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9.16.3.3

Alarm function

GUID-1B932D89-3233-4841-977A-5B61346B057B v2

The alarm function is operated by PICKUP signal and used to warn the operator for an
abnormal situation, for example, when generator continuous negative sequence current
capability is exceeded, thereby allowing corrective action to be taken before removing
the generator from service. A settable time delay

tAlarm

is provided for the alarm

function to avoid false alarms during short-time unbalanced conditions.

9.17

Voltage-restrained time overcurrent protection

VRPVOC (51V)

GUID-613620B1-4092-4FB6-901D-6810CDD5C615 v4

9.17.1

Identification

GUID-7835D582-3FF4-4587-81CE-3B40D543E287 v4

Function description

IEC 61850

identification

IEC 60617

identification

ANSI/IEEE C37.2

device number

Voltage-restrained time overcurrent

protection

VRPVOC

I>/U<

51V

9.17.2

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 the voltage-restrained time overcurrent protection is in the
generator protection system, where it is used as backup protection. If a phase-to-phase
fault affects a generator, the fault current amplitude is a function of time, and it
depends on generator characteristic (reactances and time constants), its load conditions
(immediately before the fault) and excitation system performance and characteristic.
So the fault current amplitude may decay with time. A voltage-restrained overcurrent
relay can be set in order to remain in the picked-up state in spite of the current decay,
and perform a backup trip in case of failure of the main protection.

The IED can be provided with a voltage-restrained time overcurrent protection
(VRPVOC, 51V). The VRPVOC (51V) function is always connected to three-phase
current and three-phase voltage input in the configuration tool, but it will always
measure the maximum phase current and the minimum phase-to-phase voltage.

VRPVOC (51V) function module has two independent protection each consisting of:

•

One overcurrent step with the following built-in features:

Section 9

1MRK 504 163-UUS A

Current protection

606

Transformer protection RET670 2.2 ANSI

Application manual

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Summary of Contents for RELION RET670

Page 1: ...RELION 670 SERIES Transformer protection RET670 Version 2 2 ANSI Application manual ...

Page 2: ......

Page 3: ...Document ID 1MRK 504 163 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: ...otection functions 46 Control and monitoring functions 48 Communication 53 Basic IED functions 56 Section 3 Configuration 59 Description of configuration RET670 59 Introduction 59 Description of configuration A10 59 Description of configuration A25 62 Description of configuration B30 63 Description of configuration B40 66 Section 4 Analog inputs 69 Introduction 69 Setting guidelines 69 Setting of ...

Page 8: ... a phase to phase connected VT to the IED 90 Example on how to connect an open delta VT to the IED for high impedance grounded or ungrounded networks 92 Example how to connect the open delta VT to the IED for low impedance grounded or solidly grounded power systems 95 Section 5 Local HMI 99 Display 100 LEDs 103 Keypad 104 Local HMI functionality 106 Protection and alarm indication 106 Parameter ma...

Page 9: ...tor 141 On line compensation for on load tap changer position 143 Differential current alarm 144 Open CT detection 144 Switch onto fault feature 145 Setting example 145 Introduction 145 Typical main CT connections for transformer differential protection 146 Application Examples 147 Summary and conclusions 155 High impedance differential protection single phase HZPDIF 87 157 Identification 157 Appl...

Page 10: ...ntial protection LDRGFC 11 184 Identification 184 Application 184 Setting guidelines 186 Section 8 Impedance protection 189 Distance measuring zone quadrilateral characteristic for series compensated lines ZMCPDIS 21 ZMCAPDIS 21 ZDSRDIR 21D 189 Identification 189 Application 189 Introduction 189 System grounding 190 Fault infeed from remote end 192 Load encroachment 193 Long transmission line appl...

Page 11: ...entification 248 Application 249 Setting guidelines 249 Load encroachment characteristics 249 Resistive reach with load encroachment characteristic 255 Minimum operate currents 256 Distance measuring zones quadrilateral characteristic ZMQPDIS 21 ZMQAPDIS 21 ZDRDIR 21D 257 Identification 257 Application 257 System grounding 257 Fault infeed from remote end 261 Load encroachment 262 Short line appli...

Page 12: ...eral for earth faults ZMMPDIS 21 ZMMAPDIS 21 290 Identification 290 Application 290 Introduction 290 System grounding 290 Fault infeed from remote end 294 Load encroachment 295 Short line application 296 Long transmission line application 297 Parallel line application with mutual coupling 297 Tapped line application 303 Setting guidelines 306 General 306 Setting of zone1 306 Setting of overreachin...

Page 13: ...hort line application 327 Long transmission line application 328 Parallel line application with mutual coupling 328 Tapped line application 335 Setting guidelines 337 General 337 Setting of zone 1 338 Setting of overreaching zone 338 Setting of reverse zone 339 Setting of zones for parallel line application 340 Setting of reach in resistive direction 341 Load impedance limitation without load encr...

Page 14: ...tection ZMFPDIS 21 367 Identification 367 Application 368 System grounding 368 Fault infeed from remote end 371 Load encroachment 372 Short line application 373 Long transmission line application 374 Parallel line application with mutual coupling 375 Tapped line application 382 Setting guidelines 384 General 384 Setting of zone 1 385 Setting of overreaching zone 385 Setting of reverse zone 386 Set...

Page 15: ...ching and overreaching schemes 426 Setting guidelines 433 General 433 Setting of zone 1 434 Setting of overreaching zone 434 Setting of reverse zone 435 Series compensated and adjacent lines 435 Setting of zones for parallel line application 440 Setting of reach in resistive direction 442 Load impedance limitation without load encroachment function 443 Zone reach setting higher than minimum load i...

Page 16: ...ogic ZCVPSOF 488 Identification 488 Application 488 Setting guidelines 489 Phase preference logic PPLPHIZ 490 Identification 490 Application 491 Setting guidelines 494 Phase preference logic PPL2PHIZ 495 Identification 495 Application 496 Setting guidelines 499 Under impedance protection for generators and transformers ZGVPDIS 501 Identification 501 Application 501 Operating zones 503 Zone 1 opera...

Page 17: ...tion 531 Setting guidelines 531 Directional residual overcurrent protection four steps EF4PTOC 51N 67N 534 Identification 534 Application 535 Setting guidelines 537 Common settings for all steps 537 2nd harmonic restrain 539 Parallel transformer inrush current logic 539 Switch onto fault logic 540 Settings for each step x 1 2 3 and 4 541 Transformer application example 544 Four step directional ne...

Page 18: ... Setting guidelines 576 Pole discrepancy protection CCPDSC 52PD 577 Identification 577 Application 577 Setting guidelines 578 Directional underpower protection GUPPDUP 37 579 Identification 579 Application 579 Setting guidelines 581 Directional overpower protection GOPPDOP 32 585 Identification 585 Application 585 Setting guidelines 587 Broken conductor check BRCPTOC 46 591 Identification 591 Appl...

Page 19: ...nsformer 610 Overcurrent protection with undervoltage seal in 610 Section 10 Voltage protection 613 Two step undervoltage protection UV2PTUV 27 613 Identification 613 Application 613 Setting guidelines 614 Equipment protection such as for motors and generators 614 Disconnected equipment detection 614 Power supply quality 614 Voltage instability mitigation 614 Backup protection for power system fau...

Page 20: ...n 624 Overexcitation protection OEXPVPH 24 626 Identification 626 Application 626 Setting guidelines 629 Recommendations for input and output signals 629 Settings 629 Service value report 630 Setting example 631 Voltage differential protection VDCPTOV 60 632 Identification 632 Application 633 Setting guidelines 634 Loss of voltage check LOVPTUV 27 636 Identification 636 Application 636 Setting gui...

Page 21: ...tection in accordance with IEC or ANSI standards 654 Open phase protection for transformer lines or generators and circuit breaker head flashover protection for generators 656 Voltage restrained overcurrent protection for generator and step up transformer 657 Loss of excitation protection for a generator 657 Section 13 System protection and control 661 Multipurpose filter SMAIHPAC 661 Identificati...

Page 22: ...e 683 Application examples 684 Single circuit breaker with single busbar 685 Single circuit breaker with double busbar external voltage selection 686 Single circuit breaker with double busbar internal voltage selection 687 Double circuit breaker 688 Breaker and a half 689 Setting guidelines 692 Apparatus control APC 697 Application 697 Bay control QCBAY 703 Switch controller SCSWI 704 Switches SXC...

Page 23: ... 3 730 Application 730 Signals from bus coupler 731 Configuration setting 732 Interlocking for bus section breaker A1A2_BS 3 733 Application 733 Signals from all feeders 733 Configuration setting 736 Interlocking for bus section disconnector A1A2_DC 3 737 Application 737 Signals in single breaker arrangement 737 Signals in double breaker arrangement 740 Signals in breaker and a half arrangement 74...

Page 24: ...ation 803 Setting guidelines 804 Generic communication function for Double Point indication DPGAPC 804 Identification 804 Application 804 Setting guidelines 805 Single point generic control 8 signals SPC8GAPC 805 Identification 806 Application 806 Setting guidelines 806 AutomationBits command function for DNP3 0 AUTOBITS 806 Identification 807 Application 807 Setting guidelines 807 Single command ...

Page 25: ...uidelines 824 Permissive underreache scheme 825 Permissive overreach scheme 825 Blocking scheme 825 Intertrip scheme 825 Current reversal and Weak end infeed logic for distance protection 3 phase ZCRWPSCH 85 826 Identification 826 Application 826 Current reversal logic 826 Weak end infeed logic 827 Setting guidelines 828 Current reversal logic 828 Weak end infeed logic 828 Current reversal and wea...

Page 26: ...ngle and or three pole tripping 841 Single two or three pole tripping 842 Lock out 843 Example of directional data 843 Blocking of the function block 845 Setting guidelines 845 Trip matrix logic TMAGAPC 845 Identification 846 Application 846 Setting guidelines 846 Logic for group alarm ALMCALH 846 Identification 846 Application 847 Setting guidelines 847 Logic for group alarm WRNCALH 847 Identific...

Page 27: ... to Boolean 16 conversion with logic node representation ITBGAPC 855 Identification 856 Application 856 Elapsed time integrator with limit transgression and overflow supervision TEIGAPC 857 Identification 857 Application 857 Setting guidelines 857 Comparator for integer inputs INTCOMP 858 Identification 858 Application 858 Setting guidelines 858 Setting example 859 Comparator for real inputs REALC...

Page 28: ...ntification 884 Application 884 Setting guidelines 885 Disturbance report DRPRDRE 885 Identification 886 Application 886 Setting guidelines 887 Recording times 890 Binary input signals 890 Analog input signals 891 Sub function parameters 892 Consideration 892 Logical signal status report BINSTATREP 893 Identification 893 Application 894 Setting guidelines 894 Fault locator LMBRFLO 894 Identificati...

Page 29: ...entification 919 Application 919 Setting guidelines 919 Function for energy calculation and demand handling ETPMMTR 920 Identification 920 Application 920 Setting guidelines 921 Section 20 Ethernet based communication 923 Access point 923 Application 923 Setting guidelines 923 Redundant communication 925 Identification 925 Application 925 Setting guidelines 927 Merging unit 928 Application 928 Set...

Page 30: ...y 941 Design 942 Settings 945 Settings for RS485 and optical serial communication 945 Settings from PCM600 946 Function and information types 948 DNP3 Communication protocol 949 Application 949 Section 22 Remote communication 951 Binary signal transfer 951 Identification 951 Application 951 Communication hardware solutions 952 Setting guidelines 953 Section 23 Security 959 Authority status ATHSTAT...

Page 31: ...6 Application 966 Setting guidelines 966 Summation block 3 phase 3PHSUM 967 Application 967 Setting guidelines 967 Global base values GBASVAL 967 Identification 967 Application 968 Setting guidelines 968 Signal matrix for binary inputs SMBI 968 Application 968 Setting guidelines 968 Signal matrix for binary outputs SMBO 969 Application 969 Setting guidelines 969 Signal matrix for mA inputs SMMI 96...

Page 32: ...ion 988 Distance protection 989 Breaker failure protection 990 Restricted ground fault protection low impedance differential 991 Current transformer requirements for CTs according to other standards 993 Current transformers according to IEC 61869 2 class P PR 994 Current transformers according to IEC 61869 2 class PX PXR and old IEC 60044 6 class TPS and old British Standard class X 994 Current tr...

Page 33: ...ovide assistance for calculating settings 1 2 Intended audience GUID C9B8127F 5748 4BEA 9E4F CC762FE28A3A v11 This manual addresses the protection and control engineer responsible for planning pre engineering and engineering The protection and control engineer must be experienced in electrical power engineering and have knowledge of related technology such as protection schemes and communication p...

Page 34: ... 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 and ...

Page 35: ...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 communica...

Page 36: ...al 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 electric...

Page 37: ...ersonal 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 button...

Page 38: ... another diagram have the suffix cont Dimensions are provided both in inches and millimeters If it is not specifically mentioned then the dimension is in millimeters Illustrations are used as an example and might show other products than the one the manual describes The example that is illustrated is still valid 1 5 IEC 61850 edition 1 edition 2 mapping GUID C5133366 7260 4C47 A975 7DBAB3A33A96 v4...

Page 39: ...2 BFPTRC BFPTRC BFPTRC_F13 BFPTRC BFPTRC BFPTRC_F14 BFPTRC BFPTRC BFPTRC_F15 BFPTRC BFPTRC BFPTRC_F16 BFPTRC BFPTRC BFPTRC_F17 BFPTRC BFPTRC BFPTRC_F18 BFPTRC BFPTRC BFPTRC_F19 BFPTRC BFPTRC BFPTRC_F20 BFPTRC BFPTRC BFPTRC_F21 BFPTRC BFPTRC BFPTRC_F22 BFPTRC BFPTRC BFPTRC_F23 BFPTRC BFPTRC BFPTRC_F24 BFPTRC BFPTRC BICPTRC_01 BICPTRC BICPTRC BICPTRC_02 BICPTRC BICPTRC BICPTRC_03 BICPTRC BICPTRC BIC...

Page 40: ...BUSPTRC_B16 BUSPTRC BUSPTRC BUSPTRC_B17 BUSPTRC BUSPTRC BUSPTRC_B18 BUSPTRC BUSPTRC BUSPTRC_B19 BUSPTRC BUSPTRC BUSPTRC_B20 BUSPTRC BUSPTRC BUSPTRC_B21 BUSPTRC BUSPTRC BUSPTRC_B22 BUSPTRC BUSPTRC BUSPTRC_B23 BUSPTRC BUSPTRC BUSPTRC_B24 BUSPTRC BUSPTRC BUTPTRC_B1 BUTPTRC BBTPLLN0 BUTPTRC BUTPTRC_B2 BUTPTRC BUTPTRC BUTPTRC_B3 BUTPTRC BUTPTRC BUTPTRC_B4 BUTPTRC BUTPTRC BUTPTRC_B5 BUTPTRC BUTPTRC BUTP...

Page 41: ...ZNTGAPC 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 GF2PTUC...

Page 42: ...OC EFPIOC EFRWPIOC EFRWPIOC EFRWPIOC ETPMMTR ETPMMTR ETPMMTR FDPSPDIS FDPSPDIS FDPSPDIS FMPSPDIS FMPSPDIS FMPSPDIS FRPSPDIS FPSRPDIS FPSRPDIS FTAQFVR FTAQFVR FTAQFVR FUFSPVC SDDRFUF FUFSPVC SDDSPVC GENPDIF GENPDIF GENGAPC GENPDIF GENPHAR GENPTRC GOPPDOP GOPPDOP GOPPDOP PH1PTRC GRPTTR GRPTTR GRPTTR GSPTTR GSPTTR GSPTTR GUPPDUP GUPPDUP GUPPDUP PH1PTRC HZPDIF HZPDIF HZPDIF INDCALCH INDCALH INDCALH IT...

Page 43: ...CP3PTUC 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 LT6CPD...

Page 44: ...PTOV 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 SAPFRC ...

Page 45: ... 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 TEILGAPC ...

Page 46: ...SGAPC 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 PSFPDIS ...

Page 47: ...IS ZMMAPDIS ZMMPDIS ZMMPDIS ZMMPDIS ZMQAPDIS ZMQAPDIS ZMQAPDIS ZMQPDIS ZMQPDIS ZMQPDIS ZMRAPDIS ZMRAPDIS ZMRAPDIS ZMRPDIS ZMRPDIS ZMRPDIS ZMRPSB ZMRPSB ZMRPSB ZSMGAPC ZSMGAPC ZSMGAPC 1MRK 504 163 UUS A Section 1 Introduction Transformer protection RET670 2 2 ANSI 41 Application manual ...

Page 48: ...42 ...

Page 49: ...by using a sensitive differential protection feature based on an amplitude measurement and directional comparison of the negative sequence components Multiple low impedance restricted ground fault protection functions are available as a sensitive and fast main protection against winding ground faults This function includes a internal external fault discriminator for additional security Additionall...

Page 50: ... applications such as automatic opening of disconnectors in multi breaker arrangements closing of breaker rings and load transfer logic Logic can be monitored and debugged online in real time for testing and commissioning Forcing of binary inputs and outputs is a convenient way to test wiring in substations as well as testing configuration logic in the IEDs Basically it means that all binary input...

Page 51: ...stricted earth fault protection low impedance 0 3 LDRGFC 11RE L Additional security logic for differential protection 0 1 Impedance protection ZMQPDIS ZMQAPDIS 21 Distance protection zone quadrilateral characteristic 0 5 ZDRDIR 21D Directional impedance quadrilateral 0 2 ZMCPDIS ZMCAPDIS 21 Distance measuring zone quadrilateral characteristic for series compensated lines 0 5 ZDSRDIR 21D Directiona...

Page 52: ...rotection 0 1 ZCVPSOF Automatic switch onto fault logic voltage and current based 0 1 ZGVPDIS 21 Underimpedance protection for generators and transformers 0 2 2 3 Back up protection functions GUID A8D0852F 807F 4442 8730 E44808E194F0 v13 IEC 61850 or function name ANSI Function description RET670 Customized Current protection PHPIOC 50 Instantaneous phase overcurrent protection 0 8 OC4PTOC 51_671 ...

Page 53: ...VOC 51V Voltage restrained overcurrent protection 0 3 Voltage protection UV2PTUV 27 Two step undervoltage protection 0 3 OV2PTOV 59 Two step overvoltage protection 0 3 ROV2PTOV 59N Two step residual overvoltage protection 0 3 OEXPVPH 24 Overexcitation protection 0 2 VDCPTOV 60 Voltage differential protection 0 2 LOVPTUV 27 Loss of voltage check 1 Frequency protection SAPTUF 81 Underfrequency prote...

Page 54: ...inary inputs 0 4 SLGAPC Logic rotating switch for function selection and LHMI presentation 15 VSGAPC Selector mini switch 30 DPGAPC Generic communication function for Double Point indication 16 SPC8GAPC Single point generic control function 8 signals 5 AUTOBITS Automation bits command function for DNP3 0 3 SINGLECMD Single command 16 signals 4 I103CMD Function commands for IEC 60870 5 103 1 I103GE...

Page 55: ...ORYQT SRMEMORYQT TIMERSETQT XORQT Configurable logic blocks Q T see Table 5 0 1 AND GATE INV LLD OR PULSETIMER RSMEMORY SLGAPC SRMEMORY TIMERSET VSGAPC XOR Extension logic package see Table 6 0 1 FXDSIGN Fixed signal function block 1 B16I Boolean to integer conversion 16 bit 18 BTIGAPC Boolean to integer conversion with logical node representation 16 bit 16 IB16 Integer to Boolean 16 conversion 18...

Page 56: ...unction description Total number of instances SCILO Interlocking 30 BB_ES 6 A1A2_BS 4 A1A2_DC 6 ABC_BC 2 BH_CONN 2 BH_LINE_A 2 BH_LINE_B 2 DB_BUS_A 3 DB_BUS_B 3 DB_LINE 3 ABC_LINE 6 AB_TRAFO 4 SCSWI Switch controller 30 SXSWI Circuit switch 24 QCRSV Apparatus control 6 RESIN1 1 RESIN2 59 POS_EVAL Evaluation of position indication 30 QCBAY Bay control 5 Table continues on next page Section 2 1MRK 5...

Page 57: ...locks Q T Total number of instances ANDQT 120 INDCOMBSPQT 20 INDEXTSPQT 20 INVALIDQT 22 INVERTERQT 120 ORQT 120 PULSETIMERQT 40 RSMEMORYQT 40 SRMEMORYQT 40 TIMERSETQT 40 XORQT 40 Table 6 Total number of instances for extended logic package Extended configurable logic block Total number of instances AND 180 GATE 49 INV 180 LLD 49 OR 180 PULSETIMER 89 RSMEMORY 40 SLGAPC 74 SRMEMORY 130 TIMERSET 109 ...

Page 58: ...alue expander block 66 SSIMG 63 Insulation supervision for gas medium 21 SSIML 71 Insulation supervision for liquid medium 4 SSCBR Circuit breaker condition monitoring 0 18 LMBRFLO Fault locator 0 1 LOLSPTR 26 49 HS 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 au...

Page 59: ...n protocol 1 CHSEROPT DNP3 0 for TCP IP and EIA 485 communication protocol 1 MSTSER DNP3 0 serial master 1 MST1TCP MST2TCP MST3TCP MST4TCP DNP3 0 for TCP IP communication protocol 1 DNPFREC DNP3 0 fault records for TCP IP and EIA 485 communication protocol 1 IEC 61850 8 1 IEC 61850 1 GOOSEINTLKRCV Horizontal communication via GOOSE for interlocking 59 GOOSEBINRCV GOOSE binary receive 16 GOOSEDPRCV...

Page 60: ...its 0 1 ACTIVLOG Activity logging 1 ALTRK Service tracking 1 PRP IEC 62439 3 Parallel redundancy protocol 0 1 HSR IEC 62439 3 High availability seamless redundancy 0 1 PMUCONF PMUREPORT PHASORREPORT1 PHASORREPORT2 PHASORREPORT3 ANALOGREPORT1 BINARYREPORT1 SMAI1 SMAI12 3PHSUM PMUSTATUS Synchrophasor report 24 phasors see Table 7 0 1 PTP Precision time protocol 1 FRONTSTATUS Access point diagnostic ...

Page 61: ...on 0 2 ZCLCPSCH Local acceleration logic 0 1 ECPSCH 85 Scheme communication logic for residual overcurrent protection 0 1 ECRWPSCH 85 Current reversal and weak end infeed logic for residual overcurrent protection 0 1 Table 7 Number of function instances in Synchrophasor report 24 phasors Function name Function description Number of instances PMUCONF Configuration parameters for C37 118 2011 and IE...

Page 62: ... 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 with ...

Page 63: ...avior 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 1MRK 504 163 UUS A Section 2 Application Transformer protection RET670 2 2 ANSI 57 Application manual ...

Page 64: ...58 ...

Page 65: ...with a synchronism check function for manual closing of the low voltage side breaker The high voltage breaker is foreseen to always energize the transformer and be interlocked with an open LV side breaker The tripping from transformer auxiliaries such as buchholtz temperature devices are linked through the binary inputs which are stabilized against unnecessary operations due to capacitive discharg...

Page 66: ...basic IED delivery and one 9I 3U input transformer module It is possible to add IO as required to for example have neutral currents connected to ground fault functions The configuration alternative can often be used for two winding transformers and the neutral currents can then be connected instead of the third winding inputs Section 3 1MRK 504 163 UUS A Configuration 60 Transformer protection RET...

Page 67: ...Id ROV2 PTOV 59N 2 U0 NS4 PTOC 46I2 4 I2 SA PFRC 81 df dt SA PTOF 81 f SA PTUF 81 f UV2 PTUV 27 2 3U OV2 PTOV 59 2 3U REF PDIF 87N IdN I VDC PTOV 60 Ud BRC PTOC 46 Iub VD SPVC 60 Ud Q CBAY 3 Control VN MMXU MET UN EF4 PTOC 51N 4 IN SES RSYN 25 SC VC CV MMXN MET P Q IEC07000191 5 en vsdx S SCBR Control S SCBR Control S SCBR 3 Control S SCBR Control S SCBR Control S SCBR 3 Control S XCBR 3 Control S...

Page 68: ...een up to eight control function blocks are either internal or over IEC 61850 8 1 Both automatic and manual tap changer control are provided in the configuration If the manual control is required to be separate from the automatic control it can be done in any other IED670 where the local HMI interfaces to show position Switching Auto Manual Raise and Lower commands and so on can be provided Sectio...

