

0.01

1=Measured Io

1=Measured Uo

Description

Admittance calculation mode

Reset delay time




Selection for used

Io signal

Selection for used

Uo signal

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4.2.4.9

Monitored data

Table 442: EFPADM Monitored data

Name

START_DUR

Type

FLOAT32


0.00...100.00

%

FAULT_DIR Enum

COND_RES

SUS_RES

EFPADM

FLOAT32

FLOAT32

Enum

0=unknown

1=forward

2=backward

3=both

-1000.00...1000.0

0 mS

-1000.00...1000.0

0 mS

1=on

2=blocked

3=test

4=test/blocked

5=off

Description



Real part of calculated neutral admittance

Imaginary part of calculated neutral admittance

Status

4.2.4.10

Technical data

Table 443: EFPADM Technical data

Characteristic

Operation accuracy

Start time

Reset time



4.2.5

Value

At the frequency f = f n

±1.0% or ±0.01 mS

(In range of 0.5...100 mS)

Minimum

56 ms

Typical

60 ms

40 ms

±1.0% of the set value of ±20 ms

-50 dB at f = n × f n

, where n = 2, 3, 4, 5,…

Maximum

64 ms

Rotor earth-fault protection MREFPTOC

1

2

Uo = 1.0 × Un.

Includes the delay of the signal output contact, results based on statistical distribution of 1000 measurements.

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1MRS757644 H

4.2.5.1

4.2.5.2


Identification


Rotor earth-fault protection

Function block


MREFPTOC


Io>R

ANSI/IEEE C37.2

device number

64R

4.2.5.3

4.2.5.4


Functionality

The rotor earth-fault protection function MREFPTOC is used to detect an earth fault in the rotor circuit of synchronous machines. MREFPTOC is used with the injection device REK510, which requires a secured 58, 100 or 230 V AC 50/60 Hz input source and injects a 100 V AC voltage via its coupling capacitors to the rotor circuit towards earth.

MREFPTOC consists of independent alarm and operating stages. The operating time characteristic is according to definite time (DT) for both stages.



The operation of MREFPTOC can be described using a module diagram. All the modules in the diagram are explained in the next sections.

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4.2.5.5

456

1MRS757644 H


The measured rotor earth-fault current (DFT value) is compared to the Operate start value setting. If the measured value exceeds that of the Operate start value setting, Level detector 1 sends a signal to start the Timer 1 module.


The measured rotor earth-fault current (DFT value) is compared to the set Alarm start value. If the measured value exceeds that of the Alarm start value setting,

Level detector 2 sends a signal to start the Timer 2 module.

For MREFPTOC, the earth-fault current is the current that flows due to the voltage injected by the injection device in the rotor circuit when an earth fault arises.

A considerable amount of harmonics, mainly 3rd and 6th, can occur in the excitation current under normal no-fault conditions, especially with the thyristor excitation and rotating diode rectifier systems. MREFPTOC uses DFT value calculation to filter DC and harmonic components which could otherwise give out false alarms or trips.

Timer 1

Once activated, the Timer activates the START output. The timer characteristic is according to DT. When the operation timer has reached the value set by Operate delay time in the DT mode, the OPERATE output is activated. If a drop-off situation occurs, that is, a fault suddenly disappears before the operating delay is exceeded, the timer reset state is activated. The reset time depends on the Reset delay time setting.

The binary input BLOCK can be used to block the function. The activation of the

BLOCK input deactivates all outputs and resets the internal timers.

Timer 2

Once activated, the Timer activates the alarm timer. The timer characteristic is according to DT. When the alarm timer has reached the value set by Alarm delay time in the DT mode, the ALARM output is activated. If a drop-off situation occurs, that is, a fault suddenly disappears before the alarm delay is exceeded, the timer reset state is activated. The reset time depends on the Alm reset delay time setting.

The binary input BLOCK can be used to block the function. The activation of the

BLOCK input deactivates all outputs and resets the internal timers.

Application

The rotor circuit of synchronous machines is normally isolated from the earth.

The rotor circuit can be exposed to an abnormal mechanical or thermal stress due to, for example, vibrations, overcurrent and choked cooling medium flow. This can result in the breakdown of the insulation between the field winding and the rotor iron at the point exposed to excessive stress. If the isolation resistance is decreased significantly, this can be seen as an earth fault. For generators with slip rings, the rotor insulation resistance is sometimes reduced due to the accumulated carbon dust layer produced by the carbon brushes. As the circuit has a high impedance to earth, a single earth fault does not lead to any immediate damage because the fault current is small due to a low voltage. There is, however, a risk that a second earth fault appears, creating a rotor winding interturn fault and causing

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1MRS757644 H Protection functions severe magnetic imbalance and heavy rotor vibrations that soon lead to a severe damage.

Therefore, it is essential that any occurrence of an insulation failure is detected and that the machine is disconnected as soon as possible. Normally, the device is tripped after a short time delay.

A 50/60 Hz voltage is injected via the injection device REK 510 to the rotor field winding circuit of the synchronous machine as shown in

Figure 232 . The injected

voltage is 100 V AC via the coupling capacitors. A coupling capacitor prevents a DC current leakage through the injection device.

