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14.3.1.1

Bay control QCBAY

M16595-3 v9

The Bay control (QCBAY) is used to handle the selection of the operator place per bay.
The function gives permission to operate from two main types of locations either from
Remote (for example, control centre or station HMI) or from Local (local HMI on the
IED) or from all (Local and Remote). The Local/Remote switch position can also be
set to Off, which means no operator place selected that is, operation is not 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 alternatives:

•

Blocking of update of positions

•

Blocking of commands

IEC13000016-2-en.vsd

IEC13000016 V2 EN-US

Figure 123:

APC - Local remote function block

Section 14

1MRK 511 401-UUS A

Control

356

Bay control REC670 2.2 ANSI

Application manual

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Summary of Contents for Relion REC670

Page 1: ...RELION 670 SERIES Bay control REC670 Version 2 2 ANSI Application manual ...

Page 2: ......

Page 3: ...Document ID 1MRK 511 401 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: ...up protection functions 39 Control and monitoring functions 40 Communication 48 Basic IED functions 51 Section 3 Configuration 53 Description of configuration REC670 53 Introduction 53 Description of configuration A30 53 Description of configuration B30 55 Description of configuration C30 57 Description of configuration D30 59 Section 4 Analog inputs 61 Introduction 61 Setting guidelines 61 Settin...

Page 8: ...o connect a phase to phase connected VT to the IED 82 Example on how to connect an open delta VT to the IED for high impedance grounded or ungrounded networks 84 Example how to connect the open delta VT to the IED for low impedance grounded or solidly grounded power systems 87 Section 5 Local HMI 91 Display 92 LEDs 95 Keypad 96 Local HMI functionality 98 Protection and alarm indication 98 Paramete...

Page 9: ... for 1Ph High impedance differential protection HZPDIF 87 136 Setting guidelines 137 Configuration 138 Settings of protection function 138 T feeder protection 138 Tertiary reactor protection 142 Alarm level operation 145 Section 8 Current protection 147 Instantaneous phase overcurrent protection PHPIOC 50 147 Identification 147 Application 147 Setting guidelines 148 Meshed network without parallel...

Page 10: ...ting guidelines 186 Settings for each step 186 Common settings for all steps 189 Sensitive directional residual overcurrent and power protection SDEPSDE 67N 190 Identification 191 Application 191 Setting guidelines 193 Thermal overload protection one time constant Fahrenheit Celsius LFPTTR LCPTTR 26 202 Identification 202 Thermal overload protection two time constants TRPTTR 49 202 Identification ...

Page 11: ...ction 230 Setting guidelines 232 Restrike detection 234 Voltage restrained time overcurrent protection VRPVOC 51V 235 Identification 235 Application 235 Base quantities 236 Application possibilities 236 Undervoltage seal in 237 Setting guidelines 237 Explanation of the setting parameters 237 Voltage restrained overcurrent protection for generator and step up transformer 239 Overcurrent protection ...

Page 12: ...ltage protection ROV2PTOV 59N 249 Identification 249 Application 249 Setting guidelines 250 Equipment protection such as for motors generators reactors and transformersEquipment protection for transformers 250 Equipment protection capacitors 250 Power supply quality 251 High impedance grounded systems 251 Direct grounded system 252 Settings for two step residual overvoltage protection 252 Voltage ...

Page 13: ...APC function 273 Application possibilities 273 Inadvertent generator energization 274 Setting guidelines 275 Directional negative sequence overcurrent protection 275 Negative sequence overcurrent protection 277 Generator stator overload protection in accordance with IEC or ANSI standards 280 Open phase protection for transformer lines or generators and circuit breaker head flashover protection for...

Page 14: ...99 Application 299 Setting guidelines 300 Section 14 Control 303 Synchronism check energizing check and synchronizing SESRSYN 25 303 Identification 303 Application 303 Synchronizing 303 Synchronism check 305 Energizing check 307 Voltage selection 308 External fuse failure 309 Application examples 310 Single circuit breaker with single busbar 311 Single circuit breaker with double busbar external v...

Page 15: ...ode 1 2ph 1 3ph 1 phase 2 phase or 3 phase reclosing in the first shot 331 ARMode 1ph 1 2 3ph 1 phase 2 phase or 3 phase reclosing in the first shot 331 External selection of auto reclosing mode 332 Auto reclosing reset timer 333 Pulsing of the circuit breaker closing command and counter 333 Transient fault 333 Permanent fault and reclosing unsuccessful signal 333 Lock out initiation 334 Evolving ...

Page 16: ...378 Signals from all feeders 378 Signals from bus coupler 381 Configuration setting 382 Interlocking for transformer bay AB_TRAFO 3 383 Application 383 Signals from bus coupler 384 Configuration setting 385 Interlocking for bus section breaker A1A2_BS 3 386 Application 386 Signals from all feeders 386 Configuration setting 389 Interlocking for bus section disconnector A1A2_DC 3 390 Application 390...

Page 17: ...esentation SLGAPC 455 Identification 455 Application 455 Setting guidelines 455 Selector mini switch VSGAPC 456 Identification 456 Application 456 Setting guidelines 457 Generic communication function for Double Point indication DPGAPC 457 Identification 457 Application 457 Setting guidelines 458 Single point generic control 8 signals SPC8GAPC 458 Identification 459 Application 459 Setting guideli...

Page 18: ...otection 3 phase ZCRWPSCH 85 474 Identification 474 Application 474 Current reversal logic 474 Weak end infeed logic 475 Setting guidelines 476 Current reversal logic 476 Weak end infeed logic 477 Local acceleration logic ZCLCPSCH 477 Identification 477 Application 477 Setting guidelines 478 Scheme communication logic for residual overcurrent protection ECPSCH 85 479 Identification 479 Application...

Page 19: ...lication 492 Setting guidelines 492 Logic for group alarm ALMCALH 492 Identification 492 Application 493 Setting guidelines 493 Logic for group alarm WRNCALH 493 Identification 493 Application 493 Setting guidelines 493 Logic for group indication INDCALH 493 Identification 493 Application 494 Setting guidelines 494 Configurable logic blocks 494 Application 494 Setting guidelines 494 Configuration ...

Page 20: ...ication 503 Setting guidelines 503 Comparator for integer inputs INTCOMP 504 Identification 504 Application 504 Setting guidelines 504 Setting example 505 Comparator for real inputs REALCOMP 506 Identification 506 Application 506 Setting guidelines 506 Setting example 507 Section 17 Monitoring 509 Measurement 509 Identification 509 Application 510 Zero clamping 511 Setting guidelines 512 Setting e...

Page 21: ... function parameters 538 Consideration 538 Logical signal status report BINSTATREP 539 Identification 539 Application 540 Setting guidelines 540 Fault locator LMBRFLO 540 Identification 540 Application 540 Setting guidelines 541 Connection of analog currents 542 Limit counter L4UFCNT 543 Identification 543 Application 544 Setting guidelines 544 Running hour meter TEILGAPC 544 Identification 544 Ap...

Page 22: ... 569 Application 569 Setting guidelines 569 Redundant communication 571 Identification 571 Application 571 Setting guidelines 573 Merging unit 574 Application 574 Setting guidelines 575 Routes 575 Application 575 Setting guidelines 575 Section 20 Station communication 577 Communication protocols 577 IEC 61850 8 1 communication protocol 577 Application IEC 61850 8 1 577 Setting guidelines 579 Horiz...

Page 23: ...ication 595 Binary signal transfer 595 Identification 595 Application 595 Communication hardware solutions 596 Setting guidelines 597 Section 22 Security 603 Authority status ATHSTAT 603 Application 603 Self supervision with internal event list INTERRSIG 603 Application 603 Change lock CHNGLCK 604 Application 604 Denial of service SCHLCCH RCHLCCH 605 Application 605 Setting guidelines 606 Section ...

Page 24: ...Signal matrix for binary inputs SMBI 612 Application 612 Setting guidelines 612 Signal matrix for binary outputs SMBO 613 Application 613 Setting guidelines 613 Signal matrix for mA inputs SMMI 613 Application 613 Setting guidelines 613 Signal matrix for analog inputs SMAI 613 Application 614 Frequency values 614 Setting guidelines 615 Test mode functionality TESTMODE 620 Application 620 IEC 61850...

Page 25: ...ent protection 633 Directional phase and residual overcurrent protection 634 Current transformer requirements for CTs according to other standards 635 Current transformers according to IEC 61869 2 class P PR 635 Current transformers according to IEC 61869 2 class PX PXR and old IEC 60044 6 class TPS and old British Standard class X 635 Current transformers according to ANSI IEEE 636 Voltage transf...

Page 26: ...20 ...

Page 27: ...so 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 communicat...

Page 28: ...tains 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...

Page 29: ...d The 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 com...

Page 30: ...l manual 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 el...

Page 31: ...g to 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 ...

Page 32: ...ue 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 7DBAB3A33A...

Page 33: ...TRC_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 BICPT...

Page 34: ...SPTRC 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 BUTPTR...

Page 35: ...DIF 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 GF...

Page 36: ...C EFPIOC 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 INDC...

Page 37: ...PTOC 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 ...

Page 38: ...RC 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 S...

Page 39: ...PGAPC 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 TEIL...

Page 40: ...GIO 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 PSF...

Page 41: ...MMAPDIS ZMMAPDIS ZMMPDIS ZMMPDIS ZMMPDIS ZMQAPDIS ZMQAPDIS ZMQAPDIS ZMQPDIS ZMQPDIS ZMQPDIS ZMRAPDIS ZMRAPDIS ZMRAPDIS ZMRPDIS ZMRPDIS ZMRPDIS ZMRPSB ZMRPSB ZMRPSB ZSMGAPC ZSMGAPC ZSMGAPC 1MRK 511 401 UUS A Section 1 Introduction Bay control REC670 2 2 ANSI 35 Application manual ...

Page 42: ...36 ...

Page 43: ...arrangements there are different pre configurations for control and interlocking One control IED can be used for single bay or multi bay applications The control operation is based on the select before execute principle to give highest possible security There are synchrocheck functions available to assist optimal breaker closing at the right instance in synchronous as well as asynchronous networks...

Page 44: ...es 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 Flexible Product Naming allows the...

Page 45: ...se sequence overcurrent protection 0 6 SDEPSDE 67N Sensitive directional residual overcurrent and power protection 0 6 LCPTTR 26 Thermal overload protection one time constant Celsius 0 6 LFPTTR 26 Thermal overload protection one time constant Fahrenheit 0 6 TRPTTR 49 Thermal overload protection two time constants 0 6 CCRBRF 50BF Breaker failure protection 0 6 STBPTOC 50STB Stub protection 0 6 CCPD...

Page 46: ...s voltage 2 67N requires voltage 2 4 Control and monitoring functions GUID E3777F16 0B76 4157 A3BF 0B6B978863DE v15 IEC 61850 or function name ANSI Function description Bay control REC670 Customized Control SESRSYN 25 Synchrocheck energizing check and synchronizing 0 6 SMBRREC 79 Autorecloser 0 6 APC10 3 Control functionality for a single bay max 10 objects 1CB including interlocking see Table 4 0...

Page 47: ...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 for IEC 60870 5 103 50 I103IEDCMD IED commands for IEC 60870 5 103 1 I103USRCMD Function commands user defined for IEC 60870 5 ...

Page 48: ...lock 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 ITBGAPC Integer to Boolean 16 conversion with Logic Node representation 16 TEIGAPC Elapsed time integrator with limit transgression and overflow supervision 12 INTCOMP Comparator for integer inputs 30 REALCOMP Comparator for r...

Page 49: ...A2_DC 3 ABC_BC 1 BH_CONN 1 BH_LINE_A 1 BH_LINE_B 1 DB_BUS_A 1 DB_BUS_B 1 DB_LINE 1 ABC_LINE 1 AB_TRAFO 1 SCSWI Switch controller 10 SXSWI Circuit switch 9 QCRSV Apparatus control 2 RESIN1 1 RESIN2 59 POS_EVAL Evaluation of position indication 10 XLNPROXY Proxy for signals from switching device via GOOSE 12 GOOSEXLNRCV GOOSE function block to receive a switching device 12 1MRK 511 401 UUS A Section...

Page 50: ..._A 1 DB_BUS_B 1 DB_LINE 1 ABC_LINE 1 AB_TRAFO 1 SCSWI Switch controller 15 SXSWI Circuit switch 14 QCRSV Apparatus control 2 RESIN1 1 RESIN2 59 POS_EVAL Evaluation of position indication 15 XLNPROXY Proxy for signals from switching device via GOOSE 20 GOOSEXLNRCV GOOSE function block to receive a switching device 20 Section 2 1MRK 511 401 UUS A Application 44 Bay control REC670 2 2 ANSI Applicatio...

Page 51: ...Evaluation of position indication 30 QCBAY Bay control 5 LOCREM Handling of LR switch positions 5 XLNPROXY Proxy for signals from switching device via GOOSE 42 GOOSEXLNRCV GOOSE function block to receive a switching device 42 Table 7 Total number of instances for configurable logic blocks Q T Configurable logic blocks Q T Total number of instances ANDQT 120 INDCOMBSPQT 20 INDEXTSPQT 20 INVALIDQT 2...

Page 52: ...r function name ANSI Function description Bay control REC670 Customized Monitoring CVMMXN Power system measurement 6 CMMXU Current measurement 10 VMMXU Voltage measurement phase phase 6 CMSQI Current sequence measurement 6 VMSQI Voltage sequence measurement 6 VNMMXU Voltage measurement phase ground 6 AISVBAS General service value presentation of analog inputs 1 EVENT Event function 20 DRPRDRE A4RA...

Page 53: ...S Transformer insulation loss of life monitoring 0 4 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 5 103 1 I103FLTPROT Function status fault protection for IEC 60870 5 103 1 I103IED IED status for IEC 60870 5 103 1 I103SUPERV Supe...

Page 54: ... 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 point value 64 GOOSEV...

Page 55: ...ront Ethernet port 1 SCHLCCH Access point diagnostic for non redundant Ethernet port 6 RCHLCCH Access point diagnostic for redundant 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 ...

Page 56: ...able 9 Number of function instances in Synchrophasor report 8 phasors Function name Function description Number of instances PMUCONF Configuration parameters for C37 118 2011 and IEEE1344 protocol 1 PMUREPORT Protocol reporting via IEEE 1344 and C37 118 1 PHASORREPORT1 Protocol reporting of phasor data via IEEE 1344 and C37 118 phasors 1 8 1 ANALOGREPORT1 Protocol reporting of analog data via IEEE...

Page 57: ...Number 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...

Page 58: ...en behavior 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 511 401 UUS A Application 52 Bay control REC670 2 2 ANSI Application manual ...

Page 59: ... measuring and interlocking is fully configured The following should be noted The configuration is made with the binary input and binary output boards in the basic delivery In many cases this is sufficient in other cases for example with full control of all apparatuses included more IO cards are required Our proposal for a full version with control is to use two binary input modules and one binary...

Page 60: ...V2 PTUV 27 2 3U SA PTOF 81 f OV2 PTOV 59 2 3U GOP PDOP 32 P SA PFRC 81 df dt GUP PDUP 37 P TR PTTR 49 θ CV GAPC 2 I U LMB RFLO 21FL FL EC PSCH 85 TR8 ATCC 90 U ECRW PSCH 85 TR1 ATCC 90 U ROV2 PTOV 59N 2 U0 SA PTUF 81 f VD SPVC 60 Ud SMP PTRC 94 1 0 CC RBRF 50BF 3I BF VN MMXU MET UN V MMXU MET U V MSQI MET Usqi C MMXU MET I C MSQI MET Isqi S CILO 3 Control S CSWI 3 Control S XCBR 3 Control VN MMXU ...

Page 61: ...be noted The configuration is made with the binary input and binary output boards in the basic IED delivery In many cases this is sufficient in other cases e g with full control of all apparatuses included more IO cards are required Our proposal for a full version with control is to use two binary input modules and one or two binary output modules For systems without Substation Automation a second...

Page 62: ...T Isqi FUF SPVC U I WA1 WA2_VT WA1_VT WA2 LINE_VT LINE_CT1 LINE_CT2 S CILO 3 Control S CSWI 3 Control S XSWI 3 Control S CILO 3 Control S CSWI 3 Control S XSWI 3 Control VN MMXU MET UN S CILO 3 Control S CSWI 3 Control S XCBR 3 Control VN MMXU MET UN VN MMXU MET UN V MMXU MET U V MSQI MET Usqi DRP RDRE DFR SER DR Q CBAY Q CRSV 3 Control R ESIN 3 Control S CILO 3 Control S CSWI 3 Control S XSWI 3 C...

Page 63: ... as other lines and the bus coupler over GOOSE The following should be noted The configuration is made with the binary input and binary output boards in the basic IED delivery In many cases this is sufficient in other cases for example with full control of all apparatuses included more IO cards are required Our proposal for a full version with control is to use three binary input modules and two b...

Page 64: ...PDUP 37 P LMB RFLO 21FL FL EC PSCH 85 ECRW PSCH 85 SMP PTRC 94 1 0 Q CRSV 3 Control C MMXU MET I C MSQI MET Isqi C MMXU MET I C MSQI MET Isqi WA1 WA2_VT FUF SPVC U I V MSQI MET Usqi V MSQI MET Usqi S SIMG 63 TR PTTR 49 θ CV GAPC U I S SIML 71 VD SPVC 60 Ud QB1 WA1_QA1 WA1_QB6 LINE1_QC9 QB61 TIE_QA1 QB62 LINE1_QB9 LINE2_QC9 WA2_QB6 LINE2_QB9 WA2_QA1 QB2 WA1_VT WA1_CT WA2_CT LINE2_VT TIE_CT LINE1_VT...

Page 65: ...P 37 P CV GAPC 2 I U LMB RFLO 21FL FL EC PSCH 85 ECRW PSCH 85 VD SPVC 60 Ud SMP PTRC 94 1 0 CC RBRF 50BF 3I BF VN MMXU MET UN V MMXU MET U V MSQI MET Usqi C MMXU MET I C MSQI MET Isqi S CILO 3 Control S CSWI 3 Control S XCBR 3 Control VN MMXU MET UN SMB RREC 79 5 0 1 WA1 WA2 WA2_VT WA1_VT LINE_CT LINE_VT S CILO 3 Control S CSWI 3 Control S XSWI 3 Control QC1 QC2 S CILO 3 Control S CSWI 3 Control S...

