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Advanced Zone Selection logic accompanied by optionally available end-fault and/or
circuit breaker failure protections ensure minimum possible tripping time and
selectivity for faults within the blind spot or the end zone between bay CT and bay
circuit breaker. Therefore the IED offers best possible coverage for such faults in
feeder and bus-section/bus-coupler bays.

Optionally available circuit breaker failure protection, one for every CT input into the
IED, offers secure local back-up protection for the circuit breakers in the station.

Optionally available four-stage, non-directional overcurrent protections, one for every
CT input into the IED, provide remote backup functionality for connected feeders and
remote-end stations.

Optionally available voltage and frequency protection functions enable to include
voltage release criterion for busbar protection or to integrate independent over-, under-
voltage protection for the bus in the busbar protection IED.

Optionally available over-current, thermal overload and capacitor bank protection
functions open possibilities to integrate protection of shunt reactors and shunt capacitor
banks into the busbar protection IED.

It is normal practice to have just one busbar protection IED per busbar. Nevertheless
some utilities do apply two independent busbar protection IEDs per zone of protection.
This IED fits both solutions.

A simplified bus differential protection for multi-phase faults and ground faults can be
obtained by using a single, one-phase IED with external auxiliary summation current
transformers.

The IED can be used in applications with IEC/UCA 61850-9-2LE process bus with up
to eight merging units (MU) depending on the other functionality included in the IED.
Each MU has eight analog channels, four currents and four voltages. Conventional and
Merging Unit channels can be mixed freely in the application.

Forcing of binary inputs and outputs is a convenient way to test wiring in substations
as well as testing configuration logic in the IEDs. Basically it means that all binary
inputs and outputs on the IED I/O modules (BOM, BIM, IOM & SOM) can be forced
to arbitrary values.

Central Account Management is an authentication infrastructure that offers a secure
solution for enforcing access control to IEDs and other systems within a substation.
This incorporates management of user accounts, roles and certificates and the
distribution of such, a procedure completely transparent to the user.

The Flexible Product Naming allows the customer to use an IED-vendor independent
IEC 61850 model of the IED. This customer model will be exposed in all IEC 61850
communication, but all other aspects of the IED will remain unchanged (e.g., names on

Section 2

1MRK 505 370-UUS A

Application

38

Busbar protection REB670 2.2 ANSI

Application manual

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Summary of Contents for RELION REB670

Page 1: ...RELION 670 SERIES Busbar protection REB670 Version 2 2 ANSI Application manual ...

Page 2: ......

Page 3: ...Document ID 1MRK 505 370 UUS Issued October 2017 Revision A Product version 2 2 1 Copyright 2017 ABB All rights reserved ...

Page 4: ...erms of such license This product includes software developed by the OpenSSL Project for use in the OpenSSL Toolkit http www openssl org This product includes cryptographic software written developed by Eric Young eay cryptsoft com and Tim Hudson tjh cryptsoft com Trademarks ABB and Relion are registered trademarks of the ABB Group All other brand or product names mentioned in this document may be...

Page 5: ...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 document has been carefully checked by ABB but deviations cannot be compl...

Page 6: ...rning electrical equipment for use within specified voltage limits Low voltage directive 2006 95 EC This conformity is the result of tests conducted by ABB in accordance with the product standard EN 60255 26 for the EMC directive and with the product standards EN 60255 1 and EN 60255 27 for the low voltage directive The product is designed in accordance with the international standards of the IEC ...

Page 7: ...nd monitoring functions 42 Communication 47 Basic IED functions 49 Section 3 Configuration 51 Description of configuration REB670 51 Available ACT configurations for pre configured REB670 51 Configuration X01 51 Configuration X02 52 Configuration X03 52 Description of 3 ph package A20A 52 Description of 3 ph package A31A 54 Description of 1 ph package B20A 58 Description of 1 ph package B31A 62 Se...

Page 8: ... a three phase to ground connected VT to the IED 86 Example on how to connect a phase to phase connected VT to the IED 88 Example on how to connect an open delta VT to the IED for high impedance grounded or ungrounded networks 90 Example how to connect the open delta VT to the IED for low impedance grounded or solidly grounded power systems 93 Section 5 Local HMI 97 Display 98 LEDs 101 Keypad 102 ...

Page 9: ...half busbar arrangements 143 Double busbar single breaker arrangement 145 Double busbar arrangements with two bus section breakers and two bus coupler breakers 151 Combined busbar arrangements 152 Six zone busbar arrangements 155 General 155 Typical arrangement which can be covered 155 Example engineering procedure 157 Summation principle 163 Introduction 163 Auxiliary summation CTs 166 Possible A...

Page 10: ...ings for each step x 1 2 3 and 4 202 Four step directional negative phase sequence overcurrent protection NS4PTOC 46I2 204 Identification 204 Application 204 Setting guidelines 206 Settings for each step 207 Common settings for all steps 210 Thermal overload protection two time constants TRPTTR 49 211 Identification 211 Application 211 Setting guideline 212 Breaker failure protection CCRBRF 50BF 2...

Page 11: ...Backup protection for power system faults 244 Settings for two step undervoltage protection 244 Two step overvoltage protection OV2PTOV 59 246 Identification 246 Application 246 Setting guidelines 247 Equipment protection such as for motors generators reactors and transformers 248 Equipment protection capacitors 248 Power supply quality 248 High impedance grounded systems 248 The following setting...

Page 12: ...61 Setting guidelines 262 Overfrequency protection SAPTOF 81 262 Identification 263 Application 263 Setting guidelines 263 Rate of change of frequency protection SAPFRC 81 264 Identification 264 Application 264 Setting guidelines 265 Section 10 Multipurpose protection 267 General current and voltage protection CVGAPC 267 Identification 267 Application 267 Current and voltage selection for CVGAPC f...

Page 13: ...uence based 287 Zero sequence based 288 Delta V and delta I 289 Dead line detection 289 Fuse failure supervision VDSPVC 60 289 Identification 290 Application 290 Setting guidelines 291 Section 12 Control 293 Synchronism check energizing check and synchronizing SESRSYN 25 293 Identification 293 Application 293 Synchronizing 293 Synchronism check 295 Energizing check 297 Voltage selection 298 Extern...

Page 14: ...hase or 2 phase reclosing in the first shot 321 ARMode 1 2ph 1 3ph 1 phase 2 phase or 3 phase reclosing in the first shot 322 ARMode 1ph 1 2 3ph 1 phase 2 phase or 3 phase reclosing in the first shot 322 External selection of auto reclosing mode 323 Auto reclosing reset timer 323 Pulsing of the circuit breaker closing command and counter 323 Transient fault 324 Permanent fault and reclosing unsucc...

Page 15: ...locking for bus coupler bay ABC_BC 3 369 Application 369 Configuration 369 Signals from all feeders 369 Signals from bus coupler 372 Configuration setting 373 Interlocking for transformer bay AB_TRAFO 3 374 Application 374 Signals from bus coupler 375 Configuration setting 376 Interlocking for bus section breaker A1A2_BS 3 377 Application 377 Signals from all feeders 377 Configuration setting 380 ...

Page 16: ... 399 Identification 399 Application 399 Setting guidelines 400 Generic communication function for Double Point indication DPGAPC 400 Identification 401 Application 401 Setting guidelines 402 Single point generic control 8 signals SPC8GAPC 402 Identification 402 Application 402 Setting guidelines 402 AutomationBits command function for DNP3 0 AUTOBITS 403 Identification 403 Application 403 Setting ...

Page 17: ... 412 Boolean 16 to Integer conversion B16I 413 Identification 413 Application 413 Boolean to integer conversion with logical node representation 16 bit BTIGAPC 414 Identification 415 Application 415 Integer to Boolean 16 conversion IB16 416 Identification 416 Application 416 Integer to Boolean conversion for six zone busbar BCTZCONN 417 Identification 417 Application 418 Integer to Boolean 16 conv...

Page 18: ...tting guidelines 430 Setting examples 433 Gas medium supervision SSIMG 63 440 Identification 440 Application 440 Setting guidelines 441 Liquid medium supervision SSIML 71 442 Identification 442 Application 442 Setting guidelines 442 Breaker monitoring SSCBR 443 Identification 443 Application 443 Setting guidelines 447 Setting procedure on the IED 447 Event function EVENT 448 Identification 448 App...

Page 19: ... 459 Setting guidelines 460 Section 15 Metering 461 Pulse counter logic PCFCNT 461 Identification 461 Application 461 Setting guidelines 461 Function for energy calculation and demand handling ETPMMTR 462 Identification 462 Application 462 Setting guidelines 463 Section 16 Ethernet based communication 465 Access point 465 Application 465 Setting guidelines 465 Redundant communication 467 Identific...

Page 20: ...0 Application 480 Setting guidelines 482 IEC 60870 5 103 communication protocol 483 Application 483 Functionality 483 Design 484 Settings 486 Settings for RS485 and optical serial communication 486 Settings from PCM600 487 Function and information types 489 DNP3 Communication protocol 490 Application 490 Section 18 Remote communication 491 Binary signal transfer 491 Identification 491 Application ...

Page 21: ...lication 505 Setting guidelines 505 Parameter setting groups 505 Application 505 Setting guidelines 506 Rated system frequency PRIMVAL 506 Identification 506 Application 506 Setting guidelines 506 Summation block 3 phase 3PHSUM 507 Application 507 Setting guidelines 507 Global base values GBASVAL 507 Identification 507 Application 508 Setting guidelines 508 Signal matrix for binary inputs SMBI 508...

Page 22: ...rent transformer requirements 527 Rated equivalent secondary e m f requirements 527 Busbar protection 528 Breaker failure protection 529 Non directional instantaneous and definitive time phase and residual overcurrent protection 529 Non directional inverse time delayed phase and residual overcurrent protection 530 Current transformer requirements for CTs according to other standards 531 Current tr...

Page 23: ...ation of communication requirements for the protection and control terminals in digital telecommunication networks 534 Section 22 Glossary 537 Table of contents Busbar protection REB670 2 2 ANSI 17 Application manual ...

Page 24: ...18 ...

Page 25: ...provide assistance for calculating settings 1 2 Intended audience GUID C9B8127F 5748 4BEA 9E4F CC762FE28A3A v11 This manual addresses the protection and control engineer responsible for planning pre engineering and engineering The protection and control engineer must be experienced in electrical power engineering and have knowledge of related technology such as protection schemes and communication...

Page 26: ...ns instructions on how to engineer the IEDs using the various tools available within the PCM600 software The manual provides instructions on how to set up a PCM600 project and insert IEDs to the project structure The manual also recommends a sequence for the engineering of protection and control functions LHMI functions as well as communication engineering for IEC 60870 5 103 IEC 61850 DNP3 LON an...

Page 27: ...he manual can also provide assistance for calculating settings The technical manual contains operation principle 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 The commun...

Page 28: ...anual IEC 61850 Edition 2 1MRK 511 393 UEN Point list manual DNP3 1MRK 511 397 UUS Accessories guide 1MRK 514 012 BUS Connection and Installation components 1MRK 513 003 BEN Test system COMBITEST 1MRK 512 001 BEN 1 4 Document symbols and conventions 1 4 1 Symbols GUID 2945B229 DAB0 4F15 8A0E B9CF0C2C7B15 v12 The electrical warning icon indicates the presence of a hazard which could result in elect...

Page 29: ...o personal injury or death It is important that the user fully complies with all warning and cautionary notices 1 4 2 Document conventions GUID 96DFAB1A 98FE 4B26 8E90 F7CEB14B1AB6 v6 Abbreviations and acronyms in this manual 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 but...

Page 30: ...in another diagram have the suffix cont Dimensions are provided both in inches and millimeters If it is not specifically mentioned then the dimension is in millimeters Illustrations are used as an example and might show other products than the one the manual describes The example that is illustrated is still valid 1 5 IEC 61850 edition 1 edition 2 mapping GUID C5133366 7260 4C47 A975 7DBAB3A33A96 ...

Page 31: ..._F12 BFPTRC BFPTRC BFPTRC_F13 BFPTRC BFPTRC BFPTRC_F14 BFPTRC BFPTRC BFPTRC_F15 BFPTRC BFPTRC BFPTRC_F16 BFPTRC BFPTRC BFPTRC_F17 BFPTRC BFPTRC BFPTRC_F18 BFPTRC BFPTRC BFPTRC_F19 BFPTRC BFPTRC BFPTRC_F20 BFPTRC BFPTRC BFPTRC_F21 BFPTRC BFPTRC BFPTRC_F22 BFPTRC BFPTRC BFPTRC_F23 BFPTRC BFPTRC BFPTRC_F24 BFPTRC BFPTRC BICPTRC_01 BICPTRC BICPTRC BICPTRC_02 BICPTRC BICPTRC BICPTRC_03 BICPTRC BICPTRC ...

Page 32: ...RC BUSPTRC_B16 BUSPTRC BUSPTRC BUSPTRC_B17 BUSPTRC BUSPTRC BUSPTRC_B18 BUSPTRC BUSPTRC BUSPTRC_B19 BUSPTRC BUSPTRC BUSPTRC_B20 BUSPTRC BUSPTRC BUSPTRC_B21 BUSPTRC BUSPTRC BUSPTRC_B22 BUSPTRC BUSPTRC BUSPTRC_B23 BUSPTRC BUSPTRC BUSPTRC_B24 BUSPTRC BUSPTRC BUTPTRC_B1 BUTPTRC BBTPLLN0 BUTPTRC BUTPTRC_B2 BUTPTRC BUTPTRC BUTPTRC_B3 BUTPTRC BUTPTRC BUTPTRC_B4 BUTPTRC BUTPTRC BUTPTRC_B5 BUTPTRC BUTPTRC B...

Page 33: ... BZNTGAPC BZNTPDIF CBPGAPC CBPLLN0 CBPMMXU CBPPTRC HOLPTOV HPH1PTOV PH3PTUC PH3PTOC RP3PDOP CBPMMXU CBPPTRC HOLPTOV HPH1PTOV PH3PTOC PH3PTUC RP3PDOP CCPDSC CCRPLD CCPDSC CCRBRF CCRBRF CCRBRF CCRWRBRF CCRWRBRF CCRWRBRF CCSRBRF CCSRBRF CCSRBRF CCSSPVC CCSRDIF CCSSPVC CMMXU CMMXU CMMXU CMSQI CMSQI CMSQI COUVGAPC COUVLLN0 COUVPTOV COUVPTUV COUVPTOV COUVPTUV CVGAPC GF2LLN0 GF2MMXN GF2PHAR GF2PTOV GF2PT...

Page 34: ...FPIOC EFPIOC EFRWPIOC EFRWPIOC EFRWPIOC ETPMMTR ETPMMTR ETPMMTR FDPSPDIS FDPSPDIS FDPSPDIS FMPSPDIS FMPSPDIS FMPSPDIS FRPSPDIS FPSRPDIS FPSRPDIS FTAQFVR FTAQFVR FTAQFVR FUFSPVC SDDRFUF FUFSPVC SDDSPVC GENPDIF GENPDIF GENGAPC GENPDIF GENPHAR GENPTRC GOPPDOP GOPPDOP GOPPDOP PH1PTRC GRPTTR GRPTTR GRPTTR GSPTTR GSPTTR GSPTTR GUPPDUP GUPPDUP GUPPDUP PH1PTRC HZPDIF HZPDIF HZPDIF INDCALCH INDCALH INDCALH...

Page 35: ...C LCP3PTUC LCP3PTUC LCP3PTUC LCPTTR LCPTTR LCPTTR LCZSPTOC LCZSPTOC LCZSPTOC LCZSPTOV LCZSPTOV LCZSPTOV LD0LLN0 LLN0 LDLPSCH LDLPDIF LDLPSCH LDRGFC STSGGIO LDRGFC LEXPDIS LEXPDIS LEXPDIS LEXPTRC LFPTTR LFPTTR LFPTTR LMBRFLO LMBRFLO LMBRFLO LOLSPTR LOLSPTR LOLSPTR LOVPTUV LOVPTUV LOVPTUV LPHD LPHD LPTTR LPTTR LPTTR LT3CPDIF LT3CPDIF LT3CGAPC LT3CPDIF LT3CPHAR LT3CPTRC LT6CPDIF LT6CPDIF LT6CGAPC LT6...

Page 36: ...OV2PTOV PH1PTRC PAPGAPC PAPGAPC PAPGAPC PCFCNT PCGGIO PCFCNT PH4SPTOC GEN4PHAR OCNDLLN0 PH1BPTOC PH1PTRC GEN4PHAR PH1BPTOC PH1PTRC PHPIOC PHPIOC PHPIOC PSLPSCH ZMRPSL PSLPSCH PSPPPAM PSPPPAM PSPPPAM PSPPTRC QCBAY QCBAY BAY LLN0 QCRSV QCRSV QCRSV RCHLCCH RCHLCCH RCHLCCH REFPDIF REFPDIF REFPDIF ROTIPHIZ ROTIPHIZ ROTIPHIZ ROTIPTRC ROV2PTOV GEN2LLN0 PH1PTRC ROV2PTOV PH1PTRC ROV2PTOV SAPFRC SAPFRC SAPF...

Page 37: ...PC SPGGIO SPGAPC SSCBR SSCBR SSCBR SSIMG SSIMG SSIMG SSIML SSIML SSIML STBPTOC STBPTOC BBPMSS STBPTOC STEFPHIZ STEFPHIZ STEFPHIZ STTIPHIZ STTIPHIZ STTIPHIZ SXCBR SXCBR SXCBR SXSWI SXSWI SXSWI T2WPDIF T2WPDIF T2WGAPC T2WPDIF T2WPHAR T2WPTRC T3WPDIF T3WPDIF T3WGAPC T3WPDIF T3WPHAR T3WPTRC TCLYLTC TCLYLTC TCLYLTC TCSLTC TCMYLTC TCMYLTC TCMYLTC TEIGAPC TEIGGIO TEIGAPC TEIGGIO TEILGAPC TEILGGIO TEILGAP...

Page 38: ... VSGAPC WRNCALH WRNCALH WRNCALH ZC1PPSCH ZPCPSCH ZPCPSCH ZC1WPSCH ZPCWPSCH ZPCWPSCH ZCLCPSCH ZCLCPLAL ZCLCPSCH ZCPSCH ZCPSCH ZCPSCH ZCRWPSCH ZCRWPSCH ZCRWPSCH ZCVPSOF ZCVPSOF ZCVPSOF ZGVPDIS ZGVLLN0 PH1PTRC ZGVPDIS ZGVPTUV PH1PTRC ZGVPDIS ZGVPTUV ZMCAPDIS ZMCAPDIS ZMCAPDIS ZMCPDIS ZMCPDIS ZMCPDIS ZMFCPDIS ZMFCLLN0 PSFPDIS ZMFPDIS ZMFPTRC ZMMMXU PSFPDIS ZMFPDIS ZMFPTRC ZMMMXU ZMFPDIS ZMFLLN0 PSFPDI...

Page 39: ...PDIS ZMMAPDIS ZMMPDIS ZMMPDIS ZMMPDIS ZMQAPDIS ZMQAPDIS ZMQAPDIS ZMQPDIS ZMQPDIS ZMQPDIS ZMRAPDIS ZMRAPDIS ZMRAPDIS ZMRPDIS ZMRPDIS ZMRPDIS ZMRPSB ZMRPSB ZMRPSB ZSMGAPC ZSMGAPC ZSMGAPC 1MRK 505 370 UUS A Section 1 Introduction Busbar protection REB670 2 2 ANSI 33 Application manual ...

Page 40: ...34 ...

Page 41: ...ction IED will be applicable for buses with a fewer number of bays Practically the number of available CT inputs will limit the size of the station which can be protected The IED has very low requirements on the main current transformers that is CTs and no interposing current transformers are necessary For all applications it is possible to include and mix main CTs with 1A and 5A rated secondary c...

Page 42: ... detects instantly the open CT secondary circuits and prevents differential protection operation without any need for additional check zone Differential protection zones in the IED include a sensitive operational pickup This sensitive operational pickup is designed to be able to detect internal busbar ground faults in low impedance grounded power systems that is power systems where the ground faul...

Page 43: ... breaker and a half stations double busbar double breaker stations ring busbars and so on The software based dynamic Zone Selections ensures Dynamic linking of measured CT currents to the appropriate differential protection zone as required by substation topology Efficient merging of the two or more differential zones when required by substation topology that is load transfer Easy zone merging ini...

Page 44: ...ent busbar protection IEDs per zone of protection This IED fits both solutions A simplified bus differential protection for multi phase faults and ground faults can be obtained by using a single one phase IED with external auxiliary summation current transformers The IED can be used in applications with IEC UCA 61850 9 2LE process bus with up to eight merging units MU depending on the other functi...

Page 45: ...hich is the closest to the actual application Then necessary modifications shall be applied in order to adopt the customized IED configuration to suite the actual station layout The PCM600 project for the pre configured REB670 IEDs is available in the Connectivity Package DVD GUID F5776DD1 BD04 4872 BB89 A0412B4B5CC3 v1 The following tables list all the functions available in the IED Those functio...

Page 46: ...ial protection 2 zones single phase 24 bays 1 BDZSGAPC BFPTRC BICPTRC BZNPDIF BCZPDIF BSMGAPC 87B Busbar differential protection 6 zones single phase 24 bays 1 BDCGAPC 87B Status of primary switching object for busbar protection zone selection 128 2 3 Back up protection functions GUID A8D0852F 807F 4442 8730 E44808E194F0 v13 IEC 61850 or function name ANSI Function description Busbar REB670 Custom...

Page 47: ...erpower protection 0 4 CBPGAPC Capacitor bank protection 0 2 Voltage protection UV2PTUV 27 Two step undervoltage protection 0 2 OV2PTOV 59 Two step overvoltage protection 0 2 ROV2PTOV 59N Two step residual overvoltage protection 0 2 VDCPTOV 60 Voltage differential protection 0 2 LOVPTUV 27 Loss of voltage check 0 2 Frequency protection SAPTUF 81 Underfrequency protection 0 6 SAPTOF 81 Overfrequenc...

Page 48: ...e Point indication 16 SPC8GAPC Single point generic control function 8 signals 5 AUTOBITS Automation bits command function for DNP3 0 3 SINGLECMD Single command 16 signals 4 I103CMD Function commands for IEC 60870 5 103 1 I103GENCMD Function commands generic for IEC 60870 5 103 50 I103POSCMD IED commands with position and select for IEC 60870 5 103 50 I103POSCMDV IED direct commands with position ...

Page 49: ...MORY TIMERSET VSGAPC XOR Extension logic package see Table 6 0 1 FXDSIGN Fixed signal function block 1 B16I Boolean to integer conversion 16 bit 18 BTIGAPC Boolean to integer conversion with logical node representation 16 bit 16 IB16 Integer to Boolean 16 conversion 18 BCTZCONN Integer to Boolean conversion for six zone busbar 34 ITBGAPC Integer to Boolean 16 conversion with Logic Node representat...

Page 50: ...e Function description Total number of instances SCILO Interlocking 30 BB_ES 6 A1A2_BS 4 A1A2_DC 6 ABC_BC 2 BH_CONN 2 BH_LINE_A 2 BH_LINE_B 2 DB_BUS_A 3 DB_BUS_B 3 DB_LINE 3 ABC_LINE 6 AB_TRAFO 4 SCSWI Switch controller 30 SXSWI Circuit switch 24 QCRSV Apparatus control 6 RESIN1 1 RESIN2 59 POS_EVAL Evaluation of position indication 30 QCBAY Bay control 5 Table continues on next page Section 2 1MR...

Page 51: ...c blocks Q T Total number of instances ANDQT 120 INDCOMBSPQT 20 INDEXTSPQT 20 INVALIDQT 22 INVERTERQT 120 ORQT 120 PULSETIMERQT 40 RSMEMORYQT 40 SRMEMORYQT 40 TIMERSETQT 40 XORQT 40 Table 6 Total number of instances for extended logic package Extended configurable logic block Total number of instances AND 180 GATE 49 INV 180 LLD 49 OR 180 PULSETIMER 89 RSMEMORY 40 SLGAPC 74 SRMEMORY 130 TIMERSET 1...

Page 52: ... Measured value expander block 28 SSIMG 63 Insulation supervision for gas medium 21 SSIML 71 Insulation supervision for liquid medium 3 SSCBR Circuit breaker condition monitoring 0 24 I103MEAS Measurands for IEC 60870 5 103 1 I103MEASUSR Measurands user defined signals for IEC 60870 5 103 3 I103AR Function status auto recloser for IEC 60870 5 103 1 I103EF Function status earth fault for IEC 60870 ...

Page 53: ...nication protocol 1 IEC 61850 8 1 IEC 61850 1 GOOSEINTLKRCV Horizontal communication via GOOSE for interlocking 59 GOOSEBINRCV GOOSE binary receive 16 GOOSEDPRCV GOOSE function block to receive a double point value 64 GOOSEINTRCV GOOSE function block to receive an integer value 32 GOOSEMVRCV GOOSE function block to receive a measurand value 60 GOOSESPRCV GOOSE function block to receive a single po...

Page 54: ...ndant Ethernet ports 3 DHCP DHCP configuration for front access point 1 QUALEXP IEC 61850 quality expander 96 Remote communication BinSignRec1_1 BinSignRec1_2 BinSignReceive2 Binary signal transfer receive 3 3 6 BinSignTrans1_1 BinSignTrans1_2 BinSignTransm2 Binary signal transfer transmit 3 3 6 BinSigRec1_12M BinSigRec1_22M BinSigTran1_12M BinSigTran1_22M Binary signal transfer 2Mbit receive tran...

Page 55: ...er of setting groups ACTVGRP Parameter setting groups TESTMODE Test mode functionality CHNGLCK Change lock function SMBI Signal matrix for binary inputs SMBO Signal matrix for binary outputs SMMI Signal matrix for mA inputs SMAI1 SMAI12 Signal matrix for analog inputs 3PHSUM Summation block 3 phase ATHSTAT Authority status ATHCHCK Authority check AUTHMAN Authority management FTPACCS FTP access wit...