620 series

Technical Manual

Figure 232: Principle of the rotor earth-fault protection with the current injection device

The auxiliary AC voltage forms a small charging current I

1

to flow via the coupling capacitors, resistances of the brushes and the leakage capacitance between the field circuit and earth. The field-to-earth capacitance C operating conditions.

E

affects the level of the resulting current to an extent which is a few milliamperes during normal no-fault

If an earth fault arises in the rotor field circuit, this current increases and can reach a level of 130 mA at a fully developed earth fault (fault resistance R

E

= 0, one coupling capacitor C

1

= 2μF is used). The integrated current transformer of the injection device REK 510 then amplifies this current with the ratio of 1:10 to a measurable level. MREFPTOC is used to measure this current.

An example of the measured curves with various field-to-earth leakage capacitance values is given in

Figure 233

.

It is recommended that the alarm and operation stages of MREFPTOC are both used. The alarm stage for giving an indication for weakly developed earth faults with a start value setting corresponds to a 10 kΩ fault resistance with a 10-second delay. The operation stage for a protection against fully developed earth faults with a start value setting corresponds to a 1...2 kΩ fault resistance with a 0.5-second delay.

The current setting values corresponding to the required operating fault resistances can be tested by connecting an adjustable faultsimulating resistor between the excitation winding poles and the earth. Whether only one of the coupling capacitors or both should be used in a parallel connection should be determined on a case-by-case basis, taking into consideration the consequences of a possibly excessive current at a direct earth fault.

457


458

Figure 233: Measured current as a function of the rotor earth-fault resistance with various field-to-earth capacitance values with the measuring circuit resistance Rm =

3.0 Ω, fn = 50 Hz. Only one coupling capacitor is used.

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1MRS757644 H

4.2.5.6

Signals

Table 444: MREFPTOC Input signals

Name

Io

BLOCK

Type

SIGNAL

BOOLEAN

Default

0

0=False

Table 445: MREFPTOC Output signals

Name

OPERATE

START

ALARM

Type

BOOLEAN

BOOLEAN

BOOLEAN

4.2.5.7

Settings

Table 446: MREFPTOC Group settings (Basic)


Operate start value 0.010...2.000

Alarm start value 0.010...2.000


Alarm delay time 40...200000

Unit xIn xIn ms ms

Table 447: MREFPTOC Non group settings (Basic)

Parameter

Operation

Values (Range)

1=on

5=off

Unit Step

Step

1

1

0.001

0.001

Table 448: MREFPTOC Non group settings (Advanced)

Parameter

Reset delay time

Alm reset delay time

Values (Range)

0...60000

0...60000

Unit ms ms

Step

1

1

Description

Residual current


Description

Operate

Start

Alarm

Default

0.010

0.010

500

10000

Default

1=on

Default

20

20


Description

Operate start value

Alarm start value

Operate delay time

Alarm delay time

Description

Operation Off / On

Description

Reset delay time

Alarm reset delay time

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4.2.5.8

Monitored data

Table 449: MREFPTOC Monitored data

Name

START_DUR

Type

FLOAT32

MREFPTOC Enum

Values (Range)

0.00...100.00

1=on

2=blocked

3=test

4=test/blocked

5=off

Unit

%

Description


Status

4.2.5.9

Technical data

Table 450: MREFPTOC Technical data

Characteristic

Operation accuracy

Start time 1 , 2

Reset time

Reset ratio

Retardation time



I value

= 1.2 × set Start

Value

Depending on the frequency of the current measured: f n

±2 Hz



30 ms

<50 ms

34 ms 38 ms

Typically 0.96

<50 ms

±1.0% of the set value of ±20 ms

-50 dB at f = n × f n

, where n = 2, 3, 4, 5,…

4.2.6

4.2.6.1

4.2.6.2

Harmonics-based earth-fault protection HAEFPTOC

Identification

Description

Harmonics-based earth-fault protection


HAEFPTOC


Io>HA

ANSI/IEEE C37.2

device number

51NHA

Function block

HAEFPTOC

Io

I_REF_RES

BLOCK

OPERATE

START


1

2

Current before fault = 0.0 × I n

, f n

= 50 Hz, earth-fault current with nominal frequency injected from random phase angle, results based on statistical distribution of 1000 measurements.


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4.2.6.3

4.2.6.4

Functionality

The harmonics-based earth-fault protection function HAEFPTOC is used instead of a traditional earth-fault protection in networks where a fundamental frequency component of the earth-fault current is low due to compensation.

By default, HAEFPTOC is used as a standalone mode. Substation-wide application can be achieved using horizontal communication where the detection of a faulty feeder is done by comparing the harmonics earth-fault current measurements.

The function starts when the harmonics content of the earth-fault current exceeds the set limit. The operation time characteristic is either definite time (DT) or inverse definite minimum time (IDMT). If the horizontal communication is used for the exchange of current values between the protection relays, the function operates according to the DT characteristic.

The function contains a blocking functionality. It is possible to block function outputs, timer or the function itself, if desired.



The operation of HAEFPTOC can be described using a module diagram. All the modules in the diagram are explained in the next sections.