Page 69: ...C MSQI MET Isqi CV MMXN P Q MET CV MMXN MET P Q C MSQI MET Isqi C MMXU MET I V MMXU MET U Q CBAY 3 Control S SIML 71 EF4 PTOC 51N_67N 4 IN Q CRSV 3 Control VD SPVC 60 Ud TRF1_W2_VT TRF2_W2_VT TRF1_W2_CT TRF2_W2_CT W1 W2 TRF1 W1 W2 TRF2 TRF2_W2_QA1 VN MMXU MET UN V MSQI Usqi MET VN MMXU MET UN V MMXU MET U V MSQI Usqi MET PMU REP IEC07000192 4 en vsdx IEC07000192 V4 EN US Figure 3 Configuration dia...

Page 70: ...l faults Stabilization against through faults inrush and overexcitation are standard features The function is provided with six stabilized inputs which allows all CT sets possible with multi breaker arrangements on several of the windings to be possible Measuring functions for S P Q I V PF f are available for local presentation on the local HMI and or remote presentation The availability of additi...

Page 71: ...SB 68 Zpsb 32 P GOP PDOP GUP PDUP 37 P TR8 ATCC 90 TCL YLTC 84 S CILO 3 Control S CSWI 3 Control S XSWI 3 Control Q CRSV 3 Control VD SPVC 60 Ud ZGV PDIS 21 Z VN MMXU MET UN EF4 PTOC 51N_67N 4 IN WA1 WA2 W1_CT2 W1_CT1 W1_NCT W2_NCT W2_CT W2_VT WA1 W2_WA1_VT VN MMXU MET UN SES RSYN 25 SC VC IEC05000849 5 en vsd S XCBR 3 Control S SCBR Control S SCBR Control S SCBR 3 Control PMU REP STB PTOC 50STB 3...

Page 72: ... function is provided with six stabilized inputs which allows all CT sets possible with multi breaker arrangements on several of the windings to be possible Measuring functions for S P Q I V PF f are available for local presentation on the local HMI and or remote presentation The availability of additional analog inputs allows connection of separate metering cores and a calibration parameter on th...

Page 73: ...81 df dt SA PTOF 81 f SA PTUF 81 f OEX PVPH 24 U f ZM RPSB 68 Zpsb 32 P GOP PDOP GUP PDUP 37 P TR8 ATCC 90 TCL YLTC 84 SDE PSDE 67N IN S CILO 3 Control S CSWI 3 Control S XSWI 3 Control Q CRSV 3 Control VD SPVC 60 Ud ZGV PDIS 21 Z VN MMXU MET UN VN MMXU MET UN EF4 PTOC 51N_67N 4 IN WA1 WA2 W1_CT2 W1_CT1 W1_NCT W2_NCT W3_VT_3U0 W3_CT W2_CT W2_VT WA1 W2_WA1_VT WA1 VN MMXU MET UN SES RSYN 25 SC VC IE...

Page 74: ...68 ...

Page 75: ... 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 SEMOD550...

Page 76: ...object is defined as Forward and the direction out from the object is defined as Reverse See Figure 7 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 7 Protected Object Line transformer etc Forward Reverse Definition of direction for...

Page 77: ... 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 9 Example how to set CT_WyePoint parameters in the IED ...

Page 78: ...tection 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 symmetri...

Page 79: ...etting is ToObject Forward Reverse Definition of direction for directional line functions Setting of current input for transformer functions Set parameter CT_WyePoint with Transformer as reference object Correct setting is ToObject Setting of current input for line functions Set parameter CT_WyePoint with Line as reference object Correct setting is FromObject en05000462_ansi vsd ANSI05000462 V1 EN...

Page 80: ...at case for all CT inputs marked with 1 in Figure 12 set CT_WyePoint ToObject and for all CT inputs marked with 2 in Figure 12 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 12 set CT_WyePoint FromObject and for all CT inputs marked with 2 in Figure 12 set CT_WyePoint ToObject Section 4 1M...

Page 81: ... 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 13 Commonly used markings of CT terminals Where a is symbol and terminal marking used in this document T...

Page 82: ...ted 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 14 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 control ...

Page 83: ...t 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 14 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 currents a...

Page 84: ...y for IEDs installed in power plants then the setting parameters DFTReference shall be set accordingly Section SMAI in this manual provides information on adaptive frequency tracking for the signal matrix for analogue inputs SMAI 5 AI3P in the SMAI function block is a grouped signal which contains all the data about the phases A B C and neutral quantity in particular the data about fundamental fre...

Page 85: ...etting of the parameter CTStarPoint of the used current inputs on the TRM item 2 in Figure 15 and 14 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 alternative...

Page 86: ...mation 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 measu...

Page 87: ...tion 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 shall b...

Page 88: ...Delta DAB Connected IA IB IB IC IC IA 1 2 3 4 ANSI11000027 2 en vsd SMAI_20 ANSI11000027 V2 EN US Figure 17 Delta DAB connected three phase CT set Section 4 1MRK 504 163 UUS A Analog inputs 82 Transformer protection RET670 2 2 ANSI Application manual ...

Page 89: ...r 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 protection ...

Page 90: ...t 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 19 gives an example how to connect the single phase CT to the IED It gives an overview of the required actions by the user in order t...

Page 91: ...oObject For connection b shown in Figure 19 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 prote...

Page 92: ...oltage level This will effectively make the protection scheme less sensitive however such measures are necessary in order to avoid possible problems with loss of the measurement accuracy in the IED Regardless of the applied relationship between the IBase parameter and the rated CT primary current the corresponding minimum pickup of the function on the CT secondary side must always be verified It i...

Page 93: ... 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 connecte...

Page 94: ...1 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 504 163 UUS A Analog inputs 88 Transformer prot...

Page 95: ...I2 AI3 AI4 AIN GRP2_B GRP2_C GRP2N 4 ANSI06000599 V2 EN US Figure 21 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 22 A two phase to earth connected VT 1MRK 504 163 UUS A Section 4 Analog inputs Transformer protection RET670 2 2 ANSI 89 Ap...

Page 96: ...o 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 protec...

Page 97: ...ted 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 1MRK ...

Page 98: ...l be set as shown here ConnectionType Ph Ph VBase 13 8 kV If frequency tracking and compensation is required this feature is typically required only for IEDs installed in the generating stations then the setting parameters DFTReference shall be set accordingly 4 2 4 5 Example on how to connect an open delta VT to the IED for high impedance grounded or ungrounded networks SEMOD55055 163 v9 Figure 2...

Page 99: ... 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 24 Open delta connected VT in high impedance grounded power system 1MRK 504 163 UUS A Section 4 Analog inputs Transformer protection RET670 2 2 ANSI 93 Application manual ...

Page 100: ...tage 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 inpu...

Page 101: ... V EQUATION1927 ANSI V1 EN US Equation 7 The primary rated voltage of such VT is always equal to VPh Gnd Therefore three series connected VT secondary windings will give the secondary voltage equal only to one individual VT secondary winding rating Thus the secondary windings of such open delta VTs quite often has a secondary rated voltage close to rated phase to phase VT secondary voltage that is...

Page 102: ...V 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 25 Open delta connected VT in low impedance or solidly grounded power system Section 4 1MRK 504 163 UUS A Analog inputs 96 Transformer protection RET670 2 2 ANSI Application manual ...

Page 103: ...h input channel of the preprocessing function block 4 5 preprocessing block has a task to digitally filter the connected analog inputs and calculate fundamental frequency phasors for all four input channels harmonic content for all four input channels positive negative and zero sequence quantities by using the fundamental frequency phasors for the first three input channels channel one taken as re...

Page 104: ...98 ...

Page 105: ... ANSI13000239 2 en vsd ANSI13000239 V2 EN US Figure 26 Local human machine interface The LHMI of the IED contains the following elements 1MRK 504 163 UUS A Section 5 Local HMI Transformer protection RET670 2 2 ANSI 99 Application manual ...

Page 106: ...y 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 504 163 UUS A Local HMI 100 Transformer protection RET670 2 2 ANSI Application manual ...

Page 107: ... 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 504 163 UUS A Section 5 Local HMI Transformer protection RET670 2 2 ANSI 101 Application manual ...

Page 108: ...00F E8C0 4FAB B979 FD4A971475E3 V1 EN US Figure 29 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 504 163 UUS A Local...

Page 109: ...h the LHMI or PCM600 Information panels for the indication LEDs are shown by pressing the Multipage button Pressing that button cycles through the three pages A lit or un acknowledged LED is indicated with a highlight Such lines can be selected by using the Up Down arrow buttons Pressing the Enter key shows details about the selected LED Pressing the ESC button exits from information pop ups as we...

Page 110: ...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 504 163 UUS A Local HMI 104 Transformer protection RET670 2 2 ANSI Application manual ...

Page 111: ...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 504 163 UUS A Section 5 Local HMI Transformer protection RET670 2 2 ANSI 105 Application manual ...

Page 112: ...unction has picked up and an indication message is displayed The pick up indication is latching and must be reset via communication LHMI or binary input on the LEDGEN component To open the reset menu on the LHMI press Flashing The IED is in test mode and protection functions are blocked or the IEC61850 protocol is blocking one or more functions The indication disappears when the IED is no longer i...

Page 113: ...he 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 acknowled...

Page 114: ...C13000280 1 en vsd 1 2 GUID 94AF2358 6905 4782 B37B ACD3DCBF7F9C V1 EN US Figure 32 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 port...

Page 115: ...tings 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 33 demonstrates the communication configuration diagram A...

Page 116: ...44 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 33 The communication configuration PMUCONF structure in the IED 6 1 3 1 S...

Page 117: ...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 PMU dia...

Page 118: ...nored 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 command f...

Page 119: ...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 TCPportUDP...

Page 120: ...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 PMUREPOR...

Page 121: ... phase phasor A B C IEC140000119 2 en vsd IEC140000119 V2 EN US Figure 35 Multiple instances of PHASORREPORT blocks Figure 36 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 block T...

Page 122: ...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 37 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 funct...

Page 123: ...BE 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 the IE...

Page 124: ... 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 order to ...

Page 125: ...ith 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 prior...

Page 126: ... 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 follows th...

Page 127: ...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 minimum ...

Page 128: ...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 scale fact...

Page 129: ...000124 2 en vsd IEC140000124 V2 EN US Figure 39 An example of correct connection of SMAI and PHASORREPORT blocks in ACT Figure 40 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 40 An example of wrong connection of SMAI and ...

Page 130: ...ock demonstrated by PCM600 Parameter Setting Tool PST IEC140000126 2 en vsd IEC140000126 V2 EN US Figure 41 PMUREPORT settings in PCM600 PST Figure 42 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 different in...

Page 131: ...tances 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 PHASORREPORT ...

Page 132: ...d 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 44 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 3PHSUM...

Page 133: ...nd PHASORREPORT blocks in ACT IEC140000130 1 en vsd IEC140000130 V1 EN US Figure 45 SMAI1 setting parameters example showing that SMAI3 is selected as the DFT reference DFTRefGrp3 1MRK 504 163 UUS A Section 6 Wide area measurement system Transformer protection RET670 2 2 ANSI 127 Application manual ...

Page 134: ...DFT reference from SMAI3 IEC140000132 2 en vsd IEC140000132 V2 EN US Figure 47 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 reas...

Page 135: ...nected 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 IEEE...

Page 136: ...e 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 system tha...

Page 137: ...taType 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 respectively ...

Page 138: ... 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 fr s o...

Page 139: ... 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 channels...

Page 140: ...ls 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 504 163 UUS A Wide area measurement system 134 Transformer protection RET670 2 2 ANSI Application manual ...

Page 141: ...erential IED the protective zone does not include the bus work or cables between the circuit breaker and the power transformer In some substations there is a current differential protection relay for the busbar Such a busbar protection will include the bus work or cables between the circuit breaker and the power transformer Internal electrical faults are very serious and will cause immediate damag...

Page 142: ...ernal faults if the turn ratio and the phase shift are correctly compensated However there are several different phenomena other than internal faults that will cause unwanted and false differential currents The main reasons for unwanted differential currents may be mismatch due to varying tap changer positions different characteristics loads and operating conditions of the current transformers zer...

Page 143: ...matter of judgment The second slope is increased to ensure stability under heavy through fault conditions which could lead to increased differential current due to saturation of current transformers Default settings for the operating characteristic with IdMin 0 3pu of the power transformer rated current can be recommended as a default setting in normal applications If the conditions are known more...

Page 144: ...nt transformers for connection to a single restraint input Each current connected to the IED is available for biasing the differential protection function The unrestrained operation level has a default value of IdUnre 10pu which is typically acceptable for most of the standard power transformer applications In the following case this setting need to be changed accordingly When CT from T connection...

Page 145: ... en05000187 2 vsd IEC05000187 V2 EN US Figure 48 Representation of the restrained and the unrestrained operate characteristics 100 Ioperate slope Irestrain D D EQUATION1246 V1 EN US Equation 13 and where the restrained characteristic is defined by the settings 1 IdMin 2 EndSection1 3 EndSection2 4 SlopeSection2 5 SlopeSection3 1MRK 504 163 UUS A Section 7 Differential protection Transformer protec...

Page 146: ...aps Instead it is necessary to eliminate the zero sequence current from every individual winding by proper setting of setting parameters ZSCurrSubtrWx Disabled or Enabled 7 1 3 3 Inrush restraint methods M15266 6 v7 With a combination of the second harmonic restraint and the waveform restraint methods it is possible to get a protection with high security and stability against inrush effects and at...

Page 147: ...is is the default recommended setting value for this parameter When parameter CrossBlockEn is set to Disabled any cross blocking between phases will be disabled 7 1 3 6 External Internal fault discriminator M15266 269 v10 The external internal fault discriminator operation is based on the relative position of the two phasors in case of a two winding transformer representing the W1 and W2 negative ...

Page 148: ...from HV and LV sides are 180 degrees out of phase or at least in the external fault region the fault is external Under external fault condition and with no current transformer saturation the relative angle is theoretically equal to 180 degrees During internal fault and with no current transformer saturation the angle shall ideally be 0 degrees but due to possible different negative sequence source...

Page 149: ...rsion Nevertheless the whole power transformer is protected including the non connected winding 7 1 3 7 On line compensation for on load tap changer position M15266 326 v5 The Transformer differential function in the IED has a built in facility to on line compensate for on load tap changer operation The following parameters which are set under general settings are related to this compensation feat...

Page 150: ...ng value 10s 7 1 3 9 Open CT detection M15266 340 v5 The Transformer differential function has a built in advanced open CT detection feature This feature can block the unexpected operation created by the Transformer differential function in case of open CT secondary circuit under normal load condition An alarm signal can also be issued to station operational personnel to make remedy action once th...

Page 151: ...t sides of the protected transformer ratio compensation zero sequence current elimination zero sequence current reduction shall be done In the past this was performed with help of interposing CTs or special connection of main CTs delta connected CTs With numerical technology all these compensations are done in IED software The Differential transformer protection is capable to provide differential ...

Page 152: ...sition can be used in the IED 7 1 4 2 Typical main CT connections for transformer differential protectionSEMOD167749 5 v3 Three most typical main CT connections used for transformer differential protection are shown in figure 49 It is assumed that the primary phase sequence is A B C A IA IA IB IB IC IC IA IA IC IB IA IC IB IA IB IC Protected Transformer Winding CT Wye Connected CT in Delta DAC Con...

Page 153: ...1 732 times in comparison with wye connected CTs lead by 30 the primary winding currents this CT connection rotates currents by 30 in anti clockwise direction do not contain zero sequence current component For DAB delta connected main CT ratio shall be set for 3 times smaller in RET 670 then the actual ratio of individual phase CTs The WyePoint parameter for this particular connection shall be set...

Page 154: ...iven in figure 50 CT 300 5 in Delta DAC CT 800 5 Wye 20 9 MVA 69 12 5 kV YNd1 YDAC CT 300 5 Wye CT 800 5 Wye 20 9 MVA 69 12 5 kV YNd1 YDAC en06000554_ansi vsd ANSI06000554 V1 EN US Figure 50 Two differential protection solutions for wye delta connected power transformer For this particular power transformer the 69 kV side phase to ground no load voltages lead by 30 degrees the 12 5 kV side phase t...

Page 155: ... Table 15 CT input channels used for the LV side CTs Setting parameter Selected value for both solutions CTprim 800 CTsec 5 CT_WyePoint ToObject 5 Enter the following settings for all three CT input channels used for the HV side CTs see table 16 Table 16 CT input channels used for the HV side CTs Setting parameter Selected value for solution 1 wye connected CT Selected value for solution 2 delta c...

Page 156: ...CurrSubtrW1 On Off 2 ZSCurrSubtrW2 Off Off TconfigForW1 No No TconfigForW2 No No LocationOLTC1 Not used Not used Other Parameters Not relevant for this application Use default value Not relevant for this application Use default value 1 To compensate for delta connected CTs 2 Zero sequence current is already removed by connecting main CTs in delta Delta wye connected power transformer without tap c...

Page 157: ...ed that the 24 9 kV currents are rotated by 30 in anti clockwise direction Thus the DAB CT delta connection see figure 51 must be used for 24 9 kV CTs in order to put 115 kV 24 9 kV currents in phase To ensure proper application of the IED for this power transformer it is necessary to do the following 1 Check that HV LV CTs are connected to 5 A CT inputs in the IED 2 For second solution make sure ...

Page 158: ... delta connected CTs see equation 15 6 Enter the following values for the general settings of the differential protection function see table19 Table 19 General settings of the differential protection Setting parameter selected value for both Solution 1 wye conected CT Selected value for both Solution 2 delta connected CT RatedVoltageW1 115 kV 115 kV Rated VoltageW2 24 9 kV 24 9 kV RatedCurrentW1 3...

Page 159: ...that this example is applicable for protection of autotransformer with not loaded tertiary delta winding as well CT 500 5 Wye 31 5 31 5 10 5 MVA 110 11 1 5 36 75 10 5 kV YNyn0 d5 CT 200 1 Wye CT 500 5 in Delta DAB 31 5 31 5 10 5 MVA 110 11 1 5 36 75 10 5 kV YNyn0 d5 CT 200 1 in Delta DAB en06000558_ansi vsd ANSI06000558 V1 EN US Figure 52 Two differential protection solutions for wye wye connected...

Page 160: ...ed for the HV side CTs see table 20 Table 20 CT input channels used for the HV side CTs Setting parameter Selected value for both solution 1 wye connected CTs Selected value for both Solution 2 delta connected CTs CTprim 200 200 115 3 EQUATION1891 V1 EN US Equation 16 CTsec 1 1 CT_WyePoint FromObject ToObject To compensate for delta connected CTs see equation 16 6 Enter the following settings for ...

Page 161: ...1 Winding 1 W1 Winding 1 W1 LowTapPosOLTC1 1 1 RatedTapOLTC1 12 12 HighTapPsOLTC1 23 23 TapHighVoltTC1 23 23 StepSizeOLTC1 1 5 1 5 Other parameters Not relevant for this application Use default value Not relevant for this application Use default value 1 Zero sequence current is already removed by connecting main CTs in delta 7 1 4 4 Summary and conclusions SEMOD168160 5 v3 The IED can be used for ...

Page 162: ...he following table summarizes the most commonly used wye delta phase shift around the world and provides information about the required type of main CT delta connection on the wye side of the protected transformer IEC vector group ANSI designation Positive sequence no load voltage phasor diagram Required delta CT connection type on wye side of the protected power transformer and internal vector gr...

Page 163: ...563 V1 EN US DAB Yy6 Dyn5 DY150 Y IEC06000564 V1 EN US DAC Yy6 7 2 High impedance differential protection single phase HZPDIF 87 IP14239 1 v4 7 2 1 Identification M14813 1 v4 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number High impedance differential protection single phase HZPDIF Id SYMBOL CC V2 EN US 87 1MRK 504 163 UUS A Section 7 Differentia...

Page 164: ...ments and location of breakers available CT cores and so on ANSI05000738 2 en vsd 3 87 21 3 87 21 52 52 52 ANSI05000738 V2 EN US Figure 53 Different applications of a 1Ph High impedance differential protection HZPDIF 87 function 7 2 2 1 The basics of the high impedance principle SEMOD54734 153 v9 The high impedance differential protection principle has been used for many years and is well document...

Page 165: ...t the lifetime of the equipment in order to be able to withstand the high voltage peaks that is pulses which may appear during an internal fault Otherwise any flash over in CT secondary circuits or any other part of the scheme may prevent correct operation of the high impedance differential relay for an actual internal fault 87N en05000164_ansi vsd ANSI05000164 V1 EN US Figure 54 Example for the h...

Page 166: ...across the series resistor Note that very high peak voltages can appear To prevent the risk of flashover in the circuit a voltage limiter must be included The voltage limiter is a voltage dependent resistor Metrosil The external unit with stabilizing resistor has a value of either 6800 ohms or 1800 ohms depending on ordered alternative with a sliding link to allow adjustment to the required value ...

Page 167: ...0 V 1000 0 040 A 60 V 1500 0 040 A 600 0 100 A 80 V 2000 0 040 A 800 0 100 A 100 V 2500 0 040 A 1000 0 100 A 150 V 3750 0 040 A 1500 0 100 A 200 V 5000 0 040 A 2000 0 100 A Table 24 5 A channels input with minimum operating down to 100 mA Operating voltage TripPickup Stabilizing resistor R1 ohms Operating current level 5 A Stabilizing resistor R1 ohms Operating current level 5 A Stabilizing resist...

Page 168: ...d be remembered that the vectorial sum of the currents must be used IEDs Metrosil and resistor currents are resistive The current measurement is insensitive to 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 61 Series resistor thermal capacity SEMOD54734...

Page 169: ...fault situation VR VR c Internal faults VR Protected Object ANSI05000427 V2 EN US Figure 55 The high impedance principle for one phase with two current transformer inputs 1MRK 504 163 UUS A Section 7 Differential protection Transformer protection RET670 2 2 ANSI 163 Application manual ...

Page 170: ...r 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 56 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 X1 R4...

Page 171: ...istor 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 2 3 2 Connections for 1Ph High impedance differential protection HZPDIF 87 GUID D68A237F 610C 4AF0 870F 273117F64D92 v10 Restricted earth fault protecti...

Page 172: ...t 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 protect...

Page 173: ...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 Serie...

Page 174: ...set to achieve a sensitivity of around 20 percent of the used CT primary rating so that a low ohmic value can be used for the series resistor It is strongly recommended to use the highest tap of the CT whenever high impedance protection is used This helps in utilizing maximum CT capability minimize the secondary fault current thereby reducing the stability voltage limit Another factor is that duri...

Page 175: ...resistances the required series stabilizing resistor value to use As this application requires to be so sensitive select R Series 500 ohm which gives an IED operating current of 200 mA Calculate the primary sensitivity at operating voltage using the following equation 3 2000 200 0 3 50 60 10 100 5 IP approx A EQUATION1887 ANSI V1 EN US Equation 22 where 100 mA is the current drawn by the IED circu...

Page 176: ...r 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 differential protection function HZPDIF 87 can be used to protect the tertiary reactor for phase faults as well as ground faults if the power system of the tertiary winding is direct or low impedance grounde...

Page 177: ... 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 504 163 UUS A Section 7 Differential protection Transformer protection RET670 2 2 ANSI 171 ...

Page 178: ...0 1 8 20 VR EQUATION1768 ANSI V1 EN US Equation 23 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 24 that is greater than 2 ˣ TripPickup Check from the table of selected resistances the required series stabilizing resistor value to use Since ...

Page 179: ...sitivity for internal earth faults in the transformer winding Sensitivities of 2 8 can be achieved whereas the normal differential function will have sensitivities of 20 40 The sensitivity for high impedance restricted ground fault function is mostly dependent on the current transformers magnetizing currents The connection of a restricted earth fault function is shown in Figure 60 It is connected ...

Page 180: ... farthest CT to be limited to approx 0 05 Ohms at 75 C gives loop resistance 2 ˣ 0 05 0 1 Ohms Max fault current The maximum through fault current is limited by the transformer reactance use 15 ˣ rated current of the transformer Calculation 250 15 0 1 0 1 6 25 600 5 VR V EQUATION1775 ANSI V1 EN US Equation 26 Select a setting of TripPickup 40 V The current transformerknee point voltage can roughly...