Page 56: ...ehavior FNKEYTY1 FNKEYTY5 FNKEYMD1 FNKEYMD5 Parameter setting function for HMI in PCM600 LEDGEN General LED indication part for LHMI OPENCLOSE_LED LHMI LEDs for open and close keys GRP1_LED1 GRP1_LED15 GRP2_LED1 GRP2_LED15 GRP3_LED1 GRP3_LED15 Basic part for CP HW LED indication module Section 2 1MRK 505 370 UUS A Application 50 Busbar protection REB670 2 2 ANSI Application manual ...

Page 57: ...up trip signal from every bay facility to connect external bay trip signal 3 1 2 Configuration X01 SEMOD129275 116 v6 This configuration includes only busbar protection for simple stations layouts in other words breaker and a half double breaker or single breaker stations Additionally it can be used for double busbar single breaker stations where disconnector replica is done by using only b auxili...

Page 58: ...75 124 v5 This configuration includes BBP with breaker failure protection CCRBRF 50BF end fault protection and overcurrent protection PH4SPTOC 51 for double busbar single breaker stations where Zone Selection is done by using a and b auxiliary contacts from every disconnectors and or circuit breakers Thus full disconnector breaker supervision is available This configuration is available for only t...

Page 59: ...F 87B 3Id I OC4 PTOC 51_67 4 3I CC RBRF 50BF 3I BF SMB RREC 79 5 0 1 BZIT GGIO 87B 3Id I BCZT PDIF 87B 3Id I Other Functions in Library BDC GAPC 87B QB1 DRP RDRE DFR SER DR C MMXU MET I C MMXU MET I Q CBAY Control C MSQI MET Isqi VN MMXU MET UN S SIML 71 S SIMG 63 S XCBR 3 Control S SCBR Control V MMXU MET U V MSQI MET Usqi ETP MMTR MET W Varh IEC16000254 1 en vsd CV MMXN MET P Q IEC16000254 V1 EN...

Page 60: ...C 87B 3Id I BZNT PDIF 87B 3Id I Other Functions in Library BDC GAPC 87B 152 BKR 152 BKR 152 BKR 152 BKR 152 BKR 189 189 BZIT GGIO 87B 3Id I BCZT PDIF 87B 3Id I C MMXU MET I DRP RDRE DFR SER DR BZIT GGIO 87B 3Id I BCZT PDIF 87B 3Id I C MMXU MET I DRP RDRE DFR SER DR VERSION OF REB670 NUMBER OF FEDERS IN BOTH BUSBAR SECTIONS REB670 ANSI A20A X00 3 Phase 4 Bays 2 Zones for Simple Station Layout 12 AI...

Page 61: ... BZIT GGIO 87B 3Id I DRP RDRE DFR SER DR C MMXU MET I C MSQI MET Isqi C MMXU MET I C MMXU MET I Optional Functions OC4 PTOC 51_67 4 3I CC RBRF 50BF 3I BF SMB RREC 79 5 0 1 Other Functions in Library BDC GAPC 87B Q CBAY Control C MSQI MET Isqi VN MMXU MET UN S SIML 71 S SIMG 63 S XCBR 3 Control S SCBR Control V MMXU MET U V MSQI MET Usqi ETP MMTR MET W Varh CV MMXN MET P Q IEC16000255 1 en vsd IEC1...

Page 62: ...D 1264BCF9 F245 423C B620 3D66F3292F41 V2 EN US Figure 6 Configuration diagram for A31 configuration X01_1 Section 3 1MRK 505 370 UUS A Configuration 56 Busbar protection REB670 2 2 ANSI Application manual ...

Page 63: ...B 3Id I BZNT PDIF 87B 3Id I Optional Functions OC4 PTOC 51_67 4 3I CC RBRF 50BF 3I BF SMB RREC 79 5 0 1 Other Functions in Library BDC GAPC 87B BUT PTRC 87B 3Id I With Just one CT in the Bus Section Bay DRP RDRE DFR SER DR C MMXU MET I C MMXU MET I C MMXU MET I Q CBAY Control C MSQI MET Isqi VN MMXU MET UN S SIML 71 S SIMG 63 S XCBR 3 Control S SCBR Control V MMXU MET U V MSQI MET Usqi ETP MMTR ME...

Page 64: ...DFR SER DR CC RBRF 50BF 3I BF CC RBRF 50BF 3I BF CC RBRF 50BF 3I BF OC4 PTOC 51_67 4 3I OC4 PTOC 51_67 4 3I OC4 PTOC 51_67 4 3I C MMXU MET I C MMXU MET I C MMXU MET I Optional Functions SMB RREC 79 5 0 1 Other Functions in Library BDC GAPC 87B Q CBAY Control C MSQI MET Isqi VN MMXU MET UN S SIML 71 S SIMG 63 S XCBR 3 Control S SCBR Control V MMXU MET U V MSQI MET Usqi ETP MMTR MET W Varh CV MMXN M...

Page 65: ...eaker and a half or double breaker arrangements Three such IEDs offer cost effective solutions for such simple substation arrangements with up to twelve CT inputs This version can be used with external auxiliary 3 phase to 1 phase summation current transformers with different turns ratio for each phase 1MRK 505 370 UUS A Section 3 Configuration Busbar protection REB670 2 2 ANSI 59 Application manu...

Page 66: ...hase 12 Bays 2 Zones for Simple Station Layout 12 AI 12 REB670 B21 X01 1 Phase 12 Bays 2 Zones for Simple Station Layout 12 AI 12 NUMBER OF REB670 REQUIRED BY THE SCHEME 3 3 REB670 B31 X01 1 Phase 24 Bays 2 Zones for Simple Station Layout 24 AI 24 3 QB1 C MMXU MET I DRP RDRE DFR SER DR IEC13000223 2 en vsd NUMBER OF FEEDERS IN BOTH BUSBAR SECTIONS C MMXU MET I Q CBAY Control C MSQI MET Isqi VN MMX...

Page 67: ...12 Bays 2 Zones for Simple Station Layout 12 AI 11 With Just one CT in the Bus Section Bay NUMBER OF REB670 REQUIRED BY THE SCHEME 3 3 REB670 B31 X01 1 Phase 24 Bays 2 Zones for Simple Station Layout 24 AI 23 3 C MMXU MET I C MMXU MET I NUMBER OF FEEDERS IN BOTH BUSBAR SECTIONS IEC13000224 2 en vsd Optional Functions PH4S PTOC 51 I CCS RBRF 50BF I BF SMB RREC 79 5 0 1 Other Functions in Library BD...

Page 68: ...y inputs and outputs and many CT inputs are needed The IED includes two differential zones and twenty four CT inputs Note that binary inputs can be shared between phases by including the LDCM communication module This simplifies panel wiring and saves IO boards This version can be used with external auxiliary 3 phase to 1 phase summation current transformers with different turns ratio for each pha...

Page 69: ...imple Station Layout 12 AI 22 With Just one CT in the Bus Section Bay NUMBER OF REB670 REQUIRED BY THE SCHEME 6 6 REB670 B31 X01 1 Phase 24 Bays 2 Zones for Simple Station Layout 24 AI 46 6 QB1 QB2 QA1 BCZS PDIF 87B Id I BZIS GGIO 87B Id I C MMXU MET I DRP RDRE DFR SER DR BCZS PDIF 87B Id I BZIS GGIO 87B Id I C MMXU MET I DRP RDRE DFR SER DR BUS PTRC 87B Id I BUS PTRC 87B Id I IEC13000225 2 en vsd...

Page 70: ...ction Bay NUMBER OF REB670 REQUIRED BY THE SCHEME 3 REB670 B31 X02 1 Phase 24 Bays 2 Zones for Double Busbar Station 24AI 23 3 BUS PTRC 87B Id I BUS PTRC 87B Id I C MMXU MET I DRP RDRE DFR SER DR C MMXU MET I C MMXU MET I NUMBER OF FEEDERS IN THE STATION EXCLUDING BUS COUPLER BAY IEC13000226 2 en vsd Optional Functions PH4S PTOC 51 I CCS RBRF 50BF I BF SMB RREC 79 5 0 1 Other Functions in Library ...

Page 71: ...uble Busbar Station with Breaker Failure and End Fault Protection 12AI 11 With Just one CT in the Bus Section Bay NUMBER OF REB670 REQUIRED BY THE SCHEME 3 REB670 B31 X03 1 Phase 24 Bays 2 Zones for Double Busbar Station with Breaker Failure and End Fault Protection 24AI 23 3 DRP RDRE DFR SER DR C MMXU MET I C MMXU MET I C MMXU MET I IEC13000227 2 en vsd NUMBER OF FEEDERS IN THE STATION EXCLUDING ...

Page 72: ...66 ...

Page 73: ...l s phase angle will always be fixed to zero degrees and remaining analog channel s phase angle information will be shown in relation to this analog input During testing and commissioning of the IED the reference channel can be changed to facilitate testing and service values reading The availability of VT inputs depends on the ordered transformer input module TRM type 4 2 Setting guidelines SEMOD...

Page 74: ... object is defined as Forward and the direction out from the object is defined as Reverse See Figure 14 A positive value of current power and so on forward means that the quantity flows towards the object A negative value of current power and so on reverse means that the quantity flows away from the object See Figure 14 Protected Object Line transformer etc Forward Reverse Definition of direction ...

Page 75: ...eir own CTs The settings for CT direction shall be done according to the figure To protect the line direction of the directional functions of the line protection shall be set to Forward This means that the protection is looking towards the line 4 2 2 2 Example 2 SEMOD55055 29 v7 Two IEDs used for protection of two objects and sharing a CT Figure 16 Example how to set CT_WyePoint parameters in the ...

Page 76: ...rotection is towards the transformer To look towards the line the direction of the directional functions of the line protection must be set to Reverse The direction Forward Reverse is related to the reference object that is the transformer in this case When a function is set to Reverse and shall protect an object in reverse direction it shall be noted that some directional functions are not symmet...

Page 77: ... setting is ToObject Forward Reverse Definition of direction for directional line functions Setting of current input for transformer functions Set parameter CT_WyePoint with Transformer as reference object Correct setting is ToObject Setting of current input for line functions Set parameter CT_WyePoint with Line as reference object Correct setting is FromObject en05000462_ansi vsd ANSI05000462 V1 ...

Page 78: ...that case for all CT inputs marked with 1 in Figure 19 set CT_WyePoint ToObject and for all CT inputs marked with 2 in Figure 19 set CT_WyePoint FromObject The second solution will be to use all connected bays as reference objects In that case for all CT inputs marked with 1 in Figure 19 set CT_WyePoint FromObject and for all CT inputs marked with 2 in Figure 19 set CT_WyePoint ToObject Section 4 ...

Page 79: ...ave to set if the SMAI block is measuring current or voltage This is done with the parameter AnalogInputType Current Voltage The ConnectionType phase phase phase ground and GlobalBaseSel ISec I Pri S1 X1 P1 H1 P2 H2 S2 X2 P2 H2 P1 H1 x x a b c en06000641 vsd S2 X2 S1 X1 IEC06000641 V1 EN US Figure 20 Commonly used markings of CT terminals Where a is symbol and terminal marking used in this documen...

Page 80: ... rated CT input into the IED in order to connect CTs with 5A and 10A secondary rating 4 2 2 5 Example on how to connect a wye connected three phase CT set to the IED SEMOD55055 352 v11 Figure 21 gives an example about the wiring of a wye connected two phase CT set to the IED It gives an overview of the actions which are needed to make this measurement available to the built in protection and contr...

Page 81: ...rent inputs are located in the TRM It shall be noted that for all these current inputs the following setting values shall be entered for the example shown in Figure 21 CTprim 600A CTsec 5A CTStarPoint ToObject Ratio of the first two parameters is only used inside the IED The third parameter CTStarPoint ToObject as set in this example causes no change on the measured currents In other words current...

Page 82: ...nly for IEDs installed in power plants then the setting parameters DFTReference shall be set accordingly Section SMAI in this manual provides information on adaptive frequency tracking for the signal matrix for analogue inputs SMAI 5 AI3P in the SMAI function block is a grouped signal which contains all the data about the phases A B C and neutral quantity in particular the data about fundamental f...

Page 83: ... setting of the parameter CTStarPoint of the used current inputs on the TRM item 2 in Figure 22 and 21 CTprim 600A CTsec 5A CTWyePoint FromObject The ratio of the first two parameters is only used inside the IED The third parameter as set in this example will negate the measured currents in order to ensure that the currents are measured towards the protected object within the IED A third alternati...

Page 84: ...ummation of the three individual phase currents 3 Is the TRM where these current inputs are located It shall be noted that for all these current inputs the following setting values shall be entered CTprim 800A CTsec 1A CTStarPoint FromObject ConnectionType Ph N The ratio of the first two parameters is only used inside the IED The third parameter as set in this example will have no influence on mea...

Page 85: ...tection and control functions within the IED which are connected to this preprocessing function block in the configuration tool For this application most of the preprocessing settings can be left to the default values If frequency tracking and compensation is required this feature is typically required only for IEDs installed in the generating stations then the setting parameters DFTReference shal...

Page 86: ...n Delta DAB Connected IA IB IB IC IC IA 1 2 3 4 ANSI11000027 2 en vsd SMAI_20 ANSI11000027 V2 EN US Figure 24 Delta DAB connected three phase CT set Section 4 1MRK 505 370 UUS A Analog inputs 80 Busbar protection REB670 2 2 ANSI Application manual ...

Page 87: ...ter the connected analog inputs and calculate fundamental frequency phasors for all three input channels harmonic content for all three input channels positive negative and zero sequence quantities by using the fundamental frequency phasors for the first three input channels channel one taken as reference for sequence quantities These calculated values are then available for all built in protectio...

Page 88: ...int ToObject ConnectionType Ph Ph It is important to notice the references in SMAI As inputs at Ph Ph are expected to be A B B Crespectively C A we need to tilt 180º by setting ToObject 4 2 2 7 Example how to connect single phase CT to the IED SEMOD55055 431 v8 Figure 26 gives an example how to connect the single phase CT to the IED It gives an overview of the required actions by the user in order...

Page 89: ... ToObject For connection b shown in Figure 26 CTprim 1000 A CTsec 1A CTWyePoint FromObject 3 shows the connection made in SMT tool which connect this CT input to the fourth input channel of the preprocessing function block 4 4 is a Preprocessing block that has the task to digitally filter the connected analog inputs and calculate values The calculated values are then available for all built in pro...

Page 90: ... voltage level This will effectively make the protection scheme less sensitive however such measures are necessary in order to avoid possible problems with loss of the measurement accuracy in the IED Regardless of the applied relationship between the IBase parameter and the rated CT primary current the corresponding minimum pickup of the function on the CT secondary side must always be verified It...

Page 91: ...of VT terminals Where a is the symbol and terminal marking used in this document Terminals marked with a square indicate the primary and secondary winding terminals with the same positive polarity b is the equivalent symbol and terminal marking used by IEC ANSI standard for phase to ground connected VTs c is the equivalent symbol and terminal marking used by IEC ANSI standard for open delta connec...

Page 92: ... 28 gives an example on how to connect the three phase to ground connected VT to the IED It gives an overview of required actions by the user in order to make this measurement available to the built in protection and control functions within the IED For correct terminal designations see the connection diagrams valid for the delivered IED Section 4 1MRK 505 370 UUS A Analog inputs 86 Busbar protect...

Page 93: ...1 AI2 AI3 AI4 AIN GRP2_B GRP2_C GRP2N 4 ANSI06000599 V2 EN US Figure 28 A Three phase to ground connected VT L1 IED L2 132 2 110 2 kV V 1 3 2 132 2 110 2 kV V IEC16000140 1 en vsdx 4 SMAI2 BLOCK GRP2L1 GRP2L2 GRP2L1L2 GRP2N AI2P AI1 AI2 AI3 AI4 AIN 5 IEC16000140 V1 EN US Figure 29 A two phase to earth connected VT 1MRK 505 370 UUS A Section 4 Analog inputs Busbar protection REB670 2 2 ANSI 87 Appl...

Page 94: ...k to digitally filter the connected analog inputs and calculate fundamental frequency phasors for all input channels harmonic content for all input channels positive negative and zero sequence quantities by using the fundamental frequency phasors for the first three input channels channel one taken as reference for sequence quantities These calculated values are then available for all built in pro...

Page 95: ...nected VT Where 1 shows how to connect the secondary side of a phase to phase VT to the VT inputs on the IED 2 is the TRM where these three voltage inputs are located It shall be noted that for these three voltage inputs the following setting values shall be entered VTprim 13 8 kV VTsec 120 V Please note that inside the IED only ratio of these two parameters is used Table continues on next page 1M...

Page 96: ...all be set as shown here ConnectionType Ph Ph VBase 13 8 kV If frequency tracking and compensation is required this feature is typically required only for IEDs installed in the generating stations then the setting parameters DFTReference shall be set accordingly 4 2 4 5 Example on how to connect an open delta VT to the IED for high impedance grounded or ungrounded networks SEMOD55055 163 v9 Figure...

Page 97: ... 3 110 3 kV V 1 2 4 3 Not Used 5 ANSI06000601 2 en vsd Not Used Not Used SMAI2 BLOCK GRP2_A GRP2_B GRP2_C GRP2N TYPE AI3P AI1 AI2 AI3 AI4 AIN ANSI06000601 V2 EN US Figure 31 Open delta connected VT in high impedance grounded power system 1MRK 505 370 UUS A Section 4 Analog inputs Busbar protection REB670 2 2 ANSI 91 Application manual ...

Page 98: ...oltage input to the fourth input channel of the preprocessing function block 5 5 is a Preprocessing block that has the task to digitally filter the connected analog input and calculate fundamental frequency phasors for all four input channels harmonic content for all four input channels positive negative and zero sequence quantities by using the fundamental frequency phasors for the first three in...

Page 99: ... Vo V EQUATION1927 ANSI V1 EN US Equation 7 The primary rated voltage of such VT is always equal to VPh Gnd Therefore three series connected VT secondary windings will give the secondary voltage equal only to one individual VT secondary winding rating Thus the secondary windings of such open delta VTs quite often has a secondary rated voltage close to rated phase to phase VT secondary voltage that...

Page 100: ... kV V 1 2 4 3 ANSI06000602 2 en vsd 5 Not Used Not Used Not Used SMAI2 BLOCK GRP2_A GRP2_B GRP2_C GRP2N TYPE AI3P AI1 AI2 AI3 AI4 AIN ANSI06000602 V2 EN US Figure 32 Open delta connected VT in low impedance or solidly grounded power system Section 4 1MRK 505 370 UUS A Analog inputs 94 Busbar protection REB670 2 2 ANSI Application manual ...

Page 101: ...urth input channel of the preprocessing function block 4 5 preprocessing block has a task to digitally filter the connected analog inputs and calculate fundamental frequency phasors for all four input channels harmonic content for all four input channels positive negative and zero sequence quantities by using the fundamental frequency phasors for the first three input channels channel one taken as...

Page 102: ...96 ...

Page 103: ...14 ANSI13000239 2 en vsd ANSI13000239 V2 EN US Figure 33 Local human machine interface The LHMI of the IED contains the following elements 1MRK 505 370 UUS A Section 5 Local HMI Busbar protection REB670 2 2 ANSI 97 Application manual ...

Page 104: ...play GUID 55739D4F 1DA5 4112 B5C7 217AAF360EA5 v11 The LHMI includes a graphical monochrome liquid crystal display LCD with a resolution of 320 x 240 pixels The character size can vary The display view is divided into four basic areas Section 5 1MRK 505 370 UUS A Local HMI 98 Busbar protection REB670 2 2 ANSI Application manual ...

Page 105: ...ton panel shows on request what actions are possible with the function buttons Each function button has a LED indication that can be used as a feedback signal for the function button control action The LED is connected to the required signal with PCM600 1MRK 505 370 UUS A Section 5 Local HMI Busbar protection REB670 2 2 ANSI 99 Application manual ...

Page 106: ...7100F E8C0 4FAB B979 FD4A971475E3 V1 EN US Figure 36 Indication LED panel The function button and indication LED panels are not visible at the same time Each panel is shown by pressing one of the function buttons or the Multipage button Pressing the ESC button clears the panel from the display Both panels have a dynamic width that depends on the label string length Section 5 1MRK 505 370 UUS A Loc...

Page 107: ...with the LHMI or PCM600 Information panels for the indication LEDs are shown by pressing the Multipage button Pressing that button cycles through the three pages A lit or un acknowledged LED is indicated with a highlight Such lines can be selected by using the Up Down arrow buttons Pressing the Enter key shows details about the selected LED Pressing the ESC button exits from information pop ups as...

Page 108: ...e in different views or menus The push buttons are also used to acknowledge alarms reset indications provide help and switch between local and remote control mode The keypad also contains programmable push buttons that can be configured either as menu shortcut or control buttons Section 5 1MRK 505 370 UUS A Local HMI 102 Busbar protection REB670 2 2 ANSI Application manual ...

Page 109: ...d with object control navigation and command push buttons and RJ 45 communication port 1 5 Function button 6 Close 7 Open 8 Escape 9 Left 10 Down 11 Up 12 Right 13 Key 14 Enter 15 Remote Local 16 Uplink LED 17 Not in use 18 Multipage 1MRK 505 370 UUS A Section 5 Local HMI Busbar protection REB670 2 2 ANSI 103 Application manual ...

Page 110: ... function has picked up and an indication message is displayed The pick up indication is latching and must be reset via communication LHMI or binary input on the LEDGEN component To open the reset menu on the LHMI press Flashing The IED is in test mode and protection functions are blocked or the IEC61850 protocol is blocking one or more functions The indication disappears when the IED is no longer...

Page 111: ... The activation signal is on or it is off but the indication has not been acknowledged LatchedAck F S sequence The indication has been acknowledged but the activation signal is still on LatchedAck S F sequence The activation signal is on or it is off but the indication has not been acknowledged LatchedReset S sequence The activation signal is on or it is off but the indication has not been acknowl...

Page 112: ...IEC13000280 1 en vsd 1 2 GUID 94AF2358 6905 4782 B37B ACD3DCBF7F9C V1 EN US Figure 39 RJ 45 communication port and green indicator LED 1 RJ 45 connector 2 Green indicator LED The default IP address for the IED front port is 10 1 150 3 and the corresponding subnetwork mask is 255 255 254 0 It can be set through the local HMI path Main menu Configuration Communication Ethernet configuration FRONT po...

Page 113: ...tection 2Z 3Ph 4 8CT differential protection function BZNTPDIF_x x A B 3Id I SYMBOL JJ V1 EN US 87B Busbar protection 2Z 3Ph 4 8CT check zone protection function BTCZPDIF 3Id I SYMBOL JJ V1 EN US 87B Busbar protection 2Z 3Ph 4 8CT bay function BUTPTRC_Bx 1 x 4 or 1 x 8 3Id I SYMBOL JJ V1 EN US 87B Busbar protection 2Z 3Ph 4 8CT zone interconnection function BZITGGIO 3Id I SYMBOL JJ V1 EN US 87B 1M...

Page 114: ...0 V1 EN US 87B GUID 23F2558B FB4A 4912 9EF9 F93706F32213 v1 Six zone busbar differential protection twenty four single phase CT Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Busbar protection 6Z 1Ph 24CT main function BDZSGAPC Id I IEC16000110 V1 EN US 87B Busbar protection 6Z 1Ph 24CT differential protection function BZNPDIF_Zx 1 x 6 Id I IEC...

Page 115: ...cation and T connection application M12098 3 v4 The REB670 general differential function is suitable for application on mesh corner arrangements Mesh corners might have four or even up to six CT inputs and are basically simple single busbar arrangements A similar application will occur when a T protection is required for breaker and a half or ring busbar arrangements ANSI11000237 1 en vsd 252 352 ...

Page 116: ...juries power system blackout transient instability or considerable damage to the surrounding substation equipment and the close by generators are some of the possible outcomes Therefore Busbar differential protection must fulfill the following requirements 1 Must be absolutely stable during all external faults External faults are much more common than internal faults The magnitude of external faul...

Page 117: ...manence in the magnetic core of a current transformer is an additional factor which can influence the secondary CT current It can improve or reduce the capability of the current transformer to properly transfer the primary current to the secondary side However the CT remanence is a random parameter and it is not possible in practice to precisely predict it Another and maybe less known transient ph...

Page 118: ... heavy current testing this time even under extremely heavy CT saturation is for practical CTs around two milliseconds Because of this it was decided to take this time as the design criterion in REB 670 IED for the minimum acceptable time before saturation of a practical magnetic core CT Thus the CT requirements for REB 670 IED are kept to an absolute minimum Refer to section Rated equivalent seco...

Page 119: ...itive differential protection can be set independently from the operating characteristic of the main differential protection The sensitive differential level is blocked as soon as the total incoming current exceeds the pre set level By appropriate setting then it can be insured that this sensitive level is blocked for external phase to phase or three phase faults which can cause CT saturation Comp...

Page 120: ...in which part of the station the fault is located When the check zone detects a fault it gives a release signal to the busbar protection relays in all individual discriminating zones The busbar protection discriminating zones will then trip the part of the substation that is faulty However this principle creates not only a high cost as separate CT cores are required but also a need for extra cabli...

Page 121: ...tation a check zone must not be used For such applications the check zone shall be disabled by the setting parameter Operation to Off The check zone measures only the currents from the bays which leaves the station Exactly which CTs shall be measured by the check zone varies depending on the version of the IED used In two zone busbar differential protections it is freely settable by using the sett...

Page 122: ...ction Traditionally the CT switching has been done in CT secondary circuits However with REB670 this is not the case All necessary zone selection that is CT switching is done in software Therefore the CT secondary circuits are always intact and without any auxiliary relay contacts To provide proper zone selection that is busbar replica the position information from all relevant primary switches th...

Page 123: ... contacts signal clean open position normally open auxiliary NO contact input inactive and normally closed auxiliary NC contact input active the disconnector is taken to be open For all other signal combinations the disconnector is considered to be closed This scheme does not pose any special requirements to the auxiliary contact timing Only the disconnector NC contact must open before the disconn...