Page 66: ...figuration Tool and can be configured by the user Interface to analog and binary IO s are configurable without need of configuration changes Analog and control circuits have been pre defined Other signals need to be applied as required for each application The main differences between the packages above are the interlocking modules and the number of apparatuses to control Section 3 1MRK 511 401 UU...

Page 67: ...nnel 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 SE...

Page 68: ...o the object is defined as Forward and the direction out from the object is defined as Reverse See Figure 6 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 6 Protected Object Line transformer etc Forward Reverse Definition of directi...

Page 69: ...their 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 8 Example how to set CT_WyePoint parameters in the...

Page 70: ...e protection 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 sym...

Page 71: ...ect 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 ...

Page 72: ...In that case for all CT inputs marked with 1 in Figure 11 set CT_WyePoint ToObject and for all CT inputs marked with 2 in Figure 11 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 11 set CT_WyePoint FromObject and for all CT inputs marked with 2 in Figure 11 set CT_WyePoint ToObject Section...

Page 73: ...u have 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 12 Commonly used markings of CT terminals Where a is symbol and terminal marking used in this docu...

Page 74: ... 5A 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 13 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 co...

Page 75: ...current 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 13 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 curr...

Page 76: ...d only 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 fundamenta...

Page 77: ...the setting of the parameter CTStarPoint of the used current inputs on the TRM item 2 in Figure 14 and 13 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 altern...

Page 78: ...l summation 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 ...

Page 79: ...protection 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 s...

Page 80: ...5 in Delta DAB Connected IA IB IB IC IC IA 1 2 3 4 ANSI11000027 2 en vsd SMAI_20 ANSI11000027 V2 EN US Figure 16 Delta DAB connected three phase CT set Section 4 1MRK 511 401 UUS A Analog inputs 74 Bay control REC670 2 2 ANSI Application manual ...

Page 81: ...filter 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 protec...

Page 82: ...ePoint 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 18 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 or...

Page 83: ...int ToObject For connection b shown in Figure 18 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 ...

Page 84: ...ame 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...

Page 85: ...gs 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 con...

Page 86: ...ure 20 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 511 401 UUS A Analog inputs 80 Bay control...

Page 87: ... AI1 AI2 AI3 AI4 AIN GRP2_B GRP2_C GRP2N 4 ANSI06000599 V2 EN US Figure 20 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 21 A two phase to earth connected VT 1MRK 511 401 UUS A Section 4 Analog inputs Bay control REC670 2 2 ANSI 81 Applica...

Page 88: ...task 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 ...

Page 89: ...connected 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...

Page 90: ... shall 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 Fig...

Page 91: ...6 6 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 23 Open delta connected VT in high impedance grounded power system 1MRK 511 401 UUS A Section 4 Analog inputs Bay control REC670 2 2 ANSI 85 Application manual ...

Page 92: ...s voltage 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...

Page 93: ...d V 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 t...

Page 94: ...5 3 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 24 Open delta connected VT in low impedance or solidly grounded power system Section 4 1MRK 511 401 UUS A Analog inputs 88 Bay control REC670 2 2 ANSI Application manual ...

Page 95: ... fourth 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...

Page 96: ...90 ...

Page 97: ...2 v14 ANSI13000239 2 en vsd ANSI13000239 V2 EN US Figure 25 Local human machine interface The LHMI of the IED contains the following elements 1MRK 511 401 UUS A Section 5 Local HMI Bay control REC670 2 2 ANSI 91 Application manual ...

Page 98: ...Display 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 511 401 UUS A Local HMI 92 Bay control REC670 2 2 ANSI Application manual ...

Page 99: ...button 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 511 401 UUS A Section 5 Local HMI Bay control REC670 2 2 ANSI 93 Application manual ...

Page 100: ... 5157100F E8C0 4FAB B979 FD4A971475E3 V1 EN US Figure 28 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 511 401 UUS A...

Page 101: ...ed 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...

Page 102: ...igate 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 511 401 UUS A Local HMI 96 Bay control REC670 2 2 ANSI Application manual ...

Page 103: ...eypad 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 511 401 UUS A Section 5 Local HMI Bay control REC670 2 2 ANSI 97 Application manual ...

Page 104: ...tion 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 lo...

Page 105: ...ence 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 ack...

Page 106: ...ff IEC13000280 1 en vsd 1 2 GUID 94AF2358 6905 4782 B37B ACD3DCBF7F9C V1 EN US Figure 31 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...

Page 107: ...d settings and parameters in order to establish and define a number of TCP and or UDP connections with one or more PDC clients synchrophasor client This includes port numbers TCP UDP IP addresses and specific settings for IEEE C37 118 as well as IEEE 1344 protocols 6 1 3 Operation principle GUID 2608FBC4 9036 476A 942B 13452019BC11 v2 The Figure 32 demonstrates the communication configuration diag...

Page 108: ...118 1344 C37 118 1344 C37 118 1344 C37 118 1344 C37 118 1344 C37 118 1344 C37 118 1344 C37 118 Unicast Multicast 1344 C37 118 Unicast Multicast 1344 C37 118 Unicast Multicast 1344 C37 118 Unicast Multicast 1344 C37 118 Unicast Multicast 1344 C37 118 Unicast Multicast PMU ID PMU ID IEC140000117 1 en vsd IEC140000117 V2 EN US Figure 32 The communication configuration PMUCONF structure in the IED 6 1...

Page 109: ...e PMU ID will be extracted out of the command if there is a PMUREPORT instance configured in the IED with matching PMU ID then the client connection over TCP with the IED will be established and further communication will take place Otherwise the connection will be terminated and the TCPCtrlCfgErrCnt is incremented in the PMU Diagnostics on the Local HMI under Main menu Diagnostics Communication P...

Page 110: ...are ignored in the IED It is recommended not to set the parameter SendDataUDP x to SetByProtocol in case of a multicast This is because if one of the clients sends the RTDOFF command all the clients will stop receiving the frames The UDP implementation in the IED is a UDP_TCP This means that by default only the data frames are sent out on UDP stream and the header frame configuration frame and com...

Page 111: ...quest command frame config frame 1 config frame 2 config frame 3 or header frame and to disable enable real time data This can be done by connecting to the TCP port selected in TCPportUDPdataCtrl x for each UDP group This connection is done using TCP The IED allows 4 concurrent client connections for every TCPportUDPdataCtrl x port for each UDP client group x If the client tries to connect on TCPp...

Page 112: ... the IED which can stream out same or different data at different reporting rates or different performance service classes There are 2 instances of PMU functionality available in the IED Each instance of PMU functionality includes a set of PMU reporting function blocks tagged by the same instance number 1 or 2 As shown in the following figures each set of PMU reporting function blocks includes PMU...

Page 113: ...ingle phase phasor A B C IEC140000119 2 en vsd IEC140000119 V2 EN US Figure 34 Multiple instances of PHASORREPORT blocks Figure 35 shows both instances of ANALOGREPORT function blocks The instance number is visible in the bottom of each function block For each instance there are three separate ANALOGREPORT blocks capable of reporting up to 24 Analog signals 8 Analog signals in each ANALOGREPORT bl...

Page 114: ...gnals 8 Binary signals in each BINARYREPORT block These binary signals can be for example dis connector or breaker position indications or internal external protection alarm signals IEC140000121 2 en vsd IEC140000121 V2 EN US Figure 36 Multiple instances of BINARYREPORT blocks 6 2 3 Operation principle GUID EB2B9096 2F9D 4264 B2D2 8D9DC65697E8 v3 The Phasor Measurement Unit PMU features three main...

Page 115: ...B4DEBBE V1 EN US Equation 11 where Xr n and Xi n are the measured values Xr and Xi are the theoretical values In order to comply with TVE requirements special calibration is done in the factory on the analog input channels of the PMU resulting in increased accuracy of the measurements The IEEE C37 118 standard also imposes a variety of steady state and dynamic requirements which are fulfilled in t...

Page 116: ...cessor block is used to provide the required information for each respective PMUREPORT phasor channel More information about preprocessor block is available in the section Signal matrix for analog inputs SMAI 6 2 3 1 Frequency reporting GUID 4F3BA7C7 8C9B 4266 9F72 AFB139E9DC21 v2 By using patented algorithm the IED can track the power system frequency in quite wide range from 9 Hz to 95 Hz In ord...

Page 117: ...nel with a lower channel number is prioritized to the one with a higher channel number As a result the first voltage phasor is always the one delivering the system frequency to the PDC client and if by any reason this voltage gets disconnected then the next available voltage phasor is automatically used as the frequency source and so on If the first voltage phasor comes back since it has a higher ...

Page 118: ...te for internal processing For this purpose there is an anti aliasing filter designed for each reporting rate The correct anti aliasing filter will be automatically selected based on the reporting rate and the performance class P M settings The filters are designed to attenuate all aliasing frequencies to at least 40 dB a gain of 0 01 at M class The synchrophasor measurement is adaptive as it foll...

Page 119: ...cale factors conversion factor for analog channels are defined in configuration frame 2 CFG 2 and configuration frame 3 CFG 3 frames as follows CFG 2 frame The field ANUNIT 4 bytes specifies the conversion factor as a signed 24 bit word for user defined scaling Since it is a 24 bit integer in order to support the floating point scale factor the scale factor itself is multiplied in 10 so that a min...

Page 120: ...V1 EN US The scale factor will be sent as 1 on configuration frame 2 and 0 15 on configuration frame 3 The range of analog values that can be transmitted in this case is 0 15 to 4915 5 and 0 15 to 4915 5 Example 3 10000000000 AnalogXRange IECEQUATION2450 V1 EN US The scale factor is calculated as follows 10000000000 2 0 305180 43 and 0 0 65535 5 scalefactor offset IECEQUATION2451 V1 EN US The scal...

Page 121: ...IEC140000124 2 en vsd IEC140000124 V2 EN US Figure 38 An example of correct connection of SMAI and PHASORREPORT blocks in ACT Figure 39 shows an example of wrong connection of SMAI and PHASORREPORT blocks in ACT where the SMAI block is working on 3 ms while PHASORREPORT block is working on 0 9 ms cycle time IEC140000125 2 en vsd IEC140000125 V2 EN US Figure 39 An example of wrong connection of SMA...

Page 122: ...ion block demonstrated by PCM600 Parameter Setting Tool PST IEC140000126 2 en vsd IEC140000126 V2 EN US Figure 40 PMUREPORT settings in PCM600 PST Figure 41 shows an example of correct connection of SMAI and PHASORREPORT blocks in ACT where two different SMAI blocks are connected to different PHASORREPORT blocks with different instance numbers In this example as the PHASORREPORT blocks have differ...

Page 123: ...T instances differ for SvcClass or ReportRate then PHASOR1 connection in PHASORREPORT1 instance 2 will not be compliant with IEEE C37 118 standard The reason is that the filtering in SMAI 3PHSUM block is adapted according to the performance class SvcClass and reporting rate of the connected instance of PHASORREPORT function block In this example SMAI1 will adapt its filtering according to PHASORRE...

Page 124: ...nected to In other words both the SMAI reference block and 3PHSUM block 3PHSUM block with external DFT reference shall be connected to the same instance of PHASORREPORT block PHASOR1 32 of Instance number 1 or 2 Figure 43 shows an example of correct connection of 3PHSUM and PHASORREPORT blocks in ACT where SMAI3 is configured as the reference block for DFT reference external out DFTRefExtOut and 3...

Page 125: ...HSUM and PHASORREPORT blocks in ACT IEC140000130 1 en vsd IEC140000130 V1 EN US Figure 44 SMAI1 setting parameters example showing that SMAI3 is selected as the DFT reference DFTRefGrp3 1MRK 511 401 UUS A Section 6 Wide area measurement system Bay control REC670 2 2 ANSI 119 Application manual ...

Page 126: ...rnal DFT reference from SMAI3 IEC140000132 2 en vsd IEC140000132 V2 EN US Figure 46 An example of wrong connection of 3PHSUM and PHASORREPORT blocks in ACT If settings for PMUREPORT instances PHASORREPORT1 instances 1 and 2 above differ for SvcClass or ReportRate then the synchrophasor reported by PHASOR2 connection from PHASORREPORT1 instance 2 will not be compliant with IEEE C37 118 standard The...

Page 127: ...e connected to the same instance of PHASORREPORT blocks PHASOR1 32 of Instance number 1 or 2 Note If settings SvcClass and ReportRate are the same for different instances of PHASORREPORT blocks then 3PHSUM block can be freely connected to any of them regardless of 3PHSUM block DFT reference setting or the reference SMAI block connection Note Violation of rules 2 or 3 results in non compliancy with...

Page 128: ...ailable under section PMU Report Function Blocks Connection Rules in PCM600 Application Configuration Tool ACT Global_PMU_ID It refers to the 16 byte G_PMU_ID field of the configuration frame 3 CFG 3 organization defined in IEEE C37 118 2 message format It is a 16 character 128 bits user assigned value which can be sent with the configuration 3 message It allows uniquely identifying PMUs in a syst...

Page 129: ...alogDataType It refers to the Bit 2 of the FORMAT field of the configuration frames 1 2 and 3 organization defined in IEEE C37 118 2 message format Here the user can select the type of the analog data which are reported along with the synchrophasor data over IEEE C37 118 2 message The options are Integer or Float data corresponding to the 16 bit integer or 32 bit IEEE floating point values respect...

Page 130: ...t The DATA_RATE field is identifying the Rate of phasor data transmissions by a 2 byte integer word 32 767 to 32 767 Here the user can select the synchrophasor data reporting rate from the PMU based on the number of frames per second In general the IED has 5 different reporting rates 10 25 50 100 200 fr s on the 50 Hz system frequency and has 8 different reporting rates 10 12 15 20 30 60 120 240 f...

Page 131: ...On Off setting Each voltage connected preprocessor block delivers the frequency data derived from the analog input AC voltage values to the respective voltage phasor channel Every phasor channel has a user settable parameter PhasorXUseFreqSrc to be used as a source of frequency data for reporting to the PDC client It is very important to set this parameter to On for the voltage connected phasor ch...

Page 132: ...hannels AnalogXUnitType Unit type for analog signal X It refers to the 4 byte ANUNIT field of the configuration frames 1 2 organization defined in IEEE C37 118 2 message format The options are Single point on wave RMS of analog input and Peak of analog input Section 6 1MRK 511 401 UUS A Wide area measurement system 126 Bay control REC670 2 2 ANSI Application manual ...

Page 133: ...ion function HZPDIF 87 can be used as Generator differential protection Reactor differential protection Busbar differential protection Autotransformer differential protection for common and serial windings only T feeder differential protection Capacitor differential protection Restricted ground fault protection for transformer generator and shunt reactor windings Restricted ground fault protection...

Page 134: ...ANSI05000163 1 en vsd 3 87 87N 3 87T G 3 87G 3 87B 3 87T 3 87 3 87 3 87B ANSI05000163 V2 EN US Section 7 1MRK 511 401 UUS A Differential protection 128 Bay control REC670 2 2 ANSI Application manual ...

Page 135: ...een involved current transformers and not through the IED due to high impedance in the measuring branch This stabilizing resistance is in the range of hundreds of ohms and sometimes above one kilo Ohm When an internal fault occurs the current cannot circulate and is forced through the measuring branch causing relay operation It should be remembered that the whole scheme its built in components and...

Page 136: ...ranch The calculations are made with the worst situations in mind and a minimum operating voltage VR is calculated according to equation 13 max VR IF Rct Rl EQUATION1531 ANSI V1 EN US Equation 13 where IFmax is the maximum through fault current at the secondary side of the CT Rct is the current transformer secondary winding resistance and Rl is the maximum loop resistance of the circuit at any CT ...

Page 137: ...higher resistance value will give a higher sensitivity and a lower value a lower sensitivity of the relay The function has a recommended operating current range 40 mA to 1 0A for 1 A inputs and 200 mA to 5A for 5A inputs This together with the selected and set value is used to calculate the required value of current at the set TripPickup and R series values The CT inputs used for 1Ph High impedanc...

Page 138: ...0 0 200 A 40 V 400 0 100 A 200 0 200 A 100 0 400 60 V 600 0 100 A 300 0 200 A 150 0 400 A 80 V 800 0 100 A 400 0 200 A 200 0 400 A 100 V 1000 0 100 A 500 0 200 A 250 0 400 A 150 V 1500 0 100 A 750 0 200 A 375 0 400 A 200 V 2000 0 100 A 1000 0 200 A 500 0 400 A The current transformer saturation voltage must be at least 2 ˣ TripPickup to have sufficient operating margin This must be checked after c...

Page 139: ...o DC component in fault current to allow the use of only the AC components of the fault current in the above calculations The voltage dependent resistor Metrosil characteristic is shown in Figure 54 Series resistor thermal capacity SEMOD54734 336 v6 The series resistor is dimensioned for 200 W Care shall be exercised while testing to ensure that if current needs to be injected continuously or for ...

Page 140: ...ough fault situation VR VR c Internal faults VR Protected Object ANSI05000427 V2 EN US Figure 49 The high impedance principle for one phase with two current transformer inputs Section 7 1MRK 511 401 UUS A Differential protection 134 Bay control REC670 2 2 ANSI Application manual ...

Page 141: ...busbar differential protection is a typical application for three phase high impedance differential protection Typical CT connections for three phase high impedance differential protection scheme are shown in figure 50 L1 A L2 B L3 C Protected Object CT 1200 1 Star Wye Connected L1 A L2 B L3 C CT 1200 1 Star Wye Connected 7 8 9 1 0 1 1 1 2 1 2 3 4 5 6 AI01 I AI02 I AI03 I AI04 I AI05 I AI06 I 7 6 ...

Page 142: ...ng resistor set The star point connector must be removed for installations with 670 series IEDs This star point is required for RADHA schemes only 7 Connections of three individual phase currents for high impedance scheme to three CT inputs in the IED 7 1 3 2 Connections for 1Ph High impedance differential protection HZPDIF 87 GUID D68A237F 610C 4AF0 870F 273117F64D92 v10 Restricted earth fault pr...

Page 143: ...g point exists in this scheme 2 One phase plate with stabilizing resistor and metrosil Protective ground is a separate 4 mm screw terminal on the plate 3 Necessary connection for the metrosil 4 Position of optional test switch for secondary injection into the high impedance differential IED 5 Necessary connection for stabilizing resistor 6 How to connect the high impedance restricted earth fault p...