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Harmonics calculation

This module feeds the measured residual current to the high-pass filter, where the frequency range is limited to start from two times the fundamental frequency of the network (for example, in a 50 Hz network the cutoff frequency is 100 Hz), that is, summing the harmonic components of the network from the second harmonic.

The output of the filter, later referred to as the harmonics current, is fed to the Level detector and Current comparison modules.

461


The harmonics current I_HARM_RES is available in the monitored data view. The value is also sent over horizontal communication to the other protection relays on the parallel feeders configured in the protection scheme.

1.0

0.5

462

0

0 f 2f

Frequency

Figure 236: High-pass filter

Level detector

The harmonics current is compared to the Start value setting. If the value exceeds the value of the Start value setting, Level detector sends an enabling signal to the

Timer module.

Current comparison

The maximum of the harmonics currents reported by other parallel feeders in the substation, that is, in the same busbar, is fed to the function through the I_REF_RES input. If the locally measured harmonics current is higher than

I_REF_RES , the enabling signal is sent to Timer.

If the locally measured harmonics current is lower than I_REF_RES , the fault is not in that feeder. The detected situation blocks Timer internally, and simultaneously also the BLKD_I_REF output is activated.

The module also supervises the communication channel validity which is reported to the Timer.

Timer

The START output is activated when Level detector sends the enabling signal.

Functionality and the time characteristics depend on the selected value of the

Enable reference use setting.

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Table 451: Values of the Enable reference use setting

Enable reference use

Standalone

Reference use

Functionality

In the standalone mode, depending on the value of the Operating curve type setting, the time characteristics are according to DT or IDMT. When the operation timer has reached the value of the Operate delay time setting in the DT mode or the value defined by the inverse time curve, the OPERATE output is activated.

Communication valid

When using the horizontal communication, the function is forced to use the DT characteristics.

When the operation timer has reached the value of the Minimum operate time setting and simultaneously the enabling signal from the Current comparison module is active, the OPERATE signal is activated.

Communication invalid

Function operates as in the standalone mode.

The Enable reference use setting forces the function to use the DT characteristics where the operating time is set with the Minimum operate time setting.

If the communication for some reason fails, the function switches to use the

Operation curve type setting, and if DT is selected, Operate delay time is used. If the

IDMT curve is selected, the time characteristics are according to the selected curve and the Minimum operate time setting is used for restricting too fast an operation time.

In case of a communication failure, the start duration may change substantially depending on the user settings.

When the programmable IDMT curve is selected, the operation time characteristics are defined with the Curve parameter A, Curve parameter B, Curve parameter C,

Curve parameter D and Curve parameter E parameters.

If a drop-off situation happens, that is, a fault suddenly disappears before the operation delay is exceeded, the Timer reset state is activated. The functionality of Timer in the reset state depends on the combination of the Operating curve type, Type of reset curve and Reset delay time settings. When the DT characteristic is selected, the reset timer runs until the value of the Reset delay time setting is exceeded. When the IDMT curves are selected, the Type of reset curve setting can be set to "Immediate", "Def time reset" or "Inverse reset". The reset curve type

"Immediate" causes an immediate reset. With the reset curve type "Def time reset", the reset time depends on the Reset delay time setting. With the reset curve type

"Inverse reset", the reset time depends on the current during the drop-off situation.

If the drop-off situation continues, the reset timer is reset and the START output is deactivated.

The "Inverse reset" selection is only supported with ANSI or the programmable types of the IDMT operating curves. If another operating curve type is selected, an immediate reset occurs during the drop-off situation.

The setting Time multiplier is used for scaling the IDMT operation and reset times.

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1MRS757644 H

The setting parameter Minimum operate time defines the minimum desired operation time for IDMT. The setting is applicable only when the IDMT curves are used

The Minimum operate time setting should be used with great care because the operation time is according to the IDMT curve but always at least the value of the Minimum operate time setting. More information

can be found in Chapter 11.2.1 IDMT curves for overcurrent protection .

Timer calculates the start duration value START_DUR, which indicates the percentage ratio of the start situation, and the set operating time, which can be either according to DT or IDMT. The value is available in the monitored data view.

More information can be found in Chapter 11 General function block features .

Blocking logic




Application

During an earth fault, HAEFPTOC calculates the maximum current for the current feeder. The value is sent over an analog GOOSE to other protection relays of the busbar in the substation. At the configuration level, all the values received over the analog GOOSE are compared through the MAX function to find the maximum value. The maximum value is sent back to HAEFPTOC as the I_REF_RES input. The operation of HAEFPTOC is allowed in case I_REF_RES is lower than the locally measured harmonics current. If I_REF_RES exceeds the locally measured harmonics current, the operation of HAEFPTOC is blocked.