Page 124: ...these two schemes Table 13 Treatment of primary object auxiliary contact status within BBP in REB670 Primary equipment Status in busbar protection Alarm facility Normally Open auxiliary contact status closed or a contact Normally Closed auxiliary contact status open or b contact when Scheme 1 RADSS is selected when Scheme 2 INX is selected Alarm after settable time delay Information visible on loc...

Page 125: ...coupler the zone between the CT and the CB can be better protected while CB is open However in such cases it is of utmost importance to connect the CB closing command to the busbar protection in order to include again the CT current to the busbar protection zones in time It is as strongly recommended to always use Scheme1_RADSS for all CBs positions connected to the IED in order to minimize any ri...

Page 126: ...ection and CT measurement can be disconnected from both differential zones as soon line disconnector is open Similar functionality can be obtained by instead monitoring the position of feeder breaker 152 In such case the breaker closing signal shall be connected to busbar protection as well 6 1 3 5 CT connection control M12108 3 v4 The IED offers an extremely effective solution for stations where ...

Page 127: ...stations or double breaker stations If for a particular CT input setting parameter ZoneSel is set to FIXEDtoZA ZB then this CT input will be included to the differential zone A but its inverted current value will be as well included to the differential zone B This setting is typically used for bus coupler or bus section bays when only one current transformer is available see Figure 47 If for a par...

Page 128: ...cally used for feeder bays in double busbar single breaker stations in order to form proper busbar disconnector replica It is especially suitable when only normally closed that is b contact auxiliary contact from the busbar disconnector s is available to the IED For more information please refer to Figure 64 6 1 3 6 CT disconnection for bus interconnector CT cores M12113 3 v4 For simplicity purpos...

Page 129: ...current inputs of the IED Meanwhile these currents should be given to both related differential zones To ensure this in two zone busbar protections it requires to set the corresponding bays the parameter ZoneSel to FIXEDtoZA in one bay and FIXEDtoZB in another bay in the parameter setting tool PST When live tank circuit breakers are used often only one current transformer is available in bus secti...

Page 130: ... the parameter ZoneSel to FIXEDtoZA ZB in PST In six zone busbar protections this single CT current should be connected to both CT inputs on the bus section or bus coupler function block and then invert one of them in software by using the parameter setting OperMode in PST This shall be done taking into account the actual location of the CT star point in this bay When the bus coupler section break...

Page 131: ...is time delay is absolutely necessary in order to prevent racing between the opening of the main breaker contact and disconnection of the CT from the differential zones This scheme will as well disconnect the CT in case of the operation of any of the two internal differential zones used in the scheme This will secure the delayed 150 ms depending one the values of the setting tZeroCurrent clearing ...

Page 132: ...be automatically protected with just one differential zone Since there are no current transformer in the bus coupler bay there is no need to allocate internal bay function block for the bus coupler bay However some additional configuration logic is required to obtain automatic zone interconnection activation when bus coupler breaker shall be closed Example of such logic is shown in Figure 50 for a...

Page 133: ... SEMOD127750 31 v4 When Live tank CBs or GIS are involved there is a physical separation between the CT and the CB End Fault Protection is related to primary faults between main CT and CB in a feeder bay Therefore it is directly related to the position of the main CT in feeder bay Three CT positions in feeder bays are typically used in power systems around the world as shown in Figure 51 1MRK 505 ...

Page 134: ... between CT and CB will cause certain problems Typically such fault will be detected and tripped by busbar protection However to completely clear such fault the remote feeder end CB must be tripped as well It shall be noted that for the feeder protection such fault will be either a reverse fault that is distance protection used for feeder protection or external fault that is line transformer diffe...

Page 135: ...ts located within measuring boundary determined by CT locations see Figure 52 However its operation will only completely clear faults within clearing boundary determined by CB locations as shown in Figure 52 Obviously the primary faults in between these two boundaries do pose certain practical problems First of all it shall be noted that there is no ideal solution for faults within end zone region...

Page 136: ...command must be connected to the binary inputs of busbar protection scheme in order to be available for zone selection logic End fault protection logic can be easily done with the help of graphical configuration tool One stage that is 4th stage from optionally available overcurrent protection can be used as dedicated end fault protection for feeders with CT on the line side of the CB End fault pro...

Page 137: ...n the IED can manage this situation in an elegant and simple way Internal feature called Zone Interconnection will be used to handle both situations This feature can be activated either externally via binary input or derived internally by built in logic Especially in two zone busbar protections to internally activate such feature the setting ZoneSel shall be also considered Consequently the zone i...

Page 138: ... This practically means that for double busbar station when zone switching feature is active all feeder bays will be connected to both differential zones while bus coupler CT will be disconnected from both zones In this way simple but effective solution is formed It is as well important to notice that all necessary changes in the individual bay tripping arrangements will be automatically performed...

Page 139: ...trip commands will be given to all bays but internal circuit breaker failure function will be started in the same phase only In order to secure internal breaker failure picking up in all three phases it is advisable to do the following Connect a zone say Zone A trip signal from one IED to the external trip input of the Zone A in the other two IEDs Thus all three IEDs will then issue trip in Zone A...

Page 140: ...g setup is suitable when no individual circuit breaker failure IEDs or lock out of individual bay CB closing coils is required A suitable external trip unit consists of a combination of RXMS1 RXMH 2 alternatively AR MG6 when heavy duty contacts are required and only RXMS 1 AR relays when medium duty contacts are sufficient M12118 4 v4 Decentralized trip arrangement Tripping is performed directly f...

Page 141: ...ut trip IEDs might have the following drawbacks The trip contacts will remain closed If the breaker would fail to open the tripping coil will be burnt and the DC supply short circuited The trip circuit supervision TCS IEDs will reset and give alarm for a failure in the trip circuit if the alarm is not opened by the lock out IED or a double trip circuit supervision is recommended where the trip cir...

Page 142: ...iples for typical busbar arrangements up to two differential zones are shown and described in the following sections 6 1 4 2 Single busbar arrangements M6641 3 v5 The simplest form of busbar protection is a one zone protection for single busbar configuration as shown in Figure 54 When different CT ratios exist in the bays compensation is done by setting the CT ratio individually for each bay The o...

Page 143: ...onnector has to be done without any load This means that one of the two busbars has to be de energized before any opening or closing of the sectionalizer For this case the protection scheme must have two differential zones which can be either split to work independently from each other or switched to one overall differential zone when sectionalizing disconnector is closed Nevertheless when section...

Page 144: ...d in Section Zone interconnection Load transfer In practice the closed position of the sectionalizer shall start the zone interconnection logic inside the IED All other thinks that is tripping will automatically be arranged 6 1 4 4 Single busbar arrangements with bus section breaker M6643 3 v5 This arrangement is very similar to the single busbar arrangement The bus section breaker allows the oper...

Page 145: ...6 3 6 with just one CT input from bus section bay Please note that Table 16 is given for the preconfigured versions of REB670 which do not contain any VT inputs For station with just one CT in the bus section bay it might be required depending on the client requirements to provide the special scheme for disconnection of bus section CT when the bus section CB is open For more information refer to F...

Page 146: ...ne which protects both busbar sections However at an internal fault on any of the two buses all feeder circuit breakers have to be tripped which will cause loss of supply to all loads connected to this station Some utilities prefer to have two differential zones one for each bus section The most common setups for this type of station are given in the following table Section 6 1MRK 505 370 UUS A Di...

Page 147: ...on of bus section CT when the bus section CB is open For more information refer to Figure 48 6 1 4 6 Double circuit breaker busbar arrangement M6645 3 v5 The circuit breaker disconnectors and instrument transformers are duplicated for every feeder as shown in Figure 58 ZB 252 252 252 252 252 ZA xx06000018_ansi vsd 152 152 152 152 152 ANSI06000018 V1 EN US Figure 58 Example of double breaker statio...

Page 148: ...s per station Number of REB670 IEDs required for the scheme 3PH 2 zones 4 bays BBP A20 4 2 3PH 2 zones 8 bays BBP A31 4 8 1 2 1Ph 2 zones 12 bays BBP B20 6 12 3 6 1Ph 2 zones 12 bays BBP B21 6 12 3 6 1Ph 2 zones 24 bays BBP B31 12 24 3 6 Please note that Table 18 is given for the preconfigured versions of REB670 which do not contain any VT inputs A principle overall drawing of how to use REB670 fo...

Page 149: ... TRIP 252 OR BFP Remote Feeder End Inter Trip Feeder Parameter ZoneSel must be set to FixedToZB Parameter ZoneSel must be set to FixedToZA 152 252 BI1 BI1 152 ANSI06000148 V1 EN US Figure 59 Feeder bay in double bus double breaker station 6 1 4 7 Breaker and a half busbar arrangements M6646 3 v5 A fewer number of circuit breakers are needed for the same flexibility as for double circuit breaker bu...

Page 150: ...ful design This type of busbar arrangement can be very easily protected The most common setups for this type of station are described in the following table Table 19 Typical solutions for breaker and a half stations when CBF for middle breaker is not required Version of REB670 IED Number of diameters in the station Number of REB670 IEDs required for the scheme 3PH 2 zones 4 bays BBP A20 2 4 1 2 3P...

Page 151: ...Input TRM 152 Internal BFP Backup Trip Command BI2 Zone B Other Equipment Other Equipment Other Equipment CT Input CT Input CTRLZA CTRLZB TRIP CONNZA CONNZB Bxxx I3PB1 BLKTR TRZONE TRBAY A D A D A D Parameter ZoneSel must be set to CtrlIncludes and CTConnection Off ZERO ZERO 252 Internal BFP Backup Trip Command OR OR Feeder 1 Feeder 2 352 Internal BFP Backup Trip Command BI1 BI3 352 152 252 ANSI06...

Page 152: ...us have to be tripped leaving other busbar still in normal operation Provision for zone selection disconnector replica and zone interconnection have to be included into the scheme design This type of busbar arrangement can be protected as described in the following table Table 20 Typical solutions for double busbar stations Version of REB670 IED Number of feeders in the station excluding bus coupl...

Page 153: ...ntact Aux b contact Open Open Closed Open Closed Closed CTRLZA CTRLZB TRIP CONNZA CONNZB Bxxx I3PB1 BLKTR TRZONE TRBAY NO NC CLOSED OPEN ALARM FORCED SSxx DISABLE NO NC CLOSED OPEN ALARM FORCED SSxx DISABLE BBP BFP trip command to feeder breaker BIM BOM Set Parameter ZoneSel CtrlIncludes TRM External or Internal Feeder BFP Backup Trip Command Feeder Backup OC Trip Disconnector aux contact timing A...

Page 154: ...et Parameter ZoneSel CtrlExcludes Feeder Bay Other Equipment A D TRM Feeder Backup OC Trip Disconnector aux contact timing External or Internal Feeder BFP Backup Trip Command b 189 989 152 b 289 ANSI06000152_2_en vsd ANSI06000152 V2 EN US Figure 64 Feeder bay where b aux contacts are used Section 6 1MRK 505 370 UUS A Differential protection 148 Busbar protection REB670 2 2 ANSI Application manual ...

Page 155: ...xxx I3PB1 BLKTR TRZONE TRBAY Parameter ZoneSel must be set to FixedToZA OR Other Equipment Other Equipment CT Input TRM Bus Coupler Backup OC Trip 289 External or Internal Bus Coupler BFP Backup Trip Command Parameter ZoneSel must be set to FixedToZB 152 ANSI06000153 V1 EN US Figure 65 Bus coupler bay with two sets of CTs 1MRK 505 370 UUS A Section 6 Differential protection Busbar protection REB67...

Page 156: ...urrent 150ms Other Equipment CT Input TRM External or Internal Bus Coupler BFP Backup Trip Command Bus Coupler Backup OC Trip 189 289 BI1 NO NC CLOSED OPEN ALARM FORCED SSxx DISABLE ZEROCUR BIM CB Closing Signal t t 1s b OR 152 a ANSI06000154 V1 EN US Figure 66 Bus coupler bay with one CT and a b aux contact from CB Section 6 1MRK 505 370 UUS A Differential protection 150 Busbar protection REB670 ...

Page 157: ...CT and b aux contact only from CB 6 1 4 9 Double busbar arrangements with two bus section breakers and two bus coupler breakers M6649 3 v5 This type of station is commonly used for GIS installations It offers high operational flexibility For this type of stations two schemes similar to the double busbar station scheme can be used 189 289 189 289 189 289 189 289 189 289 189 289 189 289 189 289 189 ...

Page 158: ...h do not contain any VT inputs Provision for zone selection disconnector replica and zone interconnection have to be included into the scheme design For station with just one CT in the bus coupler or bus section bays it might be required depending on the client requirements to provide the special scheme for disconnection of bus coupler or bus section CT when the bus coupler or bus section CB is op...

Page 159: ...ation can be protected in exactly the same way as one and half breaker stations described above The same type of IEDs can be used and same limitations regarding the number of diameters apply xx06000124_ansi vsd ZA ZB 289 189 289 189 152 152 252 152 252 152 ANSI06000124 V1 EN US Figure 70 Combination between double breaker and double busbar station layouts In this type of arrangement the double bre...

Page 160: ...h version Accordingly the following solutions are possible Table 22 Typical solutions for combination between double breaker and double busbar station layouts Version of REB670 IED Number of double breaker feeders Number of double busbar feeders in the station Number of REB670 IEDs required for the scheme 3PH 2 zones 4 bays BBP A20 NA NA 3PH 2 zones 8 bays BBP A31 2 4 1 1Ph 2 zones 12 bays BBP B20...

Page 161: ...nnection zone selection and disconnector replica facilities have to be provided for all double busbar bays 6 1 5 Six zone busbar arrangements 6 1 5 1 General GUID 28529398 F8D1 419B 9FB6 700BF19A2989 v1 Busbar differential protection application for some complex busbar arrangements with up to six differential zones are shown and described in the following sections 6 1 5 2 Typical arrangement which...

Page 162: ...ion shown in Figure 75 to illustrate the engineering principles Z1 Z2 Z5 Z6 QB1 Z3 Z4 QA1 B11 B11 QA1 B12 B14 B13 B11 QA1 QA1 QA1 Feeder 01 08 Bus Interconnector 1 with two CTs Bus Interconnector 2 with one CT Bus Interconnector 3 with one CT Feeder 09 15 QB11 QB21 QB2 QB1 QB2 QB10 QB20 QB2 QB20 QB1 QB10 QB1 QB2 IEC16000142 1 en vsdx Sectionalizing disconnectors IEC16000142 V1 EN US Figure 72 Doub...

Page 163: ...lizing disconnectors bus interconnector 3 Feeder 09 17 IEC16000145 1 en vsdx QB1 QB1 QB1 IEC16000145 V1 EN US Figure 75 Triple busbar station with two sections and six protection zones Z1 Z2 QB1 QA1 CT1 QB2 Z3 QB3 Z4 QB7 BU1 QB1 QA1 CT1 QB2 QB3 QB7 QB20 QB30 QB10 QA1 CT1 QB1 QB2 QB30 QB20 QB1 QA1 CT1 QB2 QB3 QB7 BU1 Z1 Z2 Z3 Z4 Feeder 01 07 Feeder 08 20 IEC16000146 1 en vsdx IEC16000146 V1 EN US F...

Page 164: ...OSE or via LDCM 2 Use three BDCGAPC function blocks i e one per busbar disconnector to derive open or closed status of the respective disconnector primary contacts 3 Connect the close status output from each BDCGAPC function block to the respective zone control input on the feeder bay function block BFPTRC_Fxx This will ensure proper dynamic inclusion of the feeder CT measurement towards the diffe...

Page 165: ...re 78 Any other feeders located at Section 2 shall be engineered in the similar way IEC16000148 1 en vsdx IEC16000148 V1 EN US Figure 78 ACT configuration example for Feeder 17 in Section 2 Step 4 ACT engineering of the Bus Coupler bays at Section 1 The bus coupler bay is used to interconnect the differential zones via a circuit breaker within one section In this particular station the Bus Coupler...

Page 166: ...rrents from the TRM via pre processing blocks to the bus interconnector function block BICPTRC_xx Ensure overlapping of the two CTs In case that only one CT is available connect this CT to both CT inputs on the BICPTRC_xx function block and then invert one of the two inputs in software by using the parameter setting OperMode This shall be done taking into account the actual location of the CT star...

Page 167: ...o the IED This can be done by wiring using binary inputs or via communication e g via GOOSE or via LDCM 2 Use six BDCGAPC function blocks i e one per busbar disconnector to derive open or closed status of the respective disconnector primary contacts 3 Connect the close status output from BDCGAPC function block to the respective zone control input on the bus interconnector function block BICPTRC_xx...

Page 168: ... Section bay Step 6 ACT engineering of the Bus Sectionalizing Disconnectors Three bus sectionalizing disconnectors are installed in this station Each disconnector is used to interconnect the two zones located at the two sections Ultimately when this type of disconnector is closed the two relevant zones shall be merged i e switched into one common zone in the IED software In this particular station...

Page 169: ...g disconnectors presenting in this station is given in Figure 81 IEC16000151 1 en vsdx IEC16000151 V1 EN US Figure 81 ACT configuration example for three bus sectionalizing disconnectors 6 1 6 Summation principle GUID B09585B4 A1B8 4E29 A469 25997493E434 v1 Summation principle is mainly intended for two zone busbar protection applications 6 1 6 1 Introduction M12135 3 v4 A simplified bus different...

Page 170: ...one auxiliary summation CT per each main CT is required These auxiliary summation CTs convert each main CT three phase currents to a single phase output current which are all measured by one REB670 IED The differential calculation is then made on a single phase basis By doing so this more cost effective bus differential protection can be applied Due to this characteristic this summation type of bu...

Page 171: ... these are main CT ratio differences can be tolerated up to 10 1 for example 3000 5A CT can be balanced against CT s as low as 300 5 different main CT ratios are compensated numerically by a parameter setting main CT shall not saturate quicker than 2 ms refer to section Rated equivalent secondary e m f requirements for detailed CT requirements regarding main CT knee point voltage However due to th...

Page 172: ...ture 6 1 6 2 Auxiliary summation CTs M12136 4 v4 Auxiliary Summation Current Transformer that is ASCT in further text of the type SLCE 8 is used with the summation principle of the IED The principle drawing of one such ASCT is shown in Figure 84 Auxiliary Summation CT type SLCE 8 X 1A N4 S1 S2 en03000118_ansi vsd P1 N1 P2 P3 N2 P4 P5 N3 P6 ANSI03000118 V1 EN US Figure 84 Principle ASCT drawing The...

Page 173: ...to the IED with 1A CT inputs irrespective of the rated secondary current of the main CT All of these features simplify the ordering of the ASCTs Practically in order to purchase ASCTs the only required information is the main CT rated secondary current that is 1A 2A or 5A Table 23 summarizes the ASCT data Table 23 Auxiliary summation CT data Type of fault N1 N2 N3 N4 Vkp V Burden VA ASCT SLCE 8 1 ...

Page 174: ...ical end connection with ASCT is shown in Figure 85 en06000128_ansi vsd A B C N IA IB IC IN Other relays Auxiliary Summation CT type SLCE 8 1 1A or 5 1A or 2 1A N4 S1 S2 Main CT 2000 1A or 2000 5A or 2000 2A AI03 X401 5 6 REB 670 with 1A CTs P1 N1 P2 P3 N2 P4 P5 N3 P6 ISUMM ANSI06000128 V1 EN US Figure 85 End connection with ASCT connected to CT3 input It is important to notice that even in the ca...

Page 175: ...ird type shall be used with 2A main CTs However REB670 with 1A CT inputs is always used Therefore main CT ratio shall always be set in such a way that the primary current is entered as for the main CT but secondary current is always entered as 1A that is 3000 5 main CT will be entered as 3000 1 CT in REB670 6 1 6 5 Primary pick up levels for summation type differential protection M12139 3 v4 The m...

Page 176: ...ickup value in case of C Gnd fault Answer 1 According to Table 24 pickup coefficient for this type of ASCT connection and this type of fault is 0 578 Therefore IPickup L3 Gnd 0 578 1250 722 5A EQUATION1106 V1 EN US Equation 11 0 578 1250 722 5 Pickup I C Gnd A EQUATION1784 V1 EN US Equation 11 This means that if 722 5 primary amperes is injected only in phase C of any of the connected main CTs the...

Page 177: ...ation can be effectively used However if all these limitations are acceptable it is still possible to use internal CCRBRF CCSRBRF functions OC4PTOC PHS4PTOCfunction Overcurrent Protection function will be connected to the summated bay current Therefore it will have different pickup level depending on the type of fault and involved phase s See Table 24 for more info Thus it will be very difficult t...

Page 178: ...al ASCT end connection is shown in Figure 85 For this ASCT connection type the ampere turn balance equation has the form according to Equation 12 4 1 2 3 SUMM N I N IA N IA IB N IA IB IC EQUATION1785 ANSI V1 EN US Equation 12 The relationships between number of turns for this SLCE 8 ASCT for REB670 is shown in Equation 13 Equation 14 and Equation 15 N1 N2 N EQUATION1108 V1 EN US Equation 13 N3 2 N...

Page 179: ...nt component exist For any unbalanced condition that is external or internal fault both negative and zero sequence current components will give their own contribution to the summated current 6 1 6 7 SLCE 8 ASCT characteristics for series connection M12143 3 v4 Typical ASCT series connection is shown in Figure 86 For this ASCT connection type the ampere turn balance equation has the form according ...

Page 180: ...ncluding Equation 19 Equation 20 Equation 21 and Equation 22 into the Equation 18 the equation for the series connected ASCT secondary current that is summated current can be derived according to equation 23 ISUMM 1 k I1 e j30 I2 e j30 2 3 I0 EQUATION1114 V1 EN US Equation 23 From Equation 23 it is obvious that the ASCT rated ratio is declared for balanced three phase current system when only posi...

Page 181: ...ission lines Back up short circuit protection of power transformers Short circuit protection of different kinds of equipment connected to the power system such as shunt capacitor banks shunt reactors motors and others Back up short circuit protection of power generators In many applications several steps with different current pickup levels and time delays are needed OC4PTOC 51_67 can have up to f...

Page 182: ... significantly larger than the rated current of the motor Therefore there is a possibility to give a setting of a multiplication factor to the current pick up level This multiplication factor is activated from a binary input signal to the function Power transformers can have a large inrush current when being energized This phenomenon is due to saturation of the transformer magnetic core during par...

Page 183: ...used when the harmonic contents are to be considered for example in applications with shunt capacitors Operation The protection can be set to Enabled or Disabled AngleRCA Protection characteristic angle set in degrees If the angle of the fault loop current has the angle RCA the direction to the fault is forward AngleROA Angle value given in degrees to define the angle sector of the directional fun...

Page 184: ...c angle 2 ROA Relay operating angle 3 Reverse 4 Forward 7 1 3 1 Settings for each step M12982 19 v10 x means step 1 2 3 and 4 DirModeSelx The directional mode of step x Possible settings are Disabled Non directional Forward Reverse Section 7 1MRK 505 370 UUS A Current protection 178 Busbar protection REB670 2 2 ANSI Application manual ...

Page 185: ...px Operate phase current level for step x given in of IB Ix Max and Ix Min should only be changed if remote setting of operation current level Ix is used The limits are used for decreasing the used range of the Ix setting If Ix is set outside Ix Max and Ix Min the closest of the limits to Ix is used by the function If Ix Max is smaller than Ix Min the limits are swapped tx Definite time delay for ...

Page 186: ...t setting value If a binary input signal ENMULTx enableMultiplier is activated the current operation level is increased by this setting constant Setting range 1 0 10 0 ANSI10000058 1 en vsdx Trip time Pickup current tx txMin ANSI10000058 V1 EN US Figure 88 Minimum pickup current and trip time for inverse time characteristics In order to fully comply with the definition of the curve the setting par...

Page 187: ...neous 1 IEC 2 set constant time reset and ANSI 3 current dependent reset time If the current dependent type is used settings pr tr and cr must be given tResetx Constant reset time delay in seconds for step x tPCrvx tACrvx tBCrvx tCCrvx These parameters are used by the customer to create the inverse time characteristic curve See equation 24 for the time characteristic equation For more information ...

Page 188: ...ent does not cause protection operation The protection reset current must also be considered so that a short peak of overcurrent does not cause the operation of a protection even when the overcurrent has ceased This phenomenon is described in Figure 89 Pickup current Current I The IED does not reset Line phase current Time t Reset current ANSI09000146 en 1 vsd ANSI09000146 V1 EN US Figure 89 Picku...

Page 189: ...st be detected by the phase overcurrent protection The minimum fault current Iscmin to be detected by the protection must be calculated Taking this value as a base the highest pickup current setting can be written according to Equation 26 Ipu 0 7 Iscmin EQUATION1263 V2 EN US Equation 26 where 0 7 is a safety factor Iscmin is the smallest fault current to be detected by the overcurrent protection A...

Page 190: ... remote point of the primary protection zone The operate time of the phase overcurrent protection has to be chosen so that the fault time is short enough that the protected equipment will not be destroyed due to thermal overload while at the same time selectivity is assured For overcurrent protection in a radial fed network the time setting can be chosen in a graphical way This is mostly used in t...

Page 191: ...m time difference Dt between the time delays of two protections To determine the shortest possible time difference the operation time of the protection the breaker opening time and the protection resetting time must be known These time delays can vary significantly between different protective equipment The following time delays can be estimated Protection operation time 15 60 ms Protection resett...

Page 192: ...vents during fault where t 0 is when the fault occurs t t1 is when protection IED B1 and protection IED A1 start t t2 is when the trip signal from the overcurrent protection at IED B1 is sent to the circuit breaker t t3 is when the circuit breaker at IED B1 opens The circuit breaker opening time is t3 t2 t t4 is when the overcurrent protection at IED A1 resets The protection resetting time is t4 t...

Page 193: ... phase overcurrent protection PH4SPTOC 51 function is used in several applications in the power system Some applications are Short circuit protection of feeders in distribution and subtransmission systems Normally these feeders have radial structure Back up short circuit protection of transmission lines Back up short circuit protection of power transformers Short circuit protection of different ki...