Page 144: ... the calculated value Measure the value achieved and set this value for this parameter The value shall always be high impedance This means for example for 1A circuits say bigger than 400 ohms 400 VA and for 5 A circuits say bigger than 100 ohms 2500 VA This ensures that the current will circulate and not go through the differential circuit at through faults That the settings of U Alarm U Trip and ...

Page 145: ...the feeder is protected with one scheme while the T zone is protected with a separate differential protection scheme The 1Ph high impedance differential HZPDIF 87 function in the IED allows this to be done efficiently see Figure 52 1MRK 511 401 UUS A Section 7 Differential protection Bay control REC670 2 2 ANSI 139 Application manual ...

Page 146: ...87 en05000165_ansi vsd ANSI05000165 V1 EN US 3 87 ANSI05000739 2 en vsd ANSI05000739 V2 EN US Section 7 1MRK 511 401 UUS A Differential protection 140 Bay control REC670 2 2 ANSI Application manual ...

Page 147: ...ple Basic data Current transformer ratio 2000 5A CT Class C800 At max tap of 2000 5A Secondary resistance 0 5 Ohm 2000 5A tap Cable loop resistance 2 Max fault current Equal to switchgear rated fault current 40 kA Calculation 40000 0 5 0 4 90 400 VR V EQUATION1751 ANSI V1 EN US Equation 15 Select a setting of TripPickup 100 V The current transformer saturation voltage must be at least twice the se...

Page 148: ...cient margin should be used The selection of the stabilizing resistor and the level of the magnetizing current mostly dependent of the number of turns are the most important factors 7 1 4 4 Tertiary reactor protection M16850 118 v5 Reactive power equipment for example shunt reactors and or shunt capacitors can be connected to the tertiary winding of the power transformers The 1Ph High impedance di...

Page 149: ...st tap of the CT whenever high impedance protection is used This helps in utilizing maximum CT capability minimize the secondary fault thereby reducing the stability voltage limit Another factor is that during internal faults the voltage developed across the selected tap is limited by the non linear resistor 1MRK 511 401 UUS A Section 7 Differential protection Bay control REC670 2 2 ANSI 143 Appli...

Page 150: ...0 0 1 0 1 8 20 VR EQUATION1768 ANSI V1 EN US Equation 18 Select a setting of TripPickup 30 V The current transformer knee point voltage must be at least twice the set operating voltage TripPickup 2 0 1 100 0 7 147 V VkneeANSI EQUATION1779 ANSI V2 EN US Equation 19 that is greater than 2 ˣ TripPickup Check from the table of selected resistances the required series stabilizing resistor value to use ...

Page 151: ...n current transformer secondary circuits However the stabilizing resistor can be selected to achieve sensitivity higher than normal load current and or separate criteria can be added to the operation like a check zone This can be either another IED with the same HZPDIF 87 function or be a check about the fault condition which is performed by a ground overcurrent function or neutral point voltage f...

Page 152: ...4 Current voltage characteristics for the non linear resistors in the range 10 200 V the average range of current is 0 01 10 mA Section 7 1MRK 511 401 UUS A Differential protection 146 Bay control REC670 2 2 ANSI Application manual ...

Page 153: ...ds mostly on three parameters at constant amount of transmitted electric power The type of the fault Three phase faults are the most dangerous because no power can be transmitted through the fault point during fault conditions The magnitude of the fault current A high fault current indicates that the decrease of transmitted power is high The total fault clearing time The phase angles between the E...

Page 154: ...ause high inrush current when connected to the network and can thus also cause the operation of the built in instantaneous overcurrent protection Common base IED values for primary current IBase primary voltage UBase and primary power SBase are set in the global base values for settings function GBASVAL GlobalBaseSel This is used to select GBASVAL function for reference of base values Operation Se...

Page 155: ...hould be done using the minimum source impedance values for ZA and the maximum source impedance values for ZB in order to get the maximum through fault current from A to B ZA ZB ZL A B IED I fB Fault ANSI09000022 1 en vsd ANSI09000022 V1 EN US Figure 55 Through fault current from A to B IfB Then a fault in A has to be applied and the through fault current IfA has to be calculated Figure 56 In orde...

Page 156: ...e transient overreach have to be introduced An additional 20 is suggested due to the inaccuracy of the instrument transformers under transient conditions and inaccuracy in the system data The minimum primary setting Is for the instantaneous phase overcurrent protection is then min 1 3 s I I EQUATION79 V3 EN US Equation 22 The protection function can be used for the specific application only if thi...

Page 157: ...is given in Figure 58 where the two lines are connected to the same busbars In this case the influence of the induced fault current from the faulty line line 1 to the healthy line line 2 is considered together with the two through fault currents IfA and IfB mentioned previously The maximal influence from the parallel line for the IED in Figure 58 will be with a fault at the C point with the C brea...

Page 158: ...ntioned previously the minimum setting Is for the instantaneous phase overcurrent protection 3 phase output is then Is 1 3 Imin EQUATION83 V2 EN US Equation 25 The protection function can be used for the specific application only if this setting value is equal or less than the maximum phase fault current that the IED has to clear The IED setting value Pickup is given in percentage of the primary b...

Page 159: ...apacitor 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 four different individually settable steps The following options are possible Non directional Directional function In most applications the non directional functionality i...

Page 160: ...d This phenomenon is due to saturation of the transformer magnetic core during parts of the period There is a risk that inrush current will reach levels above the pick up current of the phase overcurrent protection The inrush current has a large 2nd harmonic content This can be used to avoid unwanted operation of the protection function Therefore OC4PTOC 51 67 has a possibility of 2nd harmonic res...

Page 161: ... 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 function shown in Figure 59 NumPhSel Number of phases with high current required for operation The setting possibilities are 1 out of 3 2 out of 3 and 3 out of 3 Th...

Page 162: ...stic angle 2 ROA Relay operating angle 3 Reverse 4 Forward 8 2 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 8 1MRK 511 401 UUS A Current protection 156 Bay control REC670 2 2 ANSI Application manual ...

Page 163: ...ckupx 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 f...

Page 164: ...rent 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 60 Minimum pickup current and trip time for inverse time characteristics In order to fully comply with the definition of the curve the setting ...

Page 165: ...ntaneous 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 27 for the time characteristic equation For more informati...

Page 166: ...urrent 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 61 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 61 Pi...

Page 167: ... must 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 29 Ipu 0 7 Iscmin EQUATION1263 V2 EN US Equation 29 where 0 7 is a safety factor Iscmin is the smallest fault current to be detected by the overcurrent protectio...

Page 168: ...ost 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 i...

Page 169: ...imum 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 res...

Page 170: ...f events 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 t...

Page 171: ...S 50N 8 3 2 Application M12699 3 v5 In many applications when fault current is limited to a defined value by the object impedance an instantaneous ground fault protection can provide fast and selective tripping The Instantaneous residual overcurrent EFPIOC 50N which can operate in 15 ms 50 Hz nominal system frequency for faults characterized by very high currents is included in the IED 8 3 3 Setti...

Page 172: ...d Figure 65 The residual currents 3I0 to the protection are calculated For a fault at the remote line end this fault current is IfB In this calculation the operational state with high source impedance ZA and low source impedance ZB should be used For the fault at the home busbar this fault current is IfA In this calculation the operational state with low source impedance ZA and high source impedan...

Page 173: ...imum primary current setting Is is Is 1 3 Imin EQUATION285 V3 EN US Equation 34 In case of parallel lines with zero sequence mutual coupling a fault on the parallel line as shown in Figure 66 should be calculated ZA ZB ZL1 A B I M Fault IED ZL2 M C Line 1 Line 2 ANSI09000025_2_en vsd ANSI09000025 V2 EN US Figure 66 Two parallel lines Influence from parallel line to the through fault current IM The...

Page 174: ...ration current level IN is used The limits are used for decreasing the used range of the IN setting If IN is set outside IN Max and IN Min the closest of the limits to IN is used by the function If IN Max is smaller than IN Min the limits are swapped MultPU The set operate current can be changed by activation of the binary input MULTPU to the set factor MultPU 8 4 Directional residual overcurrent ...

Page 175: ...e both selectivity and fast fault clearance the directional function can be necessary This can be the case for ground fault protection in meshed and effectively grounded transmission systems The directional residual overcurrent protection is also well suited to operate in teleprotection communication schemes which enables fast clearance of ground faults on transmission lines The directional functi...

Page 176: ...ent pickup level for some time Therefore there is a possibility to give a setting of a multiplication factor INxMult to the residual current pick up level This multiplication factor is activated from a binary input signal MULTPUx to the function Power transformers can have a large inrush current when being energized This inrush current can produce residual current component The phenomenon is due t...

Page 177: ...ngs function GBASVAL GlobalBaseSel This is used to select GBASVAL function for reference of base values SeqTypeUPol This is used to select the type of voltage polarising quantity i e Zero seq and Neg seq for direction detection SeqTypeIPol This is used to select the type of current polarising quantity i e Zero seq and Neg seq for direction detection SeqTypeIDir This is used to select the type of o...

Page 178: ... is strong and a high sensitivity is required In such cases the polarizing voltage 3V0 can be below 1 and it is then necessary to use current polarizing or dual polarizing Multiply the required set current primary with the minimum impedance ZNpol and check that the percentage of the phase to ground voltage is definitely higher than 1 minimum 3V0 VPolMin setting as a verification RNPol XNPol The ze...

Page 179: ...ush current This will give a declining residual current in the network as the inrush current is deviating between the phases There is a risk that the residual 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 At current transformer saturat...

Page 180: ...rallel transformer energizing The settings for the parallel transformer logic are described below BlkParTransf This is used to Enable blocking at energising of parallel transformers Use_PUValue Gives which current level should be used for the activation of the blocking signal This is given as one of the settings of the steps Step 1 2 3 4 Normally the step having the lowest operation current level ...

Page 181: ...00 s t4U Time interval when the SOTF function is active after breaker closing The setting range is 0 000 60 000 s in step of 0 001 s The default setting is 1 000 s ActUndrTimeSel Describes the mode to activate the sensitive undertime function The function can be activated by Circuit breaker position change or Circuit breaker command tUnderTime Time delay for operation of the sensitive undertime fu...

Page 182: ...ckup x Operate residual current level for step x given in of IB INx Max and INx Min should only be changed if remote setting of operation current level INx is used The limits are used for decreasing the used range of the INx setting If INx is set outside INx Max and INx Min the closest of the limits to INx is used by the function If INx Max is smaller than INx Min the limits are swapped kx Time mu...

Page 183: ...xMult Multiplier for scaling of the current setting value If a binary input signal MULTPUx is activated the current operation level is increased by this setting constant ResetTypeCrvx The reset of the delay timer can be made in different ways The possibilities are described in the technical reference manual tResetx Constant reset time delay in s for step x HarmBlockx This is used to enable block o...

Page 184: ...current protection can be used in different ways Below is described one application possibility to be used in meshed and effectively grounded systems The protection measures the residual current out on the protected line The protection function has a directional function where the polarizing voltage zero sequence voltage is the polarizing quantity The polarizing voltage and current can be internal...

Page 185: ...s Step 1 M15282 123 v6 This step has directional instantaneous function The requirement is that overreaching of the protected line is not allowed ANSI05000150_2_en vsd 67 N One or two phase ground fault 67N 0 3I ANSI05000150 V2 EN US Figure 71 Step 1 first calculation 1MRK 511 401 UUS A Section 8 Current protection Bay control REC670 2 2 ANSI 179 Application manual ...

Page 186: ...remote busbar is taken out of service see Figure 72 en05000151_ansi vsd 67N One or two phase ground fault 0 3I ANSI05000151 V2 EN US Figure 72 Step 1 second calculation Remote busbar with one line taken out of service The requirement is now according to Equation 40 step1 0 I 1 2 3I remote busbar with one line out EQUATION1200 V3 EN US Equation 40 A higher value of step 1 might be necessary if a bi...

Page 187: ...ep 1 is chosen as the largest of the above calculated residual currents measured by the protection Step 2 M15282 144 v7 This step has directional function and a short time delay often about 0 4 s Step 2 shall securely detect all ground faults on the line not detected by step 1 67N One or two phase ground fault 50 51N 0 3I ANSI05000154_2_en vsd ANSI05000154 V2 EN US Figure 74 Step 2 check of reach ...

Page 188: ...SI05000155_2_en vsd ANSI05000155 V2 EN US Figure 75 Step 2 selectivity calculation A second criterion for step 2 is according to equation 43 1 1 0 step2 step1 0 3I I 2 I 3I EQUATION1203 V4 EN US Equation 43 where Istep1 is the current setting for step 1 on the faulted line Step 3 M15282 164 v6 This step has directional function and a time delay slightly larger than step 2 often 0 8 s Step 3 shall ...

Page 189: ... Both high resistance ground faults and series faults give zero sequence current flow in the network Such currents give disturbances on telecommunication systems and current to ground It is important to clear such faults both concerning personal security as well as risk of fire The current setting for step 4 is often set down to about 100 A primary 3I0 In many applications definite time delay in t...

Page 190: ...ault and phase phase short circuit protection of different kinds of equipment connected to the power system such as shunt capacitor banks shunt reactors and others In many applications several steps with different current pickup levels and time delays are needed NS4PTOC 4612 can have up to four individual settable steps The flexibility of each step of NS4PTOC 4612 function is great The following o...

Page 191: ...e ANSI Long Time Inverse IEC Normal Inverse IEC Very Inverse IEC Inverse IEC Extremely Inverse IEC Short Time Inverse IEC Long Time Inverse IEC Definite Time User Programmable ASEA RI RXIDG logarithmic There is also a user programmable inverse time characteristic Normally it is required that the negative sequence overcurrent function shall reset as fast as possible when the current level gets lowe...

Page 192: ...e 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 8 5 3 1 Settings for each step GUID CFB327EF C5C4 44B5 AB4B 9C2916355FC5 v5 x means step 1 2 3 and 4 DirModeSelx The directional mode of step x Possible settings are off nondirectional forward ...

Page 193: ...inverse characteristic IMinx Minimum pickup current for step x in of IBase Set IMinx below Pickupx for every step to achieve ANSI reset characteristic according to standard If IMinx is set above Pickupx for any step the ANSI reset works as 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 ...

Page 194: ...e delay time settings are instantaneous 1 and IEC 2 set constant time reset For ANSI 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 For IEC inverse time delay characteristics the possible delay time settings are instantaneous 1 and IEC 2 set constant time reset For ...

Page 195: ...arameters for customer creation of inverse reset time characteristic curve Further description can be found in the Technical Reference Manual 8 5 3 2 Common settings for all steps GUID A00A942B E760 42EE 8FEB F723426783F3 v1 x means step 1 2 3 and 4 AngleRCA Relay characteristic angle given in degrees This angle is defined as shown in figure 78 The angle is defined positive when the residual curre...

Page 196: ...se 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 signal must be configured to the communication scheme block 8 6 Sensitive directional residual overcurrent and power protection SDEPSDE 67N SEMOD171436 1 v4 Section 8 1MRK 511 401 UUS A Current ...

Page 197: ...ound faults in high impedance grounded networks The protection uses the residual power component 3I0 3V0 cos φ where φ is the angle between the residual current and the reference residual voltage compensated with a characteristic angle A normal non directional residual current function can also be used with definite or inverse time delay A backup neutral point voltage function is also available fo...

Page 198: ...and by using sensitive directional residual power protection the operating quantity is elevated Therefore better possibility to detect ground faults In addition in low impedance grounded networks the inverse time characteristic gives better time selectivity in case of high zero resistive fault currents Phase currents Phase ground voltages IN VN ANSI13000013 1 en vsd ANSI13000013 V1 EN US Figure 79...

Page 199: ...age and the ground fault current will be calculated at the desired sensitivity fault resistance The complex neutral point voltage zero sequence can be calculated as phase 0 f 0 V V 3 R 1 Z EQUATION2020 ANSI V1 EN US Equation 46 Where Vphase is the phase voltage in the fault point before the fault Rf is the resistance to ground in the fault point and Z0 is the system zero sequence impedance to grou...

Page 200: ...al points In such a system the impedance Z0 can be calculated as n n c 0 c n n n c n n c 9R X X Z jX 3R j3X 3X X j3R 3X X EQUATION1947 V1 EN US Equation 50 Where Xn is the reactance of the Petersen coil If the Petersen coil is well tuned we have 3Xn Xc In this case the impedance Z0 will be Z0 3Rn Now consider a system with an grounding via a resistor giving higher ground fault current than the hig...

Page 201: ...nt can be written phase 0 1 0 f 3V 3I 2 Z Z 3 R EQUATION2023 ANSI V1 EN US Equation 51 Where Vphase is the phase voltage in the fault point before the fault Z1 is the total positive sequence impedance to the fault point Z1 Zsc ZT 1 ZlineAB 1 ZlineBC 1 Z0 is the total zero sequence impedance to the fault point Z0 ZT 0 3RN ZlineAB 0 ZlineBC 0 Rf is the fault resistance The residual voltages in stati...

Page 202: ...n be written 0A prot 0A 0 A S 3V 3I cos j EQUATION2028 ANSI V1 EN US Equation 56 0B prot 0B 0 B S 3V 3I cos j EQUATION2029 ANSI V1 EN US Equation 57 The angles φA and φB are the phase angles between the residual current and the residual voltage in the station compensated with the characteristic angle RCA The protection will use the power components in the characteristic angle direction for measure...

Page 203: ... this parameter correctly With the setting OpModeSel the principle of directional function is chosen With OpModeSel set to 3I0cosfi the current component in the direction equal to the characteristic angleRCADir has the maximum sensitivity The characteristic for RCADir is equal to 0 is shown in Figure 81 3V0 Vref 3I0 RCA 0 ROA 90 ang 3I0 ang 3Vref 3I0 cos en06000648_ansi vsd Vref ANSI06000648 V1 EN...

Page 204: ...omponent in the direction is measured When OpModeSel is set to 3I0 and fi the function will operate if the residual current is larger than the setting INDirPU and the residual current angle is within the sector RCADir ROADir The characteristic for this OpModeSel when RCADir 0 and ROADir 80 is shown in figure 83 Section 8 1MRK 511 401 UUS A Current protection 198 Bay control REC670 2 2 ANSI Applica...

Page 205: ...rent protection tReset is the time delay before the definite timer gets reset given in s With a tReset time of few cycles there is an increased possibility to clear intermittent ground faults correctly The setting shall be much shorter than the set trip delay In case of intermittent ground faults the fault current is intermittently dropping below the set value during consecutive cycles Therefore t...