Page 181: ...ty of HZPDIF 87 function is normally high which means that the function will in many cases operate also for short circuits or open 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 8...

Page 182: ...ication ANSI IEEE C37 2 device number Restricted earth fault protection low impedance REFPDIF IdN I SYMBOL AA V1 EN US 87N 7 3 2 Application IP14941 1 v1 M13940 3 v12 A breakdown of the insulation between a transformer winding and the core or the tank may result in a large fault current which causes severe damage to the windings and the transformer core A high gas pressure may develop damaging the...

Page 183: ... power transformer winding can have and will detect faults such as ground faults in the transformer winding when the network is grounded through an impedance ground faults in the transformer winding in solidly grounded network when the point of the fault is close to the winding star point The restricted ground fault protection is not affected as a differential protection with the following power t...

Page 184: ...ded through Zig Zag grounding transformer M13048 8 v10 A common application is for low reactance grounded transformer where the grounding is through separate Zig Zag grounding transformers The fault current is then limited to typical 800 to 2000 A for each transformer The connection for this application is shown in figure 63 Section 7 1MRK 504 163 UUS A Differential protection 178 Transformer prot...

Page 185: ...ng transformer 7 3 2 3 Autotransformer winding solidly grounded M13048 13 v9 Autotransformers can be protected with the low impedance restricted ground fault protection function REFPDIF The complete transformer will then be protected 1MRK 504 163 UUS A Section 7 Differential protection Transformer protection RET670 2 2 ANSI 179 Application manual ...

Page 186: ...stricted ground fault low impedance function REFPDIF 87N for an autotransformer solidly grounded 7 3 2 4 Reactor winding solidly grounded M13048 18 v10 Reactors can be protected with restricted ground fault protection low impedance function REFPDIF 87N The connection of REFPDIF 87N for this application is shown in figure 65 Section 7 1MRK 504 163 UUS A Differential protection 180 Transformer prote...

Page 187: ...er and mesh corner arrangements have two sets of current transformers on the phase side The restricted earth fault protection low impedance function REFPDIF 87N has inputs to allow two current inputs from each side of the transformer The second winding set is only applicable for autotransformers A typical connection for a star delta transformer is shown in figure 66 1MRK 504 163 UUS A Section 7 Di...

Page 188: ...ernally REFPDIF 87N always uses reference directions towards the protected transformers as shown in Figure 66 Thus the IED always measures the primary currents on all sides and in the neutral of the power transformer with the same reference direction towards the power transformer windings The grounding can be freely selected for each of the involved current transformers 7 3 3 Setting guidelines IP...

Page 189: ...c TRIP The trip output is activated when all operating criteria are fulfilled DIR_INT The output is activated when the directional criteria has been fulfilled BLK2H The output is activated when the function is blocked due to high level of second harmonic 7 3 3 2 Settings M13052 28 v13 The parameters for the restricted earth fault protection low impedance function REFPDIF 87N are set via the local ...

Page 190: ... Only difference is that CTFactorSec1 is related to W2 side CTFactorSec2 See setting CTFactorPri2 Only difference is that CTFactorSec2 is related to W2 side 7 4 Additional security logic for differential protection LDRGFC 11 GUID 0E064528 0E70 4FA1 87C7 581DADC1EB55 v2 7 4 1 Identification GUID 3081E62B 3E96 4615 97B8 2CCA92752658 v2 Function description IEC 61850 identification IEC 60617 identifi...

Page 191: ...d through the line and protection is not working correctly Features Startup element is sensitive enough to detect the abnormal status of the protected system Startup element does not influence the operation speed of main protection Startup element detects the evolving faults high impedance faults and three phase fault on weak side It is possible to block the each sub function of startup element St...

Page 192: ...d in most applications Pick Up ICV Level of fixed threshold given in of IBase This setting should be based on fault calculations to find the current increase in case of a fault at the point on the protected line giving the smallest fault current to the protection The phase current shall be calculated for different types of faults single phase to ground phase to phase to ground phase to phase and t...

Page 193: ...round at different switching states in the network The setting must be higher than the lowest phase ground voltage during non faulted operation V_Ph Ph Level of low phase phase voltage detection given in of VBase This setting should be based on fault calculations to find the phase phase voltage decrease in case of a fault at the most remote point where the differential protection shall be active T...

Page 194: ...188 ...

Page 195: ...d lines zone 2 5 ZMCAPDIS S00346 V1 EN US 21 Directional impedance quadrilateral including series compensation ZDSRDIR Z IEC09000167 V1 EN US 21D 8 1 2 Application SEMOD168236 1 v1 8 1 2 1 Introduction SEMOD168232 4 v2 Sub transmission networks are being extended and often become more and more complex consisting of a high number of multi circuit and or multi terminal lines of very different length...

Page 196: ...ly grounded network The ground fault current is as high or even higher than the short circuit current The series impedances determine the magnitude of the fault current The shunt admittance has very limited influence on the ground fault current The shunt admittance may however have some marginal influence on the ground fault current in networks with long transmission lines The ground fault current...

Page 197: ...s effectively grounded if the ground fault factor fe is less than 1 4 The ground fault factor is defined according to equation 30 max e pn V f V ANSIEQUATION1268 V1 EN US Equation 30 Where Vmax is the highest fundamental frequency voltage on one of the healthy phases at single phase to ground fault Vpn is the phase to ground fundamental frequency voltage before fault Another definition for effecti...

Page 198: ...tection system and making the settings With reference to figure 69 we can draw the equation for the bus voltage Va at left side as A A L A B f V I p Z I I R EQUATION1273 V1 EN US Equation 33 If we divide Va by IA we get Z present to the IED at A side a A B A L f A A V I I Z p Z R I I EQUATION1274 V2 EN US Equation 34 The infeed factor IA IB IA can be very high 10 20 depending on the differences in...

Page 199: ...gle for the load encroachment function the resistive blinder for the zone measurement can be expanded according to the right in figure 70 given higher fault resistance coverage without risk for unwanted operation due to load encroachment This is valid in both directions The use of the load encroachment feature is essential for long heavy loaded lines where there might be a conflict between the nec...

Page 200: ...Table 25 Definition of long lines Line category Vn Vn 110 kV 500 kV Long lines 45 60 miles 200 250 miles Very long lines 60 miles 250 miles The possibility in IED to set resistive and reactive reach independent for positive and zero sequence fault loops and individual fault resistance settings for phase to phase and phase to ground fault together with load encroachment algorithm improves the possi...

Page 201: ...e same voltage to experience mutual coupling and some coupling exists even for lines that are separated by 100 meters or more The reason to the introduced error in measuring due to mutual coupling is the zero sequence voltage inversion that occurs It can be shown from analytical calculations of line impedances that the mutual impedances for positive and negative sequence are very small 1 2 of the ...

Page 202: ...following ways by using The possibility of different setting values that influence the ground return compensation for different distance zones within the same group of setting parameters Different groups of setting parameters for different operating conditions of a protected multi circuit line Most multi circuit lines have two parallel operating circuits The application guide mentioned below recom...

Page 203: ...o ground voltage at the IED point Iph is phase current in the faulty phase 3I0 is ground fault current Z1 is positive sequence impedance Z0 is zero sequence impedance Z0m A B 21 21 en05000221_ansi vsd FAULT ANSI05000221 V1 EN US Figure 72 Class 1 parallel line in service The equivalent circuit of the lines can be simplified as shown in figure 73 1MRK 504 163 UUS A Section 8 Impedance protection Tr...

Page 204: ... KNm Z Z I ph I KN EQUATION1277 V3 EN US Equation 37 Where KNm Z0m 3 Z1L The second part in the parentheses is the error introduced to the measurement of the line impedance If the current on the parallel line has negative sign compared to the current on the protected line that is the current on the parallel line has an opposite direction compared to the current on the protected line the distance f...

Page 205: ...N US Equation 41 Calculation for a 400 kV line where we for simplicity have excluded the resistance gives with X1L 0 48 Ohm Mile X0L 1 4Ohms Mile zone 1 reach is set to 90 of the line reactance p 71 that is the protection is underreaching with approximately 20 The zero sequence mutual coupling can reduce the reach of distance protection on the protected circuit when the parallel line is in normal ...

Page 206: ...ends Here the equivalent zero sequence impedance is equal to Z0 Z0m in parallel with Z0 Z0m Z0 Z0m Z0m which is equal to equation 42 2 2 0 0 om E Z Z Z Z EQUATION2002 V4 EN US Equation 42 The influence on the distance measurement can be a considerable overreach which must be considered when calculating the settings All expressions below are proposed for practical use They assume the value of zero ...

Page 207: ...s high which limits the zero sequence current on the parallel line to very low values In practice the equivalent zero sequence impedance circuit for faults at the remote bus bar can be simplified to the circuit shown in figure 76 The line zero sequence mutual impedance does not influence the measurement of the distance protection in a faulty circuit This means that the reach of the underreaching d...

Page 208: ...d in reactive and resistive directions If the real and imaginary components of the constant A are equal to equation 46 and equation 47 Re 0 2 1 0 3 0 0 2 1 A R R R Rf X X X EQUATION1285 V1 EN US Equation 46 0 1 0 1 0 1 0 Im 2 3 2 A X R R R R X X EQUATION1286 V1 EN US Equation 47 The real component of the KU factor is equal to equation 48 Re Re Re Im K A X A A u m 1 0 2 2 2 EQUATION1287 V3 EN US Eq...

Page 209: ...C A B BC ANSI05000224 2 en vsd ANSI05000224 V2 EN US Figure 78 Example of tapped line with Auto transformer This application gives rise to similar problem that was highlighted in section Fault infeed from remote end that is increased measured impedance due to fault current infeed For example for faults between the T point and B station the measured impedance at A and C is as follows 1MRK 504 163 U...

Page 210: ...ave a reverse direction for fault on the protected line For example for faults at T the current from B might go in reverse direction from B to C depending on the system parameters as shown in the dotted line in figure 78 given that the distance protection in B to T will measure wrong direction In three end application depending on the source impedance behind the IEDs the impedances of the protecte...

Page 211: ...em stability and increase loadability of transmission corridors The principle is based on compensation of distributed line reactance by insertion of series capacitor SC The generated reactive power provided by the capacitor is continuously proportional to the square of the current flowing at the same time through the compensated line and series capacitor This means that the series capacitor has a ...

Page 212: ...f voltage stability by reducing the reactance of the line and consequently the SC is valuable for prevention of voltage collapse Figure 80 presents the voltage dependence at receiving bus B as shown in figure 79 on line loading and compensation degree KC which is defined according to equation 53 The effect of series compensation is in this particular case obvious and self explanatory C C Line X K ...

Page 213: ...ce between the generator and the infinite bus increases during the fault At the time of fault clearing the angle difference has increased to δC After reclosing of the system the transmitted power exceeds the mechanical input power and the generator deaccelerates The generator decelerates as long as equal area condition AACC ADEC has not been fulfilled The critical condition for post fault system s...

Page 214: ...capacitor The series compensation can improve the situation in two ways it can decrease the initial angle difference δ0 corresponding to a certain power transfer and it also shifts the P δ curve upwards Improve reactive power balance SEMOD168320 43 v2 A series capacitor increases its output of reactive power instantaneously continuously and automatically with increasing line load It is thus a self...

Page 215: ...cuit shown in figure 84 The power transfer on the transmission line is given by the equation 55 A B A B Line C Line C V V sin V V sin P X X X 1 K d d EQUATION1994 ANSI V1 EN US Equation 55 The compensation degree Kc is defined as equation A B jXC PA QA PB QB VA VB V jXL VA VB en06000590_ansi vsd D d ANSI06000590 V1 EN US Figure 84 Transmission line with series capacitor The effect on the power tra...

Page 216: ...ransmission lines with sufficient thermal capacity can relieve the possible overloading of other parallel lines This distribution is governed by the reactance while the losses are determined by the resistance A properly designed series compensation system can considerably reduce the total transmission system losses as shown in figure 86 en06000593 vsd RL1 jXL1 jXC Line 1 jXL2 RL2 Line 2 IEC0600059...

Page 217: ...sts the same increase in power transmission for up to 90 reduced costs In many cases the only practical way to increase the transmission capacity of a corridor Series compensation shortens the lead times Environmental impact EA EB New transmission line Series compensation en06000594 vsd IEC06000594 V1 EN US Figure 87 Series compensation is an important alternative to new transmission lines Advance...

Page 218: ...e path see figure 89 The main circuit of the TCSC consists of a capacitor bank and a thyristor controlled inductive branch connected in parallel The capacitor bank may have a value of for example 10 30 Ω phase and a rated continuous current of 1500 3000 A The capacitor bank for each phase is mounted on a platform providing full insulation towards ground The thyristor valve contains a string of ser...

Page 219: ...l 50Hz system The apparent impedance of the TCSC the impedance seen by the power system can typically be increased to up to 3 times the physical impedance of the capacitor see figure 91 This high apparent reactance will mainly be used for damping of power oscillations en06000598 vsd Imperatriz TCSC Operating range 0 4 0 2 0 0 2 0 4 0 6 0 8 1 1 2 1 4 1 6 1 8 2 2 2 2 4 2 6 2 8 3 3 2 0 300 600 900 12...

Page 220: ... current inversion SEMOD168320 168 v2 Series capacitors influence the magnitude and the direction of fault currents in series compensated networks They consequently influence phase angles of voltages measured in different points of series compensated networks and this performances of different protection functions which have their operation based on properties of measured voltage and current phaso...

Page 221: ...i vsd 21 XS XL1 IF V VM Source Fault voltage Pre fault voltage XC Source voltage V M With bypassed capacitor With inserted capacitor F X ANSI06000605 V1 EN US Figure 92 Voltage inversion on series compensated line en06000606_ansi vsd IF V S V M xV L xV S IF x V L V S x V C V M xV S With bypassed capacitor With inserted capacitor ANSI06000606 V1 EN US Figure 93 Phasor diagrams of currents and volta...

Page 222: ...ction for more details which must for this reason comprise special measures against this phenomenon There will be no voltage inversion phenomena for reverse faults in system with VTs located on the bus side of series capacitor The allocation of VTs to the line side does not eliminate the phenomenon because it appears again for faults on the bus side of IED point Current inversion SEMOD168320 206 v...

Page 223: ...tions on non compensated lines and in cases when the capacitor is bypassed either by spark gap or by the bypass switch as shown in phasor diagram in figure 95 The resultant reactance is in this case of inductive nature and the fault currents lags source voltage by 90 electrical degrees The resultant reactance is of capacitive nature in the second case Fault current will for this reason lead the so...

Page 224: ...The possibility for current inversion in modern networks is increasing and must be studied carefully during system preparatory studies The current inversion phenomenon should not be studied only for the purposes of protection devices measuring phase currents Directional comparison protections based on residual zero sequence and negative sequence currents should be considered in studies as well Cur...

Page 225: ... in figure 96 without series capacitor is presented by equation 62 sin w l L L L L G di L R i E t dt EQUATION1905 V1 EN US Equation 62 The solution over line current is presented by group of equations 63 0 2 2 sin sin w l j l j w w j é ù ê ú ë û æ ö ç è ø L L R t L G G L L t L L L L E E i t I e Z Z Z R L L atg R EQUATION1906 V1 EN US Equation 63 The line fault current consists of two components Th...

Page 226: ...otal loop impedance decreases for the negative reactance of the series capacitor which in fact increases the magnitude of the fault current The transient part consists of the damped oscillation which has an angular frequency b and is dying out with a time constant a 1 2 2 2 1 0 0 0 2 2 sin cos sin 1 sin sin cos 2 1 sin 2 2 1 4 a w l j b b w w l j w l l j b l j a b æ ö ç è ø é ù ê ú ê ú ê ú ê ú ë û...

Page 227: ...an on non compensated line This occurs due to the energy stored in capacitor before the fault 0 0 02 0 04 0 06 0 08 0 1 0 12 0 14 0 16 0 18 0 2 10 5 5 10 t ms I pu en06000610 vsd IEC06000610 V1 EN US Figure 97 Short circuit currents for the fault at the end of 500 km long 500 kV line without and with SC Location of instrument transformers SEMOD168320 261 v2 Location of instrument transformers rela...

Page 228: ...t the case with line side instrument transformers The protective devices will not be exposed to voltage and current inversion for faults on the protected line which increases the dependability Distance protection zone 1 may be active in most applications which is not the case when the bus side instrument transformers are used Distance IEDs are exposed especially to voltage inversion for close in r...

Page 229: ...lines Figure 99 presents typical locations of capacitor banks on power lines together with corresponding compensation degrees Distance IED near the feeding bus will see in different cases fault on remote end bus depending on type of overvoltage protection used on capacitor bank spark gap or MOV and SC location on protected power line en06000612_ansi vsd EA 0 33 50 66 KC 80 33 33 50 21 100 80 X ANS...

Page 230: ...e but it does not cause wrong directional measurement Such cases are presented in figure 100 for 50 compensation at 50 of line length and 33 compensation located on 33 and 66 of line length The remote end compensation has the same effect The voltage inversion occurs in cases when the capacitor reactance between the IED point and fault appears bigger than the corresponding line reactance Figure 23 ...

Page 231: ...Kp In IEC06000615 V1 EN US Figure 102 Equivalent impedance of MOV protected capacitor in dependence of protection factor KP Figure 102 presents three typical cases for series capacitor located at line end case LOC 0 in figure 100 Series capacitor prevails the scheme as long as the line current remains lower or equal to its protective current level I kp INC Line apparent impedance is in this case r...

Page 232: ...Figure 103 Voltage inversion in series compensated network due to fault current infeed Voltage at the B bus as shown in figure 103 is calculated for the loss less system according to the equation below B D B LB A B LF C B LB V V I jX I I j X X I jX EQUATION1998 ANSI V1 EN US Equation 68 Further development of equation 68 gives the following expressions 1 é ù æ ö ê ç ú è ø ë û A B B LB LF C B I V j...

Page 233: ...Vs on series capacitors will not conduct at all At the same time this kind of investigation must consider also the maximum sensitivity and possible resistive reach of distance protection devices which on the other hand simplifies the problem Application of MOVs as non linear elements for capacitor overvoltage protection makes simple calculations often impossible Different kinds of steady state net...

Page 234: ...rst distance underreaching protection zone must be set to a reach less than the reactance of the compensated line in accordance with figure 104 en06000618 vsd X11 X12 jXC A B DA DB Zone 1A Zone 1B Zone 2A Zone 2B G IEC06000618 V1 EN US Figure 104 Underreaching Zone 1 and overreaching Zone 2 on series compensated line The underreaching zone will have reduced reach in cases of bypassed series capaci...

Page 235: ...aching distance protection or some kind of directional or unit protection must be used The overreach must be of an order so it overreaches when the capacitor is bypassed or out of service Figure 106 shows the permissive zones The first underreaching zone can be kept in the total protection but it only has the feature of a back up protection for close up faults The overreach is usually of the same ...

Page 236: ...o consideration the negative voltage drop on XC is amplified and a protection far away from the faulty line can maloperate by its instantaneous operating distance zone if no precaution is taken Impedances seen by distance IEDs on adjacent power lines are presented by equations 73 to 76 1 2 3 I I I I EQUATION1915 V1 EN US Equation 73 X X I I X X DA A F A C 1 1 1 11 EQUATION1916 V2 EN US Equation 74...

Page 237: ...lower than the capacitor reactance and voltage inversion phenomenon may occur also on remote end of adjacent lines Distance protection of such line must have built in functionality which applies normally to protection of series compensated lines It usually takes a bit of a time before the spark gap flashes and sometimes the fault current will be of such a magnitude that there will not be any flash...

Page 238: ...ground faults satisfactory if the negative impedance occurs inside the characteristic The operating area for negative impedance depends upon the magnitude of the source impedance and calculations must be made on a case by case basis as shown in figure 108 Distance IEDs with separate impedance and directional measurement offer additional setting and operational flexibility when it comes to measurem...

Page 239: ...e negative fault current seldom occurs In normal network configurations the gaps will flash in this case Double circuit parallel operating series compensated lines SEMOD168320 417 v2 Two parallel power lines running in electrically close vicinity to each other and ending at the same busbar at both ends as shown in figure 110 causes some challenges for distance protection because of the mutual impe...

Page 240: ... operating circuits as presented in figure 112 than also one distance IED operating in POTT teleprotection scheme on parallel healthy circuit will send a carrier signal CSAB to the remote line end where this signal will be received as a carrier receive signal CRBB en06000629_ansi vsd RAA RBA IFC1 IFC1 X F RAB RBB IFC2 CSAB CRBB RAA RBA IFC1 X F RAB RBB IFC2 CSAB CRBB ANSI06000629 V1 EN US Figure 1...

Page 241: ... However they can only be used for phase to ground and phase to phase faults For three phase faults an additional protection must be provided 8 1 3 Setting guidelines SEMOD168241 1 v2 8 1 3 1 General SEMOD168247 4 v2 The settings for the distance protection function are done in primary values The instrument transformer ratio that has been set for the analog input card is used to automatically conv...

Page 242: ...le higher than the fault current at the IED location The setting must not exceed 80 of the following impedances The impedance corresponding to the protected line plus the first zone reach of the shortest adjacent line The impedance corresponding to the protected line plus the impedance of the maximum number of transformers operating in parallel on the bus at the remote end of the protected line If...

Page 243: ...alculate the reach in reverse direction when the zone is used for blocking scheme weak end infeed and so on 1 2 2 Zrev ZL Z rem EQUATION1525 V5 EN US Equation 82 Where ZL is the protected line impedance Z2rem is zone2 setting at remote end of protected line In some applications it might be necessary to consider the enlarging factor due to fault current infeed from adjacent lines in the reverse dir...

Page 244: ... on faulty line as well as on the adjacent lines This artificial fault always have a resistive component this is however small and can mostly not be used to prevent tripping of a healthy adjacent line An independent tripping zone 1 facing a bus which can be exposed to voltage reversal have to be set with reduced reach with respect to this false fault When the fault can move and pass the bus the zo...

Page 245: ...nce X1 to the driving source to the fault If only the line reactance is used the degree of compensation will be too high and the zone 1 reach unnecessary reduced The highest degree of compensation will occur at three phase fault and therefore the calculation need only to be performed for three phase faults The compensation degree in ground return path is different than in phases It is for this rea...

Page 246: ... reach XC A XLLOC XL B en07000063 vsd IEC07000063 V1 EN US Figure 115 Simplified single line diagram of series capacitor located at XLLOC ohm from A station Section 8 1MRK 504 163 UUS A Impedance protection 240 Transformer protection RET670 2 2 ANSI Application manual ...

Page 247: ... series capacitor in the picture approximate 33 of XLine X1 is set to XLindex XC p 100 p is defined according to figure 114 1 2 is safety factor for fast operation of Zone 1 Compensated line with the series capacitor not into the reach of zone 1 The setting is thus X1 is set to XLine XC p 100 1MRK 504 163 UUS A Section 8 Impedance protection Transformer protection RET670 2 2 ANSI 241 Application m...

Page 248: ...resistive direction for phase to ground fault measurement as well as for phase to phase measurement Overreaching zone 2 SEMOD168247 211 v2 In series compensated network where independent tripping zones will have reduced reach due to the negative reactance in the capacitor and the sub harmonic swinging the tripping will to a high degree be achieved by the communication scheme With the reduced reach...

Page 249: ...ding to the minimum load impedance Optional higher distance protection zones SEMOD168247 226 v2 When some additional distance protection zones zone 4 for example are used they must be set according to the influence of the series capacitor 8 1 3 6 Setting of zones for parallel line application SEMOD168247 48 v2 Parallel line in service Setting of zone1 SEMOD168247 50 v2 With reference to section Pa...

Page 250: ...uation 87 2 2 0 Im Im 0 Re Im X m B K B B EQUATION1428 V2 EN US Equation 88 Parallel line is out of service and grounded in both ends SEMOD168247 69 v2 Apply the same measures as in the case with a single set of setting parameters This means that an underreaching zone must not overreach the end of a protected circuit for the single phase to ground faults Set the values of the corresponding zone ze...

Page 251: ...tion RFP G 4 5 X1P G EQUATION1717 V1 EN US Equation 93 The fault resistance for phase to phase faults is normally quite low compared to the fault resistance for phase to ground faults Limit the setting of the zone1 reach in resistive direction for phase to phase loop measurement to 3 1 RFPP X EQUATION570 V2 EN US Equation 94 8 1 3 8 Load impedance limitation without load encroachment function SEMO...