Page 194: ...ime A typical case is when the protection will measure the current to a large motor At the start up sequence of a motor the start current can be significantly larger then the rated current of the motor Therefore there is a possibility to give a setting of a multiplication factor to the current pick up level This multiplication factor is activated from a binary input signal to the function Power tr...

Page 195: ...eristx Selection of time delay characteristic for step x Definite time delay and different types of inverse time delay characteristics are available according to table 28 Table 28 Inverse time delay characteristics Curve name ANSI Extremely Inverse ANSI Very Inverse ANSI Normal Inverse ANSI Moderately Inverse ANSI IEEE Definite time ANSI Long Time Extremely Inverse ANSI Long Time Very Inverse ANSI...

Page 196: ...ties are according to table 29 Table 29 Reset possibilities Curve name Curve index no Instantaneous 1 IEC Reset constant time 2 ANSI Reset inverse time 3 The delay characteristics are described in the Technical reference manual There are some restrictions regarding the choice of reset delay For the independent time delay characteristics the possible delay time settings are instantaneous 1 and IEC ...

Page 197: ...n the network as the inrush current is deviating between the phases There is a risk that the phase overcurrent function will give an unwanted trip The inrush current has a relatively large ratio of 2nd harmonic component This component can be used to create a restrain signal to prevent this unwanted function The settings for the 2nd harmonic restrain are described below 2ndHarmStab The rate of sec...

Page 198: ...eset current for an overcurrent protection The lowest setting value can be written according to equation 31 Imax Ipu 1 2 k EQUATION1262 V2 EN US Equation 31 where 1 2 is a safety factor k is the resetting ratio of the protection and Imax is the maximum load current The maximum load current on the line has to be estimated From operation statistics the load current up to the present situation can be...

Page 199: ...cted by the overcurrent protection As a summary the pick up current shall be chosen within the interval stated in equation 33 Imax 1 2 Ipu 0 7 Iscmin k EQUATION1264 V2 EN US Equation 33 The high current function of the overcurrent protection which only has a short delay of the operation must be given a current setting so that the protection is selective to other protection in the power system It i...

Page 200: ...ipment will not be destroyed due to thermal overload at the same time as selectivity is assured For overcurrent protection in a radial fed network the time setting can be chosen in a graphical way This is mostly used in the case of inverse time overcurrent protection In the figure below is shown how the time versus current curves are plotted in a diagram The time setting is chosen to get the short...

Page 201: ...me delays of two protections The minimum time difference can be determined for different cases To determine the shortest possible time difference between we must have knowledge about operation time of protections breaker opening time and protection resetting time These time delays can vary significantly between different pieces of equipment The following time delays can be estimated protection ope...

Page 202: ...equence of events during fault where t 0 is the fault occurs t t1 is the trip signal from the overcurrent protection at IED B1 is sent Operation time of this protection is t1 t t2 is the circuit breaker at IED B1 opens The circuit breaker opening time is t2 t1 and t t3 is the overcurrent protection at IED A1 resets The protection resetting time is t3 t2 To ensure that the overcurrent protection at...

Page 203: ...delines IP14988 1 v1 M15282 3 v11 When inverse time overcurrent characteristic is selected the trip time of the stage will be the sum of the inverse time delay and the set definite time delay Thus if only the inverse time delay is required it is important to set the definite time delay for that stage to zero The parameters for the four step residual overcurrent protection are set via the local HMI...

Page 204: ...ps M15282 81 v10 AngleRCA Relay characteristic angle given in degree This angle is defined as shown in Figure 95 The angle is defined positive when the residual current lags the reference voltage Vpol 3V0 or V2 V pol 3V0 or V2 RCA Operation IDirPU en 05000135 4 ansi vsd ANSI05000135 V3 EN US Figure 95 Relay characteristic angle given in degree In a normal transmission network a normal value of RCA...

Page 205: ...source is set The setting is in primary ohms When the dual polarizing method is used it is important that the setting Pickupx or the product 3I0 ZNpol is not greater than 3V0 If so there is a risk for incorrect operation for faults in the reverse direction IPolMin is the minimum ground fault current accepted for directional evaluation For smaller currents than this value the operation will be bloc...

Page 206: ... currents of the two transformers will be in phase opposition The summation of the two currents will thus give a small 2nd harmonic current The residual fundamental current will however be significant The inrush current of the transformer in service before the parallel transformer energizing will be a little delayed compared to the first transformer Therefore we will have high 2nd harmonic current...

Page 207: ...e operation from step 2 or 3 during a set time after change in the position of the circuit breaker The SOTF function has a set time delay The under time function which has 2nd harmonic restrain blocking will give operation from step 4 The 2nd harmonic restrain will prevent unwanted function in case of transformer inrush current The under time function has a set time delay Below the settings for sw...

Page 208: ...ions in the radial network there has to be a minimum time difference Dt between the time delays of two protections To determine the shortest possible time difference the operation time of protections breaker opening time and protection resetting time must be known These time delays can vary significantly between different protective equipment The following time delays can be estimated Protection t...

Page 209: ...t and trip time for inverse time characteristics In order to fully comply with the curves definition the setting parameter txMin shall be set to the value which is equal to the operate time of the selected IEC inverse curve for measured current of twenty times the set current pickup value Note that the operate time value is dependent on the selected setting value for time multiplier kx INxMult Mul...

Page 210: ...n the technical reference manual 7 4 Four step directional negative phase sequence overcurrent protection NS4PTOC 46I2 GUID E8CF8AA2 AF54 4FD1 A379 3E55DCA2FA3A v1 7 4 1 Identification GUID E1720ADA 7F80 4F2C 82A1 EF2C9EF6A4B4 v1 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Four step negative sequence overcurrent protection NS4PTOC I2 4 4 alt...

Page 211: ...itself In order to achieve both selectivity and fast fault clearance the directional function can be necessary This can be the case for unsymmetrical fault protection in meshed and effectively grounded transmission systems The directional negative sequence overcurrent protection is also well suited to operate in teleprotection communication schemes which enables fast clearance of unsymmetrical fau...

Page 212: ...e there is a possibility to give a setting of a multiplication factor MultPUx to the negative sequence current pick up level This multiplication factor is activated from a binary input signal MULTPUx to the function 7 4 3 Setting guidelines GUID 460D6C58 598C 421E AA9E FD240210A6CC v2 The parameters for Four step negative sequence overcurrent protection NS4PTOC 46I2 are set via the local HMI or Pr...

Page 213: ...directional forward reverse Characteristx Selection of time characteristic for step x Definite time delay and different types of inverse time characteristics are available Table 31 Inverse time characteristics Curve name ANSI Extremely Inverse ANSI Very Inverse ANSI Normal Inverse ANSI Moderately Inverse ANSI IEEE Definite time ANSI Long Time Extremely Inverse ANSI Long Time Very Inverse ANSI Long...

Page 214: ...if current is zero when current drops below IMinx MultPUx Multiplier for scaling of the current setting value If a binary input signal ENMULTx is activated the current operation level is multiplied by this setting constant txMin Minimum operation time for inverse time characteristics At high currents the inverse time characteristic might give a very short operation time By setting this parameter t...

Page 215: ...t time reset For the programmable inverse time delay characteristics all three types of reset time characteristics are available instantaneous 1 IEC 2 set constant time reset and ANSI 3 current dependent reset time If the current dependent type is used settings pr tr and cr must be given tPCrvx tACrvx tBCrvx tCCrvx Parameters for programmable inverse time characteristic curve The time characterist...

Page 216: ...vsd ANSI10000031 V1 EN US Figure 99 Relay characteristic angle given in degree In a transmission network a normal value of RCA is about 80 VPolMin Minimum polarization reference voltage of VBase I Dir Operate residual current level for directional comparison scheme The setting is given in of IBase The pickup forward or pickup reverse signals can be used in a communication scheme The appropriate si...

Page 217: ...ots within the transformer which degrades the paper insulation It might also cause bubbling in the transformer oil In stressed situations in the power system it can be required to overload transformers for a limited time This should be done without the above mentioned risks The thermal overload protection provides information and makes temporary overloading of transformers possible The permissible...

Page 218: ...sing a set cooling time constant Energizing of the transformer can be blocked until the heat content has reached a set level 7 5 3 Setting guideline M13250 3 v8 The parameters for the thermal overload protection two time constants TRPTTR 49 are set via the local HMI or Protection and Control IED Manager PCM600 The following settings can be done for the thermal overload protection Operation Disable...

Page 219: ...e time constant can be estimated from measurements of the oil temperature during a cooling sequence described in IEC 60076 7 It is assumed that the transformer is operated at a certain load level with a constant oil temperature steady state operation The oil temperature above the ambient temperature is DQo0 Then the transformer is disconnected from the grid no load After a time t of at least 30 mi...

Page 220: ... signal ALARM1 ALARM1 is set in of the trip heat content level Alarm2 Heat content level for activation of the output signal ALARM2 ALARM2 is set in of the trip heat content level LockoutReset Lockout release level of heat content to release the lockout signal When the thermal overload protection trips a lock out signal is activated This signal is intended to block switching on of the protected ci...

Page 221: ...uit breakers in case of failure to trip of the normal circuit breaker for the protected object The detection of failure to break the current through the breaker is made by means of current measurement or as detection of remaining trip signal unconditional CCRBRF 50BF can also give a re trip This means that a second trip signal is sent to the protected circuit breaker The re trip function can be us...

Page 222: ... between parameters RetripMode and FunctionMode RetripMode FunctionMode Description Retrip Off N A the re trip function is not activated CB Pos Check Current re trip is done if the phase current is larger than the operate level after re trip time has elapsed Contact re trip is done when auxiliary contact position indicates that breaker is still closed after re trip time has elapsed Current Contact...

Page 223: ...han the short circuit currents In order to detect breaker failure at single phase ground faults in these systems it is necessary to measure the residual current separately Also in effectively grounded systems the setting of the ground fault current protection can be chosen to relatively low current level The BuTripMode is set 1 out of 4 The current setting should be chosen in accordance to the set...

Page 224: ...to reduce the back up trip delay for multi phase faults Typical setting is 90 150 ms t3 Additional time delay to t2 for a second back up trip TRBU2 In some applications there might be a requirement to have separated back up trip functions tripping different back up circuit breakers tCBAlarm Time delay for alarm in case of indication of faulty circuit breaker There is a binary input 52FAIL from the...

Page 225: ...omponent Instead a breaker failure protection is used Breaker failure protection single phase version CCSRBRF 50BF function will issue a back up trip command to adjacent circuit breakers in case of failure to trip of the normal circuit breaker for the protected component The detection of failure to break the current through the breaker is made by means of current measurement or as detection of rem...

Page 226: ... No CB Pos Check means re trip is done without check of breaker position Pickup_PH Current level for detection of breaker failure set in of IBase This parameter must be set so that faults with small fault current can be detected The setting can be chosen in accordance with the most sensitive protection function to initiate the breaker failure protection Typical setting is 10 of IBase PU_BlkCont If...

Page 227: ...nce time for stability ANSI05000479_3_en vsd ANSI05000479 V3 EN US Figure 101 Time sequence t3 Additional time delay to t2 for a second back up trip TRBU2 In some applications there might be a requirement to have separated back up trip functions tripping different back up circuit breakers tCBAlarm Time delay for alarm in case of indication of faulty circuit breaker There is a binary input 52FAIL f...

Page 228: ...mes a synchronous motor and starts to take electric power from the rest of the power system This operating state where individual synchronous machines operate as motors implies no risk for the machine itself If the generator under consideration is very large and if it consumes lots of electric power it may be desirable to disconnect it to ease the task for the rest of the power system Often the mo...

Page 229: ...ne and it is necessary to ask the turbine manufacturer in each case Power to the power plant auxiliaries may come from a station service transformer connected to the secondary side of the step up transformer Power may also come from a start up service transformer connected to the external network One has to design the reverse power protection so that it can detect reverse power independent of the ...

Page 230: ...n about 2 One should set the overpower protection reference angle set to 180 to trip if the power flow from the network to the generator is higher than 1 Underpower protection Overpower protection Q Q P P Operating point without turbine torque Margin Margin Operate Line Operate Line Operating point without turbine torque IEC09000019 2 en vsd IEC09000019 V2 EN US Figure 102 Reverse power protection...

Page 231: ...tion 46 CA CA C A S V I I EQUATION2060 ANSI V1 EN US Equation 47 A 3 A A S V I EQUATION2061 ANSI V1 EN US Equation 48 B 3 B B S V I EQUATION2062 ANSI V1 EN US Equation 49 C 3 C C S V I EQUATION2063 ANSI V1 EN US Equation 50 The function has two stages that can be set independently With the parameter OpMode1 2 the function can be set Enabled Disabled The function gives trip if the power component i...

Page 232: ...is 0 2 of SN when metering class CT inputs into the IED are used N S 3 VBase IBase EQUATION2047 V1 EN US Equation 51 The setting Angle1 2 gives the characteristic angle giving maximum sensitivity of the power protection function The setting is given in degrees For active power the set angle should be 0 or 180 0 should be used for generator low forward active power protection Section 7 1MRK 505 370...

Page 233: ... 52 The drop out power will be Power1 2 Hysteresis1 2 The possibility to have low pass filtering of the measured power can be made as shown in the formula S TD S TD S Old Calculated 1 EQUATION1893 ANSI V1 EN US Equation 53 Where S is a new measured value to be used for the protection function Sold is the measured value given from the function in previous execution cycle SCalculated is the new calc...

Page 234: ...37 2 device number Directional overpower protection GOPPDOP P 2 DOCUMENT172362 IMG158942 V2 EN US 32 7 9 2 Application SEMOD172358 4 v2 The task of a generator in a power plant is to convert mechanical energy available as a torque on a rotating shaft to electric energy Sometimes the mechanical power from a prime mover may decrease so much that it does not cover bearing losses and ventilation losse...

Page 235: ...blades When a steam turbine rotates without steam supply the electric power consumption will be about 2 of rated power Even if the turbine rotates in vacuum it will soon become overheated and damaged The turbine overheats within minutes if the turbine loses the vacuum The critical time to overheating of a steam turbine varies from about 0 5 to 30 minutes depending on the type of turbine A high pre...

Page 236: ...ion with underpower IED and with overpower IED The underpower IED gives a higher margin and should provide better dependability On the other hand the risk for unwanted operation immediately after synchronization may be higher One should set the underpower IED to trip if the active power from the generator is less than about 2 One should set the overpower IED to trip if the power flow from the netw...

Page 237: ...ion 58 B C B C BC S V I I EQUATION2042 V1 EN US Equation 59 C A C A CA S V I I EQUATION2043 V1 EN US Equation 60 A A A S 3 V I EQUATION2044 V1 EN US Equation 61 B B B S 3 V I EQUATION2045 V1 EN US Equation 62 C C C S 3 V I EQUATION2046 V1 EN US Equation 63 The function has two stages that can be set independently With the parameter OpMode1 2 the function can be set Enabled Disabled The function gi...

Page 238: ...ing is 0 2 of SN when metering class CT inputs into the IED are used N S 3 VBase IBase EQUATION2047 V1 EN US Equation 64 The setting Angle1 2 gives the characteristic angle giving maximum sensitivity of the power protection function The setting is given in degrees For active power the set angle should be 0 or 180 180 should be used for generator reverse power protection Section 7 1MRK 505 370 UUS ...

Page 239: ... trip of the stage after pick up Hysteresis1 2 is given in p u of generator rated power according to equation 65 N S 3 VBase IBase EQUATION2047 V1 EN US Equation 65 The drop out power will be Power1 2 Hysteresis1 2 The possibility to have low pass filtering of the measured power can be made as shown in the formula 1MRK 505 370 UUS A Section 7 Current protection Busbar protection REB670 2 2 ANSI 23...

Page 240: ...mp5 IMagComp30 IMagComp100 VMagComp5 VMagComp30 VMagComp100 IAngComp5 IAngComp30 IAngComp100 The angle compensation is given as difference between current and voltage angle errors The values are given for operating points 5 30 and 100 of rated current voltage The values should be available from instrument transformer test protocols 7 10 Capacitor bank protection CBPGAPC GUID 41731DCF 840C 4717 9F5...

Page 241: ...The internal discharge resistor is also integrated within the capacitor unit in order to reduce trapped residual voltage after disconnection of the SCB from the power system Units are available in a variety of voltage ratings 240V to 25kV and sizes 2 5kVAr to about 1000kVAr Capacitor unit can be designed with one or two bushings The high voltage SCB is normally constructed using individual capacit...

Page 242: ...tects each capacitor unit Internally fused where each capacitor element is fused inside the capacitor unit Fuseless where SCB is built from series connections of the individual capacitor units that is strings and without any fuses Unfused where in contrary to the fuseless configuration a series or parallel connection of the capacitor units is used to form SCB still without any fuses Section 7 1MRK...

Page 243: ...hat transients caused by SCB switching are avoided 7 10 2 1 SCB protection GUID 9E537AFB BB23 4431 AC98 D4827A608F81 v2 IED protection of shunt capacitor banks requires an understanding of the capabilities and limitations of the individual capacitor units and associated electrical equipment Different types of shunt capacitor bank fusing configuration or grounding may affect the IED selection for t...

Page 244: ...ous operation at up to 135 of rated reactive power caused by the combined effects of Voltage in excess of the nameplate rating at fundamental frequency but not over 110 of rated RMS voltage Harmonic voltages superimposed on the fundamental frequency Reactive power manufacturing tolerance of up to 115 of rated reactive power 5 Capacitor units rated above 600 V shall have an internal discharge devic...

Page 245: ...tion detection CBPGAPC function can be used to provide the last four types of protection mentioned in the above list 7 10 3 Setting guidelines GUID CECD6525 779C 4A77 844D 031AAEE3A5B6 v1 GUID 7C456976 BA0D 4AAC 9C7A F73AF52B2B44 v2 This setting example will be done for application as shown in figure 109 Preprocessing Function Block Capacitor bank protection function 400kV CBPGAPC SMAI 200MVAr 400...

Page 246: ...base value for pickup settings of all other features integrated in this function Reconnection inhibit feature OperationRecIn Enabled to enable this feature IRecInhibit 10 of IBase Current level under which function will detect that SCB is disconnected from the power system tReconnInhibit 300s Time period under which SCB shall discharge remaining residual voltage to less than 5 Overcurrent feature ...

Page 247: ...rmonic overload trip Settings for IDMT delay step PU_HOL_DT_V 110 of SCB voltage rating Voltage level required for pickup of IDMT stage Selected value gives pickup recommended by international standards k_HOL_IDMT 1 0 Time multiplier for IDMT stage Selected value gives operate time in accordance with international standards tMax_HOL_IDMT 2000s Maximum time delay for IDMT stage for very low level o...

Page 248: ... feature can be used Simply any start of the overcurrent feature during breaker normal opening means a restrike Therefore simple logic can be created in the Application Configuration tool to detect such CB behavior Such CB condition can be just alarmed and if required the built in disturbance recorder can also be triggered To create this logic a binary signal that the CB is going to be opened but ...

Page 249: ...sed All voltage related settings are made as a percentage of the global base value VBase which normally is set to the primary rated voltage level phase to phase of the power system or the high voltage equipment under consideration The trip time setting for UV2PTUV 27 is normally not critical since there must be enough time available for the main protection to clear short circuits and ground faults...

Page 250: ...an be done for Two step undervoltage protection UV2PTUV 27 ConnType Sets whether the measurement shall be phase to ground fundamental value phase to phase fundamental value phase to ground RMS value or phase to phase RMS value Operation Disabled or Enabled VBase given in GlobalBaseSel Base voltage phase to phase in primary kV This voltage is used as reference for voltage setting UV2PTUV 27 will op...

Page 251: ...ration time for inverse time characteristic for step n given in s When using inverse time characteristic for the undervoltage function during very low voltages can give a short operation time This might lead to unselective tripping By setting t1Min longer than the operation time for other protections such unselective tripping can be avoided ResetTypeCrvn This parameter for inverse time characteris...

Page 252: ...gh voltage is necessary OV2PTOV 59 is used for supervision and detection of abnormal conditions which in combination with other protection functions increase the security of a complete protection system High overvoltage conditions are caused by abnormal situations in the power system OV2PTOV 59 is applied to power system elements such as generators transformers motors and power lines in order to d...

Page 253: ...overvoltage protection OV2PTOV 59 are set via the local HMI or PCM600 All the voltage conditions in the system where OV2PTOV 59 performs its functions should be considered The same also applies to the associated equipment its voltage and time characteristic There are wide applications where general overvoltage functions are used All voltage related settings are made as a percentage of a settable b...

Page 254: ...e the highest occurring normal voltage and below the lowest occurring voltage during faults A metallic single phase ground fault causes the non faulted phase voltages to increase a factor of 3 8 2 3 5 The following settings can be done for the two step overvoltage protection M13852 22 v10 ConnType Sets whether the measurement shall be phase to ground fundamental value phase to phase fundamental va...

Page 255: ...s In subtransmission and transmission networks the UV function is mainly a system supervision function and 3 out of 3 is selected Pickupn Set pickup overvoltage operation value for step n given as of VBase The setting is highly dependent of the protection application Here it is essential to consider the maximum voltage at non faulted situations Normally this voltage is less than 110 of nominal vol...

Page 256: ...rvSatn is set to compensate for this phenomenon In the voltage interval Pickup up to Pickup 1 0 CrvSatn 100 the used voltage will be Pickup 1 0 CrvSatn 100 If the programmable curve is used this parameter must be calculated so that 0 100 CrvSatn B C EQUATION1448 V1 EN US Equation 71 HystAbsn Absolute hysteresis set in of VBase The setting of this parameter is highly dependent of the application If...

Page 257: ... v8 All the voltage conditions in the system where ROV2PTOV 59N performs its functions should be considered The same also applies to the associated equipment its voltage withstand capability and time characteristic All voltage related settings are made as a percentage of a settable base voltage which shall be set to the primary nominal voltage phase phase level of the power system or the high volt...

Page 258: ... faults cause a neutral voltage in the feeding transformer neutral Two step residual overvoltage protection ROV2PTOV 59N is used to trip the transformer as a backup protection for the feeder ground fault protection and as a backup for the transformer primary ground fault protection The setting must be above the highest occurring normal residual voltage and below the lowest occurring residual volta...

Page 259: ...ase is indicated by voltage collapse in that phase The other healthy phase will still have normal phase to ground voltage The residual sum will have the same value as the remaining phase to ground voltage which is shown in Figure 111 V_A V_B V_C V _ A F I L 1 F V_B V_C 3 V 0 ANSI07000189 1 en vsd ANSI07000189 V1 EN US Figure 111 Ground fault in Direct grounded system 1MRK 505 370 UUS A Section 8 V...

Page 260: ...o ground voltage for a high impedance grounded system The measurement will be based on the neutral voltage displacement The setting parameters described below are identical for the two steps n step 1 and 2 Therefore the setting parameters are described only once OperationStepn This is to enable disable operation of step n Characteristicn Selected inverse time characteristic for step n This paramet...

Page 261: ...is used for co ordination between different inverse time delayed undervoltage protections ACrvn BCrvn CCrvn DCrvn PCrvn Parameters for step n to set to create programmable undervoltage inverse time characteristic Description of this can be found in the technical reference manual CrvSatn Set tuning parameter for step n When the denominator in the expression of the programmable curve is equal to zer...

Page 262: ...the bus is supervised with the voltage in the capacitor bank phase by phase Difference indicates a fault either short circuited or open element in the capacitor bank It is mainly used on elements with external fuses but can also be used on elements with internal fuses instead of a current unbalance protection measuring the current between the neutrals of two half s of the capacitor bank The functi...

Page 263: ...mer set has opened and not the other capacitor voltage is connected to input V2 It will also ensure that a fuse failure alarm is given instead of a Undervoltage or Differential voltage alarm and or tripping 8 4 3 Setting guidelines SEMOD153915 5 v3 The parameters for the voltage differential function are set via the local HMI or PCM600 The following settings are done for the voltage differential f...

Page 264: ... used tTrip The time delay for tripping is set by this parameter Normally the delay does not need to be so short in capacitor bank applications as there is no fault requiring urgent tripping tReset The time delay for reset of tripping level element is set by this parameter Normally it can be set to a short delay as faults are permanent when they occur For the advanced users following parameters ar...

Page 265: ...s used for signallization only through an output contact or through the event recording function 8 5 3 Setting guidelines SEMOD171929 4 v5 Loss of voltage check LOVPTUV 27 is in principle independent of the protection functions It requires to be set to open the circuit breaker in order to allow a simple system restoration following a main voltage loss of a big part of the network and only when the...

Page 266: ...260 ...

Page 267: ...grid SAPTUF 81 detects such situations and provides an output signal suitable for load shedding generator boosting HVDC set point change gas turbine start up and so on Sometimes shunt reactors are automatically switched in due to low frequency in order to reduce the power system voltage and hence also reduce the voltage dependent part of the load SAPTUF 81 is very sensitive and accurate and is use...

Page 268: ...west acceptable frequency for the equipment Power system protection by load shedding The setting has to be below the lowest occurring normal frequency and well above the lowest acceptable frequency for power stations or sensitive loads The setting level the number of levels and the distance between two levels in time and or in frequency depends very much on the characteristics of the power system ...

Page 269: ...n also be used to alert operators that frequency has slightly deviated from the set point and that manual actions might be enough 9 2 3 Setting guidelines M14959 3 v7 All the frequency and voltage magnitude conditions in the system where SAPTOF 81 performs its functions must be considered The same also applies to the associated equipment its frequency and time characteristic There are two applicat...

Page 270: ...ntification M14868 1 v4 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Rate of change of frequency protection SAPFRC df dt SYMBOL N V1 EN US 81 9 3 2 Application M14966 3 v5 Rate of change of frequency protection SAPFRC 81 is applicable in all situations where reliable detection of change of the fundamental power system voltage frequency is nee...