Page 206: ...ent for the external CT core i e any CT core can be used If the time delay for residual power is chosen the delay time is dependent on two setting parameters SRef is the reference residual power given in of SBase TDSN is the time multiplier The time delay will follow the following expression inv 0 0 TDSN Sref t 3I 3V cos measured j EQUATION2030 ANSI V1 EN US Equation 59 INDirPU is the pickup curre...

Page 207: ... Inverse time characteristics in Technical Manual for the description of different characteristics tPCrv tACrv tBCrv tCCrv Parameters for customer creation of inverse time characteristic curve Curve type 17 The time characteristic equation is _ æ ö ç ç ç æ ö ç ç è ø è ø p A t s B InMult i C Pickup N EQUATION2031 ANSI V1 EN US Equation 60 tINNonDir is the definite time delay for the non directional...

Page 208: ... power level If the current exceeds this level the losses will be higher than expected As a consequence the temperature of the transformer will increase If the temperature of the transformer reaches too high a value the equipment might be damaged The insulation within the transformer experiences forced ageing As a consequence of this the risk of internal phase to phase or phase to ground faults in...

Page 209: ... based on current measurement If the heat content of the protected transformer reaches a set alarm level a signal can be given to the operator Two alarm levels are available This enables preventive actions in the power system to be taken before dangerous temperatures are reached If the temperature continues to increase to the trip value the protection initiates a trip of the protected transformer ...

Page 210: ... of the transformer with forced cooling FOA If the transformer has no forced cooling IBase2 can be set equal to IBase1 Tau1 The thermal time constant of the protected transformer related to IBase1 no cooling given in minutes Tau2 The thermal time constant of the protected transformer related to IBase2 with cooling given in minutes The thermal time constant should be obtained from the transformer m...

Page 211: ...ns Below some examples are given In case a total interruption low current of the protected transformer all cooling possibilities will be inactive This can result in a changed value of the time constant If other components motors are included in the thermal protection there is a risk of overheating of that equipment in case of very high current The thermal time constant is often smaller for a motor...

Page 212: ...often used This means that a fault needs to be cleared even if any component in the fault clearance system is faulty One necessary component in the fault clearance system is the circuit breaker It is from practical and economical reason not feasible to duplicate the circuit breaker for the protected object Instead a breaker failure protection is used Breaker failure protection 3 phase activation a...

Page 213: ...otection or in case of line ends with weak end infeed RetripMode This setting states how the re trip function shall operate Retrip Off means that the re trip function is not activated CB Pos Check circuit breaker position check and Current means that a phase current must be larger than the operate level to allow re trip CB Pos Check circuit breaker position check and Contact means re trip is done ...

Page 214: ...lure protection Typical setting is 10 of IBase Pickup_BlkCont If any contact based detection of breaker failure is used this function can be blocked if any phase current is larger than this setting level If the FunctionMode is set Current Contact breaker failure for high current faults are safely detected by the current measurement function To increase security the contact based function should be...

Page 215: ...orrect breaker function the current criteria reset tmargin is a safety margin It is often required that the total fault clearance time shall be less than a given critical time This time is often dependent of the ability to maintain transient stability in case of a fault close to a power plant Time The fault occurs Protection operate time Trip and Pickup CCRBRF 50BF Normal tcbopen Margin Retrip del...

Page 216: ...ay for back up trip is bypassed when the 52FAIL is active Typical setting is 2 0 seconds tPulse Trip pulse duration This setting must be larger than the critical impulse time of circuit breakers to be tripped from the breaker failure protection Typical setting is 200 ms 8 10 Stub protection STBPTOC 50STB IP14515 1 v3 8 10 1 Identification M17108 1 v2 Function description IEC 61850 identification I...

Page 217: ... for Stub protection STBPTOC 50STB are set via the local HMI or PCM600 The following settings can be done for the stub protection GlobalBaseSel Selects the global base value group used by the function to define IBase VBase and SBase as applicable Operation Disabled Enabled EnableMode This parameter can be set Enable or Continuous With theEnable setting the function is only active when a binary rel...

Page 218: ...e open and the other two closed or two poles can be open and one closed Pole discrepancy of a circuit breaker will cause unsymmetrical currents in the power system The consequence of this can be Negative sequence currents that will give stress on rotating machines Zero sequence currents that might give unwanted operation of sensitive ground fault protections in the power system It is therefore imp...

Page 219: ...d to the pole discrepancy function If the Pole pos aux cont alternative is chosen each open close signal is connected to the IED and the logic to detect pole discrepancy is realized within the function itself CurrentSel Operation of the current based pole discrepancy protection Can be set Disabled CB oper monitor Continuous monitor In the alternative CB oper monitor the function is activated only ...

Page 220: ... motoring condition may imply that the turbine is in a very dangerous state The task of the reverse power protection is to protect the turbine and not to protect the generator itself Steam turbines easily become overheated if the steam flow becomes too low or if the steam ceases to flow through the turbine Therefore turbo generators should have reverse power protection There are several contingenc...

Page 221: ...ines may suffer from reverse power There is a risk that the turbine runner moves axially and touches stationary parts They are not always strong enough to withstand the associated stresses Ice and snow may block the intake when the outdoor temperature falls far below zero Branches and leaves may also block the trash gates A complete blockage of the intake may cause cavitations The risk for damages...

Page 222: ...alBaseSel Selects the global base value group used by the function to define IBase VBase and SBase as applicable Operation With the parameter Operation the function can be set Enabled Disabled Mode The voltage and current used for the power measurement The setting possibilities are shown in table 26 Table 26 Complex power calculation Set value Mode Formula used for complex power calculation A B C ...

Page 223: ...ANSI V1 EN US Equation 71 C 3 C C S V I EQUATION2063 ANSI V1 EN US Equation 72 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 in the direction defined by the setting Angle1 2 is smaller than the set pick up power value Power1 2 1MRK 511 401 UUS A Section 8 Current protect...

Page 224: ...ng 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 73 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 8 1MRK 511 ...

Page 225: ...ion 74 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 75 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 c...

Page 226: ...E C37 2 device number Directional overpower protection GOPPDOP P 2 DOCUMENT172362 IMG158942 V2 EN US 32 8 13 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 l...

Page 227: ...he 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 ...

Page 228: ...ection 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 n...

Page 229: ...uation 80 B C B C BC S V I I EQUATION2042 V1 EN US Equation 81 C A C A CA S V I I EQUATION2043 V1 EN US Equation 82 A A A S 3 V I EQUATION2044 V1 EN US Equation 83 B B B S 3 V I EQUATION2045 V1 EN US Equation 84 C C C S 3 V I EQUATION2046 V1 EN US Equation 85 The function has two stages that can be set independently With the parameter OpMode1 2 the function can be set Enabled Disabled The function...

Page 230: ...etting 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 86 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 8 1MRK 511 401 U...

Page 231: ...for trip of the stage after pick up Hysteresis1 2 is given in p u of generator rated power according to equation 87 N S 3 VBase IBase EQUATION2047 V1 EN US Equation 87 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 511 401 UUS A Section 8 Current protection Bay control REC670 2 2 ANSI 225 A...

Page 232: ...of rated current voltage IMagComp5 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 8 14 Broken conductor check BRCPTOC...

Page 233: ... GlobalBaseSel to power line rated current or CT rated current Set minimum operating level per phase Pickup_PH to typically 10 20 of rated current Set the unsymmetrical current which is relation between the difference of the minimum and maximum phase currents to the maximum phase current to typical Pickup_ub 50 Note that it must be set to avoid problem with asymmetry under minimum operating condit...

Page 234: ...er 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 capa...

Page 235: ...protects 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 1MRK 511 40...

Page 236: ...r that transients caused by SCB switching are avoided 8 15 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 fo...

Page 237: ...inuous 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 de...

Page 238: ...condition detection CBPGAPC function can be used to provide the last four types of protection mentioned in the above list 8 15 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 93 Preprocessing Function Block Capacitor bank protection function 400kV CBPGAPC SMAI 200MVAr...

Page 239: ... a 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 featu...

Page 240: ... harmonic 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 leve...

Page 241: ...r Voltage restrained time overcurrent protection VRPVOC I U 51V 8 16 2 Application GUID 622CDDDD 6D03 430E A82D 861A4CBE067C v7 A breakdown of the insulation between phase conductors or a phase conductor and ground results in a short circuit or a ground fault Such faults can result in large fault currents and may cause severe damage to the power system primary equipment A typical application of th...

Page 242: ...nder voltage seal in Sometimes in order to obtain the desired application functionality it is necessary to provide interaction between the two protection elements within the D2PTOC 51V function by appropriate IED configuration for example overcurrent protection with under voltage seal in 8 16 2 1 Base quantities GUID 08944177 73CF 4FB4 818E 3B7AC4F625EE v4 GlobalBaseSel defines the particular Glob...

Page 243: ...oltage seal in can be used To apply the VRPVOC 51V function the configuration is done according to figure 94 As seen in the figure the pickup of the overcurrent stage will enable the undervoltage stage Once enabled the undervoltage stage will start a timer which causes function tripping if the voltage does not recover above the set value To ensure a proper reset the function is blocked two seconds...

Page 244: ...is the time between activation of the start and the trip outputs EnBlkLowV This parameter enables the internal block of the undervoltage stage for low voltage condition the voltage level is defined by the parameter BlkLowVolt BlkLowVolt Voltage level under which the internal blocking of the undervoltage stage is activated it is set in of VBase This setting must be lower than the setting StartVolt ...

Page 245: ...on 4 Select Characterist to match the type of overcurrent curves used in the network IEC Very inv 5 Set the multiplier k 1 default value 6 Set tDef_OC 0 00 s in order to add no additional delay to the trip time defined by the inverse time characteristic 7 If required set the minimum operating time for this curve by using the parameter t_MinTripDelay default value 0 05 s 8 Set PickupCurr to the val...

Page 246: ...et StartCurr to the value 150 4 Set Characteristic to IEC Def Time 5 Set tDef_OC to 6000 00 s if no trip of the overcurrent stage is required 6 Set VDepFact to the value 100 in order to ensure that the pickup value of the overcurrent stage is constant irrespective of the magnitude of the generator voltage 7 Set Operation_UV to Enabled to activate the undervoltage stage 8 Set StartVolt to the value...

Page 247: ...n or faults in the power system such as Malfunctioning of a voltage regulator or wrong settings under manual control symmetrical voltage decrease Overload symmetrical voltage decrease Short circuits often as phase to ground faults unsymmetrical voltage decrease UV2PTUV 27 is used in combination with overcurrent protections either as restraint or in logic and gates of the trip signals issued by the...

Page 248: ... main protection to clear short circuits and ground faults Some applications and related setting guidelines for the voltage level are described in the following sections 9 1 3 1 Equipment protection such as for motors and generators M13851 50 v3 The setting must be below the lowest occurring normal voltage and above the lowest acceptable voltage for the equipment 9 1 3 2 Disconnected equipment det...

Page 249: ... described only once Characteristicn This parameter gives the type of time delay to be used The setting can be Definite time Inverse Curve A Inverse Curve B Prog inv curve The selection is dependent on the protection application OpModen This parameter describes how many of the three measured voltages should be below the set level to give operation for step n The setting can be 1 out of 3 2 out of ...

Page 250: ...ers to create a programmable under voltage inverse time characteristic Description of this can be found in the Technical manual CrvSatn Tuning parameter that is used to compensate for the undesired discontinuity created when the denominator in the equation for the customer programmable curve is equal to zero For more information see the Technical manual IntBlkSeln This parameter can be set to Disa...

Page 251: ...age The function has a high measuring accuracy and hysteresis setting to allow applications to control reactive load OV2PTOV 59 is used to disconnect apparatuses like electric motors which will be damaged when subject to service under high voltage conditions It deals with high voltage conditions at power system frequency which can be caused by 1 Different kinds of faults where a too high voltage a...

Page 252: ...nent can withstand smaller overvoltages for some time but in case of large overvoltages the related equipment should be disconnected more rapidly Some applications and related setting guidelines for the voltage level are given below The hysteresis is for overvoltage functions very important to prevent that a transient voltage over set level is not sealed in due to a high hysteresis Typical values ...

Page 253: ...lBaseSel Base voltage phase to phase in primary kV This voltage is used as reference for voltage setting OV2PTOV 59 measures selectively phase to ground voltages or phase to phase voltage chosen by the setting ConnType The function will operate if the voltage gets lower than the set percentage of VBase When ConnType is set to PhN DFT or PhN RMS then the IED automatically divides set value for VBas...

Page 254: ...ject The speed might be important for example in case of protection of transformer that might be overexcited The time delay must be co ordinated with other automated actions in the system tResetn Reset time for step n if definite time delay is used given in s The default value is 25 ms tnMin Minimum operation time for inverse time characteristic for step n given in s For very high voltages the ove...

Page 255: ...on M13809 3 v8 Two step residual overvoltage protection ROV2PTOV 59N is primarily used in high impedance grounded distribution networks mainly as a backup for the primary ground fault protection of the feeders and the transformer To increase the security for different ground fault related functions the residual overvoltage signal can be used as a release signal The residual voltage can be measured...

Page 256: ...me specific equipment the time delay is shorter Some applications and related setting guidelines for the residual voltage level are given below 9 3 3 1 Equipment protection such as for motors generators reactors and transformersEquipment protection for transformers M13853 9 v8 High residual voltage indicates ground fault in the system perhaps in the component to which two step residual overvoltage...

Page 257: ... above the highest occurring normal residual voltage and below the lowest occurring residual voltage during the faults under consideration A metallic single phase ground fault causes a transformer neutral to reach a voltage equal to the nominal phase to ground voltage The voltage transformers measuring the phase to ground voltages measure zero voltage in the faulty phase The two healthy phases wil...

Page 258: ...fed to the IED in different ways 1 The IED is fed from a normal voltage transformer group where the residual voltage is calculated internally from the phase to ground voltages within the protection The setting of the analogue input is given as VBase Vph ph 2 The IED is fed from a broken delta connection normal voltage transformer group In an open delta connection the protection is fed by the volta...

Page 259: ...ed systems this value depends on the ratio Z0 Z1 The required setting to detect high resistive ground faults must be based on network calculations tn time delay of step n given in s The setting is highly dependent on the protection application In many applications the protection function has the task to prevent damage to the protected object The speed might be important for example in the case of ...

Page 260: ...ent of the application The hysteresis is used to avoid oscillations of the PICKUP output signal This signal resets when the measured voltage drops below the setting level and leaves the hysteresis area Make sure that the set value for parameter HystABSn is somewhat smaller than the set pickup value Otherwise there is a risk that step n will not reset properly 9 4 Voltage differential protection VD...

Page 261: ...ision or MCB tripped can be connected to prevent problems if one fuse in the capacitor bank voltage transformer 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 Fuse failure supervision SDDRFUF function for voltage transformers In many applicatio...

Page 262: ...nction to define IBase VBase and SBase as applicable BlkDiffAtVLow The setting is to block the function when the voltages in the phases are low RFLx Is the setting of the voltage ratio compensation factor where possible differences between the voltages is compensated for The differences can be due to different voltage transformer ratios different voltage levels e g the voltage measurement inside t...

Page 263: ...ting Default values are here expected to be acceptable V1Low The setting of the undervoltage level for the first voltage input is decided by this parameter The proposed default setting is 70 V2Low The setting of the undervoltage level for the second voltage input is decided by this parameter The proposed default setting is 70 tBlock The time delay for blocking of the function at detected undervolt...

Page 264: ...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 voltage is lost with breakers still closed All settings are in primary values or per unit Set operate level per phase to ...

Page 265: ...ower 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 i...

Page 266: ...lowest 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 syste...

Page 267: ... can also be used to alert operators that frequency has slightly deviated from the set point and that manual actions might be enough 10 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 appl...

Page 268: ...Identification 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 10 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...

Page 269: ...vel 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 ins...

Page 270: ... of frequency occurs in case of generation surplus while a lack of generation results in a drop of frequency The turbine blade is designed with its natural frequency adequately far from the rated speed or multiples of the rated speed of the turbine This design avoids the mechanical resonant condition which can lead to an increased mechanical stress on turbine blade If the ratio between the turbine...

Page 271: ...bnormal operating conditions The frequency limitations and their time restrictions for different types of turbines are similar in many aspects with steam turbine limitations Certain differences in design and applications may result in different protective requirements Therefore for different type of turbine systems different recommendations on the time restriction limits are specified by the manuf...

Page 272: ...e the IEC 60034 3 1996 requirement of continuous operation within the confines of their capability curves over the ranges of 5 in voltage and 2 in frequency Operation of the machine at rated power outside these voltage frequency limits lead to increased temperatures and reduction of insulation life 10 4 3 Setting guidelines GUID 62C6D764 CAF2 4C2F B91A EBC611987D72 v3 Among the generator protectio...

Page 273: ...Set the current level just above minimum load EnaVoltCheck set to Disable tCont to be coordinated to the grid requirements tAccLimit FreqHighLimit and FreqLowLimit setting is derived from the turbine manufacturer s operating requirements note that FreqLowLimit setting must always be lower than the set value of FreqHighLimit FTAQFVR 81A used to protect a generator Frequency during start up and shut...

Page 274: ...268 ...

Page 275: ...l and 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 residu...

Page 276: ...or 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...

Page 277: ...rent 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 ...

Page 278: ... and 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 th...

Page 279: ...oltage Quantity is selected from 1 to 9 as shown in table 29 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 29 11 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 configurati...

Page 280: ...d by 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 ...

Page 281: ...912614 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 ...

Page 282: ...to 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...

Page 283: ...current 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 bui...

Page 284: ...n the 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 98 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 Current...

Page 285: ...overcurrent 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 ...

Page 286: ...levant 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 th...

Page 287: ...culation When the equation 102 is compared with the equation 103 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 e...

Page 288: ...nction 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 curr...

Page 289: ...or 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...

Page 290: ...rrent 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 1...

Page 291: ... 1 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 101 Loss of excitation 1MRK 511 401 UUS A Section 11 Multipurpose protection Bay control REC670 2 2 ANSI 285 Application manual ...

Page 292: ...286 ...

Page 293: ...into this filter i e three phases and the residual quantity the input samples from the TRM module which are coming at rate of 20 samples per fundamental system cycle are first stored When enough samples are available in the internal memory the phasor values at set frequency defined by the setting parameter SetFrequency are calculated The following values are internally available for each of the ca...