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Analogue

GOOSE receive

Analogue

GOOSE receive

MAX

Io

I_REF_RES

BLOCK

HAEFPTOC

START

OPERATE

I_HARM_RES

BLKD_I_REF

Analogue

GOOSE send

4.2.6.6

Analogue

GOOSE receive

Figure 237: Protection scheme based on the analog GOOSE communication with three analog GOOSE receivers

Signals

Table 452: HAEFPTOC Input signals

Name

Io

BLOCK

Type

SIGNAL

BOOLEAN

Default

0

0=False

I_REF_RES FLOAT32 0.0

Table 453: HAEFPTOC Output signals

Name

OPERATE

START

Type

BOOLEAN

BOOLEAN

Description

Residual current


Reference current

Description

Operate

Start

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4.2.6.7

Settings

Table 454: HAEFPTOC Group settings (Basic)

Parameter

Start value

Time multiplier

Values (Range)

0.05...5.00

0.05...15.000

Unit xIn



1=ANSI Ext. inv.

2=ANSI Very inv.

3=ANSI Norm. inv.

4=ANSI Mod. inv.

5=ANSI Def. Time

6=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. inv.

15=IEC Def. Time

17=Programmable

18=RI type

19=RD type ms

Table 455: HAEFPTOC Group settings (Advanced)

Parameter


Values (Range)

100...200000


2=Def time reset

3=Inverse reset

Enable reference use

0=False

1=True

Unit ms

Step

10

Step

0.01

0.01

10

Table 456: HAEFPTOC Non group settings (Basic)

Parameter

Operation

Values (Range)

1=on

5=off


Unit Step

1


1


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Default

0.10

1.00

600

15=IEC Def. Time

Description

Start value


Operate delay time


Default

500

1=Immediate

0=False

Description



Enable using current reference from other IEDs instead of stand-alone

Default

1=on

28.2000

0.1217

Description

Operation Off / On



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Unit Step

1

1

1

Default

2.00

29.10

1.0

Description




Table 457: HAEFPTOC Non group settings (Advanced)

Parameter

Reset delay time

Values (Range)

0...60000

Unit ms

Step

10

4.2.6.8

Monitored data

Table 458: HAEFPTOC Monitored data

Name

START_DUR

Type

FLOAT32

I_HARM_RES

BLKD_I_REF

FLOAT32

BOOLEAN

HAEFPTOC Enum

Values (Range)

0.00...100.00

0.0...30000.0

0=False

1=True

1=on

2=blocked

3=test

4=test/blocked

5=off

4.2.6.9

Technical data

Table 459: HAEFPTOC Technical data

Characteristic

Operation accuracy

Start time ,

Reset time

Reset ratio


Operate time accuracy in IDMT mode


Unit

%

A

Default

20

Description

Reset delay time

Description


Calculated harmonics current

Current comparison status indicator

Status

Value


Hz n

±2

±5% of the set value or ±0.004 × I n

Typically 77 ms

Typically 40 ms

Typically 0.96



-50 dB at f = f n

-3 dB at f = 13 × f n

1

2

3

Fundamental frequency current = 1.0 × I n

, harmonics current before fault = 0.0 × I n

, harmonics fault current 2.0 × Start value, results based on statistical distribution of 1000 measurements.



, Start value multiples in range of 2...20.

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4.2.7

4.2.7.1

4.2.7.2

Wattmetric-based earth-fault protection WPWDE

Identification


Wattmetric-based earth-fault protection


WPWDE


Po> ->

ANSI/IEEE C37.2

device number

32N

Function block

4.2.7.3

4.2.7.4

468


Functionality

The wattmetric-based earth-fault protection function WPWDE can be used to detect earth faults in unearthed networks, compensated networks (Petersen coilearthed networks) or networks with a high-impedance earthing. It can be used as an alternative solution to the traditional residual current-based earth-fault protection functions, for example, the IoCos mode in the directional earth-fault protection function DEFxPDEF.

WPWDE measures the earth-fault power 3UoIoCosφ and gives an operating signal when the residual current Io, residual voltage Uo and the earth-fault power exceed the set limits and the angle (φ) between the residual current and the residual voltage is inside the set operating sector, that is, forward or backward sector. The operating time characteristic can be selected to be either definite time (DT) or a special wattmetric-type inverse definite minimum type (wattmetric type IDMT).

The wattmetric-based earth-fault protection is very sensitive to current transformer errors and it is recommended that a core balance CT is used for measuring the residual current.




For WPWDE, certain notations and definitions are used.

Residual voltage Uo = (UA+UB+UC)/3 = U

0 voltage

, where U

0

= zero-sequence

Residual current Io = -(IA+IB+IC) = 3×- I

0 current

, where I

0

= zero-sequence

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The minus sign (-) is needed to match the polarity of calculated and measured residual currents.

The operation of WPWDE can be described with a module diagram. All the modules in the diagram are explained in the next sections.

Io

Uo

RCA_CTL

Directional calculation

Level detector

Timer t

OPERATE

Residual power calculation t

START

BLOCK

Blocking logic

Figure 239: Function module diagram


The Directional calculation module monitors the angle between the operating quantity (residual current Io) and polarizing quantity (residual voltage Uo). The operating quantity can be selected with the setting Io signal Sel. The selectable options are “Measured Io” and “Calculated Io”. The polarizing quantity can be selected with the setting Pol signal Sel. The selectable options are “Measured Uo” and “Calculated Uo”. When the angle between operating quantity and polarizing quantity after considering the Characteristic angle setting is in the operation sector, the module sends an enabling signal to Level detector. The directional operation is selected with the Directional mode setting. Either the “Forward” or

“Reverse” operation mode can be selected. The direction of fault is calculated based on the phase angle difference between the operating quantity Io and polarizing quantity Uo, and the value (ANGLE) is available in the monitored data view.