Page 271: ... closer to the primary nominal level if the rate of change frequency is large with respect to sign The pickup value for SAPFRC 81 is set in Hz s All voltage magnitude related settings are made as a percentage of a settable base voltage which normally is set to the primary nominal voltage level phase phase of the power system or the high voltage equipment under consideration SAPFRC 81 is not instan...

Page 272: ...266 ...

Page 273: ...nd or voltage controlled restrained The over under voltage protection is applied on power system elements such as generators transformers motors and power lines in order to detect abnormal voltage conditions Depending on the type of voltage deviation and type of power system abnormal condition different over under voltage protections based on measurement of phase to ground phase to phase residual ...

Page 274: ...both steps 4 Two undervoltage steps with the following built in features Definite time delay or Inverse Time Overcurrent TOC IDMT delay for both steps All these four protection elements within one general protection function works independently from each other and they can be individually enabled or disabled However it shall be once more noted that all these four protection elements measure one se...

Page 275: ...t phasor of the phase with minimum magnitude Phase angle will be set to 0 all the time 10 PhaseA PhaseB CVGAPC function will measure the current phasor internally calculated as the vector difference between the phase A current phasor and phase B current phasor VA VB 11 PhaseB PhaseC CVGAPC function will measure the current phasor internally calculated as the vector difference between the phase B c...

Page 276: ...d voltage phasor of the phase with minimum magnitude Phase angle will be set to 0 all the time 10 PhaseA PhaseB CVGAPC function will measure the voltage phasor internally calculated as the vector difference between the phase A voltage phasor and phase B voltage phasor VA VB 11 PhaseB PhaseC CVGAPC function will measure the voltage phasor internally calculated as the vector difference between the p...

Page 277: ...age Quantity is selected from 1 to 9 as shown in table 36 2 rated phase to phase voltage of the protected object in primary kV when the measured Voltage Quantity is selected from 10 to 15 as shown in table 36 10 1 2 3 Application possibilities SEMOD53443 136 v2 Due to its flexibility the general current and voltage protection CVGAPC function can be used with appropriate settings and configuration ...

Page 278: ...y mistake Three phase energizing of a generator which is at standstill or on turning gear causes it to behave and accelerate similarly to an induction motor The machine at this point essentially represents the subtransient reactance to the system and it can be expected to draw from one to four per unit current depending on the equivalent system impedance Machine terminal voltage can range from 20 ...

Page 279: ...614 v4 When inverse time overcurrent characteristic is selected the trip time of the stage will be the sum of the inverse time delay and the set definite time delay Thus if only the inverse time delay is required it is important to set the definite time delay for that stage to zero M13088 237 v3 The parameters for the general current and voltage protection function CVGAPC are set via the local HMI...

Page 280: ...phase voltage in kV 6 Set RCADir to value 65 degrees NegSeq current typically lags the inverted NegSeq voltage for this angle during the fault 7 Set ROADir to value 90 degree 8 Set LowVolt_VM to value 2 NegSeq voltage level above which the directional element will be enabled 9 Enable one overcurrent stage for example OC1 10 By parameter CurveType_OC1 select appropriate TOC IDMT or definite time de...

Page 281: ...rent reversal situations pickup signals from OC1 and OC2 elements shall be used to send forward and reverse signals to the remote end of the power line the available scheme communications function block within IED shall be used between multipurpose protection function and the communication equipment in order to insure proper conditioning of the above two pickup signals Furthermore the other built ...

Page 282: ...he following way without changing the value for the operate time of the negative sequence inverse overcurrent IED op 2 NS r 2 TD t I x I 1 x æ ö ç è ø EQUATION1741 ANSI V1 EN US Equation 76 In order to achieve such protection functionality with one CVGAPC functions the following must be done 1 Connect three phase generator currents to one CVGAPC instance for example GF01 2 Set parameter CurrentInp...

Page 283: ...rcurrent protection For this particular example the following settings shall be entered to insure proper function operation 1 select negative sequence current as measuring quantity for this CVGAPC function 2 make sure that the base current value for the CVGAPC function is equal to the generator rated current 3 set TD_OC1 20 4 set A_OC1 1 0 072 204 0816 5 set B_OC1 0 0 C_OC1 0 0 and P_OC1 2 0 6 set...

Page 284: ...ant standard TD 37 5 for the IEC standard or TD 41 4 for the ANSI standard Im is the magnitude of the measured current Ir is the generator rated current This formula is applicable only when measured current for example positive sequence current exceeds a pre set value typically in the range from 105 to 125 of the generator rated current By defining parameter x equal to the per unit value for the d...

Page 285: ...ation When the equation 80 is compared with the equation 81 for the inverse time characteristic of the OC1 step in it is obvious that if the following rules are followed 1 set TD equal to the IEC or ANSI standard generator capability value 2 set parameter A_OC1 equal to the value 1 x2 3 set parameter C_OC1 equal to the value 1 x2 4 set parameters B_OC1 0 0 and P_OC1 2 0 5 set PickupCurr_OC1 equal ...

Page 286: ...ion by enabling the current restraint feature The following shall be done in order to insure proper operation of the function 1 Connect three phase currents from the protected object to one CVGAPC instance for example GF03 2 Set CurrentInput to value UnbalancePh 3 Set EnRestrainCurr to On 4 Set RestrCurrInput to MaxPh 5 Set RestrCurrCoeff to value 0 97 6 Set base current value to the rated current...

Page 287: ...restraining by selecting PosSeq for this setting parameter 4 Set base current value to the rated generator current primary amperes 5 Set base voltage value to the rated generator phase to phase voltage in kV 6 Enable one overcurrent step for example OC1 7 Select CurveType_OC1 to value ANSI Very inv 8 If required set minimum operating time for this curve by using parameter tMin_OC1 default value 0 ...

Page 288: ...nt lead voltage for this angle 7 Set parameter ROADir to value 90 degree 8 Set parameter LowVolt_VM to value 5 9 Enable one overcurrent step for example OC1 10 Select parameter CurveType_OC1 to value IEC Def Time 11 Set parameter PickupCurr_OC1 to value 38 12 Set parameter tDef_OC1 to value 2 0s typical setting 13 Set parameter DirMode_OC1 to Forward 14 Set parameter DirPrinc_OC1 to IcosPhi V 15 S...

Page 289: ...4 0 4 0 6 0 8 rca Operating Region Q pu P pu rca VPS IPS ILowSet Operating region en05000535_ansi vsd ANSI05000535 V1 EN US Figure 113 Loss of excitation 1MRK 505 370 UUS A Section 10 Multipurpose protection Busbar protection REB670 2 2 ANSI 283 Application manual ...

Page 290: ...284 ...

Page 291: ...n the voltage measuring circuits should be located as close as possible to the voltage instrument transformers and shall be equipped with auxiliary contacts that are wired to the IEDs Separate fuse failure monitoring IEDs or elements within the protection and monitoring devices are another possibilities These solutions are combined to get the best possible effect in the fuse failure supervision fu...

Page 292: ...n the system operating conditions Pay special attention to the dissymmetry of the measuring quantities when the function is used on long untransposed lines on multicircuit lines and so on The settings of negative sequence zero sequence and delta algorithm are in percent of the base voltage and base current for the function Common base IED values for primary current IBase primary voltage VBase and ...

Page 293: ...are activated and working in an OR condition Also in mode OptimZsNs both negative and zero sequence algorithms are activated and the one that has the highest magnitude of measured negative or zero sequence current will operate If there is a requirement to increase the security of the fuse failure function OpModeSel can be selected to V0I0 AND V2I2 which gives that both negative and zero sequence a...

Page 294: ...imal zero sequence voltage during normal operation conditions plus a margin of 10 20 VBase is the base voltage for the function according to the setting GlobalBaseSel The setting of the current limit 3I0PU is done in percentage of IBase The setting of pickup must be higher than the normal unbalance current that might exist in the system The setting can be calculated according to equation 85 3 0 3 ...

Page 295: ... the system Set VPPU below the minimum operating voltage that might occur during emergency conditions A setting of approximately 70 of VBase is recommended The current threshold 50P shall be set lower than the IMinOp for the distance protection function A 5 10 lower value is recommended 11 1 3 6 Dead line detection M13683 78 v4 The condition for operation of the dead line detection is set by the p...

Page 296: ...nction and energisation check function These functions might mal operate if there is an incorrect measured voltage due to fuse failure or other kind of faults in voltage measurement circuit VDSPVC is designed to detect fuse failures or faults in voltage measurement circuit based on comparison of the voltages of the main and pilot fused circuits phase wise VDSPVC output can be configured to block v...

Page 297: ...8E 0B0C 4F75 99C4 0BCB22CDD166 v2 The parameters for Fuse failure supervision VDSPVC are set via the local HMI or PCM600 GUID 0B298162 C939 47E4 A89B 7E6BD7BEBB2C v2 The voltage input type phase to phase or phase to neutral is selected using ConTypeMain and ConTypePilot parameters for main and pilot fuse groups respectively 1MRK 505 370 UUS A Section 11 Secondary system supervision Busbar protecti...

Page 298: ...esired pick up primary phase to phase voltage of measured fuse group the setting of Vdif Main block and Vdif Pilot alarm will be given according to equation 88 Vdif Main block or Vdif Pilot alarm SetPrim Base V V 100 ANSI13000279 V1 EN US Equation 88 VSetPrim is defined as phase to neutral or phase to phase voltage dependent of the selected ConTypeMain and ConTypePilot If ConTypeMain and ConTypePi...

Page 299: ...tions across the breaker are satisfied in order to avoid stress on the network and its components The systems are defined as asynchronous when the frequency difference between bus and line is larger than an adjustable parameter If the frequency difference is less than this threshold value the system is defined to have a parallel circuit and the synchronism check function is used The synchronizing ...

Page 300: ...cided by the calculation of slip frequency and required pre closing time The synchronizing function compensates for the measured slip frequency as well as the circuit breaker closing delay The phase angle advance is calculated continuously The calculation of the operation pulse sent in advance is using the measured SlipFrequency and the set tBreaker time To prevent incorrect closing pulses a maxim...

Page 301: ...ole auto reclosing does not require any synchronism check since the system is tied together by two phases SESRSYN 25 function block includes both the synchronism check function and the energizing function to allow closing when one side of the breaker is dead SESRSYN 25 function also includes a built in voltage selection scheme which allows adoption to various busbar arrangements en04000179_ansi vs...

Page 302: ...t after the fault clearance a highspeed auto reclosing takes place This can cause a power swing in the net and the phase angle difference may begin to oscillate Generally the frequency difference is the time derivative of the phase angle difference and will typically oscillate between positive and negative values When the circuit breaker needs to be closed by auto reclosing after fault clearance s...

Page 303: ...litate the controlled re connection of disconnected lines and buses to energized buses and lines The energizing check function measures the bus and line voltages and compares them to both high and low threshold values The output is given only when the actual measured conditions match the set conditions Figure 117 shows two substations where one 1 is energized and the other 2 is not energized The l...

Page 304: ...seSelLine in a similar way the equipment is considered non energized Dead if the voltage is below the set value for VDeadBusEnerg or VDeadLineEnerg of the respective Global Base Value groups A disconnected line can have a considerable potential due to factors such as induction from a line running in parallel or feeding via extinguishing capacitors in the circuit breakers This voltage can be as hig...

Page 305: ...pervision function can also be used if a three phase voltage is present The signal BLKV from the internal fuse failure supervision function is then used and connected to the fuse supervision inputs of the SESRSYN function block In case of a fuse failure the SESRSYN energizing 25 function is blocked The VB1OK VB2OK and VB1FF VB2FF inputs are related to the busbar voltage and the VL1OK VL2OK and VL1...

Page 306: ...d arrangements but with different parameter settings Below are some examples of how different arrangements are connected to the IED analog inputs and to the function block SESRSYN 25 One function block is used per circuit breaker The input used below in example are typical and can be changed by use of configuration and signal matrix tools The SESRSYN and connected SMAI function block instances mus...

Page 307: ...IFFA FRDIFFM PHDIFFM INADVCLS VDIFFME FRDIFFME PHDIFFME Vbus VLine MODEAEN MODEMEN ANSI10000093 V1 EN US Figure 119 Connection of SESRSYN 25 function block in a single busbar arrangement Figure 119 illustrates connection principles for a single busbar For the SESRSYN 25 function there is one voltage transformer on each side of the circuit breaker The voltage transformer circuit connections are str...

Page 308: ... VDIFFSC FRDIFFA PHDIFFA FRDIFFM PHDIFFM INADVCLS VDIFFME FRDIFFME PHDIFFME Vbus VLine MODEAEN MODEMEN ANSI10000094 V1 EN US Figure 120 Connection of SESRSYN 25 function block in a single breaker double busbar arrangement with external voltage selection In this type of arrangement no internal voltage selection is required The voltage selection is made by external relays typically connected accordi...

Page 309: ...SYN FRDIFFOK FRDERIVA VOKSC VDIFFSC FRDIFFA PHDIFFA FRDIFFM PHDIFFM INADVCLS VDIFFME FRDIFFME PHDIFFME Vbus VLine MODEAEN MODEMEN ANSI10000095 V1 EN US Figure 121 Connection of the SESRSYN function block in a single breaker double busbar arrangement with internal voltage selection When internal voltage selection is needed the voltage transformer circuit connections are made according to figure 121...

Page 310: ...DIFFA PHDIFFA FRDIFFM PHDIFFM INADVCLS VDIFFME FRDIFFME PHDIFFME Vbus VLine MODEAEN MODEMEN SESRSYN 25 V3PB1 V3PB2 V3PL1 V3PL2 BLOCK BLKSYNCH BLKSC BLKENERG BUS1_OP BUS1_CL BUS2_OP BUS2_CL LINE1_OP LINE1_CL LINE2_OP LINE2_CL VB1OK VB1FF VB2OK VB2FF VL1OK VL1FF VL2OK VL2FF STARTSYN TSTSYNCH TSTSC TSTENERG AENMODE MENMODE SYNOK AUTOSYOK AUTOENOK MANSYOK MANENOK TSTSYNOK TSTAUTSY TSTMANSY TSTENOK VSE...

Page 311: ...s 12 1 3 5 Breaker and a half M12330 3 v8 Figure 123 describes a breaker and a half arrangement with three SESRSYN functions in the same IED each of them handling voltage selection for WA1_QA1 TIE_QA1 and WA2_QA1 breakers respectively The voltage from busbar 1 VT is connected to V3PB1 on all three function blocks and the voltage from busbar 2 VT is connected to V3PB2 on all three function blocks T...

Page 312: ...C FRDIFFA PHDIFFA FRDIFFM PHDIFFM INADVCLS VDIFFME FRDIFFME PHDIFFME Vbus VLine MODEAEN MODEMEN SESRSYN 25 V3PB1 V3PB2 V3PL1 V3PL2 BLOCK BLKSYNCH BLKSC BLKENERG BUS1_OP BUS1_CL BUS2_OP BUS2_CL LINE1_OP LINE1_CL LINE2_OP LINE2_CL VB1OK VB1FF VB2OK VB2FF VL1OK VL1FF VL2OK VL2FF STARTSYN TSTSYNCH TSTSC TSTENERG AENMODE MENMODE SYNOK AUTOSYOK AUTOENOK MANSYOK MANENOK TSTSYNOK TSTAUTSY TSTMANSY TSTENOK...

Page 313: ...S1_OP CL Position of WA1_QA1 breaker and belonging disconnectors BUS2_OP CL Position of WA2_QA1 breaker and belonging disconnectors LINE1_OP CL Position of LINE1_QB9 disconnector LINE2_OP CL Position of LINE2_QB9 disconnector VB1OK FF Supervision of WA1_MCB fuse VB2OK FF Supervision of WA2_MCB fuse VL1OK FF Supervision of LINE1_MCB fuse VL2OK FF Supervision of LINE2_MCB fuse Setting CBConfig Tie C...

Page 314: ...RSYN 25 SC VC X has been divided into four different setting groups General Synchronizing Synchrocheck and Energizingcheck General settings Operation The operation mode can be set Enabled or Disabled The setting Disabled disables the whole function GblBaseSelBus and GblBaseSelLine These configuration settings are used for selecting one of twelve GBASVAL functions which then is used as base value r...

Page 315: ...tion is in the service mode and the output signal depends on the input conditions VHighBusSynch and VHighLineSynch The voltage level settings shall be chosen in relation to the bus line network voltage The threshold voltages VHighBusSynch and VHighLineSynch have to be set lower than the value where the network is expected to be synchronized A typical value is 80 of the rated voltage VDiffSynch Set...

Page 316: ...etween bus and line at which synchronizing is accepted To minimize the moment stress when synchronizing near a power station a narrower limit should be used A typical value is 15 degrees tBreaker The tBreaker shall be set to match the closing time for the circuit breaker and should also include the possible auxiliary relays in the closing circuit It is important to check that no slow logic compone...

Page 317: ... can be 80 of the base voltages VDiffSC The setting for voltage difference between line and bus in p u This setting in p u is defined as V Bus GblBaseSelBus V Line GblBaseSelLine A normal setting is 0 10 0 15 p u FreqDiffM and FreqDiffA The frequency difference level settings FreqDiffM and FreqDiffA shall be chosen depending on the condition in the network At steady conditions a low frequency diff...

Page 318: ...Energ Two different settings can be used for automatic and manual closing of the circuit breaker The settings for each of them are Disabled the energizing function is disabled DLLB Dead Line Live Bus the line voltage is below set value of VDeadLineEnerg and the bus voltage is above set value of VLIveBusEnerg DBLL Dead Bus Live Line the bus voltage is below set value of VDeadBusEnerg and the line v...

Page 319: ...xEnerg This setting is used to block the closing when the voltage on the live side is above the set value of VMaxEnerg tAutoEnerg and tManEnerg The purpose of the timer delay settings tAutoEnerg and tManEnerg is to ensure that the dead side remains de energized and that the condition is not due to a temporary interference Should the conditions not persist for the specified time the delay timer is ...

Page 320: ...closers are available Automatic reclosing is a well established method for the restoration of service in a power system after a transient line fault The majority of line faults are flashovers which are transient by nature When the power line is switched off by the operation of line protection and line breakers the arc de ionizes and recovers its ability to withstand voltage at a somewhat variable ...

Page 321: ...ted meshing or parallel routing single phase auto reclosing is of particular value During the single phase dead time the system is still capable of transmitting load on the two healthy phases and the system is still synchronized It requires that each circuit breaker pole can be operated individually which is usually the case for higher transmission voltages A somewhat longer dead time may be requi...

Page 322: ...on which means two auto reclosers per CB one should take measures to avoid uncoordinated reclosing commands In breaker and a half double breaker and ring bus arrangements two CBs per line end are operated One auto recloser per CB is recommended Arranged in such a way that sequential reclosing of the two CBs can be arranged with a priority circuit available in the auto recloser In case of a permane...

Page 323: ... sub systems as the requirement is for fault clearance and a failure to reclose because of the auto recloser being out of service is not considered a major disturbance If two auto reclosers are provided on the same breaker the application must be carefully checked and normally one must be the master and be connected to inhibit the other auto recloser if it has started This inhibit can for example ...

Page 324: ...start of a reclosing cycle M12391 94 v5 The usual way to start an auto reclosing cycle or sequence is to start it at selective tripping by line protection by applying a signal to the RI input Starting signals can be either general trip signals or only the conditions for differential distance protection zone 1 and distance protection aided trip In some cases also directional ground fault protection...

Page 325: ...ll prevent auto reclosing need to be connected to the INHIBIT input 12 2 2 4 Blocking of the auto recloser M12391 103 v4 Auto reclose attempts are expected to take place only for faults on the own line The auto recloser must be blocked by activating the INHIBIT input for the following conditions Tripping from delayed distance protection zones Tripping from back up protection functions Tripping fro...

Page 326: ...nhib When start pulse duration signal is longer than set maximum start pulse duration the auto reclosing sequence interrupts in the same way as for a signal to the INHIBIT input 12 2 2 7 Maximum number of reclosing shots M12391 120 v7 The maximum number of auto reclosing shots in an auto reclosing cycle is selected by the setting NoOfShots A maximum of five shots can be done The type of auto reclo...

Page 327: ...he output module for further checks and to issue a breaker closing command When a circuit breaker closing command is issued the prepare three pole output trip is set When issuing a circuit breaker closing command the tReclaim timer is started If no tripping takes place during that time the auto recloser resets to the Ready state and the ACTIVE output resets If the first reclosing shot fails a thre...

Page 328: ...ingle pole or two pole tripping the operation is as in the above described example program mode 1 2 3ph If the first reclosing shot fails a three pole trip will be issued and three pole reclosing will follow if selected At two pole or three pole trip a failure of a two pole or three pole auto reclosing attempt will inhibit the auto recloser No more shots are attempted The expression 1 2 3ph should...

Page 329: ...09000168_1_en vsd SMBRREC 79 MODEINT PSTO SWPOSN NAME1 NAME2 3 1 3 INTONE SLGGIO ANSI09000168 V1 EN US Figure 125 Selection of the auto reclose mode from a hardware functional key in front of the IED 12 2 2 15 Auto reclosing reset timer M12391 202 v4 The tReset timer defines the time it takes from issue of the breaker closing command until the auto recloser resets Should a new trip occur during th...

Page 330: ...y for a new auto reclosing cycle Normally the UNSUCCL output appears when a new start is received after the last auto reclosing shot has been made and the auto recloser is inhibited The output signal resets after reclaim time The unsuccessful signal can also be made to depend on the circuit breaker position input The UnsucClByCBChk setting should then be set to CBCheck and the tUnsucCl timer shoul...

Page 331: ...to reclosing sequence normally not as no auto closing attempt has been given In Figures 126 and 127 the logic shows how a closing lock out logic can be designed with the lock out relay as an external relay alternatively with the lock out created internally with the manual closing going through the synchrocheck function An example of lock out logic Lock out RXMD1 11 12 21 MAIN ZAK CLOSE CLOSE COMMA...

Page 332: ...ce will then be stopped and instead the timer t1 3Ph for three pole auto reclosing will be started from zero The sequence will continue as a three pole auto reclosing sequence if it is a selected alternative reclosing mode The second fault which can be single phase is tripped three pole because the trip function SMPPTRC in the IED has an evolving fault timer which ensures that second fault is alwa...

Page 333: ...er Setting Tool PST Parameter Setting Tool is a part of PCM600 Recommendations for input signals M12399 7 v10 Please see Figure 128 Figure 129 and Figure 130 and default factory configuration for examples BLKOFF Used to unblock the auto recloser when it has been blocked due to activating BLKON input or by an unsuccessful auto reclosing attempt if the BlockByUnsucCl setting is set to On BLKON Used ...

Page 334: ...ger is connected to the input MODEINT the selected ARMode setting will be invalid and the MODEINT input value will be used instead The selected mode is reported as an integer on the MODE output ON and OFF These inputs can be connected to binary inputs or to a communication interface block for external control PLCLOST This is intended for line protection permissive signal channel lost fail for exam...

Page 335: ... If neither internal nor external synchronism or energizing check is required it can be connected to a permanently high source TRUE The signal is required for three phase shots 1 5 to proceed Note Not the high speed step THOLHOLD Signal Thermal overload protection holding back auto reclosing It can be connected to a thermal overload protection trip signal which resets only when the thermal content...

Page 336: ...ivation of the ZONESTEP input This functionality is controlled by the setting ZoneSeqCoord Recommendations for output signals M12399 46 v9 Please see Figure 128 Figure 129 and Figure 130 and default factory configuration for examples 1PT1 and 2PT1 Indicates that single pole or two pole auto reclosing is in progress It is used to temporarily block an ground fault and or pole disagreement function d...

Page 337: ...nected to the MODEINT input the selected ARMode setting will be invalid and the MODEINT input value will be used instead The selected mode is reported as an integer on the MODE output The six possible modes are described in Table 38 with their corresponding MODEINT integer value PERMIT1P Permit single pole trip is the inverse of PREP3P It can be connected to a binary output relay for connection to...

Page 338: ...hrocheck or energizing check condition has not been fulfilled within the set time interval tSync Also ABORTED output will be activated UNSUCCL Indicates unsuccessful reclosing WFMASTER Wait from master is used in high priority units to hold back auto reclosing of the low priority unit during sequential auto reclosing Refer to the recommendation for multi breaker arrangements in Figure 130 Connecti...

Page 339: ...xx xx xx xx xx xx PROTECTION xxxx TRIP ZCVPSOF TRIP ZMQPDIS 21 TRIP SESRSYN 25 AUTOOK IOM IOM SMBRREC 79 PERMIT1P PREP3P RI_HS SKIPHS TR2P TR3P TRUE WAIT RSTCOUNT 3PT1 2PT1 3PT2 3PT3 3PT4 3PT5 CBREADY 52a PLCLOST ANSI04000135 V3 EN US Figure 128 Example of I O signal connections at a three phase auto reclosing sequence 1MRK 505 370 UUS A Section 12 Control Busbar protection REB670 2 2 ANSI 333 App...

Page 340: ...igure 130 In a single breaker arrangement the setting is Priority None In a multi breaker arrangement the setting for the first circuit breaker the master is Priority High and for the other circuit breaker Priority Low While the auto reclosing of the master is in progress it issues the WFMASTER output After an unsuccessful reclosing the WFMASTER output is also maintained by the UNSUCCL signal When...

Page 341: ...successful the UNSUCCL output connected to the INHIBIT input of the slave unit interrupts the auto reclosing sequence of the latter The signals can be cross connected to allow simple changing of the priority by just setting the High and the Low priorities without changing the configuration The input 52a for each circuit breaker is important in multi breaker arrangements to ensure that the circuit ...

Page 342: ...SEMD 52a SMBRREC 79 ANSI04000137 V3 EN US Figure 130 Additional input and output signals at multi breaker arrangement The connections can be made symmetrical to make it possible to control the priority by the settings Priority High Low 12 2 3 2 Auto recloser settings GUID 74980A07 CF89 488F AB17 E5351D0032EE v1 The settings for the auto recloser are set using the local HMI LHMI or PCM600 This sett...