Page 294: ...equencies e g 25Hz etc The filter output can also be connected to the measurement function blocks such as CVMMXN Measurements CMMXU Phase current measurement VMMXU Phase phase voltage measurement etc in order to report the extracted phasor values to the supervisory system e g MicroSCADA The following figure shoes typical configuration connections required to utilize this filter in conjunction with...

Page 295: ...econds K 35566 Amperes and minimal subsynchronous current trip level was set at IS0 300 Amperes primary Solution First the IED configuration shall be arranged as shown in Figure 102 Then the settings for SMAI HPAC filter and multipurpose function shall be derived from existing relay settings in the following way The subsynchronous current frequency is calculated as follows 50 18 5 31 5 s f Hz Hz H...

Page 296: ...Section Inverse time characteristics in the TRM p t A s B k i C in æ ö ç ç ç æ ö ç ç è ø è ø EQUATION13000031 V1 EN US Equation 106 In order to adapt to the previous relay characteristic the above equation can be re written in the following way 01 1 1 0 so s so t K I s T I I æ ö ç ç ç æ ö ç ç ç è ø è ø EQUATION13000032 V1 EN US Equation 107 Thus if the following rules are followed when multi purpo...

Page 297: ...BlkLevel2nd 5000 EnRestrainCurr Off RestrCurrInput PosSeq RestrCurrCoeff 0 00 RCADir 75 ROADir 75 LowVolt_VM 0 5 OC1 Setting Group1 Operation_OC1 On StartCurr_OC1 30 0 CurrMult_OC1 2 0 CurveType_OC1 Programmable tDef_OC1 0 00 k_OC1 1 00 tMin1 30 tMin_OC1 1 40 ResCrvType_OC1 Instantaneous tResetDef_OC1 0 00 P_OC1 1 000 A_OC1 118 55 B_OC1 0 640 C_OC1 0 000 1MRK 511 401 UUS A Section 12 System protec...

Page 298: ...292 ...

Page 299: ...otection functions concerned can be blocked and an alarm given In case of large currents unequal transient saturation of CT cores with different remanence or different saturation factor may result in differences in the secondary currents from the two CT sets Unwanted blocking of protection functions during the transient stage must then be avoided Current circuit supervision CCSSPVC 87 must be sens...

Page 300: ...ircuits 13 2 Fuse failure supervision FUFSPVC IP14556 1 v3 13 2 1 Identification M14869 1 v4 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Fuse failure supervision FUFSPVC 13 2 2 Application SEMOD113803 4 v10 Different protection functions within the protection IED operates on the basis of the measured voltage in the relay point Examples are i...

Page 301: ...to a fuse failure event In cases where the line can have a weak infeed of zero sequence current this function shall be avoided A criterion based on delta current and delta voltage measurements can be added to the fuse failure supervision function in order to detect a three phase fuse failure This is beneficial for example during three phase transformer switching 13 2 3 Setting guidelines IP15000 1...

Page 302: ...quirements The mode selector enables selecting interactions between the negative sequence and zero sequence algorithm In normal applications the OpModeSel is set to either V2I2 for selecting negative sequence algorithm or V0I0 for zero sequence based algorithm If system studies or field experiences shows that there is a risk that the fuse failure function will not be activated due to the system co...

Page 303: ...ent for the function according to the setting GlobalBaseSel 13 2 3 4 Zero sequence based M13683 43 v8 The IED setting value 3V0PU is given in percentage of the base voltage VBase The setting of 3V0PU should not be set lower than the value that is calculated according to equation 110 100 3 0 3 0 3 VBase V PU V EQUATION1759 ANSI V4 EN US Equation 110 where 3V0 is the maximal zero sequence voltage du...

Page 304: ...e primary voltage for operation of dU dt and ISetprim the primary current for operation of dI dt the setting of DVPU and DIPU will be given according to equation 112 and equation 113 DVPU VSet VBase prim 100 EQUATION1765 ANSI V2 EN US Equation 112 DIPU ISet IBase prim 100 ANSIEQUATION2385 V2 EN US Equation 113 The voltage thresholds VPPU is used to identify low voltage condition in the system Set ...

Page 305: ...sion VDSPVC VTS 60 13 3 2 Application GUID AD63BF6C 0351 4E48 9FB2 9AB5CF0C521E v2 Some protection functions operate on the basis of measured voltage at the relay point Examples of such protection functions are distance protection function undervoltage function and energisation check function These functions might mal operate if there is an incorrect measured voltage due to fuse failure or other k...

Page 306: ...F4E8E 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 Section 13 1MRK 511 401 UUS A Secondary system supervision 300 Bay cont...

Page 307: ... desired 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 114 Vdif Main block or Vdif Pilot alarm SetPrim Base V V 100 ANSI13000279 V1 EN US Equation 114 VSetPrim is defined as phase to neutral or phase to phase voltage dependent of the selected ConTypeMain and ConTypePilot If ConTypeMain and ConTy...

Page 308: ...302 ...

Page 309: ...nditions 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 synchronizi...

Page 310: ... decided 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 ma...

Page 311: ...e pole 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...

Page 312: ...vent 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 clearanc...

Page 313: ...acilitate 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 106 shows two substations where one 1 is energized and the other 2 is not energized Th...

Page 314: ...lBaseSelLine 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 ...

Page 315: ... supervision 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 ...

Page 316: ...yard 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 ...

Page 317: ...PHDIFFA FRDIFFM PHDIFFM INADVCLS VDIFFME FRDIFFME PHDIFFME Vbus VLine MODEAEN MODEMEN ANSI10000093 V1 EN US Figure 108 Connection of SESRSYN 25 function block in a single busbar arrangement Figure 108 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 ...

Page 318: ...KSC VDIFFSC FRDIFFA PHDIFFA FRDIFFM PHDIFFM INADVCLS VDIFFME FRDIFFME PHDIFFME Vbus VLine MODEAEN MODEMEN ANSI10000094 V1 EN US Figure 109 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 acco...

Page 319: ...DIFSYN FRDIFFOK FRDERIVA VOKSC VDIFFSC FRDIFFA PHDIFFA FRDIFFM PHDIFFM INADVCLS VDIFFME FRDIFFME PHDIFFME Vbus VLine MODEAEN MODEMEN ANSI10000095 V1 EN US Figure 110 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 ...

Page 320: ... 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 321: ...ocks 14 1 3 5 Breaker and a half M12330 3 v8 Figure 112 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 block...

Page 322: ...FFSC 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 TSTE...

Page 323: ... BUS1_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 Ti...

Page 324: ...SESRSYN 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 valu...

Page 325: ...unction 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 ...

Page 326: ...e between 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 comp...

Page 327: ...lue 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 d...

Page 328: ...ManEnerg 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 lin...

Page 329: ...VMaxEnerg 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 ...

Page 330: ...equired circuit breaker dead time is used to determine the dead time setting value When simultaneous tripping and reclosing at the two line ends occurs line dead time is approximately equal to the auto recloser dead time If the auto reclosing dead time and line dead time differ then the line will be energized until the breakers at both ends have opened en04000146_ansi vsd Open Closed Operate time ...

Page 331: ... to pole discrepancy that arises when circuit breakers are provided with single phase operating devices These breakers need pole discrepancy protection They must also be coordinated with the single phase auto recloser and blocked during the dead time when a normal discrepancy occurs Alternatively they should use a trip time longer than the set single phase dead time For the individual line breaker...

Page 332: ...ction zones indicating faults outside the own line are typically connected to inhibit the auto recloser Automatic reclosing should not be attempted when closing a CB and energizing a line onto a fault SOTF except when multiple shots are used where shots 2 etc will be started at SOTF Likewise a CB in a multi breaker busbar arrangement which was not closed when a fault occurred should not be closed ...

Page 333: ...closer will mean that the other sub system will start a three pole trip A permanent fault will cause the line protection to trip again when it recloses in an attempt to energize the line The auto reclosing function allows a number of parameters to be adjusted Examples number of auto reclosing shots auto reclosing program auto reclosing dead times for each shot 14 2 2 1 Auto reclosing operation Off...

Page 334: ...ycle for example charged operating gear CBCLOSED to ensure that the circuit breaker was closed when the line fault occurred and start was applied No signal at INHIBIT input that is no blocking or inhibit signal present After the start has been accepted it is latched in and an internal signal start is set It can be interrupted by certain events like an inhibit signal 14 2 2 3 Initiate auto reclosin...

Page 335: ...hout synchrocheck t1 3PhHS available for use when required It is activated by the RI_HS input A time extension delay tExtended t1 can be added to the dead time delay for the first shot It is intended to come into use if the communication channel for permissive line protection is lost In a case like this there can be a significant time difference in fault clearance at the two line ends where a long...

Page 336: ... phase or three phase auto reclosing first shot followed by 3 phase auto reclosing shots if selected Here the auto recloser is assumed to be On and Ready The circuit breaker is closed and the operation gear ready operating energy stored START input or STARTHS is received and sealed in The READY output is reset set to false ACTIVE output is set If TR2P and TR3P inputs are low i e single phase trip ...

Page 337: ...empted If the first trip is a three pole trip the auto reclosing will be inhibited No more shots are attempted The expression 1 2ph should be understood as Only one shot at two phase auto reclosing 14 2 2 12 ARMode 1 2ph 1 3ph 1 phase 2 phase or 3 phase reclosing in the first shot GUID 9C2FB801 F324 465E 8FD2 715A9C3D0BD8 v2 At single pole or two pole tripping the operation is as in the example de...

Page 338: ... when the set number of reclosing shots have been reached 14 2 2 14 External selection of auto reclosing mode M12391 241 v5 The auto reclosing mode can be selected by use of available logic function blocks Below is an example where the choice of mode ARMode 3ph or ARMode 1 2 3ph is done from a hardware function key at the front of the IED but alternatively there can for example be a physical selec...

Page 339: ... then cut interrupted The minimum breaker closing command pulse length is always 50ms At the issue of the breaker closing command the appropriate auto recloser operation counter is incremented There is a counter for each type of auto reclosing command and one for the total number of auto reclosing commands 14 2 2 17 Transient fault M12391 208 v4 After the breaker closing command the reclaim timer ...

Page 340: ...here is a requirement that a lock out is generated when the auto reclosing attempt fails This is done with logic connected to the in and outputs of the auto recloser and connected to binary I O as required Many alternative ways of performing the logic exist depending on whether manual circuit breaker closing is interlocked in the IED whether an external physical lock out relay exists and whether t...

Page 341: ...US Figure 116 Lock out arranged with internal logic with manual closing going through in IED 14 2 2 20 Evolving fault M12391 217 v4 An evolving fault starts as a single phase fault which leads to single pole tripping and then the fault spreads to another phase The second fault is then cleared by three pole tripping The auto recloser will first receive a start signal START without any three phase s...

Page 342: ...nctions but the circuit breaker is still not closed This is done by setting AutoCont Enabled and tAutoContWait to the required delay for the function to proceed without a new start 14 2 2 22 Thermal overload protection holding the auto recloser back M12391 226 v3 If the THOLHOLD input thermal overload protection holding auto reclosing back is activated it will keep the auto recloser on a hold unti...

Page 343: ...prevent a start from being accepted Such signals can come from protection for a line connected shunt reactor from transfer trip receive from back up protection functions busbar protection trip or from breaker failure protection When the circuit breaker open position is set to start the auto recloser then manual opening must also be connected here The inhibit is often a combination of signals from ...

Page 344: ...ivating SKIPHS input before the STARTHS high speed start input is activated The replacement is done for the 1st shot RI The START input should be connected to the trip function SMPPTRC output which starts the auto recloser for 1 2 3 phase operation It can also be connected to a binary input for start from an external contact A logical OR gate can be used to combine the number of start sources If S...

Page 345: ...l Trip by Switch Onto Fault It is usually connected to the switch onto fault output of line protection if multi shot auto reclosing attempts are used The input will start the shots two to five WAIT Used to hold back reclosing of the low priority unit during sequential auto reclosing See Recommendation for multi breaker arrangement below The signal is activated from output WFMASTER on the second br...

Page 346: ...e reclaim timer wait an auto recloser acting as slave is waiting for a release from the master to proceed with its own reclosing sequence ACTIVE Indicates that the auto recloser is active from start until end of reset time BLOCKED Indicates that auto recloser is temporarily or permanently blocked CLOSECMD Connect to a binary output for circuit breaker closing command COUNT1P COUNT2P COUNT3P1 COUNT...

Page 347: ... auto recloser is ready for a new and complete auto reclosing sequence It can be connected to the zone extension if a line protection should have extended zone reach before auto reclosing SETON Indicates that auto recloser is switched on and operative SUCCL If the circuit breaker closing command is given and the circuit breaker is closed within the set time interval tUnsucCl the SUCCL output is ac...

Page 348: ... ACTIVE UNSUCCL SUCCL CLOSECMD 1PT1 WFMASTER RESET RI THOLHOLD READY TRSOTF SYNC INPUT xx xx xx xx xx xx xx xx xx xx OR OR OUTPUT xx xx xx xx 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 117 Example of I...

Page 349: ...o figure 119 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 W...

Page 350: ... unsuccessful 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 circu...

Page 351: ...CLOSEMD 52a SMBRREC 79 ANSI04000137 V3 EN US Figure 119 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 14 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 s...

Page 352: ...ContWait 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 ci...

Page 353: ...y cycle 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 UnsucC...

Page 354: ...um 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 re...

Page 355: ...eclosing 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 multi...

Page 356: ...3 4 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...

Page 357: ...nction 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 rea...

Page 358: ...description 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 communicati...

Page 359: ...ILO SXSWI 189 989 IEC 61850 QCBAY 152 ANSI05000116 V1 EN US Figure 121 Signal flow between apparatus control function blocks when all functions are situated within the IED 1MRK 511 401 UUS A Section 14 Control Bay control REC670 2 2 ANSI 353 Application manual ...

Page 360: ...CV SCILO XLNPROXY GOOSEXLNRCV XLNPROXY QA1 QB1 QB9 GOOSEover process bus IEC16000070 1 EN vsdx IEC16000070 V1 EN US Figure 122 Signal flow between apparatus control functions with XCBR and XSWI located in a breaker IED Section 14 1MRK 511 401 UUS A Control 354 Bay control REC670 2 2 ANSI Application manual ...

Page 361: ...ted originator categories for each PSTO value are shown in Table 33 Table 33 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 ...

Page 362: ... not 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 ...

Page 363: ...check 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...

Page 364: ...it switch SXSWI with mandatory functionality 14 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 ...

Page 365: ... EN US Figure 124 Configuration with XLNPROXY and GOOSEXLNRCV where all the IEC 61850 modelled data is used including selection 1MRK 511 401 UUS A Section 14 Control Bay control REC670 2 2 ANSI 359 Application manual ...

Page 366: ...e switch 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 consid...

Page 367: ...n The 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 14 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...

Page 368: ...mber 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 ...

Page 369: ...e solution in Figure 126 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 128 Application principle for an alternative reservation solution 14 3 2 Interaction between modules M16626 3 v8 A typical bay with...

Page 370: ... be 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 Th...

Page 371: ...Synchronizer 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 ...

Page 372: ...sition 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 129 Example overview of the interactions ...

Page 373: ...l according 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 addit...

Page 374: ...code 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 I...

Page 375: ...aker 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 functi...

Page 376: ...rs 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 lim...

Page 377: ...me 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 ...

Page 378: ... 189G 289G 989 989G WA1 A WA2 B WA7 C 789 en04000478_ansi vsd 152 ANSI04000478 V1 EN US Figure 130 Switchyard layout ABC_LINE 3 M13560 4 v5 The signals from other bays connected to the module ABC_LINE 3 are described below 14 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 sta...

Page 379: ...OPTR 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 131 Signals from bypass busbar in line bay n 14 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 a...

Page 380: ...s valid 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...

Page 381: ...akers 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 ...

Page 382: ...TR 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 133 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 abov...

Page 383: ...89G_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_O...

Page 384: ...yard layout ABC_BC 3 14 4 3 2 Configuration M13553 138 v4 The signals from the other bays connected to the bus coupler module ABC_BC are described below 14 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 tran...

Page 385: ...ANSI04000481 V1 EN US Figure 135 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 ...

Page 386: ..._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 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 vs...

Page 387: ...oupler 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 B...

Page 388: ...C_12 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 139 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 ver...

Page 389: ...2_CL 0 VP_BC_12 1 BBTR_OP 1 VP_BBTR 1 14 4 4 Interlocking for transformer bay AB_TRAFO 3 IP14149 1 v2 14 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 140 The function is used when there is no disconnector between circuit breaker and transformer Otherwise the interloc...

Page 390: ... The signals from other bays connected to the module AB_TRAFO are described below 14 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 Section 14 1MRK 511 401 UUS A Control 384 Bay control REC670 2 2 ANSI Application...

Page 391: ...h status 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 14 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 inpu...

Page 392: ...ich 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 142 Switchyard layout A1A2_BS 3 M15111 4 v3 The signals from other bays connected to the module A1A2_BS are described below 14 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 ...

Page 393: ...nsformer 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 T...

Page 394: ...y n 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 ANSI...

Page 395: ... 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 A1A2 EXDU_BC sect 1 EXDU_BC sect 2 ANSI04000491 V1 EN US Figure 145 Signals from any bays for a bus section circuit breaker between sections B1 and B2 14 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 15...

Page 396: ...d below 14 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...

Page 397: ... the 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 c...

Page 398: ...bus 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 149 Signals from any bays in section A2 to a bus section disconn...

Page 399: ... B2 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 151 Signals from any bays in section B2 to a bus section disconnector 14 4 6 3 Signals in double breaker arrangement M13542 80 v5 If the busbar is divided...

Page 400: ...f all 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 va...

Page 401: ...or 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 154 Signals from double breaker bays in section A2 to a bus section disconnector For a bus section disconnector these conditio...

Page 402: ...bay n sect B2 EXDU_DB bay 1 sect B2 EXDU_DB bay n sect B2 AND AND ANSI04000502 V1 EN US Figure 156 Signals from double breaker bays in section B2 to a bus section disconnector 14 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 ...

Page 403: ...is 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 14 4 7 Interlocking for busbar grounding switch BB_ES 3 IP14164 1 v4 14 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 accor...

Page 404: ...on 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 statu...

Page 405: ...2_BS 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 189OPT...