In the phasor diagrams representing the operation of WPWDE, the polarity of the polarizing quantity (residual voltage Uo) is reversed. Reversing is done by switching the polarity of the residual current measuring channel (See the connection diagram in the application manual).

If the angle difference lies between -90° to 0° or 0° to +90°, a forward-direction fault is considered. If the phase angle difference lies within -90° to -180° or +90° to +180°, a reverse-direction fault is detected. Thus, the normal width of a sector is 180°.

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470

Figure 240: Definition of the relay characteristic angle

The phase angle difference is calculated based on the Characteristic angle setting

(also known as Relay Characteristic Angle (RCA) or Relay Base Angle or Maximum

Torque Angle (MTA)). The Characteristic angle setting is done based on the method of earthing employed in the network. For example, in case of an unearthed network, the Characteristic angle setting is set to -90°, and in case of a compensated network, the Characteristic angle setting is set to 0°. In general, Characteristic angle is selected so that it is close to the expected fault angle value, which results in maximum sensitivity. Characteristic angle can be set anywhere between -179° to +180°. Thus, the effective phase angle ( ϕ ) for calculating the residual power considering characteristic angle is according to the equation.

φ ( Uo ) − ∠ Io Characteristic angle )

(Equation 44)

In addition, the characteristic angle can be changed via the control signal RCA_CTL .

The RCA_CTL input is used in the compensated networks where the compensation coil sometimes is temporarily disconnected. When the coil is disconnected, the compensated network becomes isolated and the Characteristic angle setting must be changed. This can be done automatically with the RCA_CTL input, which results in the addition of -90° in the Characteristic angle setting.

The value (ANGLE_RCA) is available in the monitored data view.

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Forward area

RCA = -90˚

Maximum torque line

Io (Operating quantity)

Forward area

-Uo (Polarizing quantity)

Backward area

Minimum operate current

Backward area

Figure 241: Definition of relay characteristic angle, RCA = -90° in an isolated network

Characteristic angle should be set to a positive value if the operating signal lags the polarizing signal and to a negative value if the operating signal leads the polarizing signal.

Type of network

Compensated network

Unearthed network

Recommended characteristic angle

0°

-90°

In unearthed networks, when the characteristic angle is -90°, the measured residual power is reactive (varmetric power).

The fault direction is also indicated FAULT_DIR (available in the monitored data view), which indicates 0 if a fault is not detected, 1 for faults in the forward direction and 2 for faults in the backward direction.

The direction of the fault is detected only when the correct angle calculation can be made. If the magnitude of the operating quantity or polarizing quantity is not high enough, the direction calculation is not reliable. Hence, the magnitude of the operating quantity is compared to the Min operate current setting and the magnitude of the polarizing quantity is compared to Min operate voltage, and if both the operating quantity and polarizing quantity are higher than their respective limit, a valid angle is calculated and the residual power calculation module is enabled.

The Correction angle setting can be used to improve the selectivity when there are inaccuracies due to the measurement transformer. The setting decreases the operation sector. The Correction angle setting should be done carefully as the phase angle error of the measurement transformer varies with the connected burden as well as with the magnitude of the actual primary current that is being measured. An example of how Correction angle alters the operating region is as shown:

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1MRS757644 H

Zero torque line

Correction angle

Maximum torque line forward direction (RCA = 0˚)



Forward area

Forward area

Correction angle


Backward area

Backward area

Figure 242: Definition of correction angle

The polarity of the polarizing quantity can be changed (rotated by 180°) by setting Pol reversal to "True" or by switching the polarity of the residual voltage measurement wires.

Residual power calculation

The Residual power calculation module calculates the magnitude of residual power

3UoIoCosφ. Angle φ is the angle between the operating quantity and polarizing quantity, compensated with a characteristic angle. The angle value is received from the Directional calculation module. The Directional calculation module enables the residual power calculation only if the minimum signal levels for both operating quantity and polarizing quantity are exceeded. However, if the angle calculation is not valid, the calculated residual power is zero. Residual power (RES_POWER) is calculated continuously and it is available in the monitored data view. The power is given in relation to nominal power calculated as Pn = Un × In, where Un and In are obtained from the entered voltage transformer and current transformer ratios entered, and depend on the Io signal Sel and Uo signal Sel settings.

Level detector

Level detector compares the magnitudes of the measured operating quantity

(residual current Io), polarizing quantity (residual voltage Uo) and calculated residual power to the set Current start value (×In), Voltage start value (×Un) and

Power start value (×Pn) respectively. When all three quantities exceed the limits,

Level detector enables the Timer module.

When calculating the setting values for Level detector, it must be considered that the nominal values for current, voltage and power depend on whether the residual quantities are measured from a dedicated measurement channel or calculated from phase quantities, as defined in the Io signal Sel and Uo signal Sel settings.