Page 343: ...tWait can be 2 sec StartByCBOpen The normal setting Disabled is used when the function is started by protection trip signals If set Enabled the start of the auto recloser is controlled by an circuit breaker auxiliary contact LongStartInhib Usually the protection trip command used as an auto reclosing start signal resets quickly as the fault is cleared A prolonged trip command may depend on a circu...

Page 344: ...ycle always have storing energy for a CO operation after the first trip IEC 56 duty cycle is O 0 3sec CO 3min CO FollowCB The usual setting is Follow CB Off The setting On can be used for delayed auto reclosing with long delay to cover the case when a circuit breaker is being manually closed during the auto reclosing dead time before the auto recloser has issued its breaker close command UnsucClBy...

Page 345: ...time an auto reclosing start will not be accepted tSuccessful If the circuit breaker closing command is given and the circuit breaker is closed within the set time interval tUnsucCl the SUCCL output is activated after the set time interval tSuccessful tUnsucCl The reclaim timer tReset is started each time a circuit breaker closing command is given If no start occurs within this time the auto reclo...

Page 346: ...osing is done without the requirement of synchrocheck conditions to be fulfilled A typical dead time is 400ms t2 3Ph t3 3Ph t4 3Ph t5 3Ph The delay of auto reclosing shot two and possible later shots are usually set at 30s or more A check that the circuit breaker duty cycle can manage the selected setting must be done The setting can in some cases be restricted by national regulations For multiple...

Page 347: ... v13 The apparatus control is a functionality for control and supervising of circuit breakers disconnectors and grounding switches within a bay Permission to operate is given after evaluation of conditions from other functions such as interlocking synchronism check operator place selection and external or internal blockings The complete apparatus control function is not included in this product an...

Page 348: ...ion to prevent simultaneous operation Selection and supervision of operator place Command supervision Block deblock of operation Block deblock of updating of position indications Substitution of position indications Overriding of interlocking functions Overriding of synchronism check Pole discrepancy supervision Operation counter Suppression of mid position The apparatus control function is realiz...

Page 349: ...cription for all these functions can be found below The function SCILO in the Figure below is the logical node for interlocking When the circuit breaker or switch is located in a breaker IED two more functions are added GOOSE receive for switching device GOOSEXLNRCV Proxy for signals from switching device via GOOSE XLNPROXY The extension of the signal flow and the usage of the GOOSE communication ...

Page 350: ... SXSWI 189 989 IEC 61850 QCBAY 152 ANSI05000116 V1 EN US Figure 132 Signal flow between apparatus control function blocks when all functions are situated within the IED Section 12 1MRK 505 370 UUS A Control 344 Busbar protection REB670 2 2 ANSI Application manual ...

Page 351: ...SCILO XLNPROXY GOOSEXLNRCV XLNPROXY QA1 QB1 QB9 GOOSEover process bus IEC16000070 1 EN vsdx IEC16000070 V1 EN US Figure 133 Signal flow between apparatus control functions with XCBR and XSWI located in a breaker IED 1MRK 505 370 UUS A Section 12 Control Busbar protection REB670 2 2 ANSI 345 Application manual ...

Page 352: ... originator categories for each PSTO value are shown in Table 39 Table 39 Accepted originator categories for each PSTO Permitted Source To Operate Originator orCat 0 Off 4 5 6 1 Local 1 4 5 6 2 Remote 2 3 4 5 6 3 Faulty 4 5 6 4 Not in use 4 5 6 5 All 1 2 3 4 5 6 6 Station 2 4 5 6 7 Remote 3 4 5 6 PSTO All then it is no priority between operator places All operator places are allowed to operate Acc...

Page 353: ...t possible either from local or from remote For IEC 61850 8 1 communication the Bay Control function can be set to discriminate between commands with orCat station and remote 2 and 3 The selection is then done through the IEC 61850 8 1 edition 2 command LocSta QCBAY also provides blocking functions that can be distributed to different apparatuses within the bay There are two different blocking alt...

Page 354: ...ck At error the command sequence is cancelled In the case when there are three one phase switches SXCBR connected to the switch controller function the switch controller will merge the position of the three switches to the resulting three phase position In case of a pole discrepancy situation that is the positions of the one phase switches are not equal for a time longer than a settable time an er...

Page 355: ...switch SXSWI with mandatory functionality 12 3 1 4 Proxy for signals from switching device via GOOSE XLNPROXY GUID 2DA1E47C 5A9A 4C53 8D60 7B1729EF6B90 v1 The purpose of the proxy for signals from switching device via GOOSE XLNPROXY is to give the same internal representation of the position status and control response for a switch modeled in a breaker IED as if represented by a SXCBR or SXSWI fun...

Page 356: ... US Figure 135 Configuration with XLNPROXY and GOOSEXLNRCV where all the IEC 61850 modelled data is used including selection Section 12 1MRK 505 370 UUS A Control 350 Busbar protection REB670 2 2 ANSI Application manual ...

Page 357: ...witch to start moving it checks if the switch is blocked for the operation When the switch has started moving and no blocking condition has been detected XLNPROXY issues a response to the SCSWI function that the command has started If OPOK is used this response is given when XLNPROXY receives the signal If no movement of the switch is registered within the limit tStartMove the command is considere...

Page 358: ...he OPCAP input and output are used for the CBOpCap data of a XCBR respectively SwOpCap for a XSWI The interpretation for the command following is controlled through the setting SwitchType 12 3 1 5 Reservation function QCRSV and RESIN M16609 3 v4 The purpose of the reservation function is primarily to transfer interlocking information between IEDs in a safe way and to prevent double operation in a ...

Page 359: ...r of involved bays up to 60 instances are available The received signals are either the request for reservation from another bay or the acknowledgment from each bay respectively which have received a request from this bay Also the information of valid transmission over the station bus must be received en 05000117 _ansi vsd IED IED From other SCSWI in the bay To other SCSWI in the bay 3 Station bus...

Page 360: ...olution in Figure 137 but instead have a higher availability since no acknowledgment is required SCSWI SELECTED RES_EXT IED IED OR Other SCWI in the bay Station bus SPGAPC IN RESGRANT IntlReceive RESGRANT IntlReceive IEC05000178 3 en vsd IEC05000178 V3 EN US Figure 139 Application principle for an alternative reservation solution 12 3 2 Interaction between modules M16626 3 v8 A typical bay with ap...

Page 361: ... transmitted to SXCBR The Autorecloser SMBRREC 79 consists of the facilities to automatically close a tripped breaker with respect to a number of configurable conditions The logical node Interlocking SCILO 3 provides the information to SCSWI whether it is permitted to operate due to the switchyard topology The interlocking conditions are evaluated with separate logic and connected to SCILO 3 The S...

Page 362: ...chronizer SCILO Interlocking QCRSV Reservation Res req Res granted GAPC Generic Automatic Process Control Open Close Open Close Enable close Enable open Open rel Close rel Open rel SMPPTRC Trip logic Position Pos from other bays I O Open cmd Close cmd Synchronizing OK Synchrocheck OK Start Synchronizing Synchronizing in progress SCILO Interlocking Enable open Enable close IEC05000120 3 EN vsdx IEC...

Page 363: ...ion SECRSYN Synchrocheck SCILO SCILO Synchrocheck OK QCRSV Reservation Res req Res granted GAPC Generic Automatic Process Control Open Close Open Close Enable close Enable open Open rel Close rel Open rel SMPPTRC Trip logic Position Enable open Enable close Pos from other bays I O Open cmd Close cmd Interlocking Interlocking ANSI05000120 V2 EN US Figure 140 Example overview of the interactions bet...

Page 364: ...ccording to IEC 61850 The default for control of circuit breakers disconnectors and grounding switches the control model is set to SBO Enh Select Before Operate with enhanced security When the operation shall be performed in one step and no monitoring of the result of the command is desired the model direct control with normal security is used At control with enhanced security there is an addition...

Page 365: ...e is given tPoleDiscord is the allowed time to have discrepancy between the poles at control of three single phase breakers At discrepancy an output signal is activated to be used for trip or alarm and during a command the control function is reset and a cause code is given SuppressMidPos when On suppresses the mid position during the time tIntermediate of the connected switches The parameter Inte...

Page 366: ...r switches Value Breaker operating capability CbOpCap Switch operating capability SwOpCap 1 None None 2 Open Open 3 Close Open Close 4 Open Close Open Close and Open 5 Close Open Close Open Larger values handled as 4 both Close and Open 6 Open Close Open Close Open 7 more tStartMove is the supervision time for the apparatus to start moving after a command execution is done from the SCSWI function ...

Page 367: ...to a maximum of two or to ensure that energizing is always from one side for example the high voltage side of a transformer This section only deals with the first point and only with restrictions caused by switching devices other than the one to be controlled This means that switch interlock because of device alarms is not included in this section Disconnectors and grounding switches have a limite...

Page 368: ...time which in the case of disconnectors may be up to 10 seconds Should both indications stay low for a longer period the position indication will be interpreted as unknown If both indications stay high something is wrong and the state is again treated as unknown In both cases an alarm is sent to the operator Indications from position sensors shall be self checked and system faults indicated by a f...

Page 369: ...9G 289G 989 989G WA1 A WA2 B WA7 C 789 en04000478_ansi vsd 152 ANSI04000478 V1 EN US Figure 141 Switchyard layout ABC_LINE 3 M13560 4 v5 The signals from other bays connected to the module ABC_LINE 3 are described below 12 4 2 2 Signals from bypass busbar M13560 6 v5 To derive the signals Signal BB7_D_OP All line disconnectors on bypass WA7 except in the own bay are open VP_BB7_D The switch status...

Page 370: ...R bay 1 789OPTR bay 2 789OPTR bay n 1 VP789TR bay 1 VP789TR bay 2 VP789TR bay n 1 EXDU_BPB bay 1 EXDU_BPB bay 2 EXDU_BPB bay n 1 ANSI04000477 V1 EN US Figure 142 Signals from bypass busbar in line bay n 12 4 2 3 Signals from bus coupler M13560 31 v4 If the busbar is divided by bus section disconnectors into bus sections the busbar busbar connection could exist via the bus section disconnector and ...

Page 371: ...alid EXDU_BC No transmission error from any bus coupler bay BC These signals from each bus coupler bay ABC_BC are needed Signal BC12CLTR A bus coupler connection through the own bus coupler exists between busbar WA1 and WA2 BC17OPTR No bus coupler connection through the own bus coupler between busbar WA1 and WA7 BC17CLTR A bus coupler connection through the own bus coupler exists between busbar WA...

Page 372: ...rs the signals from the bus section coupler bay A1A2_BS rather than the bus section disconnector bay A1A2_DC must be used For B1B2_BS corresponding signals from busbar B are used The same type of module A1A2_BS is used for different busbars that is for both bus section circuit breakers A1A2_BS and B1B2_BS Signal S1S2OPTR No bus section coupler connection between bus sections 1 and 2 S1S2CLTR A bus...

Page 373: ...sect 1 VPDCTR B1B2 VPBC27TR sect 2 EXDU_BC sect 1 EXDU_DC A1A2 EXDU_DC B1B2 EXDU_BC sect 2 BC_12_CL VP_BC_12 BC_17_OP BC_17_CL VP_BC_17 BC_27_OP BC_27_CL VP_BC_27 EXDU_BC en04000480_ansi vsd AND AND AND OR AND AND OR AND OR AND AND ANSI04000480 V1 EN US Figure 144 Signals to a line bay in section 1 from the bus coupler bays in each section For a line bay in section 2 the same conditions as above a...

Page 374: ..._CL 0 BB7_D_OP 1 BC_17_OP 1 BC_17_CL 0 BC_27_OP 1 BC_27_CL 0 EXDU_BPB 1 VP_BB7_D 1 VP_BC_17 1 VP_BC_27 1 If there is no second busbar WA2 and therefore no 289 disconnector then the interlocking for 289 is not used The state for 289 2189G BC_12 BC_27 are set to open by setting the appropriate module inputs as follows In the functional block diagram 0 and 1 are designated 0 FALSE and 1 TRUE 289_OP 1...

Page 375: ...d layout ABC_BC 3 12 4 3 2 Configuration M13553 138 v4 The signals from the other bays connected to the bus coupler module ABC_BC are described below 12 4 3 3 Signals from all feeders M13553 6 v4 To derive the signals Signal BBTR_OP No busbar transfer is in progress concerning this bus coupler VP_BBTR The switch status is valid for all apparatuses involved in the busbar transfer EXDU_12 No transmi...

Page 376: ...I04000481 V1 EN US Figure 146 Signals from any bays in bus coupler bay n If the busbar is divided by bus section disconnectors into bus sections the signals BBTR are connected in parallel if both bus section disconnectors are closed So for the basic project specific logic for BBTR above add this logic Section 1 Section 2 A1A2_DC BS B1B2_DC BS ABC_LINE ABC_BC ABC_LINE ABC_BC WA1 A1 WA2 B1 WA7 C C B...

Page 377: ... is used for different busbars that is for both bus section circuit breakers A1A2_BS and B1B2_BS Signal S1S2OPTR No bus section coupler connection between bus sections 1 and 2 VPS1S2TR The switch status of bus section coupler BS is valid EXDU_BS No transmission error from the bay that contains the above information For a bus coupler bay in section 1 these conditions are valid en04000483_ansi vsd A...

Page 378: ...ler bay BC These signals from each bus coupler bay ABC_BC except the own bay are needed Signal BC12CLTR A bus coupler connection through the own bus coupler exists between busbar WA1 and WA2 VPBC12TR The switch status of BC_12 is valid EXDU_BC No transmission error from the bay that contains the above information These signals from each bus section disconnector bay A1A2_DC are also needed For B1B2...

Page 379: ...2 EXDU_BC en04000485_ansi vsd AND AND DCCLTR A1A2 DCCLTR B1B2 BC12CLTR sect 2 VPDCTR A1A2 VPDCTR B1B2 VPBC12TR sect 2 EXDU_DC A1A2 EXDU_DC B1B2 EXDU_BC sect 2 ANSI04000485 V1 EN US Figure 150 Signals to a bus coupler bay in section 1 from a bus coupler bay in another section For a bus coupler bay in section 2 the same conditions as above are valid by changing section 1 to section 2 and vice versa ...

Page 380: ...L 0 VP_BC_12 1 BBTR_OP 1 VP_BBTR 1 12 4 4 Interlocking for transformer bay AB_TRAFO 3 IP14149 1 v2 12 4 4 1 Application M13567 3 v7 The interlocking for transformer bay AB_TRAFO 3 function is used for a transformer bay connected to a double busbar arrangement according to figure 151 The function is used when there is no disconnector between circuit breaker and transformer Otherwise the interlockin...

Page 381: ...e signals from other bays connected to the module AB_TRAFO are described below 12 4 4 2 Signals from bus coupler M13566 6 v4 If the busbar is divided by bus section disconnectors into bus sections the busbar busbar connection could exist via the bus section disconnector and bus coupler within the other bus section 1MRK 505 370 UUS A Section 12 Control Busbar protection REB670 2 2 ANSI 375 Applicat...

Page 382: ...tatus of BC_12 is valid EXDU_BC No transmission error from bus coupler bay BC The logic is identical to the double busbar configuration Signals from bus coupler 12 4 4 3 Configuration setting M13566 22 v5 If there are no second busbar B and therefore no 289 disconnector then the interlocking for 289 is not used The state for 289 2189G BC_12 are set to open by setting the appropriate module inputs ...

Page 383: ... includes a bus section circuit breaker WA1 A1 289 489G 189 389G WA2 A2 en04000516_ansi vsd 289G 189G A1A2_BS 152 ANSI04000516 V1 EN US Figure 153 Switchyard layout A1A2_BS 3 M15111 4 v3 The signals from other bays connected to the module A1A2_BS are described below 12 4 5 2 Signals from all feeders M15111 6 v4 If the busbar is divided by bus section circuit breakers into bus sections and both cir...

Page 384: ...ormer bay AB_TRAFO and bus coupler bay ABC_BC are needed Signal 1289OPTR 189 or 289 or both are open VP1289TR The switch status of 189 and 289 are valid EXDU_12 No transmission error from the bay that contains the above information These signals from each bus coupler bay ABC_BC are needed Signal BC12OPTR No bus coupler connection through the own bus coupler between busbar WA1 and WA2 VPBC12TR The ...

Page 385: ... sect 2 S1S2OPTR B1B2 BC12OPTR sect 2 1289OPTR bay 1 sect 1 1289OPTR bay n sect 1 BBTR_OP VP_BBTR EXDU_12 OR AND OR AND AND AND VPS1S2TR B1B2 VPBC12TR sect 1 VP1289TR bay 1 sect 2 VP1289TR bay n sect 1 VPBC12TR sect 2 VP1289TR bay 1 sect 1 VP1289TR bay n sect 1 AND EXDU_12 bay 1 sect 2 EXDU_12 bay n sect 2 EXDU_12 bay 1 sect 1 EXDU_12 bay n sect 1 EXDU_BS B1B2 EXDU_BC sect 1 EXDU_BC sect 2 ANSI040...

Page 386: ...AND EXDU_12 bay 1 sect 2 EXDU_12 bay n sect 2 EXDU_12 bay 1 sect 1 EXDU_12 bay n sect 1 EXDU_BS A1A2 EXDU_BC sect 1 EXDU_BC sect 2 ANSI04000491 V1 EN US Figure 156 Signals from any bays for a bus section circuit breaker between sections B1 and B2 12 4 5 3 Configuration setting M15111 57 v3 If there is no other busbar via the busbar loops that are possible then either the interlocking for the 152 o...

Page 387: ...elow 12 4 6 2 Signals in single breaker arrangement M13542 6 v5 If the busbar is divided by bus section disconnectors the condition no other disconnector connected to the bus section must be made by a project specific logic The same type of module A1A2_DC is used for different busbars that is for both bus section disconnector A1A2_DC and B1B2_DC But for B1B2_DC corresponding signals from busbar B ...

Page 388: ...e bay that contains the above information If there is an additional bus section disconnector the signal from the bus section disconnector bay A1A2_DC must be used Signal DCOPTR The bus section disconnector is open VPDCTR The switch status of bus section disconnector DC is valid EXDU_DC No transmission error from the bay that contains the above information If there is an additional bus section circ...

Page 389: ... section disconnector these conditions from the A2 busbar section are valid en04000495_ansi vsd 189OPTR bay 1 sect A2 S2DC_OP VPS2_DC EXDU_BB 189OPTR bay n sect A2 VP189TR bay 1 sect A2 VP189TR bay n sect A2 VPDCTR A2 A3 EXDU_BB bay n sect A2 AND DCOPTR A2 A3 EXDU_BB bay 1 sect A2 EXDU_DC A2 A3 AND AND ANSI04000495 V1 EN US Figure 160 Signals from any bays in section A2 to a bus section disconnect...

Page 390: ... S2DC_OP VPS2_DC EXDU_BB 289OPTR 22089OTR bay n sect B2 VP289TR V22089TR bay 1 sect B2 VP289TR V22089TR bay n sect B2 VPDCTR B2 B3 EXDU_BB bay n sect B2 AND DCOPTR B2 B3 EXDU_BB bay 1 sect B2 EXDU_DC B2 B3 AND AND ANSI04000497 V1 EN US Figure 162 Signals from any bays in section B2 to a bus section disconnector 12 4 6 3 Signals in double breaker arrangement M13542 80 v5 If the busbar is divided by...

Page 391: ...ll disconnectors on bus section 1 is valid VPS2_DC The switch status of all disconnectors on bus section 2 is valid EXDU_BB No transmission error from double breaker bay DB that contains the above information These signals from each double breaker bay DB_BUS are needed Signal 189OPTR 189 is open 289OPTR 289 is open VP189TR The switch status of 189 is valid VP289TR The switch status of 289 is valid...

Page 392: ...these conditions from the A2 busbar section are valid en04000500_ansi vsd 189OPTR bay 1 sect A2 S2DC_OP VPS2_DC EXDU_BB AND 189OPTR bay n sect A2 VP189TR bay 1 sect A2 VP189TR bay n sect A2 EXDU_DB bay 1 sect A2 EXDU_DB bay n sect A2 AND AND ANSI04000500 V1 EN US Figure 165 Signals from double breaker bays in section A2 to a bus section disconnector For a bus section disconnector these conditions ...

Page 393: ... n sect B2 EXDU_DB bay 1 sect B2 EXDU_DB bay n sect B2 AND AND ANSI04000502 V1 EN US Figure 167 Signals from double breaker bays in section B2 to a bus section disconnector 12 4 6 4 Signals in breaker and a half arrangement M13542 127 v5 If the busbar is divided by bus section disconnectors the condition for the busbar disconnector bay no other disconnector connected to the bus section must be mad...

Page 394: ...valid VPS2_DC The switch status of disconnectors on bus section 2 is valid EXDU_BB No transmission error from breaker and a half BH that contains the above information 12 4 7 Interlocking for busbar grounding switch BB_ES 3 IP14164 1 v4 12 4 7 1 Application M15015 3 v7 The interlocking for busbar grounding switch BB_ES 3 function is used for one busbar grounding switch on any busbar parts accordin...

Page 395: ...These signals from each line bay ABC_LINE each transformer bay AB_TRAFO and each bus coupler bay ABC_BC are needed Signal 189OPTR 189 is open 289OPTR 289 is open AB_TRAFO ABC_LINE 22089OTR 289 and 2089 are open ABC_BC 789OPTR 789 is open VP189TR The switch status of 189 is valid VP289TR The switch status of 289 is valid V22089TR The switch status of 289and 2089 is valid VP789TR The switch status o...

Page 396: ...S Signal 189OPTR 189 is open 289OPTR 289 is open VP189TR The switch status of 189 is valid VP289TR The switch status of 289 is valid EXDU_BS No transmission error from the bay BS bus section coupler bay that contains the above information For a busbar grounding switch these conditions from the A1 busbar section are valid en04000506_ansi vsd 189OPTR bay 1 sect A1 BB_DC_OP VP_BB_DC EXDU_BB 189OPTR b...

Page 397: ...ect A2 AND DCOPTR A1 A2 EXDU_BB bay 1 sect A2 EXDU_DC A1 A2 AND AND ANSI04000507 V1 EN US Figure 172 Signals from any bays in section A2 to a busbar grounding switch in the same section For a busbar grounding switch these conditions from the B1 busbar section are valid 1MRK 505 370 UUS A Section 12 Control Busbar protection REB670 2 2 ANSI 391 Application manual ...

Page 398: ...me section For a busbar grounding switch these conditions from the B2 busbar section are valid 289OPTR 22089OTR bay 1 sect B2 BB_DC_OP VP_BB_DC EXDU_BB en04000509_ansi vsd 289OPTR 22089OTR bay n sect B2 VP289TR V22089TR bay 1 sect B2 VP289TR V22089TR bay n sect B2 VPDCTR B1 B2 EXDU_BB bay n sect B2 AND DCOPTR B1 B2 EXDU_BB bay 1 sect B2 EXDU_DC B1 B2 AND AND ANSI04000509 V1 EN US Figure 174 Signal...

Page 399: ...of the bus section are open en04000511_ansi vsd Section 1 Section 2 A1A2_DC BS B1B2_DC BS BB_ES BB_ES DB_BUS WA1 A1 WA2 B1 B2 A2 DB_BUS ANSI04000511 V1 EN US Figure 176 Busbars divided by bus section disconnectors circuit breakers To derive the signals Signal BB_DC_OP All disconnectors of this part of the busbar are open VP_BB_DC The switch status of all disconnectors on this part of the busbar ar...

Page 400: ...ation described in section Signals in single breaker arrangement 12 4 7 4 Signals in breaker and a half arrangement M15053 123 v4 The busbar grounding switch is only allowed to operate if all disconnectors of the bus section are open en04000512_ansi vsd Section 1 Section 2 A1A2_DC BS B1B2_DC BS BB_ES BB_ES BH_LINE WA1 A1 WA2 B1 B2 A2 BH_LINE ANSI04000512 V1 EN US Figure 177 Busbars divided by bus ...

Page 401: ...ouble circuit breaker bay are defined DB_BUS_A 3 handles the circuit breaker QA1 that is connected to busbar WA1 and the disconnectors and grounding switches of this section DB_BUS_B 3 handles the circuit breaker QA2 that is connected to busbar WA2 and the disconnectors and grounding switches of this section M13584 4 v4 For a double circuit breaker bay the modules DB_BUS_A DB_LINE and DB_BUS_B mus...

Page 402: ... then set the corresponding inputs as follows VOLT_OFF 1 VOLT_ON 0 12 4 9 Interlocking for breaker and a half diameter BH 3 IP14173 1 v3 12 4 9 1 Application M13570 3 v6 The interlocking for breaker and a half diameter BH_CONN 3 BH_LINE_A 3 BH_LINE_B 3 functions are used for lines connected to a breaker and a half diameter according to figure 179 Section 12 1MRK 505 370 UUS A Control 396 Busbar pr...

Page 403: ...H_CONN 3 is the connection between the two lines of the diameter in the breaker and a half switchyard layout M13569 4 v4 For a breaker and a half arrangement the modules BH_LINE_A BH_CONN and BH_LINE_B must be used 12 4 9 2 Configuration setting M13569 6 v5 For application without 989 and 989G just set the appropriate inputs to open state and disregard the outputs In the functional block diagram 0...

Page 404: ...lity similar with the one provided by a hardware multi position selector switch Hardware selector switches are used extensively by utilities in order to have different functions operating on pre set values Hardware switches are however sources for maintenance issues lower system reliability and extended purchase portfolio The virtual selector switches eliminate all these problems SLGAPC function b...

Page 405: ...WN activation signal positive front and the output activation StopAtExtremes Sets the behavior of the switch at the end positions if set to Disabled when pressing UP while on first position the switch will jump to the last position when pressing DOWN at the last position the switch will jump to the first position when set to Enabled no jump will be allowed 12 6 Selector mini switch VSGAPC SEMOD158...