Page 406: ...n sect A2 AND DCOPTR A1 A2 EXDU_BB bay 1 sect A2 EXDU_DC A1 A2 AND AND ANSI04000507 V1 EN US Figure 161 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 Section 14 1MRK 511 401 UUS A Control 400 Bay control REC670 2 2 ANSI Application manual ...

Page 407: ... same 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 163 Sig...

Page 408: ...rs 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 165 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...

Page 409: ...guration described in section Signals in single breaker arrangement 14 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 166 Busbars divided by b...

Page 410: ...r double 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 ...

Page 411: ...ion then set the corresponding inputs as follows VOLT_OFF 1 VOLT_ON 0 14 4 9 Interlocking for breaker and a half diameter BH 3 IP14173 1 v3 14 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 168 1MRK 511 401 UUS A Section 14 Control Bay contro...

Page 412: ...r BH_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 14 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 diagra...

Page 413: ... 90 Tap changer control and supervision 6 binary inputs TCMYLTC 84 Tap changer control and supervision 32 binary inputs TCLYLTC 84 14 5 2 Application SEMOD159067 1 v2 SEMOD159053 5 v5 When the load in a power network is increased the voltage will decrease and vice versa To maintain the network voltage at a constant level power transformers are usually equipped with on load tap changer This alters ...

Page 414: ...ransformers whereas the middle alternative does not require any communication The voltage control includes many extra features such as possibility to avoid simultaneous tapping of parallel transformers hot stand by regulation of a transformer within a parallel group with a LV CB open compensation for a possible capacitor bank on the LV side bay of a transformer extensive tap changer monitoring inc...

Page 415: ...rmation about the control location is given to TR1ATCC 90 or TR8ATCC 90 function through connection of the Permitted Source to Operate PSTO output of the QCBAY function block to the input PSTO of the TR1ATCC 90 or TR8ATCC 90 function block Control Mode SEMOD159053 35 v4 The control mode of the automatic voltage control for tap changer function TR1ATCC 90 for single control and TR8ATCC 90 for paral...

Page 416: ...presents a three phase group of phase current with the highest current in any of the three phases considered As only the highest of the phase current is considered it is also possible to use one single phase current as well as two phase currents In these cases the currents that are not used will be zero For I3P2 and V3P2 the setting alternatives are any individual phase current voltage as well as ...

Page 417: ...r current protection that blocks the load tap changer in case of over current above harmful levels The voltage measurement on the LV side can be made single phase ground However it shall be remembered that this can only be used in solidly grounded systems as the measured phase ground voltage can increase with as much as a factor 3 in case of ground faults in a non solidly grounded system The analo...

Page 418: ...ange Lower Cmd ANSI06000489 2 en vsd D D V V DVin DVin ANSI06000489 V2 EN US Figure 170 Control actions on a voltage scale During normal operating conditions the busbar voltage VB stays within the outer deadband interval between V1 and V2 in figure 170 In that case no actions will be taken by TR1ATCC 90 However if VB becomes smaller than V1 or greater than V2 an appropriate raise or lower timer wi...

Page 419: ...riate VRAISE or VLOWER command is initiated The purpose of the time delay is to prevent unnecessary load tap changer operations caused by temporary voltage fluctuations and to coordinate load tap changer operations in radial networks in order to limit the number of load tap changer operations This can be done by setting a longer time delay closer to the consumer and shorter time delays higher up i...

Page 420: ...1 are for 30 60 90 120 150 180 seconds settings for t1 and 10 seconds for tMin t1 180 t1 150 t1 120 t1 90 t1 60 t1 30 IEC06000488_2_en vsd IEC06000488 V2 EN US Figure 171 Inverse time characteristic for TR1ATCC 90 and TR8ATCC 90 The second time delay t2 will be used for consecutive commands commands in the same direction as the first command It can have a definite or inverse time characteristic ac...

Page 421: ...ed by the setting parameter OperationLDC When it is enabled the voltage VL will be used by the Automatic voltage control for tap changer function TR1ATCC 90 for single control and TR8ATCC 90 for parallel control for voltage regulation instead of VB However TR1ATCC 90 or TR8ATCC 90 will still perform the following two checks 1 The magnitude of the measured busbar voltageVB shall be within the secur...

Page 422: ...l for tap changer single control TR1ATCC 90 and parallel control TR8ATCC 90 1 Automatic load voltage adjustment proportional to the load current 2 Constant load voltage adjustment with four different preset values In the first case the voltage adjustment is dependent on the load and maximum voltage adjustment should be obtained at rated load of the transformer In the second case a voltage adjustme...

Page 423: ...ol ATCC 90 TR1ATCC x TR8ATCC x Automatic control of parallel transformers SEMOD159053 135 v5 Control of parallel transformers means control of two or more power transformers connected to the same busbar on the LV side and in most cases also on the HV side Special measures must be taken in order to avoid a runaway situation where the tap changers on the parallel transformers gradually diverge and e...

Page 424: ...ll regulate the voltage in accordance with the principles for Automatic voltage control Selection of the master is made by activating the binary input FORCMAST in TR8ATCC 90 function block for one of the transformers in the group The followers can act in two alternative ways depending on the setting of the parameter MFMode When this setting is Follow Cmd raise and lower commands VRAISE and VLOWER ...

Page 425: ...rol with the reverse reactance method SEMOD159053 145 v4 Consider Figure 174 with two parallel transformers with equal rated data and similar tap changers The tap positions will diverge and finally end up in a runaway tap situation if no measures to avoid this are taken Load T1 IL T2 VB VL IT1 IT2 en06000486_ansi vsd ANSI06000486 V1 EN US Figure 174 Parallel transformers with equal rated data In t...

Page 426: ...Effectively this means that whereas the line voltage drop compensation in figure 172 gave a voltage drop along a line from the busbar voltage VB to a load point voltage VL the line voltage drop compensation in figure 175 gives a voltage increase actually by adjusting the ratio XL RL with respect to the power factor the length of the vector VL will be approximately equal to the length of VB from VB...

Page 427: ...the lower VL value Consequently when the busbar voltage increases T1 will be the one to tap down and when the busbar voltage decreases T2 will be the one to tap up The overall performance will then be that the runaway tap situation will be avoided and that the circulating current will be minimized Parallel control with the circulating current method SEMOD159053 159 v5 Two transformers with differe...

Page 428: ...VBmean will then be used in each IED instead of VB for the voltage regulation thus assuring that the same value is used by all TR8ATCC functions and thereby avoiding that one erroneous measurement in one transformer could upset the voltage regulation At the same time supervision of the VT mismatch is also performed This works such that if a measured voltage VB differs from VBmean with more than a ...

Page 429: ...mean The calculated no load voltage will then be compared with the set voltage VSet A steady deviation which is outside the outer deadband will result in VLOWER or VRAISE being initiated alternatively In this way the overall control action will always be correct since the position of a tap changer is directly proportional to the transformer no load voltage The sequence resets when VBmean is inside...

Page 430: ... for tap changer parallel control TR8ATCC 90 will select the transformer with the greatest voltage deviation Vdi to tap first That transformer will then start timing and after time delay t1 the appropriate VRAISE or VLOWER command will be initiated If now further tapping is required to bring the busbar voltage inside VDeadbandInner the process will be repeated and the transformer with the then gre...

Page 431: ...e LV side of the transformer within the deadband of the busbar voltage Homing operation with the master follower method SEMOD159053 216 v3 If one or more follower has its LV circuit breaker open and its HV circuit breaker closed and if OperHoming Enabled this follower continues to follow the master just as it would have made with the LV circuit breaker closed On the other hand if the LV circuit br...

Page 432: ...OperationAdapt is Enabled and the master is put in manual control with the followers still in parallel master follower control In this situation the followers will continue to follow the master the same way as when it is in automatic control If one follower in a master follower parallel group is put in manual mode still with the setting OperationAdaptEnabled the rest of the group will continue in ...

Page 433: ...an be compensated for Load T1 IL T2 Icc T2 I cc T1 VB VL IT1 IT2 IC I T2 I C Load T1 IL T2 Icc T2 Icc T1 VB VL IT1 IT2 IT2 IT1 IT1 IC en06000512_ansi vsd ANSI06000512 V1 EN US Figure 177 Capacitor bank on the LV side From figure 177 it is obvious that the two different connections of the capacitor banks are completely the same regarding the currents in the primary network However the CT measured c...

Page 434: ...der to make possible switching of three steps in a capacitor bank in one bay Power monitoring SEMOD159053 251 v4 The level with sign of active and reactive power flow through the transformer can be monitored This function can be utilized for different purposes for example to block the voltage control function when active power is flowing from the LV side to the HV side or to initiate switching of ...

Page 435: ...has to consider in the parallel control In a simple case when only the switchgear in the transformer bays needs to be considered there is a built in function in TR8ATCC 90 block that can provide information on whether a transformer is connected to the parallel group or not This is made by connecting the transformer CB auxiliary contact status to TR8ATCC 90 function block input DISC which can be ma...

Page 436: ...ssages only from the voltage control functions working in parallel according to the current station configuration When the parallel voltage control function detects that no other transformers work in parallel it will behave as a single voltage control function in automatic mode Exchange of information between TR8ATCC functions SEMOD159053 267 v6 Each transformer in a parallel group needs an Automa...

Page 437: ... transformer that is master in the master follower parallel control mode termReadyForMSF Activated when the transformer is ready for master follower parallel control mode raiseVoltageOut Order from the master to the followers to tap up lowerVoltageOut Order from the master to the followers to tap down Table 38 Analog signals Signal Explanation voltageBusbar Measured busbar voltage for this transfo...

Page 438: ...rom this there is also a setting in each TR8ATCC T1RXOP Off On T8RXOP Off On This setting determines from which of the other transformer individuals that data shall be received Settings in the three TR8ATCC blocks for the transformers in figure 179 would then be according to the table 39 Table 39 Setting of TxRXOP TrfId T1 T1RXOP Off T2RXOP On T3RXOP On T4RXOP Off T5RXOP Off T6RXOP Off T7RXOP Off ...

Page 439: ...Vmax see figure 170 an alarm will be initiated or further VRAISE commands will be blocked If permitted by setting in PST configuration Fast Step Down FSD of the tap changer will be initiated in order to re enter the voltage into the range Vmin VB Vmax The FSD function is blocked when the lowest voltage tap position is reached The time delay for the FSD function is separately set The output VHIGH w...

Page 440: ... given by the setting parameter tRevAct and the output signal REVACBLK will be set The reversed action feature can be turned off on with the setting parameter OperationRA CmdErrBk manually reset Alarm Auto Block Auto Man Block Typical operating time for a tap changer mechanism is around 3 8 seconds Therefore the function should wait for a position change before a new command is issued The command ...

Page 441: ... TCERRAL will be activated depending on the actual parameter setting In correct operation the TCINPROG shall appear during the VRAISE VLOWER output pulse and disappear before the tTCTimeout time has elapsed This error condition can be reset by the input RESETERR on TCMYLTC 84 function block or alternatively by changing control mode of TR1ATCC 90 or TR8ATCC 90 function to Manual and then back to Au...

Page 442: ...0mA and I_Min 4mA Very low or negative mA values Indication of hardware fault on BIM or MIM module Supervision of the input hardware module is provided by connecting the corresponding error signal to the INERR input input module error or BIERR on TCMYLTC or TCLYLTC 84 function block Interruption of communication with the tap changer The outputs POSERRAL and AUTOBLK or TOTBLK will be set This error...

Page 443: ...y reset Enabled Disabled TR1ATCC 90 or TR8ATCC 90 function can be blocked for automatic control via the setting parameter AutoBlock which can be set Enabled Disabled from the local HMI or PST The output AUTOBLK will be set TR1ATCC 90 or TR8ATCC 90 blockings that can be made via input signals in the function block are listed in table 42 Table 42 Blocking via binary inputs Input name Activation Desc...

Page 444: ...pervise if the transformer LV circuit breaker is closed or not The outputs TRFDISC MFERR and AUTOBLK will be activated The followers will also be blocked by mutual blocking in this situation Blocking will be removed when the transformer is reconnected input signal DISC set back to zero One transformer in a parallel group switched to manual control automatically reset Auto Block When the setting Op...

Page 445: ...to send a mutual blocking signal to the master This will prevent a situation where the rest of the group otherwise would be able to tap away from the blocked individual and that way cause high circulating currents Thus when a follower is blocked it broadcasts a mutual block on the horizontal communication The master picks up this message and blocks its automatic operation as well Besides the condi...

Page 446: ... bouncing etc Before the right timing data is set it may then happen that TR1ATCC 90 or TR8ATCC 90 becomes totally blocked or blocked in auto mode because of incorrect settings In this situation it is recommended to temporarily set these types of blockings to alarm instead until the commissioning of all main items are working as expected Tap Changer position measurement and monitoring SEMOD159053 ...

Page 447: ...etting tStable e New tap position reached making the signal tap change in progress disappear from the tap changer and a new position reported f The new tap position available in TCMYLTC 84 or TCLYLTC 84 g Fixed extension 2 sec of TCINPROG made internally in TCMYLTC 84 or TCLYLTC 84 function h Safety margin to avoid that TCINPROG extends beyond tTCTimeout The first use is to reset the Automatic vol...

Page 448: ...situation Hunting detection SEMOD159053 361 v4 Hunting detection is provided in order to generate an alarm when the voltage control gives an abnormal number of commands or abnormal sequence of commands within a pre defined period of time There are three hunting functions 1 The Automatic voltage control for tap changer function TR1ATCC 90 for single control and TR8ATCC 90 for parallel control will ...

Page 449: ...command to reset the counter is issued It is therefore necessary to check that the IED internal time is correct before these counters are reset The counter value can be reset on the local HMI under Main menu Reset Reset counters TransformerTapControl YLTC 84 TCMYLTC 1 or TCLYLTC 1 Reset Counter and ResetCLCounter Both counters and their last reset dates are shown on the local HMI as service values...

Page 450: ...tion to be taken in case any of the three phase currents on the HV side has exceeded Iblock MFPosDiffBk Selection of action to be taken in case the tap difference between a follower and the master is greater than MFPosDiffLim OVPartBk Selection of action to be taken in case the busbar voltage VB exceeds Vmax RevActPartBk Selection of action to be taken in case Reverse Action has been activated Tap...

Page 451: ...ng is Enabled the voltage control function TR1ATCC 90 for single control and TR8ATCC 90 for parallel control is blocked for automatic control Operation FSDMode This setting enables disables the fast step down function Enabling can be for automatic and manual control or for only automatic control alternatively tFSD Time delay to be used for the fast step down tapping Voltage UseCmdUSet This setting...

Page 452: ...er command t2Use Selection of time characteristic definite or inverse for t2 t2 Time delay for consecutive raise lower commands In the circulating current method the second third etc commands are all executed with time delay t2 independently of which transformer in the parallel group that is tapping In the master follower method with the follow tap option the master is executing the second third e...

Page 453: ...tor diagram for a transformer controlled in a parallel group with the reverse reactance method and with no circulation for example assume two equal transformers on the same tap position The load current lags the busbar voltage VB with the power factor j and the argument of the impedance Rline and Xline is designated j1 VB jIT Xline VL Xline Rline Zline IT IT Rline j j1 j2 DV en06000626_ansi vsd AN...

Page 454: ... 125 To achieve a more correct regulation an adjustment to a value of j2 slightly less than 90 2 4 less can be made The effect of changing power factor of the load will be that j2 will no longer be close to 90 resulting in VL being smaller or greater than VB if the ratio Rline Xline is not adjusted Figure 182 shows an example of this where the settings of Rline and Xline for j 11 from figure 181 h...

Page 455: ...ransformers strongly together with no or only a small difference in tap position but the voltage regulation as such will be more sensitive to a deviation from the anticipated power factor A too high setting of Xline can cause a hunting situation as the transformers will then be prone to over react on deviations from the target value There is no rule for the setting of Xline such that an optimal ba...

Page 456: ... VSet is given in percent of VBase and it is proportional to the load current with the set value reached at the nominal current I2Base RevAct OperationRA This setting enables disables the reverse action partial blocking function tRevAct After the reverse action has picked up this time setting gives the time during which the partial blocking is active RevActLim Current threshold for the reverse act...

Page 457: ... means pickup for all values to the right of the setting Reference is made to figure 178 for definition of forward and reverse direction of power through the transformer en06000634_2_en vsd P P IEC06000634 V2 EN US Figure 183 Setting of a negative value for P P When the active power falls below the value given by this setting the output PLTREV will be activated after the time delay tPower It shall...

Page 458: ...if the circulating current exceeds CircCurrLimit CircCurrLimit Pick up value for the circulating current blocking function The setting is made in percent of I2Base tCircCurr Time delay for the circulating current blocking function Comp When parallel operation with the circulating current method is used this setting increases or decreases the influence of the circulating current on the regulation I...

Page 459: ...with the circulating current method as well for parallel control with the master follower method VTmismatch Setting of the level for activation of the output VTALARM in case the voltage measurement in one transformer bay deviates to the mean value of all voltage measurements in the parallel group tVTmismatch Time delay for activation of the output VTALARM T1RXOP T8RXOP This setting is set Enabled ...

Page 460: ...actor The setting of this factor gives the weighting of the deviation with respect to the load current InitCLCounter The ContactLife counter monitors the remaining number of operations decremental counter The setting InitCLCounter then gives the start value for the counter that is the total number of operations at rated load that the tap changer is designed for EnabTapCmd This setting enables disa...

Page 461: ...as two operating inputs UP and DOWN one blocking input BLOCK and one operator position input PSTO SLGAPC can be activated both from the local HMI and from external sources switches via the IED binary inputs It also allows the operation from remote like the station computer SWPOSN is an integer value output giving the actual output number Since the number of positions of the switch can be establish...

Page 462: ...803 5 v8 Selector mini switch VSGAPC function is a multipurpose function used in the configuration tool in PCM600 for a variety of applications as a general purpose switch VSGAPC can be used for both acquiring an external switch position through the IPOS1 and the IPOS2 inputs and represent it through the single line diagram symbols or use it in the configuration through the outputs POS1 and POS2 a...

Page 463: ...ble on the single line diagram SLD this function block has two control modes settable through CtlModel Dir Norm and SBO Enh 14 8 Generic communication function for Double Point indication DPGAPC SEMOD55384 1 v4 14 8 1 Identification GUID E16EA78F 6DF9 4B37 A92D 5C09827E2297 v3 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Generic communication...