Page 252: ...orrect healthy phase IED operation under combined heavy three phase load and ground faults consider both phase to phase and phase to ground fault operating characteristics To avoid load encroachment for the phase to ground measuring elements the set resistive reach of any distance protection zone must be less than 80 of the minimum load impedance load RFPG 0 8 Z EQUATION1720 V1 EN US Equation 97 T...

Page 253: ... protection scheme Use an additional safety margin of approximately 20 in cases when a power swing detection element is in the protection scheme refer to the description of Power swing detection ZMRPSB 68 function 8 1 3 9 Load impedance limitation with load encroachment function activated SEMOD168247 129 v2 The parameters for load encroachment shaping of the characteristic are found in the descrip...

Page 254: ... timers for distance protection zones SEMOD168247 138 v2 The required time delays for different distance protection zones are independent of each other Distance protection zone1 can also have a time delay if so required for selectivity reasons One can set the time delays for all zones basic and optional in a range of 0 to 60 seconds The tripping function of each particular zone can be inhibited by...

Page 255: ...se currents and the residual current and compare them with the set values The extensive output signals from FDPSPDIS 21 give also important information about faulty phase s which can be used for fault analysis 8 2 3 Setting guidelines IP14959 1 v2 The following setting guideline consider normal overhead lines applications where φloop and φline is greater than 60 8 2 3 1 Load encroachment character...

Page 256: ...ssary increased setting of the fault resistance coverage can be derived from trigonometric evaluation of the basic characteristic for respectively fault type Phase to ground fault in forward direction M13142 6 v7 With reference to figure 117 the following equations for the setting calculations can be obtained Index PHS in images and equations reference settings for Phase selection with load encroa...

Page 257: ...21 and impedance zone ZMQPDIS 21 for phase to ground fault φloop 60 setting parameters in italic 1 FDPSPDIS phase selection 21 red line 2 ZMQPDIS Impedance protection zone 21 3 RFltRevPGPHS 4 X1PHS XN tan 60 5 RFltFwdPGPHS 6 RFPGZM 7 X1PHS XN 8 φloop 9 X1ZM XN 1MRK 504 163 UUS A Section 8 Impedance protection Transformer protection RET670 2 2 ANSI 251 Application manual ...

Page 258: ...h M13142 103 v5 The resistive reach must cover RFPG for the overreaching zone to be covered mostly zone 2 Consider the longest overreaching zone if correct fault selection is important in the application Equation 104 gives the minimum recommended resistive reach min 1 1 zm RFltFwdPG RFPG EQUATION1724 V2 EN US Equation 104 where RFPGZm is the setting RFPG for the longest overreaching zone to be cov...

Page 259: ...es in forward direction RFItFwdPP must cover RFPPZm with at least 25 margin RFPPZm is the setting of fault resistance for phase to phase fault for the longest overreaching zone to be covered by FDPSPDIS 21 see Figure 118 The minimum recommended reach can be calculated according to equation 106 1 25 zm RFltFwdPP RFPP EQUATION1318 ANSI V1 EN US Equation 106 where RFPPZm is the setting of the longest...

Page 260: ...and FDPSPDIS 21 characteristic for phase to phase fault for φline 60 setting parameters in italic 1 FDPSPDIS phase selection 21 red line 2 ZMQPDIS Impedance protection zone 21 3 0 5 RFltRevPP PHS 4 60 tan PHS X1 5 0 5 RFltFwdPP PHS 6 0 5 RFPPZm 7 X1PHS Section 8 1MRK 504 163 UUS A Impedance protection 254 Transformer protection RET670 2 2 ANSI Application manual ...

Page 261: ...e en05000226_ansi vsd LdAngle ANSI05000226 V1 EN US Figure 119 Load encroachment characteristic The load angle LdAngle is the same in forward and reverse direction so it could be suitable to begin to calculate the setting for that parameter Set the parameter to the maximum possible load angle at maximum active load A value bigger than 20 must be used The blinder in forward direction RLdFwd can be ...

Page 262: ...rrent setting parameters which blocks the respective phase to ground loop and phase to phase loop if the RMS value of the phase current ILn and phase difference current ILmILn is below the settable threshold The threshold to activate the phase selector for phase to ground IMinPUPG is set to securely detect a single phase to ground fault at the furthest reach of the phase selection It is recommende...

Page 263: ...engths These changes in the network will normally impose more stringent demands on the fault clearing equipment in order to maintain an unchanged or increased security level of the power system The distance protection function in the IED is designed to meet basic requirements for application on transmission and sub transmission lines solid grounded systems although it also can be used on distribut...

Page 264: ...e sequence impedance Ω phase Z2 is the negative sequence impedance Ω phase is considered to be equal to Z1 Z0 is the zero sequence impedance Ω phase Zf is the fault impedance Ω often resistive ZN is the ground return impedance defined as Z0 Z1 3 The voltage on the healthy phases is generally lower than 140 of the nominal phase to ground voltage This corresponds to about 80 of the nominal phase to ...

Page 265: ... Where R0 is the zero sequence source resistance X0 is the zero sequence source reactance R1 is the positive sequence source resistance X1 is the positive sequence source reactance The magnitude of the ground fault current in effectively grounded networks is high enough for impedance measuring elements to detect ground faults However in the same way as for solidlygrounded networks distance protect...

Page 266: ...3I0 is the ground fault current A IR is the current through the neutral point resistor A IL is the current through the neutral point reactor A IC is the total capacitive ground fault current A The neutral point reactor is normally designed so that it can be tuned to a position where the reactive current balances the capacitive current from the network that is 1 3 L C w w EQUATION1272 V1 EN US Equa...

Page 267: ...lt 8 3 2 2 Fault infeed from remote end M17048 83 v5 All transmission and most all sub transmission networks are operated meshed Typical for this type of network is that fault infeed from remote end will happen when fault occurs on the protected line The fault current infeed will enlarge the fault impedance seen by the distance protection This effect is very important to keep in mind when both pla...

Page 268: ...tion is to consider this with the settings that is to have a security margin between the distance zone and the minimum load impedance This has the drawback that it will reduce the sensitivity of the protection that is the ability to detect resistive faults The IED has a built in function which shapes the characteristic according to the right figure of figure 123 The load encroachment algorithm wil...

Page 269: ...sified as short medium and long The definition of short medium and long lines is found in IEEE Std C37 113 1999 The length classification is defined by the ratio of the source impedance at the protected line s terminal to the protected line s impedance SIR SIR s of about 4 or greater generally define a short line Medium lines are those with SIR s greater than 0 5 and less than 4 In short line appl...

Page 270: ...ication M17048 516 v5 For long transmission lines the margin to the load impedance that is to avoid load encroachment will normally be a major concern It is well known that it is difficult to achieve high sensitivity for phase to ground fault at remote line end of long lines when the line is heavy loaded What can be recognized as long lines with respect to the performance of distance protection ca...

Page 271: ...ling and some coupling exists even for lines that are separated by 100 meters or more The mutual coupling does influence the zero sequence impedance to the fault point but it does not normally cause voltage inversion It can be shown from analytical calculations of line impedances that the mutual impedances for positive and negative sequence are very small 1 2 of the self impedance and it is a prac...

Page 272: ...he influence of a zero sequence mutual coupling on the measurement at single phase to ground faults in the following ways by using The possibility of different setting values that influence the ground return compensation for different distance zones within the same group of setting parameters Different groups of setting parameters for different operating conditions of a protected multi circuit lin...

Page 273: ...sitive sequence impedance Z0 is zero sequence impedance Z0m A B 21 21 en05000221_ansi vsd FAULT ANSI05000221 V1 EN US Figure 125 Class 1 parallel line in service The equivalent circuit of the lines can be simplified see figure 126 A B C Z0m Z0m Z0 Z0m Z0 IEC09000253_1_en vsd IEC09000253 V1 EN US Figure 126 Equivalent zero sequence impedance circuit of the double circuit parallel operating line wit...

Page 274: ...parallel line has an opposite direction compared to the current on the protected line the distance function will overreach If the currents have the same direction the distance protection will underreach Maximum overreach will occur if the fault current infeed from remote line end is weak If considering a single phase to ground fault at p unit of the line length from A to B on the parallel line for...

Page 275: ... approximately 20 The zero sequence mutual coupling can reduce the reach of distance protection on the protected circuit when the parallel line is in normal operation The reduction of the reach is most pronounced with no current infeed in the IED closest to the fault This reach reduction is normally less than 15 But when the reach is reduced at one line end it is proportionally increased at the op...

Page 276: ... E Z Z Z Z EQUATION2002 V4 EN US Equation 124 The influence on the distance measurement will be a considerable overreach which must be considered when calculating the settings All expressions below are proposed for practical use They assume the value of zero sequence mutual resistance R0m equals to zero They consider only the zero sequence mutual reactance X0m Calculate the equivalent X0E and R0E ...

Page 277: ...ual impedance does not influence the measurement of the distance protection in a faulty circuit This means that the reach of the underreaching distance protection zone is reduced if due to operating conditions the equivalent zero sequence impedance is set according to the conditions when the parallel system is out of operation and grounded at both ends A B C IEC09000255_1_en vsd I0 I0 Z0m Z0 Z0m Z...

Page 278: ...ctor is equal to equation 130 Re Re Re Im K A X A A u m 1 0 2 2 2 EQUATION1287 V3 EN US Equation 130 The imaginary component of the same factor is equal to equation 131 2 0 2 2 Im Im Re Im m U A X K A A é ù é ù ë û ë û EQUATION1288 V2 EN US Equation 131 Ensure that the underreaching zones from both line ends will overlap a sufficient amount at least 10 in the middle of the protected circuit 8 3 2 ...

Page 279: ...mote end that is increased measured impedance due to fault current infeed For example for faults between the T point and B station the measured impedance at A and C will be ZA ZAT ZTF IA IC IA DOCUMENT11524 IMG3509 V3 EN US Equation 132 A C 2 C Trf CT TB C I I V2 Z Z Z Z V1 I EQUATION1714 V1 EN US Equation 133 1MRK 504 163 UUS A Section 8 Impedance protection Transformer protection RET670 2 2 ANSI...

Page 280: ...C depending on the system parameters see the dotted line in figure 131 given that the distance protection in B to T will measure wrong direction In three end application depending on the source impedance behind the IEDs the impedances of the protected object and the fault location it might be necessary to accept zone 2 trip in one end or sequential trip in one end Generally for this type of applic...

Page 281: ...convert the measured secondary input signals to primary values used in ZMQPDIS 21 The following basics must be considered depending on application when doing the setting calculations Errors introduced by current and voltage instrument transformers particularly under transient conditions Inaccuracies in the line zero sequence impedance data and their effect on the calculated value of the ground ret...

Page 282: ...nt lines at remote end is considerable higher than the fault current at the IED location The setting shall generally not exceed 80 of the following impedances The impedance corresponding to the protected line plus the first zone reach of the shortest adjacent line The impedance corresponding to the protected line plus the impedance of the maximum number of transformers operating in parallel on the...

Page 283: ...verreaching zone used at the remote line IED for the telecommunication purposes Consider the possible enlarging factor that might exist due to fault infeed from adjacent lines Equation 136 can be used to calculate the reach in reverse direction when the zone is used for blocking scheme weak end infeed and so on 1 2 2 Zrev ZL Z rem EQUATION1525 V5 EN US Equation 136 Where ZL is the protected line i...

Page 284: ...pedance circuit for this case is equal to the one in figure 126 in section Parallel line in service The components of the zero sequence impedance for the overreaching zones must be equal to at least R0E R0 Rm0 EQUATION553 V1 EN US Equation 137 X0E X0 Xm0 EQUATION554 V1 EN US Equation 138 Check the reduction of a reach for the overreaching zones due to the effect of the zero sequence mutual couplin...

Page 285: ...each in resistive direction SEMOD55087 84 v7 Set the resistive reach R1 independently for each zone Set separately the expected fault resistance for phase to phase faults RFPP and for the phase to ground faults RFPE for each zone For each distance zone set all remaining reach setting parameters independently of each other The final reach in resistive direction for phase to ground fault loop measur...

Page 286: ... function FDPSPDIS 21 is not used The setting of the load resistance RLdFwd and RldRev in FDPSPDIS 21 must in this case be set to max value 3000 If FDPSPDIS 21 is to be used for all or some of the measuring zones the load limitation for those zones according to this chapter can be omitted Check the maximum permissible resistive reach for any zone to ensure that there is a sufficient setting margin...

Page 287: ...than three times as large as the maximum expected load impedance angle For the case when the loop characteristic angle is less than three times the load impedance angle more accurate calculations are necessary according to equation 151 RFFwPG Z R R X X load 0 8 2 1 0 2 1 0 cos sin min ANSI13000274 V1 EN US Equation 151 Where is a maximum load impedance angle related to the maximum load power To av...

Page 288: ...of the parameter IMinPUPP and IMinPUPG The default setting of IMinPUPP and IMinPUPG is 20 of IBase where IBase is the chosen current for the analogue input channels The value has been proven in practice to be suitable in most of the applications However there might be applications where it is necessary to increase the sensitivity by reducing the minimum operating current down to 10 of IBase This h...

Page 289: ...itive sequence memorized phase voltage in phase A IA is phase current in phase A V1AB is voltage difference between phase A and B B lagging A V1ABM is memorized voltage difference between phase A and B B lagging A IAB is current difference between phase A and B B lagging A The setting of AngDir and AngNegRes is by default set to 15 15 and 115 degrees respectively as shown in figure 133 It should n...

Page 290: ...e same positive sequence voltage ensures correct directional discrimination The memory voltage is used for 100 ms or until the positive sequence voltage is restored After 100 ms the following occurs If the current is still above the set value of the minimum operating current between 10 and 30 of the set IED rated current IBase the condition seals in If the fault has caused tripping the trip endure...

Page 291: ...distance protection 8 4 Full scheme distance measuring Mho characteristic ZMHPDIS 21 SEMOD154227 1 v4 8 4 1 Identification SEMOD154447 2 v2 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Full scheme distance protection mho characteristic ZMHPDIS S00346 V1 EN US 21 8 4 2 Application SEMOD154444 1 v1 8 4 2 1 Generator underimpedance protection ap...

Page 292: ...nly be configured In this figure three underimpedance zones are included ANSI10000101 V1 EN US Figure 134 Mho function example configuration for generator protection application 8 4 3 2 Settings GUID 53D13CBF 02DD 40EE B579 5DFA16144C20 v4 Full scheme distance measuring Mho characteristic ZMHPDIS 21 used as an under impedance function shall be set for the application example shown in figure 135 Se...

Page 293: ...2kV 3062A 65MVA 123 13kV xt 10 REG670 IEC10000102 V1 EN US Figure 135 Application example for generator under impedance function The first under impedance protection zone shall cover 100 of the step up transformer impedance with a time delay of 1 0s 1MRK 504 163 UUS A Section 8 Impedance protection Transformer protection RET670 2 2 ANSI 287 Application manual ...

Page 294: ...ponding settings in primary ohms for forward and reserve reach and time delay shall be entered accordingly Parameter ZPP shall be set to 0 260Ω Parameter ZrevPP shall be set to 0 260Ω Parameter tPP shall be set to 1 0000s Parameter ZAngPP shall be set to default value 85 Deg Set the following for the directional element ZDMRDIR The parameter GlobalBaseSel shall be set in order to select the global...

Page 295: ...P P X R IEC10000105 1 en vsd IEC10000105 V1 EN US Figure 136 Operating characteristic for phase to phase loops 1MRK 504 163 UUS A Section 8 Impedance protection Transformer protection RET670 2 2 ANSI 289 Application manual ...

Page 296: ...anges in the network will normally impose more stringent demands on the fault clearing equipment in order to maintain an unchanged or increased security level of the power system The distance protection function in IED is designed to meet basic requirements for application on transmission and sub transmission lines solid grounded systems although it also can be used on distribution levels 8 5 2 2 ...

Page 297: ...e fault Z1 is the positive sequence impedance Ω phase Z2 is the negative sequence impedance Ω phase Z0 is the zero sequence impedance Ω phase Zf is the fault impedance Ω often resistive ZN is the ground return impedance defined as Z0 Z1 3 The voltage on the healthy phases is generally lower than 140 of the nominal phase to ground voltage This corresponds to about 80 of the nominal phase to phase v...

Page 298: ... high enough for impedance measuring element to detect fault However in the same way as for solid grounded networks distance protection has limited possibilities to detect high resistance faults and should therefore always be complemented with other protection function s that can carry out the fault clearance in this case High impedance grounded networks SEMOD154680 58 v3 In high impedance network...

Page 299: ... balances the capacitive current from the network that is 1 3 L C w w EQUATION1272 V1 EN US Equation 161 IEC05000216 V2 EN US Figure 138 High impedance grounding network The operation of high impedance grounded networks is different compare to solid grounded networks where all major faults have to be cleared very fast In high impedance grounded networks some system operators do not clear single ph...

Page 300: ...d meshed Typical for this type of network is that we will have fault infeed from remote end when fault occurs on the protected line The fault infeed will enlarge the fault impedance seen by the distance protection This effect is very important to keep in mind when both planning the protection system and making the settings With reference to figure 139 we can draw the equation for the bus voltage V...

Page 301: ...hat is the ability to detect resistive faults The IED has a built in function which shapes the characteristic according to the right figure 4 The load encroachment algorithm will increase the possibility to detect high fault resistances especially for line to ground faults at remote end For example for a given setting of the load angle LdAngle for the load encroachment function the resistive blind...

Page 302: ...as voltage and source impedance see table Short line application Table 28 Definition of short and very short line Line category Vn Vn 110 kV 500 kV Very short line Short line 0 75 3 5 miles 3 15 miles 4 7 miles 15 30 miles The possibility in IED to set resistive and reactive reach independent for positive and zero sequence fault loops and individual fault resistance settings for phase to phase and...

Page 303: ...for phase to phase and phase to ground fault together with load encroachment algorithm improves the possibility to detect high resistive faults at the same time as the security is improved risk for unwanted trip due to load encroachment is eliminated 8 5 2 7 Parallel line application with mutual coupling SEMOD154680 148 v1 General SEMOD154680 150 v2 Introduction of parallel lines in the network is...

Page 304: ...ration and out of service and grounded at both ends The distance protection within the IED can compensate for the influence of a zero sequence mutual coupling on the measurement at single phase to ground faults in the following ways by using The possibility of different setting values that influence the ground return compensation for different distance zones within the same group of setting parame...

Page 305: ... US Equation 164 Where Vph is phase to ground voltage at the IED point Iph is phase current in the faulty phase 3I0 is ground to fault current Z1 is positive sequence impedance Z0 is zero sequence impedance Z0m A B Z Z en05000221 vsd IEC05000221 V1 EN US Figure 141 Class 1 parallel line in service The equivalent circuit of the lines can be simplified see figure 142 1MRK 504 163 UUS A Section 8 Imp...

Page 306: ...X0L 0 88 Ω km zone 1 reach is set to 90 of the line reactance p 71 that is the protection is underreaching with approximately 20 The zero sequence mutual coupling can reduce the reach of distance protection on the protected circuit when the parallel line is in normal operation The reduction of the reach is most pronounced with no infeed in the line IED closest to the fault This reach reduction is ...

Page 307: ...ement will be a considerable overreach which must be considered when calculating the settings It is a recommendation to use a separate setting group for this operation condition since it will reduce the reach considerable when the line is in operation All expressions below are proposed for practical use They assume the value of zero sequence mutual resistance R0m equals to zero They consider only ...

Page 308: ...ce does not influence the measurement of the distance protection in a faulty circuit This means that the reach of the underreaching distance protection zone is reduced if due to operating conditions the equivalent zero sequence impedance is set according to the conditions when the parallel system is out of operation and grounded at both ends Z Z0 0 m Z Z0 0 m Z0m A B C 99000040 vsd I0 I0 IEC990000...

Page 309: ...or is equal to equation 171 Re Re Re Im K A X A A u m 1 0 2 2 2 EQUATION1287 V3 EN US Equation 171 The imaginary component of the same factor is equal to equation 172 2 0 2 2 Im Im Re Im m U A X K A A é ù é ù ë û ë û EQUATION1288 V2 EN US Equation 172 Ensure that the underreaching zones from both line ends will overlap a sufficient amount at least 10 in the middle of the protected circuit 8 5 2 8 ...

Page 310: ... DOCUMENT11524 IMG3509 V3 EN US Equation 173 2 2 1 A C C Trf CT TB C I I V Z Z Z Z V I æ ö æ ö ç ç è ø è ø EQUATION1783 ANSI V1 EN US Equation 174 Where ZAT and ZCT is the line impedance from the B respective C station to the T point IA and IC is fault current from A respective C station for fault between T and B V2 V1 Transformation ratio for transformation of impedance at V1 side of the transfor...

Page 311: ... enough sensitivity without interference with other zone1 settings that is without selectivity conflicts Careful fault calculations are necessary to determine suitable settings and selection of proper scheme communication Fault resistance SEMOD154680 288 v2 The performance of distance protection for single phase to ground faults is very important because normally more than 70 of the faults on tran...

Page 312: ...s of the protected fault resistance is considerable the effect must be recognized Zero sequence mutual coupling from parallel lines 8 5 3 2 Setting of zone1 SEMOD154704 15 v1 The different errors mentioned earlier usually require a limitation of the underreaching zone normally zone 1 to 75 90 of the protected line In case of parallel lines consider the influence of the mutual coupling according to...

Page 313: ... be reduced below 120 of the protected line section The whole line must be covered under all conditions The requirement that the zone 2 shall not reach more than 80 of the shortest adjacent line at remote end is highlighted wit a simple example below If a fault occurs at point F the IED at point A senses the impedance Z V I Z I I I Z I I I I R Z I I Z AF A A AC A C A CF A C B A F AC C A C 1 F F C ...

Page 314: ...704 48 v1 Parallel line in service Setting of zone1 SEMOD154704 50 v1 With reference to section Parallel line applications the zone reach can be set to 85 of protected line Parallel line in service setting of zone2 SEMOD154704 53 v2 Overreaching zones in general zones 2 and 3 must overreach the protected circuit in all cases The greatest reduction of a reach occurs in cases when both parallel circ...

Page 315: ...ervice and grounded in both ends SEMOD154704 69 v3 Apply the same measures as in the case with a single set of setting parameters This means that an underreaching zone must not overreach the end of a protected circuit for the single phase to ground faults Set the values of the corresponding zone zero sequence resistance and reactance equal to R0E R0 1 Xm0 2 R0 2 X0 2 è ø ç æ ö EQUATION561 V1 EN US...

Page 316: ... V2 EN US Equation 187 8 5 3 7 Load impedance limitation without load encroachment function SEMOD154704 91 v2 The following instructions is valid when the load encroachment function is not activated OperationLdCmp is set to Off If the load encroachment function is to be used for all or some of the measuring zones the load limitation for those zones according to this chapter can be omitted Check th...

Page 317: ... of the minimum load impedance 0 8 load RFPEZx Z EQUATION792 V2 EN US Equation 190 This equation is applicable only when the loop characteristic angle for the single phase to ground faults is more than three times as large as the maximum expected load impedance angle More accurate calculations are necessary according to the equation below min 2 1 0 0 8 cos sin 2 1 0 load R Zx R Zx RFPEZx Z X Zx X ...

Page 318: ... remote back up protection on series of very long transmission lines If the load current compensation is activated there is an additional criteria IMinOpIN that will block the phase ground loop if the 3I0 IMinOpIN The default setting of IMinOpIN is 5 of the IED base current IBase The minimum operating fault current is automatically reduced to 75 of its set value if the distance protection zone has...

Page 319: ...polarizing quantity The setting AngleOp max 180 degrees defines the wideness of the operating sector The sector is mirror symmetric along the MTA Maximum Torque Axis Directional elements for ground faults must operate at fault current values below the magnitude of load currents As phase quantities are adversely affected by load the use of sequence quantities are preferred as polarizing quantities ...

Page 320: ...characteristic AngleRCA is fixed and equals 0 degrees Care must be taken to ensure that neutral current direction remains unchanged during all network configurations and faults and therefore all transformer configurations constructions are not suitable for polarization In dual polarization zero sequence voltage polarization and zero sequence current polarization elements function in a one out of t...