Page 406: ... PSTO CMDPOS12 IPOS1 NAM_POS1 NAM_POS2 IPOS2 CMDPOS21 Disabled Enabled VSGAPC SMBRREC_79 ON OFF SETON INTONE INV OUT INPUT ANSI07000112 V3 EN US Figure 180 Control of Autorecloser from local HMI through Selector mini switch VSGAPC is also provided with IEC 61850 communication so it can be controlled from SA system as well 12 6 3 Setting guidelines SEMOD158807 4 v4 Selector mini switch VSGAPC funct...

Page 407: ...mbined double point position indication output POSITION by evaluating the value and the timestamp attributes of the inputs OPEN and CLOSE together with the logical input signal VALID When the input signal VALID is active the values of the OPEN and CLOSE inputs determine the two bit integer value of the output POSITION The timestamp of the output POSITION will have the latest updated timestamp of t...

Page 408: ...e sent directly to the IED outputs without confirmation Confirmation status of the result of the commands is supposed to be achieved by other means such as binary inputs and SPGAPC function blocks PSTO is the universal operator place selector for all control functions Even if PSTO can be configured to allow LOCAL or ALL operator positions the only functional position usable with the SPC8GAPC funct...

Page 409: ...dividual outputs which each can be mapped as a Binary Output point in DNP3 The output is operated by a Object 12 in DNP3 This object contains parameters for control code count on time and off time To operate an AUTOBITS output point send a control code of latch On latch Off pulse On pulse Off Trip or Close The remaining parameters are regarded as appropriate For example pulse On on time 100 off ti...

Page 410: ... via binary outputs Figure 181 shows an application example of how the user can connect SINGLECMD via configuration logic circuit to control a high voltage apparatus This type of command control is normally carried out by sending a pulse to the binary outputs of the IED Figure 181 shows a close operation An open breaker operation is performed in a similar way but without the synchro check conditio...

Page 411: ...e 1 User defined conditions Configuration logic circuits en04000208_ansi vsd AND ANSI04000208 V2 EN US Figure 183 Application example showing a logic diagram for control of external devices via configuration logic circuits 12 10 3 Setting guidelines M12448 3 v2 The parameters for Single command 16 signals SINGLECMD are set via the local HMI or PCM600 1MRK 505 370 UUS A Section 12 Control Busbar pr...

Page 412: ... the operator station or remote control gateway Steady sets the outputs to a steady signal 0 or 1 depending on the values sent from the station level Pulse gives a pulse with 100 ms duration if a value sent from the station level is changed from 0 to 1 That means the configured logic connected to the command function block may not have a cycle time longer than the cycle time for the command functi...

Page 413: ...Time Defines the pulse time when in Pulsed mode When used for direct tripping of circuit breaker s the pulse time delay shall be set to approximately 0 150 seconds in order to obtain satisfactory minimum duration of the trip pulse to the circuit breaker trip coils OnDelay Used to prevent output signals to be given for spurious inputs Normally set to 0 or a low value OffDelay Defines a delay of the...

Page 414: ...ific application needs 13 2 3 Setting guidelines GUID 0BDD898A 360B 4443 A5CF 7619C80A17F4 v2 Operation Enabled or Disabled 13 3 Logic for group alarm WRNCALH 13 3 1 Identification GUID 3EBD3D5B F506 4557 88D7 DFC0BD21C690 v4 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Logic for group warning WRNCALH 13 3 1 1 Application GUID FC0DBB7B FF86 4...

Page 415: ...ignal to physical outputs according to the specific application needs 13 4 1 2 Setting guidelines GUID 7E776D39 1A42 4F90 BF50 9B38F494A01E v2 Operation Enabled or Disabled 13 5 Configurable logic blocks IP11009 1 v3 The configurable logic blocks are available in two categories Configurable logic blocks that do not propagate the time stamp and the quality of signals They do not have the suffix QT ...

Page 416: ...ths are set from the local HMI or via the PST tool Both timers in the same logic block the one delayed on pick up and the one delayed on drop out always have a common setting value For controllable gates settable timers and SR flip flops with memory the setting parameters are accessible via the local HMI or via the PST tool 13 5 2 1 Configuration GUID D93E383C 1655 46A3 A540 657141F77CF0 v4 Logic ...

Page 417: ...etermined by the order of their serial execution numbers Always remember this when connecting two or more logical function blocks in series Always be careful when connecting function blocks with a fast cycle time to function blocks with a slow cycle time Remember to design the logic circuits carefully and always check the execution sequence for different functions In other cases additional time de...

Page 418: ...l in FXDSIGN The Restricted earth fault function REFPDIF 87N can be used both for auto transformers and normal transformers When used for auto transformers information from both windings parts together with the neutral point current needs to be available to the function This means that three inputs are needed I3PW1CT1 I3PW2CT1 I3P REFPDIF 87N ANSI11000083_1_en vsd ANSI11000083 V1 EN US Figure 186 ...

Page 419: ...a function like distance protection to integer inputs from another function like line differential protection B16I does not have a logical node mapping The Boolean 16 to integer conversion function B16I will transfer a combination of up to 16 binary inputs INx where 1 x 16 to an integer Each INx represents a value according to the table below from 0 to 32768 This follows the general formula INx 2x...

Page 420: ... BOOLEAN 0 Input 6 32 0 IN7 BOOLEAN 0 Input 7 64 0 IN8 BOOLEAN 0 Input 8 128 0 IN9 BOOLEAN 0 Input 9 256 0 IN10 BOOLEAN 0 Input 10 512 0 IN11 BOOLEAN 0 Input 11 1024 0 IN12 BOOLEAN 0 Input 12 2048 0 IN13 BOOLEAN 0 Input 13 4096 0 IN14 BOOLEAN 0 Input 14 8192 0 IN15 BOOLEAN 0 Input 15 16384 0 IN16 BOOLEAN 0 Input 16 32768 0 The sum of the numbers in column Value when activated when all INx where 1 ...

Page 421: ... that are activated OUT is an integer When all INx where 1 x 16 are activated that is Boolean 1 it corresponds to that integer 65535 is available on the output OUT BTIGAPC function is designed for receiving up to 16 booleans input locally If the BLOCK input is activated it will freeze the output at the last value Values of each of the different OUTx from function block BTIGAPC for 1 x 16 The sum o...

Page 422: ... It can be used for example to connect integer output signals from one function to binary logical inputs to another function IB16 function does not have a logical node mapping The Boolean 16 to integer conversion function IB16 will transfer a combination of up to 16 binary inputs INx where 1 x 16 to an integer Each INx represents a value according to the table below from 0 to 32768 This follows th...

Page 423: ...nput 13 4096 0 IN14 BOOLEAN 0 Input 14 8192 0 IN15 BOOLEAN 0 Input 15 16384 0 IN16 BOOLEAN 0 Input 16 32768 0 The sum of the numbers in column Value when activated when all INx where 1 x 16 are active that is 1 is 65535 65535 is the highest boolean value that can be converted to an integer by the IB16 function block 13 10 Integer to Boolean conversion for six zone busbar BCTZCONN GUID CCB3768D 001...

Page 424: ...tion 89 where 0 ZONCONI 127 Note that when a binary output ZONEx or CZ is activated it has the logical value one Otherwise it has the logical value zero The equation above also implies that each individual binary output corresponds actually to one integer which is presented in the input ZONCONI and can be defined by CZ 26 or ZONEx 2x 1 1 x 6 Refer to Table 44 for the description of such representa...

Page 425: ...ation SEMOD158512 5 v7 Integer to boolean 16 conversion with logic node representation function ITBGAPC is used to transform an integer into a set of 16 boolean signals ITBGAPC function can receive an integer from a station computer for example over IEC 61850 8 1 This function is very useful when the user wants to generate logical commands for selector switches or voltage controllers by inputting ...

Page 426: ...put 11 1024 0 OUT12 BOOLEAN Output 12 2048 0 OUT13 BOOLEAN Output 13 4096 0 OUT14 BOOLEAN Output 14 8192 0 OUT15 BOOLEAN Output 15 16384 0 OUT16 BOOLEAN Output 16 32768 0 The sum of the numbers in column Value when activated when all OUTx 1 x 16 are active equals 65535 This is the highest integer that can be converted by the ITBGAPC function block 13 12 Elapsed time integrator with limit transgres...

Page 427: ... values defined A resolution of 10 ms can be achieved when the settings are defined within the range 1 00 second tAlarm 99 999 99 seconds 1 00 second tWarning 99 999 99 seconds If the values are above this range the resolution becomes lower due to the 32 bit float representation 99 999 99 seconds tAlarm 999 999 0 seconds 99 999 99 seconds tWarning 999 999 0 seconds Note that tAlarm and tWarning ar...

Page 428: ... reference values Signed Comparison is performed on signed values of input and reference values RefSource This setting is used to select the reference source between input and setting for comparison Input REF The function will take reference value from input REF Set Value The function will take reference value from setting SetValue SetValue This setting is used to set the reference value for compa...

Page 429: ...A5B v1 The function gives the possibility to monitor the level of real values in the system relative to each other or to a fixed value It is a basic arithmetic function that can be used for monitoring supervision interlocking and other logics 13 14 3 Setting guidelines GUID DE69FF5B 7D34 4A30 9060 214E98BFF798 v2 Setting procedure on the IED EnaAbs This setting is used to select the comparison typ...

Page 430: ...lBandLow This setting is used to set the equal condition low band limit in of reference value This low band limit will act as reset limit for INLOW output when INLOW 13 14 4 Setting example GUID E7070CF6 B44B 4799 BE18 5C75B9FE2A87 v2 Let us consider a comparison is to be done between current magnitudes in the range of 90 to 110 with nominal rating is 100 and the order is kA For the above conditio...

Page 431: ... to be connected to function inputs INPUT and REF Then the settings should be adjusted as below EnaAbs Absolute RefSource Input REF EqualBandHigh 5 0 of reference value EqualBandLow 5 0 of reference value 1MRK 505 370 UUS A Section 13 Logic Busbar protection REB670 2 2 ANSI 425 Application manual ...

Page 432: ...426 ...

Page 433: ...MMXN P Q S I U f SYMBOL RR V1 EN US Phase current measurement CMMXU I SYMBOL SS V1 EN US Phase phase voltage measurement VMMXU U SYMBOL UU V1 EN US Current sequence component measurement CMSQI I1 I2 I0 SYMBOL VV V1 EN US Voltage sequence component measurement VMSQI U1 U2 U0 SYMBOL TT V1 EN US Phase neutral voltage measurement VNMMXU U SYMBOL UU V1 EN US 1MRK 505 370 UUS A Section 14 Monitoring Bus...

Page 434: ...rrent protection function The available measured values from an IED are depending on the actual hardware TRM and the logic configuration made in PCM600 All measured values can be supervised with four settable limits that is low low limit low limit high limit and high high limit A zero clamping reduction is also supported that is the measured value below a settable limit is forced to zero which red...

Page 435: ...ing functions CMSQI and VMSQI provide sequence component quantities I sequence currents positive zero negative sequence magnitude and angle V sequence voltages positive zero and negative sequence magnitude and angle 14 1 3 Zero clamping GUID 8DABC3F5 6615 493C B839 A5C557A2FAE8 v4 Measuring functions CVMMXN CMMXU VMMXU and VNMMXU have no interconnections regarding any settings or parameters Zero c...

Page 436: ... actual hardware TRM and the logic configuration made in PCM600 The parameters for the Measurement functions CVMMXN CMMXU VMMXU CMSQI VMSQI VNMMXU are set via the local HMI or PCM600 GlobalBaseSel Selects the global base value group used by the function to define IBase VBase and SBase as applicable Operation Disabled Enabled Every function instance CVMMXN CMMXU VMMXU CMSQI VMSQI VNMMXU can be take...

Page 437: ... Y is equal to 5 30 or 100 IAngCompY Angle compensation to calibrate angle measurements at Y of In where Y is equal to 5 30 or 100 The following general settings can be set for the Phase phase voltage measurement VMMXU VMagCompY Amplitude compensation to calibrate voltage measurements at Y of Vn where Y is equal to 5 30 or 100 VAngCompY Angle compensation to calibrate angle measurements at Y of Vn...

Page 438: ...nt measurement XHiLim High limit Set as of YBase Y is SBase for S P Q UBase for Voltage measurement and IBase for current measurement XLowLim Low limit Set as of YBase Y is SBase for S P Q UBase for Voltage measurement and IBase for current measurement XLowLowLim Low low limit Set as of YBase Y is SBase for S P Q UBase for Voltage measurement and IBase for current measurement XLimHyst Hysteresis v...

Page 439: ...ples in connection to Measurement function CVMMXN are provided Measurement function CVMMXN application for a OHL Measurement function CVMMXN application on the secondary side of a transformer Measurement function CVMMXN application for a generator For each of them detail explanation and final list of selected setting parameters values will be provided The available measured values of an IED are de...

Page 440: ...wer as indicated in figure 190 it is necessary to do the following 1 Set correctly CT and VT data and phase angle reference channel PhaseAngleRef using PCM600 for analog input channels 2 Connect in PCM600 measurement function to three phase CT and VT inputs 3 Set under General settings parameters for the Measurement function general settings as shown in table 46 level supervision of active power a...

Page 441: ...voltage level to 25 Voltage below 25 will force S P and Q to zero IGenZeroDb Zero point clamping in of Ibase 3 Set minimum current level to 3 Current below 3 will force S P and Q to zero VBase set in Global base Base setting for voltage level in kV 400 00 Set rated OHL phase to phase voltage IBase set in Global base Base setting for current level in A 1000 Set rated primary CT current used for OHL...

Page 442: ...ted value Comments IMagComp5 Magnitude factor to calibrate current at 5 of In 0 00 IMagComp30 Magnitude factor to calibrate current at 30 of In 0 00 IMagComp100 Magnitude factor to calibrate current at 100 of In 0 00 VAmpComp5 Magnitude factor to calibrate voltage at 5 of Vn 0 00 VMagComp30 Magnitude factor to calibrate voltage at 30 of Vn 0 00 VMagComp100 Magnitude factor to calibrate voltage at ...

Page 443: ...ted in figure 191 it is necessary to do the following 1 Set correctly all CT and VT and phase angle reference channel PhaseAngleRef data using PCM600 for analog input channels 2 Connect in PCM600 measurement function to LV side CT VT inputs 3 Set the setting parameters for relevant Measurement function as shown in the following table 49 1MRK 505 370 UUS A Section 14 Monitoring Busbar protection RE...

Page 444: ... and voltage L1L2 Only UL1L2 phase to phase voltage is available k Low pass filter coefficient for power measurement V and I 0 00 Typically no additional filtering is required VGenZeroDb Zero point clamping in of Vbase 25 Set minimum voltage level to 25 IGenZeroDb Zero point clamping in of Ibase 3 Set minimum current level to 3 VBase set in Global base Base setting for voltage level in kV 35 00 Se...

Page 445: ...ted in figure 192 it is necessary to do the following 1 Set correctly all CT and VT data and phase angle reference channel PhaseAngleRef using PCM600 for analog input channels 2 Connect in PCM600 measurement function to the generator CT VT inputs 3 Set the setting parameters for relevant Measurement function as shown in the following table 1MRK 505 370 UUS A Section 14 Monitoring Busbar protection...

Page 446: ...age level in kV 15 65 Set generator rated phase to phase voltage IBase set in Global base Base setting for current level in A 3690 Set generator rated current 14 2 Gas medium supervision SSIMG 63 GUID 358AD8F8 AE06 4AEA 9969 46E5299D5B4B v3 14 2 1 Identification GUID AD96C26E C3E5 4B21 9ED6 12E540954AC3 v4 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 devic...

Page 447: ...r tPressureAlarm This is used to set the time delay for a pressure alarm indication given in s tPressureLO This is used to set the time delay for a pressure lockout indication given in s tTempAlarm This is used to set the time delay for a temperature alarm indication given in s tTempLockOut This is used to set the time delay for a temperature lockout indication given in s tResetPressAlm This is us...

Page 448: ...d on received information 14 3 3 Setting guidelines GUID 0C8E498B 2A65 44ED 91D6 53EC72F49222 v2 The parameters for Liquid medium supervision SSIML can be set via local HMI or Protection and Control Manager PCM600 Operation This is used to disable enable the operation of liquid medium supervision i e Off On LevelAlmLimit This is used to set the limit for a level alarm condition in the transformer ...

Page 449: ...evice number Breaker monitoring SSCBR 14 4 2 Application GUID 45572680 3A39 4B3C 8639 4E4C5A95AA26 v9 The circuit breaker maintenance is usually based on regular time intervals or the number of operations performed This has some disadvantages because there could be a number of abnormal operations or few operations with high level currents within the predetermined maintenance interval Hence conditi...

Page 450: ...eaker Every time the breaker operates the circuit breaker life reduces due to wear The wear in a breaker depends on the interrupted current For breaker maintenance or replacement at the right time the remaining life of the breaker must be estimated The remaining life of a breaker can be estimated using the maintenance curve provided by the circuit breaker manufacturer Circuit breaker manufacturers...

Page 451: ...kA one operation is equivalent to 10000 900 11 operations at the rated current It is assumed that prior to tripping the remaining life of a breaker is 10000 operations Remaining life calculation for three different interrupted current conditions is explained below Breaker interrupts at and below the rated operating current that is 2 kA the remaining life of the CB is decreased by 1 operation and t...

Page 452: ...ycles Routine breaker maintenance like lubricating breaker mechanism is based on the number of operations A suitable threshold setting helps in preventive maintenance This can also be used to indicate the requirement for oil sampling for dielectric testing in case of an oil circuit breaker Circuit breaker operation monitoring By monitoring the activity of the number of operations it is possible to...

Page 453: ...reference of base values Operation Enabled or Disabled IBase Base phase current in primary A This current is used as reference for current settings OpenTimeCorr Correction factor for circuit breaker opening travel time CloseTimeCorr Correction factor for circuit breaker closing travel time tTrOpenAlm Setting of alarm level for opening travel time tTrCloseAlm Setting of alarm level for closing trav...

Page 454: ...hange of status of trip output and start of main contact separation 14 5 Event function EVENT IP14590 1 v2 14 5 1 Identification SEMOD167950 2 v2 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Event function EVENT S00946 V1 EN US 14 5 2 Application M12805 6 v11 When using a Substation Automation system with LON or SPA communication time tagged ...

Page 455: ...have no semantic prefer to be set by the user LONChannelMask or SPAChannelMask M12811 15 v2 Definition of which part of the event function block that shall generate events Disabled Channel 1 8 Channel 9 16 Channel 1 16 MinRepIntVal 1 16 M12811 29 v3 A time interval between cyclic events can be set individually for each input channel This can be set between 0 s to 3600 s in steps of 1 s It should n...

Page 456: ...s a disturbance recording could be a part of Functional Analysis FA Disturbance report DRPRDRE always included in the IED acquires sampled data of all selected analog and binary signals connected to the function blocks that is Maximum 30 external analog signals 10 internal derived analog signals and 352 binary signals Disturbance report function is a common name for several functions Indications I...

Page 457: ...y signals are identical in all functions that is Disturbance recorder DR Event recorder ER Indication IND Trip value recorder TVR and Sequential of events SOE function User defined names of binary and analog input signals is set using PCM600 The analog and binary signals appear with their user defined names The name is used in all related functions Disturbance recorder DR Event recorder ER Indicat...

Page 458: ...umber of settings which also influences the sub functions Three LED indications placed above the LCD screen makes it possible to get quick status information about the IED Green LED Steady light In Service Flashing light Internal failure Dark No power supply Yellow LED Steady light Triggered on binary signal N with SetLEDx Start or Start and Trip Flashing light The IED is in test mode Table contin...

Page 459: ...ed Every recording will get a number 0 to 999 which is used as identifier local HMI disturbance handling tool and IEC 61850 An alternative recording identification is date time and sequence number The sequence number is automatically increased by one for each new recording and is reset to zero at midnight The maximum number of recordings stored in the IED is 100 The oldest recording will be overwr...

Page 460: ... 173 v7 Disturbance report function does not automatically respond to any new trig condition during a recording after all signals set as trigger signals have been reset However under certain circumstances the fault condition may reoccur during the post fault recording for instance by automatic reclosing to a still faulty power line In order to capture the new disturbance it is possible to allow re...

Page 461: ...PCM600 is used to configure the signals For retrieving remote data from LDCM module the Disturbance report function should be connected to a 8 ms SMAI function block if this is the only intended use for the remote data The analog trigger of Disturbance report is not affected if analog input M is to be included in the disturbance recording or not OperationM Enabled Disabled If OperationM Disabled n...

Page 462: ...etting information GUID B0D40F6D 3CE4 4FF3 81B4 B453FDD389CB v1 SetInfoInDrep Parameter used to enable or disable the settings information in disturbance header Event recorder M12179 444 v4 Event recorder ER function has no dedicated parameters Trip value recorder M12179 442 v3 ZeroAngleRef The parameter defines which analog signal that will be used as phase angle reference for all other analog in...

Page 463: ...ls The level triggering should be used with great care since unfortunate settings will cause enormously number of recordings If nevertheless analog input triggering is used chose settings by a sufficient margin from normal operation values Phase voltages are not recommended for trigging There is a risk of flash wear out if the disturbance report triggers too often Remember that values of parameter...

Page 464: ...IEC09000732 1 en vsd IEC09000732 V1 EN US Figure 195 BINSTATREP logical diagram 14 7 3 Setting guidelines GUID BBDA6900 4C1A 4A7C AEA5 3C49C2749254 v2 The pulse time t is the only setting for the Logical signal status report BINSTATREP Each output can be set or reset individually but the pulse time will be the same for all outputs in the entire BINSTATREP function 14 8 Limit counter L4UFCNT GUID 2...

Page 465: ...ling over to zero In this case periodic pulses will be generated at multiple overflow of the function 14 8 3 Setting guidelines GUID 5AECCDBC 7385 4D9F 940C 9D4A0E59B106 v1 GUID DA5DA8D7 4821 4BFB 86CC 28658E376270 v1 The parameters for Limit counter L4UFCNT are set via the local HMI or PCM600 14 9 Running hour meter TEILGAPC 14 9 1 Identification GUID 3F9EF4FA 74FA 4D1D 88A0 E948B722B64F v1 Funct...

Page 466: ...olution of the settings is 0 1 hours 6 minutes tAlarm and tWarning are independent settings that is there is no check if tAlarm tWarning The limit for the overflow supervision is fixed at 99999 9 hours The setting tAddToTime is a user settable time parameter in hours Section 14 1MRK 505 370 UUS A Monitoring 460 Busbar protection REB670 2 2 ANSI Application manual ...

Page 467: ...orted via the station bus to the substation automation system or read via the station monitoring system as a service value When using IEC 61850 8 1 a scaled service value is available over the station bus The normal use for this function is the counting of energy pulses from external energy meters An optional number of inputs from an arbitrary input module in IED can be used for this purpose with ...

Page 468: ...etting also influences the inputs on the same board used for pulse counting 15 2 Function for energy calculation and demand handling ETPMMTR SEMOD153638 1 v2 15 2 1 Identification SEMOD175537 2 v4 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Function for energy calculation and demand handling ETPMMTR W_Varh 15 2 2 Application SEMOD175546 4 v5...

Page 469: ...es are scaled with the pulse output setting values EAFAccPlsQty EARAccPlsQty ERFAccPlsQty and ERVAccPlsQty of the energy metering function and then the pulse counter can be set up to present the correct values by scaling in this function Pulse counter values can then be presented on the local HMI in the same way and or sent to the SA Substation Automation system through communication where the tot...

Page 470: ...RAccPlsQty gives the MWh value in each pulse It should be selected together with the setting of the Pulse counter PCGGIO settings to give the correct total pulse value ERFAccPlsQty and ERVAccPlsQty gives the MVArh value in each pulse It should be selected together with the setting of the Pulse counter PCGGIO settings to give the correct total pulse value For the advanced user there are a number of...

Page 471: ... ports allocated to the front port and access point 1 The settings for the access points are configured using the Ethernet configuration tool ECT in PCM600 The access point is activated if the Operation checkbox is checked for the respective access point and a partial or common write to IED is performed To increase security it is recommended to deactivate the access point when it is not in use Red...

Page 472: ...s see the communication protocol chapters To increase security it is recommended to uncheck protocols that are not used on the access point The default gateway can be selected by entering the IP address in Default gateway The default gateway is the router that is used to communicate with the devices in the other subnetwork By default this is set to 0 0 0 0 which means that no default gateway is se...

Page 473: ...B0D 8C1D 2E02F70B4FCB v1 Dynamic access point diagnostic RCHLCCH is used to supervise and assure redundant Ethernet communication over two channels This will secure data transfer even though one communication channel might not be available for some reason Parallel Redundancy Protocol PRP and High availability Seamless Redundancy HSR provides redundant communication over station bus running the ava...

Page 474: ...tB AP1 PhyPortB PhyPortA AP1 PhyPortA PhyPortB Switch B Device 1 Device 2 Device 3 Device 4 IEC09000758 V4 EN US Figure 197 Parallel Redundancy Protocol PRP Section 16 1MRK 505 370 UUS A Ethernet based communication 468 Busbar protection REB670 2 2 ANSI Application manual ...

Page 475: ...vated when the parameter is set to PRP 0 PRP 1 or HSR The settings for the next access point will be hidden and PhyPortB will show the second port information Redundant communication is activated after a common write to IED is done PRP 1 should be used primarily PRP 0 is intended only for use in existing PRP networks PRP 1 and HSR can be combined in a mixed network If the access point is not taken...

Page 476: ...n as Merging Units MU The rear access points are used for the communication The merging units MU are called so because they can gather analog values from one or more measuring transformers sample the data and send the data over process bus to other clients or subscribers in the system Some merging units are able to get data from classical measuring transformers others from non conventional measuri...

Page 477: ... not in the same subnetwork as the default gateway The route specifies that when a package is sent to the destination device it should be sent through the selected router If no route is specified the source device will not find the destination device 16 4 2 Setting guidelines GUID 2C4A312A 00DC 44C8 B2D9 CD0822E1C806 v1 Routes are configured using the Ethernet configuration tool in PCM600 Operatio...