Page 464: ...OSITION will have the latest updated timestamp of the inputs OPEN and CLOSE When the input signal VALID is inactive DPGAPC function forces the position to intermediated state When the value of the input signal VALID changes the timestamp of the output POSITION will be updated as the time when DPGAPC function detects the change Refer to Table 44 for the description of the input output relationship ...

Page 465: ...PC 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 function block is REMOTE 14 9 3 Setting guidelines SEMOD176518 4 v6 The parameters for the single point generic control 8 signals SPC8GAPC function are set via the local HMI or PCM600...

Page 466: ...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 time 300 count 5 would give 5 positive 100 ms pulses 300 ms apart For description of the DNP3 protocol implementation refer to the Communication manual 14 10 3 Setting guidelines SEMOD15...

Page 467: ...ia 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 186 shows a close operation An open breaker operation is performed in a similar way but without the synchro check condition Single command function SINGLECMD CMDOUTy OUTy Close CB1 AND User defined conditions Synchro chec...

Page 468: ...vice 1 User defined conditions Configuration logic circuits en04000208_ansi vsd AND ANSI04000208 V2 EN US Figure 188 Application example showing a logic diagram for control of external devices via configuration logic circuits 14 11 3 Setting guidelines M12448 3 v2 The parameters for Single command 16 signals SINGLECMD are set via the local HMI or PCM600 Section 14 1MRK 511 401 UUS A Control 462 Ba...

Page 469: ... is 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 fun...

Page 470: ...464 ...

Page 471: ...s directly related to the transmission channel speed and security against false or lost signals Communication speed or minimum time delay is always of utmost importance because the purpose for using communication is to improve the tripping speed of the scheme To avoid false signals that could cause false tripping it is necessary to pay attention to the security of the communication channel At the ...

Page 472: ...ere on the protected line if the communication channel is out of service On the other hand it is less secure than permissive schemes because it will trip for external faults within the reach of the tripping function if the communication channel is out of service Inadequate speed or dependability can cause spurious tripping for external faults Inadequate security can cause delayed tripping for inte...

Page 473: ...s inhibited by a forward directed distance or directional current or directional ground fault element Since the scheme is sending the blocking signal during conditions where the protected line is healthy it is common to use the line itself as communication media PLC The scheme can be used on all line lengths The blocking scheme is very dependable because it will operate for faults anywhere on the ...

Page 474: ...n permissive schemes the permission to trip is sent from the local end to the remote end s when the protection at the local end has detected a fault on the protected object The received signal s is combined with an overreaching zone and gives an instantaneous trip if the received signal is present during the time the chosen zone has detected a fault Either end may send a permissive or command sign...

Page 475: ...e to the fault current distribution the overreaching zone can operate only after the fault has been cleared at the terminal nearest to the fault There is a certain risk that in case of a trip from an independent tripping zone the zone issuing the send signal CS resets before the overreaching zone has started at the remote terminal To assure a sufficient duration of the received signal CR the send ...

Page 476: ... at one end at least for faults anywhere along the protected circuit Teleprotection operating in permissive overreaching scheme must consider besides the general requirement of fast and secure operation also consider requirement on the dependability Inadequate security can cause unwanted tripping for external faults Inadequate speed or dependability can cause delayed tripping for internal faults o...

Page 477: ...fected by fault generated noise may not be suitable for conventional permissive schemes that rely on a signal transmitted during a protected line fault With power line carrier for example the communication signal may be attenuated by the fault especially when the fault is close to the line end thereby disabling the communication channel To overcome the lower dependability in permissive schemes an ...

Page 478: ... In some applications the equipment shall be able to receive while transmitting and commands may be transmitted over longer time period than for other teleprotection systems 15 1 3 Setting guidelines IP15021 1 v1 M13869 4 v4 The parameters for the scheme communication logic function are set via the local HMI or PCM600 Configure the zones used for the CS send and for scheme communication tripping b...

Page 479: ...underreaching scheme M13869 25 v4 Set Operation Enabled Set SchemeType Permissive UR Set tCoord 0 ms Set tSendMin 0 1 s Set Unblock Disabled Set tSecurity 0 035 s 15 1 3 4 Permissive overreaching scheme M13869 34 v4 Set Operation Enabled Set Scheme type Permissive OR Set tCoord 0 ms Set tSendMin 0 1 s 0 s in parallel line applications Set Unblock Disabled Set tSecurity 0 035 s 15 1 3 5 Unblocking ...

Page 480: ...umber Current reversal and weak end infeed logic for distance protection 3 phase ZCRWPSCH 85 15 2 2 Application IP15023 1 v1 15 2 2 1 Current reversal logic M13895 4 v6 To avoid this kind of disturbances a fault current reversal logic transient blocking logic can be used The unwanted operations that might occur can be explained by looking into Figure 193 and Figure 194 Initially the protection A2 ...

Page 481: ...psed To achieve this the reverse zone on the distance protection shall be connected to input IRV and the output IRVL shall be connected to input BLKCS on the communication function block ZCPSCH The function can be blocked by activating the input IRVBLK or the general BLOCK input 15 2 2 2 Weak end infeed logic M13895 16 v7 Permissive communication schemes can basically operate only when the protect...

Page 482: ... The echo signal would block the operation of the distance protection at the remote line end and in this way prevents the correct operation of a complete protection scheme A separate direct intertrip channel must be arranged from remote end when a trip or accelerated trip is given there The intertrip receive signal is connect to input CRL The WEI function shall be set to WEI Echo Trip The WEI func...

Page 483: ... to obtain echo with trip Set tPickUpWEI to 10 ms a short delay is recommended to avoid that spurious carrier received signals will activate WEI and cause unwanted carrier send ECHO signals When single pole tripping is required a detailed study of the voltages during phase to phase and phase to ground faults should be done at different fault locations 15 3 Local acceleration logic ZCLCPSCH SEMOD52...

Page 484: ...low on the healthy phase when one or two of the other phases are faulty and the breaker has opened at remote end three phase Calculate the setting according to equation 127 min 0 5 Load Base I LoadCurr I EQUATION1320 V1 EN US Equation 127 where ILoadmin is the minimum load current on the line during normal operation conditions The timer tLoadOn is used to increase the security of the loss of load ...

Page 485: ...CH 85 15 4 2 Application M13919 3 v6 To achieve fast fault clearance of ground faults on the part of the line not covered by the instantaneous step of the residual overcurrent protection the directional residual overcurrent protection can be supported with a logic that uses communication channels One communication channel is used in each direction which can transmit an on off signal if required Th...

Page 486: ...curity time is used as a CR signal This also enables a permissive scheme to operate when the line fault blocks the signal transmission Set the tSecurity to 35 ms 15 4 3 Setting guidelines M13920 4 v7 The parameters for the scheme communication logic for residual overcurrent protection function are set via the local HMI or PCM600 The following settings can be done for the scheme communication logic...

Page 487: ... in a fault current reversal Assume that fault is near the B1 breaker B1 Relay sees the fault in Zone1 and A1 relay identifies the fault in Zone2 Note that the fault current is reversed in line L2 after the breaker B1 opening It can cause an unselective trip on line L2 if the current reversal logic does not block the permissive overreaching scheme in the IED at B2 en99000043_ansi vsd Strong source...

Page 488: ...d must reset before the send signal is initiated from B2 The delayed reset of output signal IRVL also ensures the send signal from IED B2 is held back till the forward direction element is reset in IED A2 15 5 2 2 Weak end infeed logic M15285 6 v5 Figure 197 shows a typical system condition that can result in a missing operation Note that there is no fault current from node B This causes that the ...

Page 489: ... be used The signal propagation time is in the range 3 10 ms km for most types of communication media In communication networks small additional time delays are added in multiplexers and repeaters Theses delays are less than 1 ms per process It is often stated that the total propagation time is less than 5 ms When a signal picks up or drops out there is a decision time to be added This decision ti...

Page 490: ...ime sequence of signaling at current reversal 15 5 3 2 Weak end infeed M13933 12 v6 The weak end infeed can be set by setting the parameter WEI to Off Echo or Echo Trip Operating zero sequence voltage when parameter WEI is set to Echo Trip is set with 3V0PU The zero sequence voltage for a fault at the remote line end and appropriate fault resistance is calculated To avoid unwanted trip from the we...

Page 491: ...ipping for single phase faults and three pole tripping for multi phase and evolving faults 1p 3p operating mode Single pole tripping for single pole faults two pole tripping for two pole faults and three pole tripping for three pole faults 1p 2p 3p operating mode The logic also issues a three pole tripping command when phase selection within the operating protection functions is not possible or wh...

Page 492: ...puts into one output Connect the output TRIP to the binary outputs on the IO board This signal can also be used for other purposes internally in the IED An example could be the starting of breaker failure protection The three outputs TR_A TR_B TR_C will always be activated at every trip and can be utilized on individual trip outputs if single pole operating devices are available on the circuit bre...

Page 493: ...ts PS_A PS_B and PS_C to achieve the tripping on the respective single pole trip outputs TR_A TR_B and TR_C The output TRIP is a general trip and is always activated independent of which phase is involved Depending on which phases are involved the outputs TR1P TR2P and TR3P will be activated as well When single pole tripping schemes are used a single phase autoreclosing attempt is expected to foll...

Page 494: ... with 3 phase trip for example time delayed overcurrent protection OR To prepare 3 phase trip for any trip signal SMBRREC PREP3P TR3P STN ANSI05000545 6 en vsdx ANSI05000545 V6 EN US Figure 200 The trip logic function SMPPTRC 94 used for single pole tripping application 16 1 2 3 Single two or three pole tripping M14828 15 v5 The single two three pole tripping mode provides single pole tripping for...

Page 495: ...chieved by activating input SETLKOUT The setting AutoLock Disabled means that the internal trip will not activate lock out so only initiation of the input SETLKOUT will result in lock out This is normally the case for overhead line protection where most faults are transient Unsuccessful autoreclose and back up zone tripping can in such cases be connected to initiate lock out by activating the inpu...

Page 496: ...C STN FWN REVN ANSI16000180 2 en vsdx SMPPTRC 94 BLOCK BLKLKOUT TRINP_3P TRINP_A TRINP_B TRINP_C PS_A PS_B PS_C 1PTRZ 1PTRGF P3PTR SETLKOUT RSTLKOUT CND TRIP TR_A TR_B TR_C TR1P TR2P TR3P CLLKOUT BFI_3P BFI_A BFI_B BFI_C STN FW REV ANSI16000180 V2 EN US Figure 201 Example of the connection of directional start logic The Start Matrix SMAGAPC merges start and directional output signals from differen...

Page 497: ...pLockout Sets the scheme for lock out Disabled only activates the closing circuit lock out output Enabled activates the closing circuit lock out output and latches the TRIP related outputs The normal selection is Disabled AutoLock Sets the scheme for lock out Disabled only activates lock out through the input SETLKOUT Enabled additionally allows lock out activation via the trip inputs The normal s...

Page 498: ... 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 reset of the outputs after the activation conditions no longer are fulfilled It is only used in Steady mode When used for direct tripping of circuit breaker s the of...

Page 499: ...7 2 device number Logic for group warning WRNCALH 16 4 1 1 Application GUID FC0DBB7B FF86 44BF 83D6 DDF120A176DE v1 Group warning logic function WRNCALH is used to route warning signals to LEDs and or output contacts on the IED WRNCALH output signal WARNING and the physical outputs allows the user to adapt the warning signal to physical tripping outputs according to the specific application needs ...

Page 500: ...propagate the time stamp and the quality of signals They have the suffix QT at the end of their function block name for example SRMEMORYQT 16 6 1 Application GUID F5D6F065 441B 4296 AC56 F4DC1F5487E3 v3 A set of standard logic blocks like AND OR etc and timers are available for adapting the IED configuration to the specific application needs Additional logic blocks that beside the normal logical f...

Page 501: ...onfiguration tool with the designation of the function block and the cycle time see example below IEC09000695_2_en vsd IEC09000695 V2 EN US Figure 202 Example designation serial execution number and cycle time for logic function IEC09000310 2 en vsd IEC09000310 V2 EN US Figure 203 Example designation serial execution number and cycle time for logic function that also propagates timestamp and quali...

Page 502: ...n M15322 3 v12 The Fixed signals function FXDSIGN has nine pre set fixed signals that can be used in the configuration of an IED either for forcing the unused inputs in other function blocks to a certain level value or for creating certain logic Boolean integer floating point string types of signals are available One FXDSIGN function block is included in all IEDs Example for use of GRP_OFF signal ...

Page 503: ...d to something which is the GRP_OFF signal in FXDSIGN function block I3PW1CT1 I3PW2CT1 I3P REFPDIF 87N ANSI11000084_1_en vsd GRP_OFF FXDSIGN ANSI11000084 V1 EN US Figure 205 REFPDIF 87N function inputs for normal transformer application 16 8 Boolean 16 to Integer conversion B16I SEMOD175715 1 v1 16 8 1 Identification SEMOD175721 2 v2 Function description IEC 61850 identification IEC 60617 identifi...

Page 504: ...t is Boolean 1 it corresponds to that integer 65535 is available on the output OUT B16I 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 B16I for 1 x 16 The sum of the value on each INx corresponds to the integer presented on the output OUT on the f...

Page 505: ...to an integer Each INx represents a value according to the table below from 0 to 32768 This follows the general formula INx 2x 1 where 1 x 16 The sum of all the values on the activated INx will be available on the output OUT as a sum of the values of all the inputs INx 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 6553...

Page 506: ... the BTIGAPC function block 16 10 Integer to Boolean 16 conversion IB16 SEMOD158367 1 v2 16 10 1 Identification SEMOD167941 2 v2 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Integer to boolean 16 conversion IB16 16 10 2 Application SEMOD158499 5 v4 Integer to boolean 16 conversion function IB16 is used to transform an integer into a set of 16...

Page 507: ...ame of input Type Default Description Value when activated Value when deactivated IN1 BOOLEAN 0 Input 1 1 0 IN2 BOOLEAN 0 Input 2 2 0 IN3 BOOLEAN 0 Input 3 4 0 IN4 BOOLEAN 0 Input 4 8 0 IN5 BOOLEAN 0 Input 5 16 0 IN6 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 I...

Page 508: ...ogic node representation function ITBGAPC will transfer an integer with a value between 0 to 65535 communicated via IEC 61850 and connected to the ITBGAPC function block to a combination of activated outputs OUTx where 1 x 16 The values of the different OUTx are according to the Table 45 If the BLOCK input is activated it freezes the logical outputs at the last value Table 45 Output signals Name o...

Page 509: ...FD1768A87 v2 The function TEIGAPC is used for user defined logics and it can also be used for different purposes internally in the IED An application example is the integration of elapsed time during the measurement of neutral point voltage or neutral current at earth fault conditions Settable time limits for warning and alarm are provided The time limit for overflow indication is fixed to 999999 ...

Page 510: ...pplication GUID 4C6D730D BB1C 45F1 A719 1267234BF1B9 v1 The function gives the possibility to monitor the level of integer 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 16 13 3 Setting guidelines GUID ADA3E806 BEF1 4D15 B270 207386A0AEE4 v2 For proper operation of compariso...

Page 511: ... 44F231982C59 v2 For absolute comparison between inputs Set the EnaAbs Absolute Set the RefSource Input REF Similarly for Signed comparison between inputs Set the EnaAbs Signed Set the RefSource Input REF For absolute comparison between input and setting Set the EnaAbs Absolute Set the RefSource Set Value SetValue shall be set between 2000000000 to 2000000000 Similarly for signed comparison betwee...

Page 512: ...nput and reference Signed Comparison is performed with signed values of input and reference 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 compariso...

Page 513: ...Prefix Kilo EqualBandHigh 5 0 of reference value EqualBandLow 5 0 of reference value Operation The function will set the outputs for the following conditions INEQUAL will set when the INPUT is between the ranges of 95 to 105 kA INHIGH will set when the INPUT crosses above 105 kA INLOW will set when the INPUT crosses below 95 kA If the comparison should be done between two current magnitudes then t...

Page 514: ...508 ...

Page 515: ... CVMMXN 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 511 401 UUS A Section 17 Monitoring ...

Page 516: ...rcurrent 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 ...

Page 517: ...suring 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 17 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 Zer...

Page 518: ...the 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 t...

Page 519: ...ere 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...

Page 520: ...ment 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 value in of...

Page 521: ...xamples 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...

Page 522: ...ure 207 it is necessary to do the following 1 Set correctly CT and VT data and phase angle reference channel PhaseAngleRef see Section Setting of the phase reference channel 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 s...

Page 523: ...um 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 ...

Page 524: ...lected 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 ...

Page 525: ... necessary to do the following 1 Set correctly all CT and VT and phase angle reference channel PhaseAngleRef see Section Setting of the phase reference channel 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 511 401 UUS A Section 17 Mon...

Page 526: ...ent 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...

Page 527: ...s necessary to do the following 1 Set correctly all CT and VT data and phase angle reference channel PhaseAngleRef see Section Setting of the phase reference channel 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 511 401 UUS A Section 17...

Page 528: ...oltage 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 17 2 Gas medium supervision SSIMG 63 GUID 358AD8F8 AE06 4AEA 9969 46E5299D5B4B v3 17 2 1 Identification GUID AD96C26E C3E5 4B21 9ED6 12E540954AC3 v4 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 de...

Page 529: ...aker 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...

Page 530: ...ased on received information 17 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 transform...

Page 531: ...2 device number Breaker monitoring SSCBR 17 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 cond...

Page 532: ... breaker 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 manufactur...

Page 533: ...10 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 an...

Page 534: ...n cycles 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...

Page 535: ...or 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 t...

Page 536: ...n change of status of trip output and start of main contact separation 17 5 Event function EVENT IP14590 1 v2 17 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 17 5 2 Application M12805 6 v11 When using a Substation Automation system with LON or SPA communication time tagg...

Page 537: ...rs 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 shoul...

Page 538: ...urbance 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 IND Event...

Page 539: ...ions 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 Indication IND Trip value recorder TVR and ...

Page 540: ...here are a number 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 ...

Page 541: ...tored 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 ove...

Page 542: ...155 173 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...

Page 543: ...ls 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 Disable...

Page 544: ...h Setting 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...

Page 545: ...gnals 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 parame...

Page 546: ... logical diagram 17 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 17 8 Fault locator LMBRFLO IP14592 1 v2 17 8 1 Identification M14892 1 v3 Function description I...