For residual current Io, if "Measured Io" is selected, the nominal values for primary and secondary are obtained from the current transformer ratio entered for residual

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Technical Manual current channel Configuration > Analog inputs > Current (Io, CT). If "Calculated

Io" is selected, the nominal values for primary and secondary are obtained from the current transformer ratio entered for phase current channels Configuration >

Analog inputs > Current (3I, CT).

For residual voltage Uo, if "Measured Uo" is selected, the nominal values for primary and secondary are obtained from the voltage transformer ratio entered for residual voltage channel Configuration > Analog inputs > Voltage (Uo, VT). If "Calculated

Uo" is selected, the nominal values for primary and secondary are obtained from the voltage transformer ratio entered for phase voltage channels Configuration >

Analog inputs > Voltage (3U, VT).

Calculated Uo requires that all three phase-to-earth voltages are connected to the protection relay. Uo cannot be calculated from the phase-to-phase voltages.

As nominal power is the result of the multiplication of the nominal current and the nominal voltage Pn = Un × In, the calculation of the setting value for Power start value (×Pn) depends on whether Io and Uo are measured or calculated from the phase quantities.

Table 460: Measured and calculated Io and Uo

Measured Uo

Calculated Uo

Measured Io

Pn = (Uo, VT) × (Io, CT)

Pn = (3U, VT) × (Io, CT)

Calculated Io

Pn = (Uo, VT) × (3I, CT)

Pn = (3U, VT) × (3I, CT)

Example 1. Io is measured with cable core CT (100/1A) and Uo is measured from open delta-connected VTs (20/sqrt(3) kV:100/sqrt(3) V:100/3 V). In this case,

"Measured Io" and "Measured Uo" are selected. The nominal values for residual current and residual voltage are obtained from CT and VT ratios.

Residual current Io: Configuration > Analog inputs > Current (Io, CT): 100 A:1 A

Residual voltage Uo: Configuration > Analog inputs > Current (Uo, VT): 11.547

kV:100 V

Residual Current start value of 1.0 × In corresponds then 1.0 × 100 A = 100 A in primary

Residual Voltage start value of 1.0 × Un corresponds then 1.0 × 11.547 kV = 11.547 kV in primary

Residual Power start value of 1.0 × Pn corresponds then 1.0 × 11.547 kV × 100 A =

1154.7kW in primary

Example 2. Both Io and Uo are calculated from phase quantities. Phase CT-ratio is 100:1 A and Phase VT-ratio 20/sqrt(3) kV:100/sqrt(3) V. In this case "Calculated

Io" and "Calculated Uo" are selected. The nominal values for residual current and residual voltage are obtained from CT and VT ratios entered in:

Residual current Io: Configuration > Analog inputs > Current (3I, CT): 100 A:1 A

Residual voltage Uo: Configuration > Analog inputs > Current (3U, VT): 20.000

kV:100 V

Residual Current start value of 1.0 × In corresponds then 1.0 × 100 A = 100 A in primary

Residual Voltage start value of 1.0 × Un corresponds then 1.0 × 20.000 kV = 20.000

kV in primary

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Residual Power start value of 1.0 × Pn corresponds then 1.0 × 20.000 kV × 100 A =

2000kW in primary

If "Calculated Uo" is selected for the Uo signal Sel setting, the nominal value for residual voltage Un is always phase-to-phase voltage. Thus, the valid maximum setting for residual Voltage start value is 0.577 × Un, which corresponds to full phase-to-earth voltage in primary.

Timer

Once activated, Timer activates the START output. Depending on the value of the Operating curve type setting, the time characteristics are according to DT or wattmetric IDMT. When the operation timer has reached the value of Operate delay time in the DT mode or the maximum value defined by the inverse time curve, the OPERATE output is activated. If a drop-off situation happens, that is, a fault suddenly disappears before the operating delay is exceeded, the timer reset state is activated. The reset time is identical for both DT or wattmeter IDMT. The reset time depends on the Reset delay time setting.

Timer calculates the start duration value START_DUR, which indicates the percentage ratio of the start situation and the set operation time. The value is available in the monitored data view.

Blocking logic





In the wattmetric IDMT mode, the OPERATE output is activated based on the timer characteristics:

= k * P ref

P cal

(Equation 45) t[s] k

P ref

P cal operation time in seconds set value of Time multiplier set value of Reference power calculated residual power

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Figure 243: Operation time curves for wattmetric IDMT for S ref set at 0.15 xPn

475


4.2.7.6

4.2.7.7




Application

The wattmetric method is one of the commonly used directional methods for detecting the earth faults especially in compensated networks. The protection uses the residual power component 3UoIoCosφ (φ is the angle between the polarizing quantity and operating quantity compensated with a relay characteristic angle).



Forward area

Zero torque line

(RCA = 0 ˚)


Backward area

Uo

Figure 244: Characteristics of wattmetric protection

In a fully compensated radial network with two outgoing feeders, the earth-fault currents depend mostly on the system earth capacitances (C

0

) of the lines and the compensation coil (L). If the coil is tuned exactly to the system capacitance, the fault current has only a resistive component. This is due to the resistances of the coil and distribution lines together with the system leakage resistances (R

0 a resistor (R

L

). Often

) in parallel with the coil is used for increasing the fault current.