Page 321: ...equence voltage polarization with negative sequence current compensation U2Comp compares correspondingly I2 with see equation 193 and similarly it must be ensured that V2 k I2 for reverse faults AngleRCA 2 2 V k I e EQUATION1639 ANSI V2 EN US Equation 193 8 7 Mho impedance supervision logic ZSMGAPC SEMOD153841 1 v3 8 7 1 Identification GUID 030C086A 8301 481E BA0A 6550A9C1482E v2 Function descript...

Page 322: ... major factor that affects the severity of CVT transients Therefore in cases where the SIR value is too high further filtering of the measured signals will be needed 8 7 3 Setting guidelines SEMOD174968 1 v1 SEMOD154558 7 v4 GlobalBaseSel Selects the global base value group used by the function to define IBase VBase and SBase as applicable PilotMode Set PilotMode to On when pilot scheme is to be u...

Page 323: ...rations the rate of expansion and reinforcement of the power system is reduced for example difficulties to get permission to build new power lines The ability to accurately and reliably classifying different types of fault so that single pole tripping and autoreclosing can be used which plays an important roll in this matter Faulty phase identification with load encroachment for mho FMPSPDIS funct...

Page 324: ...0 that occurs when one pole opens in single pole trip applications 3I0BLK_PP The setting of 3I0BLK_PP is by default set to 40 of IBase which is suitable in most applications I1LowLevel The setting of the positive current threshold I1LowLevel used in the sequence based part of the phase selector for identifying three phase fault is by default set to 10 of IBase The default setting is suitable in mo...

Page 325: ...rs RLd for the load resistance and LdAngle for the inclination of the load sector see figure 149 R X RLdFw RLdRv LdAngle LdAngle LdAngle ANSI10000192_1_en vsd LdAngle ANSI10000192 V1 EN US Figure 149 Load encroachment characteristic The calculation of the apparent load impedance Zload and minimum load impedance Zloadmin can be done according to equations min max 3 I V Zload EQUATION1754 ANSI V1 EN...

Page 326: ...maximal apparent power transfer during emergency conditions The RLd can be calculated according to equation 199 cos RLd ZLoad LdAngle EQUATION1624 ANSI V1 EN US Equation 199 The setting of RLd and LdAngle is by default set to 80 ohm phase and 20 degrees Those values must be adapted to the specific application 8 9 Distance protection zone quadrilateral characteristic separate settings ZMRPDIS 21 ZM...

Page 327: ...r multi terminal lines of very different lengths These changes in the network will normally impose more stringent demands on the fault clearing equipment in order to maintain an unchanged or increased security level of the power system The distance protection function in the IED is designed to meet basic requirements for application on transmission and sub transmission lines although it also can b...

Page 328: ...1 is the positive sequence impedance Ω phase Z2 is the negative sequence impedance Ω phase Z0 is the zero sequence impedance Ω phase Zf is the fault impedance Ω often resistive ZN is the ground return impedance defined as Z0 Z1 3 The voltage on the healthy phases is generally lower than 140 of the nominal phase to ground voltage This corresponds to about 80 of the nominal phase to phase voltage Th...

Page 329: ...the resistive zero sequence source impedance X0 is the reactive zero sequence source impedance R1 is the resistive positive sequence source impedance X1 is the reactive positive sequence source impedance The magnitude of the ground fault current in effectively grounded networks is high enough for impedance measuring element to detect ground fault However in the same way as for solid grounded netwo...

Page 330: ...3I0 is the ground fault current A IR is the current through the neutral point resistor A IL is the current through the neutral point reactor A IC is the total capacitive ground fault current A The neutral point reactor is normally designed so that it can be tuned to a position where the reactive current balances the capacitive current from the network that is 1 3 L C w w EQUATION1272 V1 EN US Equa...

Page 331: ... 2 Fault infeed from remote end GUID 4380CD3A BCB0 45F1 A821 BC3E6D070C04 v1 All transmission and most all sub transmission networks are operated meshed Typical for this type of network is that fault infeed from remote end will happen when fault occurs on the protected line The fault current infeed will enlarge the fault impedance seen by the distance protection This effect is very important to ke...

Page 332: ... distance protection is to consider this with the settings that is to have a security margin between the distance zone and the minimum load impedance This has the drawback that it will reduce the sensitivity of the protection that is the ability to detect resistive faults The IED has a built in function which shapes the characteristic according to the right figure of figure 153 The load encroachme...

Page 333: ...purposes are classified as short medium and long The definition of short medium and long lines is found in IEEE Std C37 113 1999 The length classification is defined by the ratio of the source impedance at the protected line s terminal to the protected line s impedance SIR SIR s of about 4 or greater generally define a short line Medium lines are those with SIR s greater than 0 5 and less than 4 I...

Page 334: ... For long transmission lines the margin to the load impedance that is to avoid load encroachment will normally be a major concern It is well known that it is difficult to achieve high sensitivity for phase to ground fault at remote line end of a long line when the line is heavy loaded What can be recognized as long lines with respect to the performance of distance protection can generally be descr...

Page 335: ...with positive and zero sequence sources isolated One example of class 3 networks could be the mutual coupling between a 400kV line and rail road overhead lines This type of mutual coupling is not so common although it exists and is not treated any further in this manual For each type of network class there are three different topologies the parallel line can be in service out of service out of ser...

Page 336: ...transmission networks Let us analyze what happens when a fault occurs on the parallel line see figure 154 From symmetrical components we can derive the impedance Z at the relay point for normal lines without mutual coupling according to equation 208 ph ph 0 1 ph 0 N ph 0 1 U U Z Z I 3I K I 3I 3 Z Z EQUATION2311 V1 EN US Equation 208 ph ph 0 1 ph N ph 0 1 0 V V Z Z I 3 K I 3I 3 Z I Z EQUATION1275 V...

Page 337: ...ault at the remote busbar When mutual coupling is introduced the voltage at the relay point A will be changed according to equation 209 0 0 0 0 1 1 3 3 3 1 3 1 m L L ph p ph L L L Z Z Z V Z I I I Z Z æ ö ç è ø EQUATION1276 V4 EN US Equation 209 By dividing equation 209 by equation 208 and after some simplification we can write the impedance present to the relay at A side as 3 0 1 1 3 0 æ ö ç è ø L...

Page 338: ...infeed from remote line end is zero the voltage VA in the faulty phase at A side as in equation 211 0 0 p 3 3 1 A L ph N Nm p V Z I K I K I EQUATION1278 V4 EN US Equation 211 One can also notice that the following relationship exists between the zero sequence currents 3 0 3 0 0 2 0 I Z I Z p L p L EQUATION1279 V3 EN US Equation 212 Simplification of equation 212 solving it for 3I0p and substitutio...

Page 339: ... Parallel line out of service and grounded GUID 0242E2DB A7F8 4D7F 91D1 1C744E3378BF v1 Z0m A B 21 21 en05000222_ansi vsd CLOSED CLOSED OPEN OPEN ANSI05000222 V1 EN US Figure 156 The parallel line is out of service and grounded When the parallel line is out of service and grounded at both line ends on the bus bar side of the line CTs so that zero sequence current can flow on the parallel line the ...

Page 340: ...ng to equation 216 and equation 217 for each particular line section and use them for calculating the reach for the underreaching zone R R X R X E m 0 0 0 2 0 2 0 2 1 DOCUMENT11520 IMG3502 V2 EN US Equation 216 X X X R X E m 0 0 0 2 0 2 0 2 1 DOCUMENT11520 IMG3503 V2 EN US Equation 217 Parallel line out of service and not grounded GUID 0458F8AF BDAC 4F07 B289 15B172FB39D9 v1 Z0m A OPEN 21 21 en050...

Page 341: ...9000255 V1 EN US Figure 159 Equivalent zero sequence impedance circuit for a double circuit line with one circuit disconnected and not grounded 8 9 2 7 Tapped line application GUID 1230B60C 8C3C 4405 8209 E089CAF07847 v1 C A B BC ANSI05000224 2 en vsd ANSI05000224 V2 EN US Figure 160 Example of tapped line with Auto transformer This application gives rise to similar problem that was highlighted in...

Page 342: ... For the IED at C the impedance on the high voltage side V1 has to be transferred to the measuring voltage level by the transformer ratio Another complication that might occur depending on the topology is that the current from one end can have a reverse direction for fault on the protected line For example for faults at T the current from B might go in reverse direction from B to C depending on th...

Page 343: ...uation applies for the distance protection zone 1 Consider approximately three times arc foot spacing for the zone 2 and wind speed of approximately 30 m h I is the actual fault current in A In practice the setting of fault resistance for both phase to groundRFPG and phase to phase RFPP should be as high as possible without interfering with the load impedance in order to obtain reliable fault dete...

Page 344: ...ticular application By proper setting it is possible to compensate for the cases when the parallel line is in operation out of service and not grounded and out of service and grounded in both ends The setting of ground fault reach should be selected to be 95 also when parallel line is out of service and grounded at both ends worst case 8 9 3 3 Setting of overreaching zone GUID 2C36623A 7A29 4881 9...

Page 345: ...I I I R Z I I Z AF A A AC A C A CF A C B A F AC C A C 1 F F C B A F I I I R 1 EQUATION302 V5 EN US Equation 221 A B 21 C IA IB Z AC Z CB Z CF IA IB ANSI05000457 2 en vsd F ANSI05000457 V2 EN US Figure 161 Setting of overreaching zone 8 9 3 4 Setting of reverse zone GUID 0EDCDC8F A2C9 4625 A6BD 0E7D2B4B1F04 v1 The reverse zone is applicable for purposes of scheme communication logic current reversa...

Page 346: ...ing of zone 2 GUID 8EAD617A D33B 453C 83FC 21E3CFC37CB1 v1 Overreaching zones in general zones 2 and 3 must overreach the protected circuit in all cases The greatest reduction of a reach occurs in cases when both parallel circuits are in service with a single phase to ground fault located at the end of a protected line The equivalent zero sequence impedance circuit for this case is equal to the on...

Page 347: ...g zone must not overreach the end of a protected circuit for the single phase to ground faults Set the values of the corresponding zone zero sequence resistance and reactance equal to R0E R0 1 Xm0 2 R0 2 X0 2 è ø ç æ ö EQUATION561 V1 EN US Equation 228 X0E X0 1 Xm0 2 R0 2 X0 2 è ø ç æ ö EQUATION562 V1 EN US Equation 229 8 9 3 6 Setting of reach in resistive direction GUID 3BFE80FD 8A51 4B71 8762 7...

Page 348: ...hase to phase loop measurement in the phase domain to 6 1 RFPPZx X Zx IECEQUATION2306 V3 EN US Equation 233 8 9 3 7 Load impedance limitation without load encroachment function GUID A7CDE76A D5B5 4641 9324 2E9A99071DF5 v1 The following instructions are valid when Phase selection with load enchroachment quadrilateral characteristic function FRPSPDIS 21 is not activated To deactivate the function th...

Page 349: ...d heavy three phase load and ground faults consider both phase to phase and phase to ground fault operating characteristics To avoid load encroachment for the phase to ground measuring elements the set resistive reach of any distance protection zone must be less than 80 of the minimum load impedance load RFPG 0 8 Z EQUATION1720 V1 EN US Equation 236 This equation is applicable only when the loop c...

Page 350: ...detection function ZMRPSB 78 is activated in the IED Use an additional safety margin of approximately 20 in cases when a ZMRPSB 78 function is activated in the IED refer to the description of Power swing detection function ZMRPSB 78 8 9 3 8 Load impedance limitation with Phase selection with load encroachment quadrilateral characteristic function activated GUID 68C89E77 77E1 47A2 A0D2 B6236CB63AB1...

Page 351: ...easons Time delays for all zones can be set in a range of 0 to 60 seconds The tripping function of each particular zone can be inhibited by setting the corresponding Operation parameter to Off Different time delays are possible for the phase to groundtPG and for the phase to phase tPP measuring loops in each distance protection zone separately to further increase the total flexibility of a distanc...

Page 352: ... The measuring elements continuously measure three phase currents and the residual current and compare them with the set values The extensive output signals from FRPSPDIS 21 give also important information about faulty phase s which can be used for fault analysis Load encroachment Each of the six measuring loops has its own load encroachment characteristic based on the corresponding loop impedance...

Page 353: ...ation characteristic is dependent on the chosen operation mode of the FRPSPDIS 21 function When output signal PHSELZis selected the characteristic for the FRPSPDIS 21 and also zone measurement depending on settings can be reduced by the load encroachment characteristic as shown in figure 163 1MRK 504 163 UUS A Section 8 Impedance protection Transformer protection RET670 2 2 ANSI 347 Application ma...

Page 354: ...ith a distance measuring zone the resultant operate characteristic could look something like in figure 164 The figure shows a distance measuring zone operating in forward direction Thus the operating area of the zone together with the load encroachment area is highlighted in black Section 8 1MRK 504 163 UUS A Impedance protection 348 Transformer protection RET670 2 2 ANSI Application manual ...

Page 355: ...ording to figure 165 Notice in particular what happens with the resistive blinders of the phase selection quadrilateral zone Due to the 30 degree rotation the angle of the blinder in quadrant one is now 100 degrees instead of the original 70 degrees The blinder that is nominally located to quadrant four will at the same time tilt outwards and increase the resistive reach around the R axis Conseque...

Page 356: ...ween two phases is presented in fig 166 Since the load characteristic is based on the same measurement as the quadrilateral characteristic it will rotate with the quadrilateral characteristic clockwise by 30 degrees when subject to a pure phase to phase fault At the same time the characteristic shrinks by 2 3 from the full RLdFw RLdRv reach which is valid at load or three phase fault Section 8 1MR...

Page 357: ... be a problem even for applications on series compensated lines 8 10 3 Load encroachment characteristics GUID DD9A62C3 A56D 411B 8303 6F7BC4C6092D v1 The phase selector must at least cover the overreaching zone 2 in order to achieve correct phase selection for utilizing single phase autoreclosing for faults on the entire line It is not necessary to cover all distance protection zones A safety marg...

Page 358: ...asic characteristic for respectively fault type The following setting guideline considers normal overhead lines applications and provides two different setting alternatives A A recommended characteristic angle of 60 degrees for the phase selection B A characteristic angle of 90 and 70 degrees for phase to ground and phase to phase respectively like implemented in the REL500 series The following fi...

Page 359: ...eristic Reactive reach GUID 8C693495 10FA 47D5 BEFC E72C8577E88B v1 The reactive reach in forward direction must as minimum be set to cover the measuring zone used in the Teleprotection schemes mostly zone 2 Equation 241 and equation 242 gives the minimum recommended reactive reach These recommendations are valid for both 60 and 90 deg characteristic angle PHS Zm X1 1 44 X1 EQUATION1309 V1 EN US E...

Page 360: ...FFwPG RFPG ANSIEQUATION2223 V1 EN US Equation 243 B 90 degrees 1 2 1 0 3 Zm Zm Zm RFFwPG R PG R PG RFPG ANSIEQUATION2224 V1 EN US Equation 244 The security margin has to be increased in the case where φloop 60 to avoid that FRPSPDIS 21 characteristic cuts off some part of the zone measurement characteristic RFFwPP and RFFRvPP must be set in a way that the loop characteristic angle can be 60 degree...

Page 361: ...ults If the 500 series characteristic angle of 70 deg is desired R1PE and R0PE must be set accordingly Fault resistance reach GUID CA51D9C7 7D9A 4DE5 92F1 FA1280BB899D v1 The fault resistance reaches in forward direction RFItFwdPP must cover RFPPZm with at least 25 margin RFPPZm is the setting of fault resistance for phase to phase fault for the longest overreaching zone to be covered by FRPSPDIS ...

Page 362: ...posed margin of 25 will cater for the risk of cut off of the zone measuring characteristic that might occur at three phase fault when FRPSPDIS 21 characteristic angle is changed from 60 degrees to 90 degrees or from 70 degrees to 100 degrees rotated 30 anti clock wise Section 8 1MRK 504 163 UUS A Impedance protection 356 Transformer protection RET670 2 2 ANSI Application manual ...

Page 363: ...ANSI08000249 V1 EN US Figure 168 Relation between measuring zone and FRPSPDIS 21 characteristic for phase to phase fault for φline 70 setting parameters in italic 8 10 4 Setting guidelines IP14959 1 v2 The following setting guideline consider normal overhead lines applications where φloop and φline is greater than 60 1MRK 504 163 UUS A Section 8 Impedance protection Transformer protection RET670 2...

Page 364: ...n forward and reverse direction so it could be suitable to begin to calculate the setting for that parameter Set the parameter to the maximum possible load angle at maximum active load A value bigger than 20 must be used The blinder in forward direction RLdFwd can be calculated according to equation 249 2 min 0 8 expmax RLdFwd P V where Pexp max is the maximum exporting active power Vmin is the mi...

Page 365: ...he threshold for opening the measuring loop for phase to ground fault 3I0Enable_PG is set securely detect single line to ground fault at remote end on the protected line It is recommended to set INBlockPP to double value of 3I0Enable_PG 8 11 Phase selection quad fixed angle load encroachment FDPSPDIS 21 IP12400 1 v4 8 11 1 Identification 8 11 1 1 Identification M14850 1 v6 Function description IEC...

Page 366: ...ching zone 2 in order to achieve correct phase selection for utilizing single phase autoreclosing for faults on the entire line It is not necessary to cover all distance protection zones A safety margin of at least 10 is recommended In order to get operation from distance zones the phase selection outputs PHSELZ or DLECND must be connected to input PHSEL on ZMQPDIS 21 distance measuring block For ...

Page 367: ...ulations can be obtained Index PHS in images and equations reference settings for Phase selection with load encroachment function FDPSPDIS 21 and index Zm reference settings for Distance protection function ZMQPDIS 21 1MRK 504 163 UUS A Section 8 Impedance protection Transformer protection RET670 2 2 ANSI 361 Application manual ...

Page 368: ...21 and impedance zone ZMQPDIS 21 for phase to ground fault φloop 60 setting parameters in italic 1 FDPSPDIS phase selection 21 red line 2 ZMQPDIS Impedance protection zone 21 3 RFltRevPGPHS 4 X1PHS XN tan 60 5 RFltFwdPGPHS 6 RFPGZM 7 X1PHS XN 8 φloop 9 X1ZM XN Section 8 1MRK 504 163 UUS A Impedance protection 362 Transformer protection RET670 2 2 ANSI Application manual ...

Page 369: ...h M13142 103 v5 The resistive reach must cover RFPG for the overreaching zone to be covered mostly zone 2 Consider the longest overreaching zone if correct fault selection is important in the application Equation 253 gives the minimum recommended resistive reach min 1 1 zm RFltFwdPG RFPG EQUATION1724 V2 EN US Equation 253 where RFPGZm is the setting RFPG for the longest overreaching zone to be cov...

Page 370: ...es in forward direction RFItFwdPP must cover RFPPZm with at least 25 margin RFPPZm is the setting of fault resistance for phase to phase fault for the longest overreaching zone to be covered by FDPSPDIS 21 see Figure 171 The minimum recommended reach can be calculated according to equation 255 1 25 zm RFltFwdPP RFPP EQUATION1318 ANSI V1 EN US Equation 255 where RFPPZm is the setting of the longest...

Page 371: ...and FDPSPDIS 21 characteristic for phase to phase fault for φline 60 setting parameters in italic 1 FDPSPDIS phase selection 21 red line 2 ZMQPDIS Impedance protection zone 21 3 0 5 RFltRevPP PHS 4 60 tan PHS X1 5 0 5 RFltFwdPP PHS 6 0 5 RFPPZm 7 X1PHS 1MRK 504 163 UUS A Section 8 Impedance protection Transformer protection RET670 2 2 ANSI 365 Application manual ...

Page 372: ...e en05000226_ansi vsd LdAngle ANSI05000226 V1 EN US Figure 172 Load encroachment characteristic The load angle LdAngle is the same in forward and reverse direction so it could be suitable to begin to calculate the setting for that parameter Set the parameter to the maximum possible load angle at maximum active load A value bigger than 20 must be used The blinder in forward direction RLdFwd can be ...

Page 373: ...current ILmILn is below the settable threshold The threshold to activate the phase selector for phase to ground IMinPUPG is set to securely detect a single phase to ground fault at the furthest reach of the phase selection It is recommended to set IMinPUPP to double value of IMinPUPG The threshold for opening the measuring loop for phase to ground fault 3I0Enable_PG is set securely detect single l...

Page 374: ...ction are highlighted below Solidly grounded networks GUID 6B0F02F4 18ED 415E 8D48 0A1648F7CE00 v2 In solidly grounded systems the transformer neutrals are connected directly to ground without any impedance between the transformer neutral and ground ANSI05000215 V2 EN US Figure 173 Solidly grounded network The ground fault current is as high or even higher than the short circuit current The series...

Page 375: ...should therefore always be complemented with other protection function s that can carry out the fault clearance in those cases Effectively grounded networks GUID 39CAF169 315E 4E3E 9EE6 28CBF624B90E v5 A network is defined as effectively grounded if the ground fault factor fe is less than 1 4 The ground fault factor is defined according to equation 259 max e pn V f V ANSIEQUATION1268 V1 EN US Equa...

Page 376: ...ed to the ground through high impedance mostly a reactance in parallel with a high resistor This type of network is often operated radially but can also be found operating as a meshed network What is typical for this type of network is that the magnitude of the ground fault current is very low compared to the short circuit current The voltage on the healthy phases will get a magnitude of 3 times t...

Page 377: ...easurement elements or the sensitivity will be too low for acceptance For this reason a separate high sensitive ground fault protection is necessary to carry out the fault clearance for single phase to ground fault For cross country faults and when using phase preference it is necessary to make sure that the distance protection is operating in the phase to earth loops independently whenever possib...

Page 378: ...uilt in algorithm which compensates the overreach tendency of zone 1 at the exporting end No settings are required for this feature 8 12 2 3 Load encroachment GUID 6785BF05 2775 4422 8077 A663D01C6C07 v6 In some cases the measured load impedance might enter the set zone characteristic without any fault on the protected line This phenomenon is called load encroachment and it might occur when an ext...

Page 379: ...n heavy loaded medium long lines For short lines the major concern is to get sufficient fault resistance coverage Load encroachment is not a major problem R X Zm RldRev R Zm RLdFwd ZL ANSI05000495_2_en vsd Load impedance area in forward direction LdAngle LdAngle LdAngle LdAngle ANSI05000495 V2 EN US Figure 176 Load encroachment phenomena and shaped load encroachment characteristic 1 8 12 2 4 Short...

Page 380: ...g It is difficult if not impossible to apply distance protection for short lines It is possible to apply an overreaching pilot communication based POTT or Blocking scheme protection for such lines to have fast tripping along the entire line Usually a unit protection based on comparison of currents at the ends of the lines is applied for such lines 8 12 2 5 Long transmission line application GUID 0...

Page 381: ...ces that the mutual impedances for positive and negative sequence are very small 1 2 of the self impedance and it is a common practice to neglect them From an application point of view there exists three types of network configurations classes that must be considered when making the settings for the protection function The different network configuration classes are 1 Parallel line with common pos...

Page 382: ...common operation modes are 1 Parallel line in service 2 Parallel line out of service and grounded 3 Parallel line out of service and not grounded Parallel line in service GUID 22E1A46C 92BD 4EE4 9A2D 9EFE2DB7B4D8 v3 This type of application is very common and applies to all normal sub transmission and transmission networks Let us analyze what happens when a fault occurs on the parallel line see fi...

Page 383: ... the remote busbar When mutual coupling is introduced the voltage at the relay point A will be changed according to equation 267 0 0 0 0 1 1 3 3 3 1 3 1 m L L ph p ph L L L Z Z Z V Z I I I Z Z æ ö ç è ø EQUATION1276 V4 EN US Equation 267 By dividing equation 267 by equation 266 and after some simplification we can write the impedance present to the relay at A side as 3 0 1 1 3 0 æ ö ç è ø L I KNm ...

Page 384: ...m p V Z I K I K I EQUATION1278 V4 EN US Equation 269 One can also notice that the following relationship exists between the zero sequence currents 3 0 3 0 0 2 0 I Z I Z p L p L EQUATION1279 V3 EN US Equation 270 Simplification of equation 270 solving it for 3I0p and substitution of the result into equation 269 gives that the voltage can be drawn as 0 0 3 p p 3 2 p 1 A L ph N Nm I V Z I K I K æ ö ç...