Page 478: ...specifies the destination Destination subnet mask specifies the subnetwork mask of the destination Section 16 1MRK 505 370 UUS A Ethernet based communication 472 Busbar protection REB670 2 2 ANSI Application manual ...

Page 479: ...etween two or more intelligent electronic devices IEDs from one or several vendors to exchange information and to use it in the performance of their functions and for correct co operation GOOSE Generic Object Oriented Substation Event which is a part of IEC 61850 8 1 standard allows the IEDs to communicate state and control information amongst themselves using a publish subscribe mechanism That is...

Page 480: ... v sd KIOSK 1 IED 1 IED 2 IED 3 IED 1 IED 2 IED 3 IED 1 IED 2 IED 3 IEC09000135 V1 EN US Figure 201 SA system with IEC 61850 8 1 M16925 3 v4 Figure202 shows the GOOSE peer to peer communication Section 17 1MRK 505 370 UUS A Station communication 474 Busbar protection REB670 2 2 ANSI Application manual ...

Page 481: ...ition 2 the Ethernet link selection is done with the Ethernet Configuration Tool ECT in PCM600 17 2 3 Horizontal communication via GOOSE 17 2 3 1 Sending data GUID 9888ECAD 8221 4B31 A443 EB1E3A9022C4 v1 In addition to the data object and data attributes of the logical nodes it is possible to send the outputs of the function blocks using the generic communication blocks The outputs of this functio...

Page 482: ...eric communication function for Measured Value MVGAPC function allows the user to choose a deadband and a zero deadband for the monitored signal Values within the zero deadband are considered as zero The high and low limit settings provides limits for the high high high normal low and low low ranges of the measured value The actual range of the measured value is shown on the range output of MVGAPC...

Page 483: ... operating on a bay In the figure below the GOOSESPRCV is used to receive the status of the bay reservation The validity of the received data is used in additional logic to guarantee that the value has good quality before operation on that bay GOOSESPRCV Block Spout DataValid CommValid Test AND AND Input1 out Input2 Noput Input3 Input4 Input1 out Input2 Noput Input3 Input4 Ext_Res_OK_To_Operate IE...

Page 484: ...the LON bus from the operator s workplace from the control center and also from other IEDs via bay to bay horizontal communication For LON communication an SLM card should be ordered for the IEDs The fibre optic LON bus is implemented using either glass core or plastic core fibre optic cables Table 51 Specification of the fibre optic connectors Glass fibre Plastic fibre Cable connector ST connecto...

Page 485: ... with Classic Monitor application library LIB520 is required The HV Control 670 software module is included in the LIB520 high voltage process package which is a part of the Application Software Library in MicroSCADA applications The HV Control 670 software module is used for control functions in the IEDs The module contains a process picture dialogues and a tool to generate a process database for...

Page 486: ... M14790 3 v5 The IED provides two function blocks enabling several IEDs to send and receive signals via the interbay bus The sending function block MULTICMDSND takes 16 binary inputs LON enables these to be transmitted to the equivalent receiving function block MULTICMDRCV which has 16 binary outputs 17 3 2 3 Setting guidelines SEMOD119915 1 v1 Settings M14789 4 v3 The parameters for the multiple ...

Page 487: ...a PC can be made directly if the PC is located in the substation via a telephone modem through a telephone network with ITU former CCITT characteristics or via a LAN WAN connection glass 1000 m according to optical budget plastic 25 m inside cubicle according to optical budget Functionality SEMOD115767 25 v2 The SPA protocol V2 5 is an ASCII based protocol for serial communication The communicatio...

Page 488: ... to any value between 1 899 as long as the slave number is unique within the used SPA loop BaudRate communication speed can be set between 300 38400 baud BaudRate should be the same for the whole station although different communication speeds in a loop are possible If different communication speeds are used in the same fibre optical loop or RS485 network take this into account when making the com...

Page 489: ...lly in the station using a Personal Computer PC or a Remote Terminal Unit RTU connected to the Communication and processing module the only hardware needed is optical fibres and an opto electrical converter for the PC RTU or a RS 485 connection depending on the used IED communication interface 17 5 1 1 Functionality M17109 38 v3 IEC 60870 5 103 is an unbalanced master slave protocol for coded bit ...

Page 490: ...ly with a Personal Computer PC or a Remote Terminal Unit RTU in the station using the SPA IEC port the only hardware needed is Optical fibres glass plastic Opto electrical converter for the PC RTU PC RTU Commands M17109 62 v4 The commands defined in the IEC 60870 5 103 protocol are represented in dedicated function blocks These blocks have output signals for all available commands according to the...

Page 491: ...parameter for each block Fault location M17109 108 v1 The fault location is expressed in reactive ohms In relation to the line length in reactive ohms it gives the distance to the fault in percent The data is available and reported when the fault locator function is included in the IED Disturbance recordings M17109 111 v9 The transfer functionality is based on the Disturbance recorder function The...

Page 492: ...rotocol 1 The port specific IEC 60870 5 103 protocol parameters are configured under Main menu Configuration Communication Station Communication IEC60870 5 103 config selector SlaveAddress BaudRate RevPolarity optical channel only CycMeasRepTime MasterTimeDomain TimeSyncMode EvalTimeAccuracy EventRepMode CmdMode RepIntermediatePos config selector is OPTICAL103 1 for the optical serial channel on t...

Page 493: ... order they were generated by BSW The most recent value is the latest value delivered All GI data from a single block will come from the same cycle If EventRepMode HiPriSpont spontaneous events will be delivered prior to GI event To prevent old GI data from being delivered after a new spontaneous event the pending GI event is modified to contain the same value as the spontaneous event As a result ...

Page 494: ...nd the information number can be set to any value between 0 and 255 To get INF and FUN for the recorded binary signals there are parameters on the disturbance recorder for each input The user must set these parameters to whatever he connects to the corresponding input Refer to description of Main Function type set on the local HMI Recorded analog channels are sent with ASDU26 and ASDU31 One inform...

Page 495: ... 85 Private range 31 86 Private range 32 87 Private range 33 88 Private range 34 89 Private range 35 90 Private range 36 91 Private range 37 92 Private range 38 93 Private range 39 94 Private range 40 95 Private range 17 5 3 Function and information types M17109 145 v6 Product type IEC103mainFunType value Comment REL 128 Compatible range REC 242 Private range use default RED 192 Compatible range R...

Page 496: ...ause of transmission Info no 11 Local operation Glass or plastic fibre should be used BFOC 2 5 is the recommended interface to use BFOC 2 5 is the same as ST connectors ST connectors are used with the optical power as specified in standard For more information refer to IEC standard IEC 60870 5 103 17 6 DNP3 Communication protocol 17 6 1 Application GUID EF1F0C38 9FF6 4683 8B10 AAA372D42185 v1 For ...

Page 497: ... two IEDs is used in teleprotection schemes and for direct transfer trips In addition to this there are application possibilities for example blocking enabling functionality in the remote substation changing setting group in the remote IED depending on the switching situation in the local substation and so on If equipped with a 64kbit s LDCM module the IED can be configured to send either 192 bina...

Page 498: ...hese currents can be connected to the protection function together with the local three currents In order to forward the logic signals for example inter trip or inter block between IED A and IED C the setting LinkForwarded should be defined In IED B it is set to LDCM313 for Ldcm312 and to LDCM312 for ldcm313 This setup results in a master master master configuration but without the benefit of reve...

Page 499: ...ic G 703 IEC05000527 V2 EN US Figure 210 LDCM with an external optical to galvanic converter and a multiplexer When an external modem G 703 is used the connection between LDCM and the modem is made with a multimode fibre of max 3 km 2 mile length The IEEE ANSI C37 94 protocol is always used between LDCM and the modem 18 1 2 2 Application possibility with one phase REB670 M12844 20 v4 For busbar pr...

Page 500: ... EN US Figure 211 Example how to share binary IO between one phase REB670 IEDs by using LDCM modules As shown in figure 211 it is possible to wire only the status for bays 01 08 to A phase IED After that the information about auxiliary contact status for switchgear objects from these eight bays can be sent via LDCM modules to other two phases In the similar way information from other bays can be o...

Page 501: ...ique address to each LDCM in all current differential IEDs Up to 256 LDCMs can be assigned a unique number For example in a local IED with two LDCMs LDCM for slot 305 set TerminalNo to 1 and RemoteTermNo to 2 LDCM for slot 306 set TerminalNo to 3 and RemoteTermNo to 4 In multiterminal current differential applications with 4 LDCMs in each IED up to 20 unique addresses must be set A unique address ...

Page 502: ...and should not be mistaken for the synchronization of line differential current samples When direct fibre is used one LDCM is set as Master and the other as Slave When a modem and multiplexer is used the IED is always set as Slave because the telecommunication system provides the clock master OptoPower has two settings LowPower is used for fibres 0 1 km 0 6 mile and HighPower for fibres 1 km 0 6 m...

Page 503: ...M transmits the sum of the two CT groups CT DIFF1 transmits CT group 1 minus CT group 2 and CT DIFF2 transmits CT group 2 minus CT group 1 CT GRP1 and CT GRP2 transmit the respective CT groups and setting RedundantChannel determines that the channel is used as a redundant backup channel The redundant channel takes the CT group setting of the main channel RemAinLatency corresponds to LocAinLatency ...

Page 504: ...configured in its own transmit block LinkForwarded is used to configure the LDCM to merge the inter trip and block signals from another LDCM receiver This is used when the analog signals for the LDCM transmitter is connected to the receiver of another LDCM Section 18 1MRK 505 370 UUS A Remote communication 498 Busbar protection REB670 2 2 ANSI Application manual ...

Page 505: ...ction and control IEDs have many functions included The included self supervision with internal event list function block provides good supervision of the IED The fault signals make it easier to analyze and locate a fault Both hardware and software supervision is included and it is also possible to indicate possible faults through a hardware contact on the power supply module and or through the co...

Page 506: ... and by using the Event Monitoring Tool The PC can either be connected to the front port or to the port at the back of the IED 19 3 Change lock CHNGLCK GUID B48775D0 ACF0 49C6 A7F6 69AF37F1C68F v1 19 3 1 Application GUID 51EEC9C7 8ECF 4546 BC26 326861654340 v4 Change lock function CHNGLCK is used to block further changes to the IED configuration once the commissioning is complete The purpose is to...

Page 507: ...LCK input If such a situation would occur in spite of these precautions then please contact the local ABB representative for remedial action 19 4 Denial of service SCHLCCH RCHLCCH 19 4 1 Application GUID 64F4D905 9F73 4073 B8F6 8D373155316A v5 The denial of service functionality is designed to limit the CPU load that can be produced by Ethernet network traffic on the IED The communication faciliti...

Page 508: ...ports channel A and B redundant communication LinkStatus indicates the Ethernet link status for the front port 19 4 2 Setting guidelines GUID CE3344E8 539B 47E0 9C19 8239988BDBCF v2 The function does not have any parameters available in the local HMI or PCM600 Section 19 1MRK 505 370 UUS A Security 502 Busbar protection REB670 2 2 ANSI Application manual ...

Page 509: ...20 2 1 Application GUID D78786E6 C34A 4E63 9D1E 0582C8F1F7E1 v8 Product information contains unchangeable data that uniquely identifies the IED Product information data is visible on the local HMI under Main menu Diagnostics IED status Product identifiers and under Main menu Diagnostics IED Status Identifiers ProductVer ProductDef FirmwareVer SerialNo OrderingNo ProductionDate IEDProdType This inf...

Page 510: ...tatus Product identifiers Firmware version numbers run independently from the release production numbers For every release number there can be one or more firmware versions depending on the small issues corrected in between releases ProductVer Describes the product version Example 2 1 0 1 is the Major version of the manufactured product this means new platform of the product 2 is the Minor version...

Page 511: ...ettable parameters for the measured value expander block function 20 4 Parameter setting groups IP1745 1 v1 20 4 1 Application M12007 6 v9 Six sets of settings are available to optimize IED operation for different power system conditions By creating and switching between fine tuned setting sets either from the local HMI or configurable binary inputs results in a highly adaptable IED that can cope ...

Page 512: ...the parameter t The parameter MAXSETGR defines the maximum number of setting groups in use to switch between Only the selected number of setting groups will be available in the Parameter Setting tool PST for activation with the ActiveGroup function block 20 5 Rated system frequency PRIMVAL IP15064 1 v2 20 5 1 Identification GUID B8B3535D 227B 4151 9E98 BEB85F4D54DE v1 Function description IEC 6185...

Page 513: ...TReference The reference DFT block InternalDFT Ref DFTRefGrp1 or External DFT ref FreqMeasMinVal The minimum value of the voltage for which the frequency is calculated expressed as percent of VBasebase voltage setting for each instance x GlobalBaseSel Selects the global base value group used by the function to define IBase VBase and SBase 20 7 Global base values GBASVAL GUID 2FDB0A2C 10FE 4954 B6E...

Page 514: ... a base value for applicable functions throughout the IED SBase Standard apparent power value to be used as a base value for applicable functions throughout the IED typically SBase 3 VBase IBase 20 8 Signal matrix for binary inputs SMBI SEMOD55793 1 v2 20 8 1 Application M15310 3 v2 The Signal matrix for binary inputs function SMBI is used within the Application Configuration tool in direct relati...

Page 515: ...ll define SMBO function in the Signal Matrix tool 20 10 Signal matrix for mA inputs SMMI SEMOD55233 1 v2 20 10 1 Application SEMOD55237 5 v2 The Signal matrix for mA inputs function SMMI is used within the Application Configuration tool in direct relation with the Signal Matrix tool SMMI represents the way milliamp mA inputs are brought in for one IED configuration 20 10 2 Setting guidelines SEMOD...

Page 516: ...operation due to non valid frequency values MinValFreqMeas is set as of VBase 3 If SMAI setting ConnectionType is Ph Ph at least two of the inputs GRPx_A GRPx_B and GRPx_C where 1 x 12 must be connected in order to calculate the positive sequence voltage Note that phase to phase inputs shall always be connected as follows A B to GRPxA B C to GRPxB C A to GRPxC If SMAI setting ConnectionType is Ph ...

Page 517: ...nd one neutral value either voltage or current SMAI outputs give information about every aspect of the 3ph analog signals acquired phase angle RMS value frequency and frequency derivates and so on 244 values in total Besides the block group name the analog inputs type voltage or current and the analog input names that can be set directly in ACT Application functions should be connected to a SMAI b...

Page 518: ...RefExtOut and DFTReference shall be set to default value InternalDFTRef if no VT inputs are available Even if the user sets the AnalogInputType of a SMAI block to Current the MinValFreqMeas is still visible However using the current channel values as base for frequency measurement is not recommendable for a number of reasons not last among them being the low level of currents that one can have in ...

Page 519: ...11 35 11 SMAI12 36 12 Task time group 3 AdDFTRefCh7 AdDFTRefCh4 IEC07000197 V2 EN US Figure 213 Twelve SMAI instances are grouped within one task time SMAI blocks are available in three different task times in the IED Two pointed instances are used in the following examples The examples shows a situation with adaptive frequency tracking with one reference selected for all instances In practice eac...

Page 520: ...ce i e frequency tracking master must be a voltage type Observe that positive sequence voltage is used for the frequency tracking feature For task time group 1 this gives the following settings see Figure 213 for numbering SMAI1 1 DFTRefExtOut DFTRefGrp7 to route SMAI7 7 reference to the SPFCOUT output DFTReference DFTRefGrp7 for SMAI1 1 to use SMAI7 7 as reference see Figure 214 SMAI2 2 SMAI12 12...

Page 521: ...be a voltage type Observe that positive sequence voltage is used for the frequency tracking feature For task time group 1 this gives the following settings see Figure 213 for numbering SMAI1 1 SMAI12 12 DFTReference ExternalDFTRef to use DFTSPFC input as reference SMAI4 16 For task time group 2 this gives the following settings SMAI1 13 DFTRefExtOut DFTRefGrp4 to route SMAI4 16 reference to the SP...

Page 522: ...n 1 and Edition 2 To be able to set the IEC 61850 Mod the parameter remotely the PST setting RemoteModControl may not be set to Off The possible values are Off Maintenance or All levels The Off value denies all access to data object Mod from remote Maintenance requires that the category of the originator orCat is Maintenance and All levels allow any orCat The mod of the Root LD LNN0 can be configu...

Page 523: ...utputs on LNs related to primary equipment are blocked If there is an XCBR the outputs EXC_Open and EXC_Close are blocked When the Beh of a component is set to Blocked all control commands with a test bit are accepted Outputs to the process via a non IEC 61850 link data are blocked by the LN In addition the components can be blocked when their Beh is blocked This can be done if the component has a...

Page 524: ...IED the internal time can be synchronized from the following sources BIN Binary Minute Pulse DNP GPS IEC103 SNTP IRIG B SPA LON PPS IEEE 1588 PTP For IEDs using IEC UCA 61850 9 2LE in mixed mode a time synchronization from an external clock is recommended to the IED and all connected merging units The time synchronization from the clock to the IED can be PTP optical PPS or IRIG B For IEDs using IE...

Page 525: ... using for instance a GPS receiver If PTP is enabled on the IEDs and the switches that connect the station are compatible with IEEE 1588 the station will become synchronized to one common time with an accuracy of under 1us Using an IED as a boundary clock between several networks will keep 1us accuracy on three levels or when using an HSR 15 IEDs can be connected in a ring without losing a single ...

Page 526: ...n input to be used for minute pulse synchronization is called BININPUT For a description of the BININPUT settings see the Technical Manual The system time can be set manually either via the local HMI or via any of the communication ports The time synchronization fine tunes the clock seconds and milliseconds The parameter SyncMaster defines if the IED is a master or not a master for time synchroniz...

Page 527: ... Slave only the IED is connected to the PTP group and will synchronize to the grandmaster but cannot function as the grandmaster A PTP group is set up by connecting the IEDs to a network and enabling PTP To set one IED as the grandmaster change Priority2 to 127 instead of the default 128 IEC16000089 1 en vsdx IEC16000089 V1 EN US Figure 216 Enabling PTP in ECT The PTP VLAN tag must have the same v...

Page 528: ...he SAM600 The REL contains a GTM card which has a PPS output that is used to synchronize merging units that are not PTP compliant As a side effect the GTM contains a GPS receiver and the REL acts as a backup of the GPS on the station bus On all access points the PTP parameter is ON On the REL the parameter FineSyncSource under Configuration Time Synchronization TIMESYNCHGEN 1 General is set to GPS...

Page 529: ... according to many different classes and standards In principle there are three different types of protection CTs These types are related to the design of the iron core and the presence of airgaps Airgaps affects the properties of the remanent flux The following three different types of protection CTs have been specified The High Remanence type with closed iron core and no specified limit of the r...

Page 530: ... CT with closed iron core for example protection classes TPX P PX according to IEC class C K according to ANSI IEEE and with an iron core material new material typically new alloy based magnetic materials that gives a remanent flux higher than 80 of the saturation flux The High Remanence HR type is a CT with closed iron core for example protection classes TPX P PX according to IEC class C K accord...

Page 531: ...lasses The rated equivalent limiting secondary e m f Eal according to the IEC 61869 2 standard is used to specify the CT requirements for the IED The requirements are also specified according to other standards 21 1 2 Conditions M11610 3 v1 M11610 4 v4 The requirements are a result of investigations performed in our network simulator The current transformer models are representative for current tr...

Page 532: ...quirements are based on the maximum fault current for faults in different positions Maximum fault current will occur for three phase faults or single phase to ground faults The current for a single phase to ground fault will exceed the current for a three phase fault when the zero sequence impedance in the total fault loop is less than the positive sequence impedance When calculating the current t...

Page 533: ...bility to use a very sensitive setting of a sensitive residual overcurrent protection If a very sensitive setting of this function will be used it is recommended that the current transformer should have an accuracy class which have an current error at rated primary current that is less than 1 for example 5P If current transformers with less accuracy are used it is advisable to check the actual unw...

Page 534: ...CT current A In The nominal current of the protection IED A Rct The secondary resistance of the CT W RL The resistance of the secondary wire and additional load W The loop resistance containing the phase and neutral wires must be used for faults in solidly grounded systems The resistance of a single secondary wire should be used for faults in high impedance grounded systems SR The burden of an IED...

Page 535: ...ance of the CT W RL The resistance of the secondary cable and additional load W The loop resistance containing the phase and neutral wires must be used for faults in solidly grounded systems The resistance of a single secondary wire should be used for faults in high impedance grounded systems SR The burden of an IED current input channel VA SR 0 020 VA channel for Ir 1 A and SR 0 150 VA channel fo...

Page 536: ...yed phase and residual overcurrent protection M11339 3 v5 The requirement according to Equation 95 and Equation 96 does not need to be fulfilled if the high set instantaneous or definitive time stage is used In this case Equation is the only necessary requirement If the inverse time delayed function is the only used overcurrent protection function the CTs must have a rated equivalent limiting seco...

Page 537: ...agnetic core CTs are possible to use with the IEDs if they fulfill the requirements corresponding to the above specified expressed as the rated equivalent limiting secondary e m f Eal according to the IEC 61869 2 standard From different standards and available data for relaying applications it is possible to approximately calculate a secondary e m f of the CT comparable with Eal By comparing this ...

Page 538: ... according to ANSI IEEE M11623 22 v6 Current transformers according to ANSI IEEE are partly specified in different ways A rated secondary terminal voltage VANSI is specified for a CT of class C VANSI is the secondary terminal voltage the CT will deliver to a standard burden at 20 times rated secondary current without exceeding 10 ratio correction There are a number of standardized VANSI values for...

Page 539: ...on the quality of the measured input signal Transients caused by capacitive Coupled voltage transformers CCVTs can affect some protection functions Magnetic or capacitive voltage transformers can be used The capacitive voltage transformers CCVTs should fulfill the requirements according to the IEC 61869 5 standard regarding ferro resonance and transients The ferro resonance requirements of the CCV...

Page 540: ...3802 42FE 8970 4662798C19D1 v2 The communication requirements are based on echo timing Bit Error Rate BER according to ITU T G 821 G 826 and G 828 10 6 according to the standard for data and voice transfer Bit Error Rate BER for high availability of the differential protection 10 8 10 9 during normal operation 10 6 during disturbed operation During disturbed conditions the trip security function c...

Page 541: ...lock deviation 50 ppm nominal 100 ppm operational Jitter and Wander according to ITU T G 823 and G 825 Buffer memory 100 μs Format Transparent Maximum channel delay Loop time 40 ms continuous 2 x 20 ms IED with echo synchronization of differential clock without GPS clock Both channels must have the same route with maximum asymmetry of 0 2 0 5 ms depending on set sensitivity of the differential pro...

Page 542: ...536 ...

Page 543: ...on service data unit AWG American Wire Gauge standard BBP Busbar protection BFOC 2 5 Bayonet fibre optic connector BFP Breaker failure protection BI Binary input BIM Binary input module BOM Binary output module BOS Binary outputs status BR External bistable relay BS British Standards BSR Binary signal transfer function receiver blocks BST Binary signal transfer function transmit blocks C37 94 IEEE...

Page 544: ...COMTRADE Standard Common Format for Transient Data Exchange format for Disturbance recorder according to IEEE ANSI C37 111 1999 IEC 60255 24 Contra directional Way of transmitting G 703 over a balanced line Involves four twisted pairs two of which are used for transmitting data in both directions and two for transmitting clock signals COT Cause of transmission CPU Central processing unit CR Carrie...

Page 545: ...ltage network EIA Electronic Industries Association EMC Electromagnetic compatibility EMF Electromotive force EMI Electromagnetic interference EnFP End fault protection EPA Enhanced performance architecture ESD Electrostatic discharge F SMA Type of optical fibre connector FAN Fault number FCB Flow control bit Frame count bit FOX 20 Modular 20 channel telecommunication system for speech data and pr...

Page 546: ...Human machine interface HSAR High speed autoreclosing HSR High availability Seamless Redundancy HV High voltage HVDC High voltage direct current IDBS Integrating deadband supervision IEC International Electrical Committee IEC 60044 6 IEC Standard Instrument transformers Part 6 Requirements for protective current transformers for transient performance IEC 60870 5 103 Communication standard for prot...

Page 547: ...sentative of a type In the same way an instance of a function in the IED is representative of a type of function IP 1 Internet protocol The network layer for the TCP IP protocol suite widely used on Ethernet networks IP is a connectionless best effort packet switching protocol It provides packet routing fragmentation and reassembly through the data link layer 2 Ingression protection according to I...

Page 548: ...vercurrent protection OEM Optical Ethernet module OLTC On load tap changer OTEV Disturbance data recording initiated by other event than start pick up OV Overvoltage Overreach A term used to describe how the relay behaves during a fault condition For example a distance relay is overreaching when the impedance presented to it is smaller than the apparent impedance to the fault applied to the balanc...

Page 549: ...ion set computer RMS value Root mean square value RS422 A balanced serial interface for the transmission of digital data in point to point connections RS485 Serial link according to EIA standard RS485 RTC Real time clock RTU Remote terminal unit SA Substation Automation SBO Select before operate SC Switch or push button to close SCL Short circuit location SCS Station control system SCADA Supervisi...

Page 550: ...uit supervision TCP Transmission control protocol The most common transport layer protocol used on Ethernet and the Internet TCP IP Transmission control protocol over Internet Protocol The de facto standard Ethernet protocols incorporated into 4 2BSD Unix TCP IP was developed by DARPA for Internet working and encompasses both network layer and transport layer protocols While TCP and IP specify two...

Page 551: ...ic Time TAI by the addition of a whole number of leap seconds to synchronize it with Universal Time 1 UT1 thus allowing for the eccentricity of the Earth s orbit the rotational axis tilt 23 5 degrees but still showing the Earth s irregular rotation on which UT1 is based The Coordinated Universal Time is expressed using a 24 hour clock and uses the Gregorian calendar It is used for aeroplane and sh...

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Page 554: ... AB Grid Automation Products 721 59 Västerås Sweden Phone 46 0 21 32 50 00 abb com protection control Copyright 2017 ABB All rights reserved Specifications subject to change without notice 1MRK 505 370 UUS ...

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