When a single phase-to-earth fault occurs, the capacitance of the faulty phase is bypassed and the system becomes unsymmetrical. The fault current is composed of the currents flowing through the earth capacitances of two healthy phases. The protection relay in the healthy feeder tracks only the capacitive current flowing through its earth capacitances. The capacitive current of the complete network

(sum of all feeders) is compensated with the coil.

A typical network with the wattmetric protection is an undercompensated network where the coil current I network and I

Cfd

L

= I

Ctot

- I

Cfd

(I

Ctot

is the total earth-fault current of the

is the earth-fault current of the healthy feeder).

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L

I

L

R

L U

0

A B C

ΣI

01

ΣI

02

C

0

I

Cfd

Ic tot

= I ef

R

0

- U

0

ΣI

01

ΣI

02

- U

0

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Figure 245: Typical radial compensated network employed with wattmetric protection

The wattmetric function is activated when the residual active power component exceeds the set limit. However, to ensure a selective operation, it is also required that the residual current and residual voltage also exceed the set limit.

It is highly recommended that core balance current transformers are used for measuring Io when using the wattmetric method. When a low transformation ratio is used, the current transformer can suffer accuracy problems and even a distorted secondary current waveform with some core balance current transformers.

Therefore, to ensure a sufficient accuracy of the residual current measurement and consequently a better selectivity of the scheme, the core balance current transformer should preferably have a transformation ratio of at least 70:1. Lower transformation ratios such as 50:1 or 50:5 are not recommended, unless the phase displacement errors and current transformer amplitude are checked first.

It is not recommended to use the directional wattmetric protection in case of a ring or meshed system as the wattmetric requires a radial power flow to operate.

The relay characteristic angle needs to be set based on the system earthing. In an unearthed network, that is, when the network is only coupled to earth via the capacitances between the phase conductors and earth, the characteristic angle is chosen as -90°.

In compensated networks, the capacitive fault current and inductive resonance coil current compensate each other, meaning that the fault current is mainly resistive and has zero phase shift compared to the residual voltage. In such networks, the characteristic angle is chosen as 0°. Often the magnitude of an active component is small and must be increased by means of a parallel resistor in a compensation coil. In networks where the neutral point is earthed through a low resistance, the characteristic angle is always 0°.

As the amplitude of the residual current is independent of the fault location, the selectivity of the earth-fault protection is achieved with time coordination.

477


4.2.7.8

The use of wattmetric protection gives a possibility to use the dedicated inverse definite minimum time characteristics. This is applicable in large high-impedance earthed networks with a large capacitive earth-fault current.

In a network employing a low-impedance earthed system, a medium-size neutral point resistor is used. Such a resistor gives a resistive earth-fault current component of about 200...400 A for an excessive earth fault. In such a system, the directional residual power protection gives better possibilities for selectivity enabled by the inverse time power characteristics.

Signals

Table 461: WPWDE Input signals

Name

Io

Uo

BLOCK

Type

SIGNAL

SIGNAL

BOOLEAN

Default

0

0

0=False

RCA_CTL BOOLEAN 0=False

Table 462: WPWDE Output signals

Name

OPERATE

START

Type

BOOLEAN

BOOLEAN

Description

Residual current

Residual voltage



Description

Operate

Start

4.2.7.9

Settings

Table 463: WPWDE Group settings (Basic)

Parameter

Directional mode

Values (Range)

2=Forward

3=Reverse

Current start value 0.010...5.000

Unit xIn

Step

0.001

Default

2=Forward

0.010


Power start value 0.003...1.000

Reference power 0.050...1.000


Time multiplier

-179...180

0.05...2.00

Table continues on the next page xUn xPn xPn deg

0.001

0.001

0.001

1

0.01

0.010

0.003

0.150

-90

1.00

Description

Directional mode

Minimum operate residual current for deciding fault direction

Start value for residual voltage

Start value for residual active power

Reference value of residual power for

Wattmetric IDMT curves


Time multiplier for

Wattmetric IDMT curves

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Parameter


Values (Range)

5=ANSI Def. Time

15=IEC Def. Time

20=Wattmetric

IDMT


Unit ms

Step

10

Table 464: WPWDE Non group settings (Basic)

Parameter

Operation

Values (Range)

1=on

5=off

Unit Step

Table 465: WPWDE Non group settings (Advanced)

Parameter

Measurement mode

Values (Range)

1=RMS

2=DFT

3=Peak-to-Peak

0.0...10.0

0.010...1.000

Unit deg xIn

Correction angle

Min operate current

Min operate voltage

Reset delay time

Pol reversal

Io signal Sel

Uo signal Sel

0.01...1.00

0...60000

0=False

1=True

1=Measured Io

2=Calculated Io

1=Measured Uo

2=Calculated Uo xUn ms

Step

0.1

0.001

0.01

1

4.2.7.10

Monitored data

Table 466: WPWDE Monitored data

Name

FAULT_DIR

Type

Enum

START_DUR

DIRECTION

FLOAT32

Enum

Values (Range)