Page 547: ...ng is used to select the unit of length either in kilometer or miles for the distance to fault The distance to the fault which is calculated with a high accuracy is stored together with the recorded disturbances This information can be read on the local HMI uploaded to PCM600 and is available on the station bus according to IEC 61850 8 1 The distance to fault can be recalculated on the local HMI b...

Page 548: ...ut are set at zero Power system specific parameter settings are not general settings but specific setting included in the setting groups that is this makes it possible to change conditions for the Fault locator with short notice by changing setting group The source impedance is not constant in the network However this has a minor influence on the accuracy of the distance to fault calculation becau...

Page 549: ...t locator LMBRFLO 17 9 Limit counter L4UFCNT GUID 22E141DB 38B3 462C B031 73F7466DD135 v1 17 9 1 Identification GUID F3FB7B33 B189 4819 A1F0 8AC7762E9B7E v2 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Limit counter L4UFCNT 1MRK 511 401 UUS A Section 17 Monitoring Bay control REC670 2 2 ANSI 543 Application manual ...

Page 550: ...olling over to zero In this case periodic pulses will be generated at multiple overflow of the function 17 9 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 17 10 Running hour meter TEILGAPC 17 10 1 Identification GUID 3F9EF4FA 74FA 4D1D 88A0 E948B722B64F v1 F...

Page 551: ... C98E 4780 AB5B 12780566FFA2 v1 A typical power transformer is composed of Laminated steel core with copper or aluminium windings Solid refined paper insulation Highly refined mineral oil as insulating and cooling medium for the entire transformer The oil is cooled by a separate cooling system using air or water The core windings and insulation have specific thermal capabilities Losses in the wind...

Page 552: ... transformer loading beyond the nameplate rating Leakage flux density short circuit force and high electric stress on the insulation increases once size of the transformer increases Hence determination of hot spot temperature becomes more complex Therefore large transformers are more vulnerable than the smaller ones Consequences of transformer failures are more severe for larger sizes than for sma...

Page 553: ...Temperature Bottom oil Bottom of winding Height of transformer Average oil g H g x Top of winding IEC15000440 1 en vsdx IEC15000440 V1 EN US Figure 215 Thermal diagram Winding hot spot temperature depends on the oil temperature inside the winding load losses in the winding cooling type and ambient temperature For most transformers in service oil temperature inside a winding is difficult to measure...

Page 554: ...isk involved in the higher operating temperatures see Figure 216 The four types of loading are Normal life expectancy Normal life expectancy loading The transformer loading is continuous at rated output when operated under usual conditions Sacrifice of life expectancy Planned loading beyond nameplate Restricted to transformers that do not carry a continuous steady load and it is a normal planned r...

Page 555: ...Typical load cycles for example Impact of the increased currents and temperature leads to premature transformer failure and this may have an immediate short term effect or a cumulative long term effect Short term effect Reduction in dielectric strength due to the possible presence of gas bubbles which leads to super saturation of the oil and reduction in short circuit strength Long term effect Con...

Page 556: ...he estimation of transformer insulation life function LOLSPTR 26 49HS are set via the local HMI or PCM600 Minimum information about the transformer parameters which are required to decide the transformer insulation life are 1 Top oil temperature rise over ambient temperature at rated load 2 Average conductor temperature rise over ambient temperature at rated load 3 Winding hot spot temperature ris...

Page 557: ... single phase transformers If the transformer rating is less than 0 833 MVA the function considers this as a distribution transformer If the transformer rating is less than 33 3 MVA it is considered as a medium power transformer If the transformer rating is above 33 3 MVA it is considered as a larger power transformer NoOfWindings This setting is used to set the number of windings in the transform...

Page 558: ...he temperature inputs are converted into C for calculation Once the calculations are done the outputs in C are converted into F C The temperature unit will be selected as C All temperature inputs will be taken as they are and the output is given in C GUID 4D6F8802 AFCC 4277 8844 A87A98A5F2C8 v1 LOLSPTR 26 49HS can work with n 1 winding CT availability that is if the given transformer has three win...

Page 559: ...onstant is taken from the IEEE or IEC standard as selected for the temperature calculations User defined Oil time constant is provided by the user through setting The value may be given by the transformer manufacturer Calculated Oil time constant is calculated by the function based on the transformer parameters given by the user OilTimeConst This setting is used to get the oil time constant from t...

Page 560: ...ding time constant is taken from the IEEE or IEC standard as selected for the temperature calculations User defined Winding time constant is provided by the user through setting The value may be given by the transformer manufacturer Calculated Winding time constant is calculated by the function based on the transformer parameters given by the user WdgTimeConst1 This setting is used to get the wind...

Page 561: ...assW3 This setting is used to set the mass of the winding 3 GUID 8A9D8886 8EE5 4B02 80B8 BDDA95164BFF v1 Loss ratios at different tap positions are required for the calculation of top oil temperature especially when the transformer is using online tap changer This loss ratio is the ratio between load losses to no load loss It may vary from 6 7 for distribution transformer and 4 8 for power transfo...

Page 562: ...etting is used to set the August month average ambient temperature SepAmbTmp This setting is used to set the September month average ambient temperature OctAmbTmp This setting is used to set the October month average ambient temperature NovAmbTmp This setting is used to set the November month average ambient temperature DecAmbTmp This setting is used to set the December month average ambient tempe...

Page 563: ... winding 2 CurrTypeTestW3 This setting is used to set the RMS value of the current which is applied during the type test in A for winding 3 GUID 6CB4E94E 1DC9 46DB ADC0 F86922A8D611 v1 The following settings are required to perform the insulation loss of life calculation EnaAgeCalc This setting is used to enable or disable the transformer insulation loss of life calculation It has the following op...

Page 564: ...tion TimeToUpdate This setting is used to set the time interval for updating the transformer insulation loss of life calculation outputs LOLINDAY and LOLINYRS It can be selected as 1 hour 2 hour 4 hour 8 hour 12 hour 24 hour depending on user requirement GUID B170CF21 839E 4246 A607 55A8999FAD07 v1 Two settable warning levels are available for hot spot temperature with separate outputs If warning ...

Page 565: ... can be less than the winding time constant For example if the winding time constant is 420 sec this setting can be 400 sec tDelayToAlarm2 This setting is used to set the time delay for the level 2 hot spot temperature alarm This should be less than time setting in tDelayToAlarm1 17 11 3 Setting example 17 11 3 1 Transformer Rated Data GUID B3AE440F CC5E 4742 9483 8D6448A476C8 v1 Table 53 Transfor...

Page 566: ... Select the method for the determination of current on which the load factor needs to be calculated Maximum TempeUnitMode Select the unit of temperature should be used in the function C AvailableCT Select the available CT connections on the windings All windings RatedVoltageW1 Set the winding 1 rated nominal voltage 415 0 kV RatedVoltageW2 Set the winding 2 rated nominal voltage 230 0 kV RatedVolt...

Page 567: ...on of oil time constant 2 0 MW WdgTmConstMode Select the transformer winding time constant mode of input to the function Standard WdgTimeConst1 Set the transformer winding time constant for the winding 1 when the winding time constant mode is selected as User defined 420 0 sec WdgTimeConst2 Set the transformer winding time constant for the winding 2 when the winding time constant mode is selected ...

Page 568: ...al tapping position for the calculation of ratio loss at the given tap position 3 0 RLHighRated Set the loss ratio at principal tapping 1 position for the calculation of ratio loss at the given tap position 5 0 RLMaxTap Set the loss ratio at maximum tapping position where maximum voltage is possible for the calculation of ratio loss at the given tap position 8 0 RLMinTap Set the loss ratio at mini...

Page 569: ...ilure absence 30 C SepAmbTmp Set the September month average ambient temperature for the calculation of top oil temperature when ambient temperature sensor failure absence 30 C OctAmbTmp Set the October month average ambient temperature for the calculation of top oil temperature when ambient temperature sensor failure absence 30 C NovAmbTmp Set the November month average ambient temperature for th...

Page 570: ...c Enable the transformer insulation loss of life calculation Enable InitialLife Set the initial loss of insulation life 0 0 Hours ExpectedLife Set the expected life of the transformer 1 80 000 Hours AgeingRateMeth Select the ageing rate method of calculation IEC ThermalUpgrade Select the transformer insulation paper type Upgraded TimeToUpdate Set the time interval for the update of loss of life ou...

Page 571: ...reported 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 wi...

Page 572: ...e setting also influences the inputs on the same board used for pulse counting 18 2 Function for energy calculation and demand handling ETPMMTR SEMOD153638 1 v2 18 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 18 2 2 Application SEMOD175546 4...

Page 573: ...alues 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 ...

Page 574: ... EARAccPlsQty 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...

Page 575: ...cal 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 ...

Page 576: ...cols 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...

Page 577: ...2 4B0D 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 ...

Page 578: ...PortB AP1 PhyPortB PhyPortA AP1 PhyPortA PhyPortB Switch B Device 1 Device 2 Device 3 Device 4 IEC09000758 V4 EN US Figure 218 Parallel Redundancy Protocol PRP Section 19 1MRK 511 401 UUS A Ethernet based communication 572 Bay control REC670 2 2 ANSI Application manual ...

Page 579: ...ctivated 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 ta...

Page 580: ...nown 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 meas...

Page 581: ... is 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 19 4 2 Setting guidelines GUID 2C4A312A 00DC 44C8 B2D9 CD0822E1C806 v1 Routes are configured using the Ethernet configuration tool in PCM600 Opera...

Page 582: ...on specifies the destination Destination subnet mask specifies the subnetwork mask of the destination Section 19 1MRK 511 401 UUS A Ethernet based communication 576 Bay control REC670 2 2 ANSI Application manual ...

Page 583: ...tal communication between 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 subscrib...

Page 584: ..._en 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 222 SA system with IEC 61850 8 1 M16925 3 v4 Figure223 shows the GOOSE peer to peer communication Section 20 1MRK 511 401 UUS A Station communication 578 Bay control REC670 2 2 ANSI Application manual ...

Page 585: ... Edition 2 the Ethernet link selection is done with the Ethernet Configuration Tool ECT in PCM600 20 2 3 Horizontal communication via GOOSE 20 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 func...

Page 586: ...ilable for Generic 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 ou...

Page 587: ... An example could be to control the external reservation before 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...

Page 588: ...gh 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 55 Specification of the fibre optic connectors Glass fibre Plastic fibre Cable connector ST conne...

Page 589: ...ADA 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 ...

Page 590: ...ion 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 20 3 2 3 Setting guidelines SEMOD119915 1 v1 Settings M14789 4 v3 The parameters for the multip...

Page 591: ...to 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 communica...

Page 592: ...set 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 ...

Page 593: ...ocally 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 20 5 1 1 Functionality M17109 38 v3 IEC 60870 5 103 is an unbalanced master slave protocol for coded b...

Page 594: ...cally 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 ...

Page 595: ...ER 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 ...

Page 596: ...3 protocol 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 o...

Page 597: ...the 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 resu...

Page 598: ...e and 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 inf...

Page 599: ... 30 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 20 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 rang...

Page 600: ...e Cause 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 20 6 DNP3 Communication protocol 20 6 1 Application GUID EF1F0C38 9FF6 4683 8B10 AAA372D42185 v1 F...

Page 601: ...een 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 b...

Page 602: ...C These 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 r...

Page 603: ...ransmission network for example PDH Telecom Network Multiplexer Multiplexer en05000527 2 vsd Converting optical to galvanic G 703 IEC05000527 V2 EN US Figure 231 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...

Page 604: ... 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 is necessary to give high security against incorrect addressing in the communication system If the same number is used for TerminalNo in some of the LDCMs a loop back test in the communi...

Page 605: ...s 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 mile ComAlarmDel defines the time delay for communication failure alarm In communication systems route switching can sometimes cause interruptions with a duration of up to 50 ms Too short a time delay can thus ...

Page 606: ...nel is used as a redundant backup channel The redundant channel takes the CT group setting of the main channel RemAinLatency corresponds to LocAinLatency set in the remote IED AnalogLatency specifies the time delay number of samples between actual sampling and the time the sample reaches LDCM The value is set to 2 when transmitting analog data When a merging unit according to IEC 61850 9 2 is used...

Page 607: ...er 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 1MRK 511 401 UUS A Section 21 Remote communication Bay control REC670 2 2 ANSI 601 Application manual ...

Page 608: ...602 ...

Page 609: ...otection 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...

Page 610: ...led 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 22 3 Change lock CHNGLCK GUID B48775D0 ACF0 49C6 A7F6 69AF37F1C68F v1 22 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...

Page 611: ...HNGLCK input If such a situation would occur in spite of these precautions then please contact the local ABB representative for remedial action 22 4 Denial of service SCHLCCH RCHLCCH 22 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 facil...

Page 612: ...ar ports channel A and B redundant communication LinkStatus indicates the Ethernet link status for the front port 22 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 22 1MRK 511 401 UUS A Security 606 Bay control REC670 2 2 ANSI Application manual ...

Page 613: ...v2 23 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 ...

Page 614: ...D status 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 vers...

Page 615: ...o settable parameters for the measured value expander block function 23 4 Parameter setting groups IP1745 1 v1 23 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 co...

Page 616: ...th 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 23 5 Rated system frequency PRIMVAL IP15064 1 v2 23 5 1 Identification GUID B8B3535D 227B 4151 9E98 BEB85F4D54DE v1 Function description IEC 6...

Page 617: ... DFTReference 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 23 7 Global base values GBASVAL GUID 2FDB0A2C 10FE 4954 ...

Page 618: ... as 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 23 8 Signal matrix for binary inputs SMBI SEMOD55793 1 v2 23 8 1 Application M15310 3 v2 The Signal matrix for binary inputs function SMBI is used within the Application Configuration tool in direct rel...

Page 619: ... will define SMBO function in the Signal Matrix tool 23 10 Signal matrix for mA inputs SMMI SEMOD55233 1 v2 23 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 23 10 2 Setting guidelines SE...

Page 620: ...nt 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 ...

Page 621: ...s and 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 SMA...

Page 622: ...DFTRefExtOut 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 ...

Page 623: ...MAI11 35 11 SMAI12 36 12 Task time group 3 AdDFTRefCh7 AdDFTRefCh4 IEC07000197 V2 EN US Figure 233 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 ...

Page 624: ...tance 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 233 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 234 SMAI2 2 SMAI12...

Page 625: ...st 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 233 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...

Page 626: ...tion 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 conf...

Page 627: ...d outputs 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 ha...

Page 628: ...thin the whole network can be compared and evaluated In the 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 PMU functionality only PTP GPS or IRIG B or a combination of both GPS and IRIG B is allowed For IEDs using IEC UCA 61850 9 2LE in mixed mode a time synchronization from an externa...

Page 629: ... 1588 2008 and specifically its profile IEC IEEE 61850 9 3 for power utility automation is a synchronization method that can be used to maintain a common time within a station This time can be synchronized to the global time 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...

Page 630: ...NTP IRIG B GPS IRIG B PPS CoarseSyncSrc which can have the following values Disabled SPA LON DNP IEC 60870 5 103 The function 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 th...

Page 631: ...ly When set to 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 236 Enabling PTP in ECT The PTP VLAN tag must h...

Page 632: ...o the 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 ...

Page 633: ...ied 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 th...

Page 634: ...s a 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 acc...

Page 635: ...t classes 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 24 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...

Page 636: ... requirements 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 curren...

Page 637: ...ssibility 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 ...

Page 638: ...ondary 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 for Ir 5 A 24 1 6 2 Non directional instantaneo...

Page 639: ...layed phase and residual overcurrent protection M11339 3 v5 The requirement according to Equation 130 and Equation 131 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 ...

Page 640: ...nction is used the CTs must have a rated equivalent limiting secondary e m f Eal that is larger than or equal to the required rated equivalent limiting secondary e m f Ealreq below sn R al alreq CT L 2 pn n k max I S E E I R R I I æ ö ç è ø EQUATION1681 V1 EN US Equation 132 where Ikmax Maximum primary fundamental frequency current for close in forward and reverse faults A Ipr The rated primary CT...

Page 641: ...ALF The value of the EALF is approximately equal to the corresponding Eal Therefore the CTs according to class P and PR must have a secondary limiting e m f EALF that fulfills the following ALF alreq E max E EQUATION1383 V4 EN US Equation 133 24 1 7 2 Current transformers according to IEC 61869 2 class PX PXR and old IEC 60044 6 class TPS and old British Standard class X M11623 14 v5 CTs according...

Page 642: ...c C class V The CTs according to class C must have a calculated rated equivalent limiting secondary e m f EalANSI that fulfils the following alANSI alreq E maximum of E EQUATION1384 V2 EN US Equation 136 A CT according to ANSI IEEE is also specified by the knee point voltage VkneeANSI that is graphically defined from an excitation curve The knee point voltage VkneeANSI normally has a lower value t...

Page 643: ...ith CCVTs 24 3 SNTP server requirements GUID 588FCD12 C494 445E 8488 8287B34EFD9A v4 The SNTP server to be used is connected to the local network that is not more than 4 5 switches or routers away from the IED The SNTP server is dedicated for its task or at least equipped with a real time operating system that is not a PC with SNTP server software The SNTP server should be stable that is either sy...

Page 644: ...error 100ms Default Synchronization in SDH systems with G 703 E1 or IEEE C37 94 The G 703 E1 2 Mbit shall be set according to ITU T G 803 G 810 13 One master clock for the actual network The actual port Synchronized to the SDH system clock at 2048 kbit Synchronization bit synchronized synchronized mapping Maximum clock deviation 50 ppm nominal 100 ppm operational Jitter and Wander according to ITU...

Page 645: ...have the same route with maximum asymmetry of 0 2 0 5 ms depending on set sensitivity of the differential protection A fixed asymmetry can be compensated setting of asymmetric delay in built in HMI or the parameter setting tool PST IED with GPS clock Independent of asymmetry 1MRK 511 401 UUS A Section 24 Requirements Bay control REC670 2 2 ANSI 639 Application manual ...

Page 646: ...640 ...

Page 647: ...ation 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 I...

Page 648: ...nd 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 Car...

Page 649: ... voltage 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...

Page 650: ...MI 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 p...

Page 651: ...presentative 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 t...

Page 652: ...P Overcurrent 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 bal...

Page 653: ...uction 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 Superv...

Page 654: ...ircuit 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 ...

Page 655: ...tomic 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...

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Page 658: ... 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 511 401 UUS ...

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