Page 385: ... CLOSED OPEN OPEN ANSI05000222 V1 EN US Figure 179 The parallel line is out of service and grounded When the parallel line is out of service and grounded at both line ends on the bus bar side of the line CTs so that zero sequence current can flow on the parallel line the equivalent zero sequence circuit of the parallel lines will be according to figure 180 A B C IEC09000252_1_en vsd I0 I0 Z0m Z0 Z...

Page 386: ...0 0 2 0 2 0 2 1 DOCUMENT11520 IMG3503 V2 EN US Equation 275 Parallel line out of service and not grounded GUID 949669D3 8B9F 4ECA 8F09 52A783A494E1 v2 Z0m A OPEN 21 21 en05000223_ansi vsd CLOSED OPEN CLOSED B ANSI05000223 V1 EN US Figure 181 Parallel line is out of service and not grounded When the parallel line is out of service and not grounded the zero sequence on that line can only flow throug...

Page 387: ...E f m U f f Z Z R Z K Z Z Z R Z Z R EQUATION1284 V1 EN US Equation 276 This means that the reach is reduced in reactive and resistive directions If the real and imaginary components of the constant A are equal to equation 277 and equation 278 Re 0 2 1 0 3 0 0 2 1 A R R R Rf X X X EQUATION1285 V1 EN US Equation 277 0 1 0 1 0 1 0 Im 2 3 2 A X R R R R X X EQUATION1286 V1 EN US Equation 278 The real c...

Page 388: ...E9 41A7 9927 4DAB50BE8D1A v1 C A B BC ANSI05000224 2 en vsd ANSI05000224 V2 EN US Figure 183 Example of tapped line with Auto transformer This application gives rise to similar problem that was highlighted in section Fault infeed from remote end that is increased measured impedance due to fault current infeed For example for faults between the T point and B station the measured impedance at A and ...

Page 389: ...ng voltage level by the transformer ratio Another complication that might occur depending on the topology is that the current from one end can have a reverse direction for fault on the protected line For example for faults at T the current from B might go in reverse direction from B to C depending on the system parameters see the dotted line in figure 183 given that the distance protection in B to...

Page 390: ...stance for both phase to ground RFPGZx and phase to phase RFPPZx should be as high as possible without interfering with the load impedance in order to obtain reliable fault detection 8 12 3 Setting guidelines IP14962 1 v1 8 12 3 1 General GUID BA20D421 4435 44CA A6E9 743E461F8C59 v2 The settings for Distance measuring zones quadrilateral characteristic ZMFPDIS are done in primary values The instru...

Page 391: ...C9D 468B 465F 85D9 3D64500474DB v2 The first overreaching zone normally zone 2 must detect faults on the whole protected line Considering the different errors that might influence the measurement in the same way as for zone 1 it is necessary to increase the reach of the overreaching zone to at least 120 of the protected line The zone 2 reach can be even higher if the fault infeed from adjacent lin...

Page 392: ...0E D09CA434F01F v1 The reverse zone is applicable for purposes of scheme communication logic current reversal logic weak end infeed logic and so on The same applies to the back up protection of the bus bar or power transformers It is necessary to secure that it always covers the overreaching zone used at the remote line IED for the telecommunication purposes Consider the possible enlarging factor ...

Page 393: ...allel circuits are in service with a single phase to ground fault located at the end of a protected line The equivalent zero sequence impedance circuit for this case is equal to the one in figure 178 in section Parallel line in service The components of the zero sequence impedance for the overreaching zones must be equal to at least R0E R0 Rm0 EQUATION553 V1 EN US Equation 286 X0E X0 Xm0 EQUATION5...

Page 394: ...n 292 8 12 3 6 Setting the reach with respect to load GUID ED84BDE6 16CD 45ED A45D 5CFB828A9040 v6 Set separately the expected fault resistance for phase to phase faults RFPPZx and for the phase to ground faults RFPGZx for each zone For each distance zone set all remaining reach setting parameters independently of each other The final reach in the resistive direction for phase to ground fault loop...

Page 395: ...ch point of view As with the settings RLdFwd and RldRev XLd is representing a per phase load impedance of a symmetrical star coupled representation For a symmetrical load or three phase and phase to phase faults this means per phase or positive sequence impedance During a phase to earth fault it means the per loop impedance including the earth return impedance 8 12 3 7 Zone reach setting lower tha...

Page 396: ...hree phase load and ground faults both phase to phase and phase to ground fault operating characteristics should be considered To avoid load encroachment for the phase to ground measuring elements the set resistive reach of any distance protection zone must be less than 80 of the minimum load impedance load RFPG 0 8 Z EQUATION1720 V1 EN US Equation 299 This equation is applicable only when the loo...

Page 397: ...additional safety margin of approximately 20 in cases when a ZMRPSB 78 function is activated in the IED refer to the description of Power swing detection function ZMRPSB 78 8 12 3 8 Zone reach setting higher than minimum load impedance GUID 78D0227F 2568 4C9A 8921 45812B4ABAF2 v5 The impedance zones are enabled as soon as the symmetrical load impedance crosses the vertical boundaries defined by RL...

Page 398: ...lt with similar characteristics Should this accidental event be given precaution the phase to ground reach RFPG of all instantaneous zones has to be set below the emergency load for the pole open situation Again this is only for the application where there is a risk that one breaker pole would open without a preceding fault If this never happens for example when there is no parallel circuit there ...

Page 399: ...nes the operating direction for zones Z3 Z4 and Z5 the directionality of zones Z1 Z2 and ZRV is fixed The options are Non directional Forward or Reverse The result from respective set value is illustrated in figure186 where the positive impedance corresponds to the direction out on the protected line IEC05000182 2 en vsdx R X R X R X Non directional Forward Reverse IEC05000182 V2 EN US Figure 186 ...

Page 400: ...sed by ferro resonance This component is practically idle during normal load and fault conditions hence the name passive CVTs that have a high resistive burden to mitigate ferro resonance also fall into this category Any This option is primarily related to the so called active type CVT which uses a set of reactive components to form a filter circuit that essentially attenuates frequencies other th...

Page 401: ... case of simultaneous faults two ground faults at the same time one each on the two circuits of a double line One specific situation where the 3I0Enable_PG setting should be altered is for cross country faults in high impedance grounded networks in order to make sure that operation is phase to ground This is particularly important when using phase preference logic since it is only working per phas...

Page 402: ...5922 428B 86F5 5F3897D29807 v3 Sub transmission networks are being extended and often become more and more complex consisting of a high number of multi circuit and or multi terminal lines of very different lengths These changes in the network will normally impose more stringent demands on the fault clearing equipment in order to maintain an unchanged or increased security level of the power system...

Page 403: ...agnitude of the fault current The shunt admittance has very limited influence on the ground fault current The shunt admittance may however have some marginal influence on the ground fault current in networks with long transmission lines The ground fault current at single phase to ground in phase A can be calculated as equation 304 A A 0 1 2 0 f 1 N f 3 V 3I Z Z Z 3Z Z Z Z V EQUATION1710 V2 EN US E...

Page 404: ...4 The ground fault factor is defined according to equation 305 max e pn V f V ANSIEQUATION1268 V1 EN US Equation 305 Where Vmax is the highest fundamental frequency voltage on one of the healthy phases at single phase to ground fault Vpn is the phase to ground fundamental frequency voltage before fault Another definition for effectively grounded network is when the following relationships between ...

Page 405: ...ion is necessary to carry out the fault clearance for single phase to ground fault 8 13 2 2 Fault infeed from remote end GUID DDFE8B5C A064 4956 B8BB 49DEAC38558E v3 All transmission and most sub transmission networks are operated meshed Typical for this type of network is that fault infeed from remote end will happen when fault occurs on the protected line The fault current infeed will enlarge th...

Page 406: ...trip The traditional way of avoiding this situation is to set the distance zone resistive reach with a security margin to the minimum load impedance The drawback with this approach is that the sensitivity of the protection to detect resistive faults is reduced The IED has a built in function which shapes the characteristic according to the right part of figure 190 The load encroachment algorithm w...

Page 407: ...ected line s terminal to the protected line s impedance SIR SIR s of about 4 or greater generally define a short line Medium lines are those with SIR s greater than 0 5 and less than 4 In short line applications the major concern is to get sufficient fault resistance coverage Load encroachment is not so common The line length that can be recognized as a short line is not a fixed length it depends ...

Page 408: ...oachment will normally be a major concern It is well known that it is difficult to achieve high sensitivity for phase to ground fault at remote line end of long lines when the line is heavy loaded What can be recognized as long lines with respect to the performance of distance protection can generally be described as in table 35 long lines have Source impedance ratio SIR s less than 0 5 Table 35 D...

Page 409: ...allel lines The lines need not be of the same voltage in order to have mutual coupling and some coupling exists even for lines that are separated by 100 meters or more The mutual coupling does not normally cause voltage inversion It can be shown from analytical calculations of line impedances that the mutual impedances for positive and negative sequence are very small 1 2 of the self impedance and...

Page 410: ...luence of a zero sequence mutual coupling on the measurement at single phase to ground faults in the following ways by using The possibility of different setting values that influence the ground return compensation for different distance zones within the same group of setting parameters Different groups of setting parameters for different operating conditions of a protected multi circuit line Most...

Page 411: ...sitive sequence impedance Z0 is zero sequence impedance Z0m A B 21 21 en05000221_ansi vsd FAULT ANSI05000221 V1 EN US Figure 192 Class 1 parallel line in service The equivalent circuit of the lines can be simplified see figure 193 A B C Z0m Z0m Z0 Z0m Z0 IEC09000253_1_en vsd IEC09000253 V1 EN US Figure 193 Equivalent zero sequence impedance circuit of the double circuit parallel operating line wit...

Page 412: ...parallel line has an opposite direction compared to the current on the protected line the distance function will overreach If the currents have the same direction the distance protection will underreach Maximum overreach will occur if the fault current infeed from remote line end is weak If considering a single phase to ground fault at p unit of the line length from A to B on the parallel line for...

Page 413: ...ence mutual coupling can reduce the reach of distance protection on the protected circuit when the parallel line is in normal operation The reduction of the reach is most pronounced with no current infeed in the IED closest to the fault This reach reduction is normally less than 15 But when the reach is reduced at one line end it is proportionally increased at the opposite line end So this 15 reac...

Page 414: ...urement will be a considerable overreach which must be considered when calculating the settings It is recommended to use a separate setting group for this operation condition since it will reduce the reach considerably when the line is in operation All expressions below are proposed for practical use They assume the value of zero sequence mutual resistance R0m equals to zero They consider only the...

Page 415: ...ero sequence mutual impedance does not influence the measurement of the distance protection in a faulty circuit This means that the reach of the underreaching distance protection zone is reduced if due to operating conditions the equivalent zero sequence impedance is set according to the conditions when the parallel system is out of operation and grounded at both ends A B C IEC09000255_1_en vsd I0...

Page 416: ... equation 323 Re Re Re Im K A X A A u m 1 0 2 2 2 EQUATION1287 V3 EN US Equation 323 The imaginary component of the same factor is equal to equation 324 2 0 2 2 Im Im Re Im m U A X K A A é ù é ù ë û ë û EQUATION1288 V2 EN US Equation 324 Ensure that the underreaching zones from both line ends will overlap a sufficient amount at least 10 in the middle of the protected circuit 8 13 2 7 Tapped line a...

Page 417: ...ple for faults between the T point and B station the measured impedance at A and C will be ZA ZAT ZTF IA IC IA DOCUMENT11524 IMG3509 V3 EN US Equation 325 A C 2 C Trf CT TB C I I V2 Z Z Z Z V1 I EQUATION1714 V1 EN US Equation 326 Where ZAT and ZCT is the line impedance from the A respective C station to the T point IA and IC is fault current from A respective C station for fault between T and B Ta...

Page 418: ...t and the fault location it might be necessary to accept zone 2 trip in one end or sequential trip in one end Generally for this type of application it is difficult to select settings of zone 1 that both gives overlapping of the zones with enough sensitivity without interference with other zone 1 settings that is without selectivity conflicts Careful fault calculations are necessary to determine s...

Page 419: ...apse limit Increase power transfer capability by raising the dynamic stability limit Improved reactive power balance Increase in power transfer capacity Reduced costs of power transmission due to decreased investment costs for new power lines 8 13 3 1 Steady state voltage regulation and increase of voltage collapse limit GUID 0AB9B4B5 92DF 4A3B 9046 FC3A460DA658 v1 A series capacitor is capable of...

Page 420: ...e for a simple radial power line with 0 30 50 and 70 of compensation 8 13 3 2 Increase in power transfer GUID C9163D4E CC2B 4645 B2AC 2C8A3FE3D337 v3 The increase in power transfer capability as a function of the degree of compensation for a transmission line can be explained by studying the circuit shown in figure 201 The power transfer on the transmission line is given by the equation 330 A B A ...

Page 421: ... inversion GUID CB215C0F F4FA 4646 9235 AE6DB0255E80 v1 Series capacitors influence the magnitude and the direction of fault currents in series compensated networks They consequently influence phase angles of voltages measured in different points of series compensated networks and this performances of different protection functions which have their operation based on properties of measured voltage...

Page 422: ...dance leads the current by 90 degrees Voltage drop DVC on series capacitor lags the fault current by 90 degrees Note that line impedance XL1 could be divided into two parts one between the IED point and the capacitor and one between the capacitor and the fault position The resulting voltage VM in IED point is this way proportional to sum of voltage drops on partial impedances between the IED point...

Page 423: ...f different protections in series compensated networks depend on their operating principle The most known effect has voltage inversion on directional measurement of distance IEDs see chapter Distance protection for more details which must for this reason comprise special measures against this phenomenon There will be no voltage inversion phenomena for reverse faults in system with VTs located on t...

Page 424: ...ions on non compensated lines and in cases when the capacitor is bypassed either by spark gap or by the bypass switch as shown in phasor diagram in figure 206 The resultant reactance is in this case of inductive nature and the fault currents lags source voltage by 90 electrical degrees The resultant reactance is of capacitive nature in the second case Fault current will for this reason lead the so...

Page 425: ...ctance The possibility for current inversion in modern networks is increasing and must be studied carefully during system preparatory studies The current inversion phenomenon should not be studied only for the purposes of protection devices measuring phase currents Directional comparison protections based on residual zero sequence and negative sequence currents should be considered in studies as w...

Page 426: ...re 207 represent the case with line side instrument transformers The protective devices will not be exposed to voltage and current inversion for faults on the protected line which increases the dependability Distance protection zone 1 may be active in most applications which is not the case when the bus side instrument transformers are used Distance IEDs are exposed especially to voltage inversion...

Page 427: ...ected power lines Figure 208 presents typical locations of capacitor banks on power lines together with corresponding compensation degrees Distance IED near the feeding bus will see in different cases fault on remote end bus depending on type of overvoltage protection used on capacitor bank spark gap or MOV and SC location on protected power line en06000612_ansi vsd EA 0 33 50 66 KC 80 33 33 50 21...

Page 428: ... but it does not cause wrong directional measurement Such cases are presented in figure 209 for 50 compensation at 50 of line length and 33 compensation located on 33 and 66 of line length The remote end compensation has the same effect The voltage inversion occurs in cases when the capacitor reactance between the IED point and fault appears bigger than the corresponding line reactance Figure 209 ...

Page 429: ... In IEC06000615 V1 EN US Figure 211 Equivalent impedance of MOV protected capacitor in dependence of protection factor KP Figure 211 presents three typical cases for series capacitor located at line end case LOC 0 in figure 209 Series capacitor prevails the scheme as long as the line current remains lower or equal to its protective current level I kp INC Line apparent impedance is in this case red...

Page 430: ... V1 EN US Figure 212 Voltage inversion in series compensated network due to fault current infeed Voltage at the B bus as shown in figure 212 is calculated for the loss less system according to the equation below B D B LB A B LF C B LB V V I jX I I j X X I jX EQUATION1998 ANSI V1 EN US Equation 336 Further development of equation 336 gives the following expressions 1 é ù æ ö ê ç ú è ø ë û A B B LB ...

Page 431: ...acitors will not conduct at all At the same time this kind of investigation must consider also the maximum sensitivity and possible resistive reach of distance protection devices which on the other hand simplifies the problem Application of MOVs as non linear elements for capacitor overvoltage protection makes simple calculations often impossible Different kinds of transient or dynamic network sim...

Page 432: ...electivity the first distance underreaching protection zone must be set to a reach less than the reactance of the compensated line in accordance with figure 213 en06000618 vsd X11 X12 jXC A B DA DB Zone 1A Zone 1B Zone 2A Zone 2B G IEC06000618 V1 EN US Figure 213 Underreaching Zone 1 and overreaching Zone 2 on series compensated line The underreaching zone will have reduced reach in cases of bypas...

Page 433: ...ce protection or some kind of directional or unit protection must be used The overreach must be of an order so it overreaches when the capacitor is bypassed or out of service Figure 215 shows the permissive zones The first underreaching zone can be kept in the total protection but it only has the feature of a back up protection for close up faults The overreach is usually of the same order as the ...

Page 434: ...consideration the negative voltage drop on XC is amplified and a protection far away from the faulty line can maloperate by its instantaneous operating distance zone if no precaution is taken Impedances seen by distance IEDs on adjacent power lines are presented by equations 341 to 344 1 2 3 I I I I EQUATION1915 V1 EN US Equation 341 X X I I X X DA A F A C 1 1 1 11 EQUATION1916 V2 EN US Equation 3...

Page 435: ... than the capacitor reactance and voltage inversion phenomenon may occur also on remote end of adjacent lines Distance protection of such line must have built in functionality which applies normally to protection of series compensated lines It usually takes a bit of a time before the spark gap flashes and sometimes the fault current will be of such a magnitude that there will not be any flashover ...

Page 436: ...tions must be made on a case by case basis as shown in figure 217 Distance IEDs with separate impedance and directional measurement offer additional setting and operational flexibility when it comes to measurement of negative apparent impedance as shown in figure 218 Negative IED impedance negative fault current current inversion GUID F858877A E736 4B1C 97B4 8A2B5F8EE644 v2 If equation 347 is vali...

Page 437: ... lines running in electrically close vicinity to each other and ending at the same busbar at both ends as shown in figure 219 causes some challenges for distance protection because of the mutual impedance in the zero sequence system The current reversal phenomenon also raises problems from the protection point of view particularly when the power lines are short and when permissive overreach scheme...

Page 438: ... circuit will send a carrier signal CSAB to the remote line end where this signal will be received as a carrier receive signal CRBB en06000629_ansi vsd RAA RBA IFC1 IFC1 X F RAB RBB IFC2 CSAB CRBB RAA RBA IFC1 X F RAB RBB IFC2 CSAB CRBB ANSI06000629 V1 EN US Figure 221 Current reversal phenomenon on parallel operating circuits It is possible to expect faster IED operation and breaker opening at th...

Page 439: ... additional protection must be provided 8 13 4 Setting guidelines IP14962 1 v1 8 13 4 1 General GUID B9958CEF 90ED 4644 B169 C6B4A018193B v1 The settings for Distance measuring zones quadrilateral characteristic ZMFCPDIS are done in primary values The instrument transformer ratio that has been set for the analog input card is used to automatically convert the measured secondary input signals to pr...

Page 440: ...mote end is considerably higher than the fault current that comes from behind of the IED towards the fault The setting must not exceed 80 of the following impedances The impedance corresponding to the protected line plus the first zone reach of the shortest adjacent line The impedance corresponding to the protected line plus the impedance of the maximum number of transformers operating in parallel...

Page 441: ...cation purposes Consider the possible enlarging factor that might exist due to fault infeed from adjacent lines The equation can be used to calculate the reach in reverse direction when the zone is used for blocking scheme weak end infeed and so on Zrev 1 2 Z2rem ZL _ GUID ABFB1C53 F12A 45D5 90CC 907C9FA0EFC3 V1 EN US Equation 350 Where ZL is the protected line impedance Z2rem is the zone 2 settin...

Page 442: ...ction at the bus Different settings of the reach for the zone ZMFCPDIS 21 characteristic in forward and reverse direction makes it possible to optimize the settings in order to maximize dependability and security for independent zone1 Due to the sub harmonic oscillation swinging caused by the series capacitor at fault conditions the reach of the under reaching zone 1 must be further reduced Zone 1...

Page 443: ...zone 1 reach unnecessary reduced The highest degree of compensation will occur at three phase fault and therefore the calculation need only to be performed for three phase faults The compensation degree in ground return path is different than in phases It is for this reason possible to calculate a compensation degree separately for the phase to phase and three phase faults on one side and for the ...

Page 444: ...c equals line reactance up to the series capacitor in the picture approximate 33 of XLine X1Fw is set to XLine XC p 100 X1Rv max 1 5 x XC XLLOCC X1Fw is defined according to figure 223 When the calculation of X1Fwgives a negative value the zone 1 must be permanently blocked Section 8 1MRK 504 163 UUS A Impedance protection 438 Transformer protection RET670 2 2 ANSI Application manual ...

Page 445: ... measurement Overreaching zone 2 GUID F3704F5E 5604 470D 829F C4594329ABFB v2 In series compensated network where independent tripping zones will have reduced reach due to the negative reactance in the capacitor and the sub harmonic swinging the tripping will to a high degree be achieved by the communication scheme With the reduced reach of the under reaching zones not providing effective protecti...

Page 446: ...7C4F v1 When some additional distance protection zones zone 4 for example are used they must be set according to the influence of the series capacitor 8 13 4 6 Setting of zones for parallel line application GUID E1228762 EBF7 4E58 9A52 96C5D22A0F0D v1 Parallel line in service Setting of zone 1 GUID 1EDD265C 43D4 4D1A A9DC 830E18B3267C v1 With reference to section Parallel line applications the zon...

Page 447: ... 0 Im Im 0 Re Im X m B K B B EQUATION1428 V2 EN US Equation 356 Parallel line is out of service and grounded in both ends GUID EC052207 C9AF 47EC 999A BD485378FD9E v1 Apply the same measures as in the case with a single set of setting parameters This means that an underreaching zone must not overreach the end of a protected circuit for the single phase to ground faults Set the values of the corres...

Page 448: ... X1 ANSIEQUATION2305 V1 EN US Equation 361 The fault resistance for phase to phase faults is normally quite low compared to the fault resistance for phase to ground faults To minimize the risk for overreaching limit the setting of the zone 1 reach in resistive direction for phase to phase loop measurement to 6 1 RFPPZx X Zx IECEQUATION2306 V3 EN US Equation 362 Note that RLdFwd and RldRev are not ...

Page 449: ...V is the minimum phase to phase voltage in kV S is the maximum apparent power in MVA The load impedance Ω phase is a function of the minimum operation voltage and the maximum load current min load max Z V 3 I EQUATION1719 V1 EN US Equation 364 Minimum voltage Vmin and maximum current Imax are related to the same operating conditions Minimum load impedance occurs normally under emergency conditions...

Page 450: ...asuring zones when no Power swing detection function ZMRPSB 78 is activated in the IED Use an additional safety margin of approximately 20 in cases when a ZMRPSB 78 function is activated in the IED refer to the description of Power swing detection function ZMRPSB 78 8 13 4 9 Zone reach setting higher than minimum load impedance GUID 78D0227F 2568 4C9A 8921 45812B4ABAF2 v5 The impedance zones are e...

Page 451: ... and the load current of that phase increase there is actually no way of distinguish this from a real fault with similar characteristics Should this accidental event be given precaution the phase to ground reach RFPG of all instantaneous zones has to be set below the emergency load for the pole open situation Again this is only for the application where there is a risk that one breaker pole would ...

Page 452: ...g loops and Quadrilateral characteristic for the three Ph E measuring loops DirModeZx These settings define the operating direction for Zones Z3 Z4 and Z5 the directionality of zones Z1 Z2 and ZRV is fixed The options are Non directional Forward or Reverse The result from respective set value is illustrated in figure 226 below where positive impedance corresponds to the direction out on the protec...

Page 453: ... the fact that this circuit is always involved during transient conditions regardless of voltage level This option should also be used for types that do not fall under the other two categories for example CVTs with power electronic damping devices or if the type cannot be identified at all None Magnetic This option should be selected if the voltage transformer is fully magnetic 3I0Enable_PG This s...

Page 454: ...e attribute range in the data class MV measured value with the type ENUMERATED normal high low high high and low low in ZMFCPDIS ZMMMXU ZLimHys Hysteresis value in of range ZMax ZMin common for all limits It is used to avoid the frequent update of the value for the attribute range ZMax Estimated maximum impedance value An impedance that is higher than ZMax has the quality attribute as Out of Range...