0=unknown

1=forward

2=backward

3=both

0.00...100.00

0=unknown

1=forward

2=backward

3=both


Unit

%

Default

15=IEC Def. Time

Description


60

Default

1=on

Operate delay time for definite time

Description

Operation Off / On

Default

2=DFT

2.0

0.010

0.01

20

0=False

1=Measured Io

1=Measured Uo

Description

Selects used current measurement mode

Angle correction



Reset delay time


Selection for used

Io signal

Selection for used polarization signal

Description




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Name

ANGLE

ANGLE_RCA

RES_POWER

WPWDE

Type

FLOAT32

FLOAT32

FLOAT32

Enum

Values (Range)

-180.00...180.00

-180.00...180.00

-160.000...160.000

1=on

2=blocked

3=test

4=test/blocked

5=off

Unit deg deg xPn

Description



Calculated residual active power

Status

4.2.7.11

Technical data

Table 467: WPWDE Technical data

Characteristic

Operation accuracy

Start time 1 , 2

Reset time

Reset ratio


Operate time accuracy in IDMT mode


4.2.8

4.2.8.1

Value


±2 Hz

Current and voltage:


Power:

±3% of the set value or ±0.002 × P n

Typically 63 ms

Typically 40 ms

Typically 0.96



-50 dB at f = n × f n

, where n = 2,3,4,5,…

Multifrequency admittance-based earth-fault protection

MFADPSDE

Identification

Description

Multifrequency admittance-based earth-fault protection


MFADPSDE


Io> ->Y

ANSI/IEEE C37.2

device number

67YN

1

2

Io varied during the test, Uo = 1.0 × U n

= phase-to-earth voltage during earth fault in compensated or unearthed network, the residual power value before fault = 0.0 pu, f n

= 50 Hz, results based on statistical distribution of 1000 measurements.


480 620 series

Technical Manual

1MRS757644 H

4.2.8.2

Function block


4.2.8.3

4.2.8.4


Functionality

The multifrequency admittance-based earth-fault protection function MFADPSDE provides selective directional earth-fault protection for high-impedance earthed networks, that is, for compensated, unearthed and high resistance earthed systems. It can be applied for the earth-fault protection of overhead lines and underground cables.

The operation of MFADPSDE is based on multifrequency neutral admittance measurement, utilizing cumulative phasor summing technique. This concept provides extremely secure, dependable and selective earth-fault protection also in cases where the residual quantities are highly distorted and contain nonfundamental frequency components.

The sensitivity that can be achieved is comparable with traditional fundamental frequency based methods such as IoCos/IoSin (DEFxPDEF), Watt/Varmetric

(WPWDE) and neutral admittance (EFPADM).

MFADPSDE is capable of detecting faults with dominantly fundamental frequency content as well as transient, intermittent and restriking earth faults. MFADPSDE can be used as an alternative solution to transient or intermittent function INTRPTEF.

MFADPSDE supports fault direction indication both in operate and non-operate direction, which may be utilized during fault location process. The inbuilt transient detector can be used to identify restriking or intermittent earth faults, and discriminate them from permanent or continuous earth faults.

The operation characteristic is defined by a tilted operation sector, which is universally valid for unearthed and compensated networks.

The operating time characteristic is according to the definite time (DT).

The function contains a blocking functionality to block function outputs, timers or the function itself.



The operation of MFADPSDE can be described using a module diagram. All the modules in the diagram are explained in the following sections.

620 series

Technical Manual

481


482


General fault criterion

The General fault criterion ( GFC) module monitors the presence of earth fault in the network and it is based on the value of the fundamental frequency zero-sequence voltage defined as the vector sum of fundamental frequency phase voltage phasors divided by three.

U

1

0

=

(

U

1

A

+ U

1

B

+ U

1

C

)

/ 3

(Equation 46)

U

1

When the magnitude of o

exceeds setting Voltage start value, an earth fault is detected. The GFC module reports the exceeded value to the Fault direction determination module and Operation logic. The reporting is referenced as General

Fault Criterion release.

The setting Voltage start value defines the basic sensitivity of the MFADPSDE function. To avoid unselective start or operation, Voltage start val

ABB 620 series IEC 2.0 FP1 Technical Manual 1224 Pages

ABB 620 series IEC 2.0 FP1 Technical Manual

—

620 series

Technical Manual

Trademarks

Warranty

www.abb.com/relion

Contents

1

1.1

1.2

Introduction

This manual

Intended audience

1.3

Product documentation

1.4

Symbols and conventions

2

2.1

620 series overview

Overview

2.2

Local HMI

2.3

Web HMI

2.4

Authorization

2.5

Communication

3 Basic functions

3.1

General parameters

3.2

Self-supervision

3.3

LED indication control

3.4

Programmable LEDs

3.5

Time synchronization

3.6

Parameter setting groups

3.7

Test mode

3.8

Fault recorder FLTRFRC

3.9

Nonvolatile memory

3.10

Sensor inputs for currents and voltages

3.11

Binary inputs

3.12

Binary outputs

3.13

RTD/mA inputs

=

Value maximum − Value minimum

⋅ deadband

∆ Y s

=

°

⋅

°

≈

3.14

SMV function blocks

3.15

GOOSE function blocks

3.16

Type conversion function blocks

3.17

Configurable logic blocks

3.18

3.19

Factory settings restoration

Load profile record LDPRLRC

3.20