Page 455: ...lects further on in oscillating power flow between two parts of the system the power swings from one part to another and vice versa Distance IEDs located in interconnected networks see these power swings as the swinging of the measured impedance in relay points The measured impedance varies with time along a locus in an impedance plane see figure 227 This locus can enter the operating characterist...

Page 456: ...ption in Technical reference manual for the IEDs 8 14 3 Setting guidelines SEMOD52042 5 v4 Setting guidelines are prepared in the form of a setting example for the protected power line as part of a two machine system presented in figure 228 99001019_ansi vsd E A dA const dB f t E B A B Z SA Z SB Z L R ANSI99001019 V1 EN US Figure 228 Protected power line as part of a two machine system Reduce the ...

Page 457: ... Z j W EQUATION1329 V1 EN US Positive sequence source impedance behind A bus 1 5 3 35 7 SB Z j W EQUATION1330 V1 EN US Positive sequence source impedance behind B bus max 1000 S MVA EQUATION1331 V1 EN US Maximum expected load in direction from A to B with minimum system operating voltage Vmin max cos 0 95 j EQUATION1332 V1 EN US Power factor at maximum line loading max 25 j EQUATION1333 V1 EN US M...

Page 458: ...os 144 4 0 95 137 2 L L R Z j W EQUATION1338 V1 EN US Equation 372 The system impedance ZS is determined as a sum of all impedance in an equivalent two machine system see figure 228 Its value is calculated according to equation 373 1 1 1 17 16 154 8 S SA L SB Z Z Z Z j W EQUATION1339 V1 EN US Equation 373 The calculated value of the system impedance is of informative nature and helps determining t...

Page 459: ...sides the center of oscillation on impedance point see equation 376 1 7 43 33 9 2 S CO SA Z Z Z j W EQUATION1341 V1 EN US Equation 376 1MRK 504 163 UUS A Section 8 Impedance protection Transformer protection RET670 2 2 ANSI 453 Application manual ...

Page 460: ...cillation detection characteristic in forward direction RLdOutFw should be set with certain safety margin KL compared to the minimum expected load resistance RLmin When the exact value of the minimum load resistance Section 8 1MRK 504 163 UUS A Impedance protection 454 Transformer protection RET670 2 2 ANSI Application manual ...

Page 461: ... it comes to settings of timers tP1 and tP2 included in oscillation detection logic This requires the maximum permitted setting values of factor kLdRFw 0 8 Equation 378 presents the corresponding maximum possible value of RLdInFw 98 8 W RLdInFw kLdRFw RLdOutFw EQUATION1344 V3 EN US Equation 378 The load angles which correspond to external δOut and internal δIn boundary of proposed oscillation dete...

Page 462: ...tP d d EQUATION1349 V1 EN US Equation 383 max1 min 155 75 75 8 91 5 2 tan 2 tan 2 2 d W æ ö æ ö ç ç è ø è ø S in Z RLdInFw EQUATION1350 V1 EN US Equation 384 max1 75 8 0 61 123 5 RLdInFw kLdRFw RLdOutFw EQUATION1351 V1 EN US Equation 385 Also check if this minimum setting satisfies the required speed for detection of consecutive oscillations This requirement will be satisfied if the proposed setti...

Page 463: ...ad angle in FDPSPDIS 21 or FRPSPDIS 21 function to not less than equation 389 PSD PHS tan LdAngle tan 25 LdAngle arctan arctan 37 5 kLdRFw 0 61 é ù é ù ê ú ê ú ë û ë û EQUATION1738 ANSI V1 EN US Equation 389 It is recommended to set the corresponding resistive reach parameters in reverse direction RLdOutRv and kLdRRv to the same values as in forward direction unless the system operating conditions...

Page 464: ... usually set to approximately two seconds in older power swing devices The setting of the tGF timer must cover with sufficient margin the opening time of a circuit breaker and the dead time of a single phase autoreclosing together with the breaker closing time 8 15 Power swing logic PSLPSCH SEMOD153597 1 v3 8 15 1 Identification SEMOD175682 2 v3 Function description IEC 61850 identification IEC 60...

Page 465: ...f the measured impedance continues through zone 1 operating characteristic and causes its unwanted operation if no preventive measures have been taken see figure 231 EA A B C D F ZSA RA EC ED xx06000238 vsd ZSC ZSD IEC06000238 V1 EN US Figure 230 Fault on adjacent line and its clearance causes power swinging between sources A and C PSLPSCH function and the basic operating principle of ZMRPSB 68 fu...

Page 466: ...s SEMOD171741 1 v1 8 15 3 1 Scheme communication and tripping for faults occurring during power swinging over the protected line SEMOD131360 4 v2 The IED includes generally up to five distance protection zones It is possible to use one or two of them intentionally for selective fault clearing during power swings only Following are the basic conditions for the operation of the so called underreachi...

Page 467: ...way by means of configuration possibilities the complete functionality into regular scheme communication logic for the distance protection function The communication scheme for the regular distance protection does not operate during the power swing conditions because the distance protection zones included in the scheme are normally blocked The powerswing zones can for this reason use the same comm...

Page 468: ...e output signal of the autoreclosing function which signals the activation of the single pole autoreclosing dead time The PUPSD input should be connected to the pickup signal of the power swing detection ZMRPSB 68 function which becomes active in cases of detected system oscillations The CSUR functional input should be connected to the pickup output of the power swing distance protection zone whic...

Page 469: ...nication channel used speed of the circuit breaker used etc Time difference between 100 ms and 150 ms is generally sufficient Reactive reach setting of power swing distance protection zones SEMOD131360 37 v2 Set the reactive reach for the power swing zones according to the system selectivity planning The reach of the underreaching zone should not exceed 85 of the protected line length The reach of...

Page 470: ...f the timers within Power swing logic PSLPSCH depend to a great extent on the settings of other time delayed elements within the complete protection system These settings differ within different power systems The recommended settings consider only the general system conditions and the most used practice at different utilities It is always necessary to check the local system conditions The carrier ...

Page 471: ... Configuration SEMOD131360 60 v2 The fault impedance should be detected within the external boundary of Power Swing Detection ZMRPSB 68 function without power swing detected during the entire fault duration Configure for this reason the PUZMPSD to the functional output signal of ZMRPSB 68 function which indicates the measured impedance within its external boundaries PUZMUR BLOCK AND PUZMOR PUZMPSD...

Page 472: ... great extent the performance of the protection during the power swings which develops by occurrence and clearance of the faults on adjacent power lines It is necessary to consider the possibility for the faults to occur close to the set reach of the underreaching distance protection zone which might result in prolonged operate times of zone 1 underreaching zone compared to zone 2 pickuped time ov...

Page 473: ... occurs in the external power grid close to the generator If the fault clearance time is too long the generator will accelerate so much so the synchronism cannot be maintained The relative generator phase angle at a fault and pole slip relative to the external power system is shown in figure 234 en06000313 vsd IEC06000313 V1 EN US Figure 234 Relative generator phase angle at a fault and pole slip ...

Page 474: ...dance measurement of a three phase If this point is situated in the generator itself the generator should be tripped as fast as possible If the locus of the out of step centre is located in the power system outside the generators the power system should if possible be split into two parts and the generators should be kept in service This split can be made at predefined locations trip of predefined...

Page 475: ...ration the generator will absorb a significant amount of reactive power thus risking overload of the windings PSPPPAM 78 function shall detect out of step conditions and trip the generator as fast as possible if the locus of the pole slip is inside the generator If the centre of pole slip is outside the generator situated out in the power grid the first action should be to split the network into t...

Page 476: ...on The ImpedanceZA is the forward impedance as show in figure 236 ZA should be the sum of the transformer impedance XT and the equivalent impedance of the external system ZS The impedance is given in of the base impedance according to equation 394 3 Base UBase Z IBase EQUATION1883 V1 EN US Equation 394 Section 8 1MRK 504 163 UUS A Impedance protection 470 Transformer protection RET670 2 2 ANSI App...

Page 477: ... trip is given when the rotor angle gets below the set TripAngle The default value 90 is recommended N1Limit The setting N1Limit gives the number of pole slips that should occur before trip if the crossing of the slip line ZA ZB is within zone 1 that is the node of the pole slip is within the generator transformer block The default value 1 is recommended to minimize the stress on the generator and...

Page 478: ... Figure 237 Line application of pole slip protection If the apparent impedance crosses the impedance line ZB ZA this is the detection criterion of out of step conditions see figure 238 Section 8 1MRK 504 163 UUS A Impedance protection 472 Transformer protection RET670 2 2 ANSI Application manual ...

Page 479: ...on ZC The line impedance in the forward direction AnglePhi The impedance phase angle Use the following data UBase 400 kV SBase set to 1000 MVA Short circuit power at station 1 without infeed from the protected line 5000 MVA assumed to a pure reactance Short circuit power at station 2 without infeed from the protected line 5000 MVA assumed to a pure reactance Line impedance 2 j20 ohm 1MRK 504 163 U...

Page 480: ...US Equation 396 This corresponds to 2 52 0 0125 0 325 0 325 88 160 j ZA j pu pu Ð EQUATION1962 V1 EN US Equation 397 Set ZA to 0 32 2 400 1 32 5000 ZB Zsc station j j ohm EQUATION1963 V1 EN US Equation 398 This corresponds to 32 0 20 0 20 90 160 j ZB j pu pu Ð EQUATION1964 V1 EN US Equation 399 Set ZB to 0 2 This corresponds to 2 20 0 0125 0 125 0 126 84 160 j ZC j pu pu Ð EQUATION1966 V1 EN US Eq...

Page 481: ...A ZB Zload R X en07000016 vsd IEC07000016 V1 EN US Figure 239 Simplified figure to derive StartAngle 0 0 32 52 arctan arctan arctan arctan 21 8 33 0 55 80 80 ZB ZA angleStart Zload Zload EQUATION1968 V2 EN US Equation 402 In case of minor damped oscillations at normal operation we do not want the protection to start Therefore we set the start angle with large margin Set StartAngle to 110 1MRK 504 ...

Page 482: ...so the parameter N2Limit is set to 1 In other cases a larger number is recommended 8 16 3 2 Setting example for generator application SEMOD172162 90 v4 In case of out of step conditions this shall be checked if the pole slip centre is inside the generator zone 1 or if it is situated in the network zone 2 ZC ZA ZB en07000017 vsd IEC07000017 V1 EN US Figure 240 Generator application of pole slip pro...

Page 483: ...ameters of the protection are ZA Block transformer source impedance in the forward direction ZB The generator transient reactance ZC The block transformer reactance AnglePhi The impedance phase angle Use the following generator data VBase 20 kV SBase set to 200 MVA Xd 25 1MRK 504 163 UUS A Section 8 Impedance protection Transformer protection RET670 2 2 ANSI 477 Application manual ...

Page 484: ...are set in pu with ZBase as reference 2 2 20 2 0 200 UBase ZBase ohm SBase EQUATION1969 V1 EN US Equation 403 2 2 20 20 0 15 0 38 200 5000 ZA Z transf Zsc network j j j ohm EQUATION1970 V1 EN US Equation 404 This corresponds to 0 38 0 19 0 19 90 2 0 j ZA j pu pu Ð EQUATION1971 V1 EN US Equation 405 Set ZA to 0 19 2 20 0 25 0 5 200 d ZB jX j j ohm EQUATION1972 V2 EN US Equation 406 This corresponds...

Page 485: ...arning angle StartAngle should be chosen not to cross into normal operating area The maximum line power is assumed to be 200 MVA This corresponds to apparent impedance 2 2 20 2 200 U Z ohm S EQUATION1976 V1 EN US Equation 410 Simplified the example can be shown as a triangle see figure 242 1MRK 504 163 UUS A Section 8 Impedance protection Transformer protection RET670 2 2 ANSI 479 Application manu...

Page 486: ...erefore we set the start angle with large margin Set StartAngle to 110 For the TripAngle it is recommended to set this parameter to 90 to assure limited stress for the circuit breaker If the centre of pole slip is within the generator block set N1Limit to 1 to get trip at first pole slip If the centre of pole slip is within the network set N2Limit to 3 to get enable split of the system before gene...

Page 487: ...d Almost all mechanical power from the turbine is under this condition used to accelerate the moving parts that is the rotor and the turbine If the fault is not cleared quickly the generator may not remain in synchronism after the fault has been cleared If the generator loses synchronism Out of step with the rest of the system pole slipping occurs This is characterized by a wild flow of synchroniz...

Page 488: ...ropriate choice of other protection relays their locations and settings require detailed stability studies for each particular power system and or subsystem On the other hand if severe swings occur from which a fast recovery is improbable an attempt should be made to isolate the affected area from the rest of the system by opening connections at predetermined points The electrical system parts swi...

Page 489: ...celerates so much that the synchronism cannot be maintained even if the power system is restored to the pre fault configuration see Figure 244 0 500 1000 1500 2000 2500 3000 0 95 1 1 05 1 1 time in milliseconds Generator rotational speed in per unit unstable stable 260 ms 200 ms 3 ph fault For fault clearing time 200 ms generator remains stable and in synchronism After oscillations around the nomi...

Page 490: ...ate electrical centre of a swing 4 Detect the first and the subsequent pole slips 5 Prevent stress on the circuit breaker 6 Distinguish between generator and motor out of step conditions 7 Provide information for post disturbance analysis 8 17 3 Setting guidelines GUID CB86FCF6 8718 40BE BDF2 028C24AB367D v6 The setting example for generator protection application shows how to calculate the most i...

Page 491: ...talled is modeled as a two machine equivalent system or as a single machine infinite bus equivalent power system Then the impedances from the position of the Out of step protection in the direction of the normal load flow can be taken as forward The settings ForwardX ForwardR ReverseX and ReverseR must if possible take into account the post disturbance configuration of the simplified power system ...

Page 492: ...ic is determined by the value of this setting Whenever the complex impedance Z R X enters the lens this is a sign of instability The angle recommended is 110 or 120 degrees because it is at this rotor angle where problems with dynamic stability usually begin Power angle 120 degrees is sometimes called the angle of no return because if this angle is reached under generator swings the generator is m...

Page 493: ...abled all pole slips with centre of the electromagnetic oscillation within zone 1 are ignored Default setting Enabled More likely to be used is the option to extend zone 1 so that zone 1 even covers zone 2 This feature is activated by the input to extend the zone 1 EXTZ1 OperationZ2 Operation zone 2 Enabled Disabled If OperationZ1 Disabled all pole slips with centre of the electromagnetic oscillat...

Page 494: ...be established for example due to lack of polarizing voltage when a line potential transformer is used Automatic activation based on dead line detection can only be used when the voltage transformer is situated on the line side of a circuit breaker When line side voltage transformers are used the use of the nondirectional distance zones secures switch onto fault tripping for close in three phase s...

Page 495: ...harging current of an overhead line when only one phase is disconnected mutual coupling in the other phases UPh is used to set the voltage level for the detection of a dead line UPh is by default set to 70 of UBase This is a suitable setting in most cases but it is recommended to check the suitability in the actual application AutoInitMode automatic activating of ZCVPSOF is by default set to DLD d...

Page 496: ...te criterion is based on the BC input breaker closing which can be the start of the overreaching zone from the impedance zone measurement or a tOperate delayed START_DLYD input A nondirectional output signal should be used from an overreaching zone The selection of the Impedance mode gives increased security When Mode is set to UILvl Imp the condition for tripping is an ORed between UILevel and Im...

Page 497: ...he risk of a second fault in a healthy phase and the second fault can occur at any location When it occurs on another feeder the fault is commonly called cross country fault Different practices for tripping is used by different utilities The main use of this logic is in systems where single phase to ground faults are not automatically cleared only alarm is given and the fault is left on until a su...

Page 498: ...from the phase selection function which gives the type of fault undergoes a check and will release the distance protection zones as decided by the logic The logic includes a check of the fault loops given by the phase selection and if the fault type indicates a two or three phase fault the integer releasing the zone is not changed If the fault indicates and ground fault checks are done which mode ...

Page 499: ...247 The connection of Phase preference logic function PPLPHIZ between Distance protection zone quadrilateral characteristic ZMQPDIS 21 and ZMQAPDIS 21 and Phase selection with load encroachment quadrilateral characteristic function FDPSPDIS 21 As the fault is a double ground faults at different locations of the network the fault current in the faulty phase on each of the lines will be seen as a ph...

Page 500: ...DIS 21 and Phase selection with load encroachment quadrilateral characteristic function FDPSPDIS 21 Phase selection and zones are set according to normal praxis including ground fault loops although ground fault loops will only be active during a cross country fault GlobalBaseSel Selects the global base value group used by the function to define IBase VBase and SBase as applicable OperMode The ope...

Page 501: ...current IBase but the setting shall be above the maximum current generated by the system grounding Note that the systems are high impedance grounded which means that the ground fault currents at ground faults are limited and the occurring IN above this level shows that there exists a two phase fault on this line and a parallel line where the IN is the fault current level in the faulty phase A high...

Page 502: ...oss country fault may still occur before the ground fault protection has had the time to trip Cross country faults can generate relatively high currents and need to be tripped automatically and fast The strategy is still often to trip only one of the two faulty feeders during the cross country fault and then continue to run the system The PPL2PHIZ function is designed to enable this strategy being...

Page 503: ...ound fault During a cross country fault the fault current path for the fault that is not on the protected feeder will not go through the relay For a more meshed network though there will be some current See Figure 251 Only in the one phase with the fault on the protected feeder a significant fault current may be measured by the relay The result is 1MRK 504 163 UUS A Section 8 Impedance protection ...

Page 504: ...ith the fault on the protected feeder will of course also experience a voltage drop The healthy phase voltage will stay around its rated value Using the voltage drops it is possible to detect the two faulty phases of the cross country fault Another advantage with using voltage and voltage only is that it will be the same for all the feeders on a bus and similar for other buses This will give the r...

Page 505: ... ZREL CA BC AB CG BG AG TRUE TRUE RELCNDZ1 bitwise AND relcndphs enable TRZ1 Zone1 Phase selection bitwise AND enable TRZ2 Zone2 RELCNDZ2 RELCNDZ4 Zone5 ZMFPDIS PPL2PHIZ Phase preference AG BG CG enable TRZRV bitwise AND enable bitwise AND enable TRZ4 bitwise AND enable TRZ5 bitwise AND Zone3 Zone4 ZoneRV RELCNDZ3 RELCNDZ5 RELCNDZRV ANSI16000017 1 en vsdx ANSI16000017 V1 EN US Figure 252 The conne...

Page 506: ...h is used by the evaluation logic to verify that a cross country fault exists The setting can typically be 20 of base current IBase but the setting shall be above the maximum current generated during a single ground fault A high sensitivity is not crucial as the two phase fault level normally is well above base current tIN The time delay for detecting that the fault is cross country It should be s...

Page 507: ...he under impedance protection is provided with undervoltage detection feature in order to provide the seal in for the impedance based trip Additionally it is provided with load encroachment feature in order to avoid tripping of the protection during heavy load conditions The load encroachment functionality is based on the positive sequence components of voltage and current Characteristics of backu...

Page 508: ... voltage HV side of generator transformer are 1 Phase to ground faults in the HV side of generator transformer and in the power system 2 Phase to phase faults in the HV side of generator transformer and in the power system 3 Phase phase ground faults in the HV side of generator transformer and in the power system 4 Three phase faults in the HV side of generator transformer and in the power system ...

Page 509: ... g Z2Fwd Z3Fwd Z1Fwd Z3Rev Z2Rev Z1Rev R ohm X ohm B Typical setting of zones for under impedance relay IEC11000308 3 en vsd Zone3 Zone1 REG670 A Power system model Zone2 Y Y D Y IEC11000308 V3 EN US 1MRK 504 163 UUS A Section 8 Impedance protection Transformer protection RET670 2 2 ANSI 503 Application manual ...

Page 510: ...of the generator transformer are Sl No Phase to phase loop Voltage phasor Current phasor 1 A B VAB IAB 2 B C VBC IBC 3 C A VCA ICA VAB VBC VCA are three phase to phase voltages IAB IBC ICA are the three phase to phase currents For this application the zone 1 element is typically set to see 75 of the transformer impedance 8 21 2 3 Zone 2 operation GUID F9622D3F DDA1 451B A1C6 71F030725D25 v5 Zone 2...

Page 511: ...ltage drops and the load current in the machine leads due to which zone 2 element picks up resulting in misleading indications Zone 2 is not intended to operate for the generator winding ground faults The protection for generator winding ground fault is provided by sensitive ground fault relays that are time delayed To prevent such an operation the phase to ground measuring voltage is compensated ...

Page 512: ...v3 For faults close to generating terminals the CTs might go in to saturation The problem is due to very long DC constant of the generators The persistent DC component of primary currents even if relatively small has a tendency to drive current transformers into saturation The ZGVPDIS under this condition might reset for some duration A reliable backup protection is provided under these conditions...

Page 513: ... IRated GUID 90239033 D824 4479 A03A 41EE034C9021 ANSI V1 EN US Equation 412 The LdAngle is a separate setting 8 21 2 8 External block signals GUID 8DDEDD52 37DC 4330 BE56 CBC37F0545AD v2 The under impedance function will have to be blocked in the event of PT fuse fail A BLKZ input for this purpose is provided Also a BLOCK input is provided 1MRK 504 163 UUS A Section 8 Impedance protection Transfo...

Page 514: ...P Loops Z1Fwd Zone 1 forward reach in percentage It is recommended to set zone 1 forward reach to 75 of transformer impedance Z1Rev Zone 1 reverse reach in percentage It is recommended to set zone 1 reverse reach same as Z1Fwd tZ1 Zone 1 trip time delay in seconds Zone 2 Zone 2 in ZGVPDIS function has offset mho characteristic and it can evaluate three phase to phase impedance measuring loops or E...

Page 515: ... backup protection or slowest local backup for faults within zone 3 reach A safety margin of 100 ms should be considered 8 21 3 2 Load encroachment GUID EF64E2B4 2B84 421A B719 2DCA6883D21A v2 The settings involved in load encroachment feature are LdAngle Angle in degrees of load encroachment characteristics RLd Positive sequence resistance in per unit The procedure of calculating the settings for...

Page 516: ...stive load ANSI11000304 1 en vsd ANSI11000304 V1 EN US Figure 255 Characteristics of load encroachment in R X plane 8 21 3 3 Under voltage seal in GUID 946B8F59 8609 4F93 B346 AE053F1C2F9C v2 Settings involved in under voltage seal in are OpMode27pickup Under voltage seal in feature is enabled using this setting and can be selected as Disabled or Z2pick up or Z3pick up If the under voltage seal in...

Page 517: ...ng 27_COMP This is provided in percentage of VBase Recommended setting is 70 timeDelay27 The operate time delay in seconds for the under voltage seal in The recommended time delay is to provide the same trip delay setting as the selected zone that is either zone 2 or zone 3 1MRK 504 163 UUS A Section 8 Impedance protection Transformer protection RET670 2 2 ANSI 511 Application manual ...

Page 518: ...512 ...

Page 519: ...tly 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 EMFs of...

Page 520: ...igh 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 Set the ...

Page 521: ...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 256 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 257 In order to...

Page 522: ...nsient 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 416 The protection function can be used for the specific application only if this se...

Page 523: ...ven in Figure 259 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 259 will be with a fault at the C point with the C breaker...

Page 524: ...ed 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 419 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 base ...

Page 525: ...tor 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 is use...

Page 526: ... 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 restrain ...

Page 527: ...RCA 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 260 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 The def...

Page 528: ...angle 2 ROA Relay operating angle 3 Reverse 4 Forward 9 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 9 1MRK 504 163 UUS A Current protection 522 Transformer protection RET670 2 2 ANSI Application manual ...

Page 529: ...Operate phase current level for step x given in of IB Ix Max and Ix Min should only be changed if remote setting of operation current level Ix is used The limits are used for decreasing the used range of the Ix setting If Ix is set outside Ix Max and Ix Min the closest of the limits to Ix is used by the function If Ix Max is smaller than Ix Min the limits are swapped tx Definite time delay for ste...

Page 530: ...etting 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 261 Minimum pickup current and trip time for inverse time characteristics In order to fully comply with the definition of the curve the setting param...

Page 531: ...us 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 421 for the time characteristic equation For more information re...

Page 532: ...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 262 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 262 Pickup ...

Page 533: ...e 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 423 Ipu 0 7 Iscmin EQUATION1263 V2 EN US Equation 423 where 0 7 is a safety factor Iscmin is the smallest fault current to be detected by the overcurrent protection As ...

Page 534: ...mote point of the primary protection zone The operate time of the phase overcurrent protection has to be chosen so that the fault time is short enough that the protected equipment will not be destroyed due to thermal overload while at the same time selectivity is assured For overcurrent protection in a radial fed network the time setting can be chosen in a graphical way This is mostly used in the ...

Page 535: ...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 resettin...

Page 536: ...ents during fault where t 0 is when the fault occurs t t1 is when protection IED B1 and protection IED A1 start t t2 is when the trip signal from the overcurrent protection at IED B1 is sent to the circuit breaker t t3 is when the circuit breaker at IED B1 opens The circuit breaker opening time is t3 t2 t t4 is when the overcurrent protection at IED A1 resets The protection resetting time is t4 t3...

Page 537: ... 9 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 9 3 3 Setting gu...

Page 538: ...re 266 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 impedance ZB...

Page 539: ...imary current setting Is is Is 1 3 Imin EQUATION285 V3 EN US Equation 428 In case of parallel lines with zero sequence mutual coupling a fault on the parallel line as shown in Figure 267 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 267 Two parallel lines Influence from parallel line to the through fault current IM The min...

Page 540: ...n 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 9 4 Directional residual overcurrent prote...

Page 541: ...h 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 function us...

Page 542: ...ickup 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 to sat...

Page 543: ...nction 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 operati...

Page 544: ...trong 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 zero se...

Page 545: ...urrent 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 saturation a...

Page 546: ...l 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 shoul...

Page 547: ...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 functio...

Page 548: ...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 multipl...

Page 549: ... 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 of ste...

Page 550: ...nsformer namely if residual current can be fed from the protected transformer winding or not The protected winding will feed ground fault residual current to ground faults in the connected power system The residual current fed from the transformer at external phase to ground faults is highly dependent on the total positive and zero sequence source impedances It is also dependent on the residual cu...

Page 551: ...time delay definite or inverse time delay and a lower current operation level Step 2 shall detect and clear transformer winding ground faults with low ground fault current that is faults close to the transformer winding neutral point If the current setting gap between step 1 and step 2 is large another step can be introduced with a current and time delay setting between the two described steps The...

Page 552: ... dependent on the positive and zero sequence source impedances as well as the division of residual current in the network Ground fault current calculations are necessary for the setting Setting of step 1 SEMOD55591 35 v5 One requirement is that ground faults at the busbar where the transformer winding is connected shall be detected Therefore a fault calculation as shown in Figure 273 is made Secti...

Page 553: ...ound fault protections in the network a short delay is selected Normally a delay in the range 0 3 0 4 s is appropriate To assure selectivity to line faults tripped after a delay typically distance protection zone 2 of about 0 5 s the current setting must be set so high so that such faults does not cause unwanted step 1 trip Therefore a fault calculation as shown in Figure 274 is made 1MRK 504 163 ...

Page 554: ...ault2 The setting of step 1 can be chosen within the interval shown in equation 433 0fault2 step1 0fault1 3I lowmar I 3I highmar EQUATION1455 V2 EN US Equation 433 Where lowmar is a margin to assure selectivity typical 1 2 and highmar is a margin to assure fast fault clearance of busbar fault typical 1 2 Setting of step 2 SEMOD55591 57 v5 The setting of the sensitive step 2 is dependent of the cho...

Page 555: ...OC I2 4 4 alt IEC10000053 V1 EN US 46I2 9 5 2 Application GUID 343023F8 AFE3 41C2 8440 1779DD7F5621 v2 Four step negative sequence overcurrent protection NS4PTOC 4612 is used in several applications in the power system Some applications are Ground fault and phase phase short circuit protection of feeders in effectively grounded distribution and subtransmission systems Normally these feeders have r...

Page 556: ... the voltage polarizing quantity Choice of time characteristics There are several types of time characteristics available such as definite time delay and different types of inverse time characteristics The selectivity between different overcurrent protections is normally enabled by co ordination between the operating time of the different protections To enable optimal co ordination all overcurrent...

Page 557: ...e sequence overcurrent protection NS4PTOC 46I2 are set via the local HMI or Protection and Control Manager PCM600 The following settings can be done for the four step negative sequence overcurrent protection Operation Sets the protection to Enabled or Disabled Common base IED values for primary current IBase primary voltage VBase and primary power SBase are set in Global base values for settings f...

Page 558: ...EA RI RXIDG logarithmic The different characteristics are described in the Technical Reference Manual TRM Pickupx Operation negative sequence current level for step x given in of IBase tx Definite time delay for step x The definite time tx is added to the inverse time when inverse time characteristic is selected Note that the value set is the time between activation of the start and the trip outpu...

Page 559: ...peCrvx The reset of the delay timer can be made in different ways By choosing setting there are the following possibilities Curve name Instantaneous IEC Reset constant time ANSI Reset inverse time The different reset characteristics are described in the Technical Reference Manual TRM There are some restrictions regarding the choice of reset delay For the independent time delay characteristics the ...

Page 560: ...to equation 434 p A t s B TD i C ipickup æ ö ç ç ç æ ö ç ç è ø è ø EQUATION1722 V1 EN US Equation 434 Further description can be found in the Technical reference manual TRM tPRCrvx tTRCrvx tCRCrvx Parameters for customer creation of inverse reset time characteristic curve Further description can be found in the Technical Reference Manual 9 5 3 2 Common settings for all steps GUID A00A942B E760 42E...

Page 561: ...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 9 6 Sensitive directional residual overcurrent and power protection SDEPSDE 67N SEMOD171436 1 v4 1MRK 504 163 UUS A Section 9 Current prote...

Page 562: ...aults 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 for non ...

Page 563: ... 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 277 Conn...

Page 564: ... 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 435 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 ground The...

Page 565: ...nts 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 439 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 high imp...

Page 566: ... be written phase 0 1 0 f 3V 3I 2 Z Z 3 R EQUATION2023 ANSI V1 EN US Equation 440 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 stations A...

Page 567: ...written 0A prot 0A 0 A S 3V 3I cos j EQUATION2028 ANSI V1 EN US Equation 445 0B prot 0B 0 B S 3V 3I cos j EQUATION2029 ANSI V1 EN US Equation 446 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 measuremen...

Page 568: ...arameter 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 279 3V0 Vref 3I0 RCA 0 ROA 90 ang 3I0 ang 3Vref 3I0 cos en06000648_ansi vsd Vref ANSI06000648 V1 EN US Fi...

Page 569: ...nt 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 281 1MRK 504 163 UUS A Section 9 Current protection Transformer protection RET670 2 2 ANSI 563 A...

Page 570: ...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 the de...

Page 571: ...r 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 448 INDirPU is the pickup current le...

Page 572: ...se 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 449 tINNonDir is the definite time delay for the non directional grou...

Page 573: ... 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 increase...

Page 574: ...d 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 After...

Page 575: ...e 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 manufac...

Page 576: ...low 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 than...

Page 577: ... 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 and ou...

Page 578: ...on 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 when c...

Page 579: ...rotection 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 disab...

Page 580: ...t 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 delay t1...

Page 581: ... 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 9 10 Stub protection STBPTOC 50STB IP14515 1 v3 9 10 1 Identification M17108 1 v2 Function description IEC 61850 identification IEC 606...

Page 582: ...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 release ...

Page 583: ...n 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 importan...

Page 584: ...he 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 direct...

Page 585: ...ring 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 contingencies t...

Page 586: ...ay 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 to hy...

Page 587: ...el 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 44 Table 44 Complex power calculation Set value Mode Formula used for complex power calculation A B C A A B B...

Page 588: ...V1 EN US Equation 460 C 3 C C S V I EQUATION2063 ANSI V1 EN US Equation 461 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 Section 9 1MRK 504 163 UUS A Current protection...

Page 589: ... 0 2 of SN when metering class CT inputs into the IED are used N S 3 VBase IBase EQUATION2047 V1 EN US Equation 462 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 1MRK 504 163 UUS A Sect...

Page 590: ...3 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 464 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 calcu...

Page 591: ... 2 device number Directional overpower protection GOPPDOP P 2 DOCUMENT172362 IMG158942 V2 EN US 32 9 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 losses...

Page 592: ...ades 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 press...

Page 593: ... 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 network...

Page 594: ...469 B C B C BC S V I I EQUATION2042 V1 EN US Equation 470 C A C A CA S V I I EQUATION2043 V1 EN US Equation 471 A A A S 3 V I EQUATION2044 V1 EN US Equation 472 B B B S 3 V I EQUATION2045 V1 EN US Equation 473 C C C S 3 V I EQUATION2046 V1 EN US Equation 474 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 595: ...g 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 475 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 1MRK 504 163 UUS A Section 9...

Page 596: ...ip of the stage after pick up Hysteresis1 2 is given in p u of generator rated power according to equation 476 N S 3 VBase IBase EQUATION2047 V1 EN US Equation 476 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 Section 9 1MRK 504 163 UUS A Current protection 590 Transformer protection RET670 2 2...

Page 597: ...ted 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 9 14 Broken conductor check BRCPTOC 46 S...

Page 598: ...lBaseSel 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 conditions S...

Page 599: ... 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 capacitor ...

Page 600: ...cts each capacitor unit Internally fused where each capacitor element is fused inside the capacitor unit Fuseless where SCB is built from series connections of the individual capacitor units that is strings and without any fuses Unfused where in contrary to the fuseless configuration a series or parallel connection of the capacitor units is used to form SCB still without any fuses Section 9 1MRK 5...

Page 601: ... transients caused by SCB switching are avoided 9 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 for the ...

Page 602: ... 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 device t...

Page 603: ...on detection CBPGAPC function can be used to provide the last four types of protection mentioned in the above list 9 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 291 Preprocessing Function Block Capacitor bank protection function 400kV CBPGAPC SMAI 200MVAr 400kV...

Page 604: ...se value for pickup settings of all other features integrated in this function Reconnection inhibit feature OperationRecIn Enabled to enable this feature IRecInhibit 10 of IBase Current level under which function will detect that SCB is disconnected from the power system tReconnInhibit 300s Time period under which SCB shall discharge remaining residual voltage to less than 5 Overcurrent feature Op...

Page 605: ...onic overload trip Settings for IDMT delay step PU_HOL_DT_V 110 of SCB voltage rating Voltage level required for pickup of IDMT stage Selected value gives pickup recommended by international standards k_HOL_IDMT 1 0 Time multiplier for IDMT stage Selected value gives operate time in accordance with international standards tMax_HOL_IDMT 2000s Maximum time delay for IDMT stage for very low level of ...

Page 606: ...0F FC6DD9F4F140 v2 9 16 1 Identification GUID 19BB1653 55AE 44D1 B964 F59AED5350C4 v3 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Negative sequence time overcurrent protection for machines NS2PTOC 2I2 46I2 9 16 2 Application GUID 66CBDF76 B548 478F 8D59 CBAC4F6C1F85 v1 GUID ED2E176E BE14 45C2 875F 369E1F27BC29 v1 Negative sequence overcurren...

Page 607: ...FD 2EB16B206B25 v4 Negative sequence time overcurrent protection NS2PTOC 46I2 is designed to provide a reliable protection for generators of all types and sizes against the effect of unbalanced system conditions The following features are available Two steps independently adjustable with separate tripping outputs Sensitive protection capable of detecting and tripping for negative sequence currents...

Page 608: ... been established that determine generator continuous and short time unbalanced current capabilities in terms of negative sequence current I2 and rotor heating criteria 2 2 I t Typical short time capability referred to as unbalanced fault capability expressed in terms of rotor heating criterion 2 2 I t K is shown below in Table 46 Table 46 ANSI requirements for unbalanced faults on synchronous mac...

Page 609: ...to 1200 MVA 6 1201 to 1500 MVA 5 As it is described in the table above that the continuous negative sequence current capability of the generator is in range of 5 to 10 of the rated generator current During an open conductor or open generator breaker pole condition the negative sequence current can be in the range of 10 to 30 of the rated generator current Other generator or system protections will...

Page 610: ...ercurrent protection for machines NS2PTOC 46I2 provides two operating time delay characteristics for step 1 and 2 Definite time delay characteristic Inverse time delay characteristic The desired operate time delay characteristic is selected by setting CurveType1 as follows CurveType1 Definite CurveType1 Inverse Definite time delay 1 is independent of the magnitude of the negative sequence current ...

Page 611: ... sec The setting t1Min is freely settable and is used as a security measure This minimum setting assures appropriate coordination with for example line protections It is also possible to set the upper time limit t1Max 9 16 3 2 Pickup sensitivity GUID 1D038486 7086 466F A92F 30E1A47D0298 v3 The trip pickup levels Current I2 1 and I2 2 of NS2PTOC 46I2 are freely settable over a range of 3 to 500 of ...

Page 612: ...use severe damage to the power system primary equipment A typical application of the voltage restrained time overcurrent protection is in the generator protection system where it is used as backup protection If a phase to phase fault affects a generator the fault current amplitude is a function of time and it depends on generator characteristic reactances and time constants its load conditions imm...

Page 613: ... v4 GlobalBaseSel defines the particular Global Base Values Group where the base quantities of the function are set In that Global Base Values Group IBase shall be entered as rated phase current of the protected object in primary amperes VBase shall be entered as rated phase to phase voltage of the protected object in primary kV 9 17 2 2 Application possibilities GUID 5053F964 C2D6 4611 B5EF AC3DB...

Page 614: ...ip signal is issued Trip output OR OR t ANSI12000183 1 en vsd VRPVOC 51V I3P I3P V3P V3P BLOCK BLOCK BLKOC BLKOC BLKUV BLKUV TRIP TRIP TROC TROC 27 Trip 27 Trip PICKUP PICKUP PU_OC PU_OC 27 PU 27 PU ANSI12000183 V1 EN US Figure 294 Undervoltage seal in of current pickup 9 17 3 Setting guidelines GUID 2AE85EC4 669E 47C0 ADD4 3DBA83581096 v2 9 17 3 1 Explanation of the setting parameters GUID 9B777E...

Page 615: ...meter 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 The setting can be very low for example lower than 10 VDepMode Selection of the characteristic of the start level of the overcurrent stage as a function of the phase to phase voltage two options are available ...

Page 616: ...elect 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 value 185...

Page 617: ...rtCurr 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 values 70 9...

Page 618: ...612 ...

Page 619: ... 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 two...

Page 620: ...rotection to clear short circuits and ground faults Some applications and related setting guidelines for the voltage level are described in the following sections 10 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 10 1 3 2 Disconnected equipment detectio...

Page 621: ...ribed 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 3 or ...

Page 622: ...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 Disabled Bl...

Page 623: ...he 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 appear...

Page 624: ...n 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 should ...

Page 625: ...Sel 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 VBase by ...

Page 626: ...he 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 overvolta...

Page 627: ...13809 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 eit...

Page 628: ...ific equipment the time delay is shorter Some applications and related setting guidelines for the residual voltage level are given below 10 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 prote...

Page 629: ... 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 will meas...

Page 630: ...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 voltage 3...

Page 631: ...stems 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 the p...

Page 632: ...resis for step n set in of VBase The setting of this parameter is highly dependent 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 ...

Page 633: ...NSI IEEE standards the transformers shall be capable of delivering rated load current continuously at an output voltage of 105 of rated value at rated frequency and operate continuously with output voltage equal to 110 of rated value at no load The capability of a transformer or generator to withstand overexcitation can be illustrated in the form of a thermal capability curve that is a diagram whi...

Page 634: ...ge from 100 to 180 of rated V Hz When configured to a single phase to phase voltage input a corresponding phase to phase current is calculated which has the same phase angle relative the phase to phase voltage as the phase currents have relative the phase voltages in a symmetrical system The function should preferably be configured to use a three phase voltage input if available It then uses the p...

Page 635: ...reached It can be used to initiate time measurement TRIP The TRIP output is activated after the operate time for the V f level has expired TRIP signal is used to trip the circuit breaker s ALARM The output is activated when the alarm level has been reached and the alarm timer has elapsed When the system voltage is high this output sends an alarm to the operator 10 4 3 2 Settings M6496 91 v7 Global...

Page 636: ...n be selected depending of which one matches the capability curve best TDforIEEECurve The time constant for the inverse characteristic Select the one giving the best match to the transformer capability t_CooolingK The cooling time constant giving the reset time when voltages drops below the set value Shall be set above the cooling time constant of the transformer The default value is recommended t...

Page 637: ...according to figure 298 105 When the overexcitation is equal to Pickup1 tripping is obtained after a time equal to the setting of t1 This is the case when VBase is equal to the transformer rated voltages For other values the percentage settings need to be adjusted accordingly When the overexcitation is equal to the set value of Pickup2 tripping is obtained after a time equal to the setting of t6 A...

Page 638: ...vsd IEC01000377 V1 EN US Figure 298 Example on overexcitation capability curve and V Hz protection settings for power transformer 10 5 Voltage differential protection VDCPTOV 60 SEMOD153860 1 v2 10 5 1 Identification SEMOD167723 2 v2 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Voltage differential protection VDCPTOV 60 Section 10 1MRK 504 16...

Page 639: ...he capacitor bank Figure 299 shows some different alternative connections of this function Vd L1 Ph B Ph C V1 V2 Vd A Ph B Ph C V1 V2 Ph C Ph B en06000390_ansi vsd Single grounded wye Double wye ANSI06000390 V1 EN US Figure 299 Connection of voltage differential protection VDCPTOV 60 function to detect unbalance in capacitor banks one phase only is shown VDCPTOV 60 function has a block input BLOCK...

Page 640: ...own in figure 300 Vd V1 v2 To Protection To Excitation Gen en06000389_ansi vsd ANSI06000389 V1 EN US Figure 300 Supervision of fuses on generator circuit voltage transformers 10 5 3 Setting guidelines SEMOD153915 5 v3 The parameters for the voltage differential function are set via the local HMI or PCM600 The following settings are done for the voltage differential function Operation Off On Global...

Page 641: ... delay does not need to be so short in capacitor bank applications as there is no fault requiring urgent tripping tReset The time delay for reset of tripping level element is set by this parameter Normally it can be set to a short delay as faults are permanent when they occur For the advanced users following parameters are also available for setting Default values are here expected to be acceptabl...

Page 642: ...through an output contact or through the event recording function 10 6 3 Setting guidelines SEMOD171929 4 v5 Loss of voltage check LOVPTUV 27 is in principle independent of the protection functions It requires to be set to open the circuit breaker in order to allow a simple system restoration following a main voltage loss of a big part of the network and only when the voltage is lost with breakers...

Page 643: ...rid SAPTUF 81 detects such situations and provides an output signal suitable for load shedding generator boosting HVDC set point change gas turbine start up and so on Sometimes shunt reactors are automatically switched in due to low frequency in order to reduce the power system voltage and hence also reduce the voltage dependent part of the load SAPTUF 81 is very sensitive and accurate and is used...

Page 644: ...t acceptable frequency for the equipment Power system protection by load shedding The setting has to be below the lowest occurring normal frequency and well above the lowest acceptable frequency for power stations or sensitive loads The setting level the number of levels and the distance between two levels in time and or in frequency depends very much on the characteristics of the power system und...

Page 645: ...lso be used to alert operators that frequency has slightly deviated from the set point and that manual actions might be enough 11 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 applicatio...

Page 646: ...ification 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 11 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 need...

Page 647: ...oser 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 instantan...

Page 648: ...642 ...

Page 649: ...or voltage controlled restrained The over under voltage protection is applied on power system elements such as generators transformers motors and power lines in order to detect abnormal voltage conditions Depending on the type of voltage deviation and type of power system abnormal condition different over under voltage protections based on measurement of phase to ground phase to phase residual or ...

Page 650: ...th 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 sele...

Page 651: ...hasor of the phase with minimum magnitude Phase angle will be set to 0 all the time 10 PhaseA PhaseB CVGAPC function will measure the current phasor internally calculated as the vector difference between the phase A current phasor and phase B current phasor VA VB 11 PhaseB PhaseC CVGAPC function will measure the current phasor internally calculated as the vector difference between the phase B curr...

Page 652: ...oltage phasor of the phase with minimum magnitude Phase angle will be set to 0 all the time 10 PhaseA PhaseB CVGAPC function will measure the voltage phasor internally calculated as the vector difference between the phase A voltage phasor and phase B voltage phasor VA VB 11 PhaseB PhaseC CVGAPC function will measure the voltage phasor internally calculated as the vector difference between the phas...

Page 653: ...e Quantity is selected from 1 to 9 as shown in table 50 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 50 12 1 2 3 Application possibilities SEMOD53443 136 v2 Due to its flexibility the general current and voltage protection CVGAPC function can be used with appropriate settings and configuration in...

Page 654: ...mistake Three phase energizing of a generator which is at standstill or on turning gear causes it to behave and accelerate similarly to an induction motor The machine at this point essentially represents the subtransient reactance to the system and it can be expected to draw from one to four per unit current depending on the equivalent system impedance Machine terminal voltage can range from 20 to...

Page 655: ... v4 When inverse time overcurrent characteristic is selected the trip time of the stage will be the sum of the inverse time delay and the set definite time delay Thus if only the inverse time delay is required it is important to set the definite time delay for that stage to zero M13088 237 v3 The parameters for the general current and voltage protection function CVGAPC are set via the local HMI or...

Page 656: ...ase 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 dela...

Page 657: ...t reversal situations pickup signals from OC1 and OC2 elements shall be used to send forward and reverse signals to the remote end of the power line the available scheme communications function block within IED shall be used between multipurpose protection function and the communication equipment in order to insure proper conditioning of the above two pickup signals Furthermore the other built in ...

Page 658: ... 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 487 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 CurrentInpu...

Page 659: ...current protection For this particular example the following settings shall be entered to insure proper function operation 1 select negative sequence current as measuring quantity for this CVGAPC function 2 make sure that the base current value for the CVGAPC function is equal to the generator rated current 3 set TD_OC1 20 4 set A_OC1 1 0 072 204 0816 5 set B_OC1 0 0 C_OC1 0 0 and P_OC1 2 0 6 set ...

Page 660: ... standard TD 37 5 for the IEC standard or TD 41 4 for the ANSI standard Im is the magnitude of the measured current Ir is the generator rated current This formula is applicable only when measured current for example positive sequence current exceeds a pre set value typically in the range from 105 to 125 of the generator rated current By defining parameter x equal to the per unit value for the desi...

Page 661: ...on When the equation 491 is compared with the equation 492 for the inverse time characteristic of the OC1 step in it is obvious that if the following rules are followed 1 set TD equal to the IEC or ANSI standard generator capability value 2 set parameter A_OC1 equal to the value 1 x2 3 set parameter C_OC1 equal to the value 1 x2 4 set parameters B_OC1 0 0 and P_OC1 2 0 5 set PickupCurr_OC1 equal t...

Page 662: ...n by enabling the current restraint feature The following shall be done in order to insure proper operation of the function 1 Connect three phase currents from the protected object to one CVGAPC instance for example GF03 2 Set CurrentInput to value UnbalancePh 3 Set EnRestrainCurr to On 4 Set RestrCurrInput to MaxPh 5 Set RestrCurrCoeff to value 0 97 6 Set base current value to the rated current o...

Page 663: ...straining by selecting PosSeq for this setting parameter 4 Set base current value to the rated generator current primary amperes 5 Set base voltage value to the rated generator phase to phase voltage in kV 6 Enable one overcurrent step for example OC1 7 Select CurveType_OC1 to value ANSI Very inv 8 If required set minimum operating time for this curve by using parameter tMin_OC1 default value 0 05...

Page 664: ...lead voltage for this angle 7 Set parameter ROADir to value 90 degree 8 Set parameter LowVolt_VM to value 5 9 Enable one overcurrent step for example OC1 10 Select parameter CurveType_OC1 to value IEC Def Time 11 Set parameter PickupCurr_OC1 to value 38 12 Set parameter tDef_OC1 to value 2 0s typical setting 13 Set parameter DirMode_OC1 to Forward 14 Set parameter DirPrinc_OC1 to IcosPhi V 15 Set ...

Page 665: ... 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 301 Loss of excitation 1MRK 504 163 UUS A Section 12 Multipurpose protection Transformer protection RET670 2 2 ANSI 659 Application manual ...

Page 666: ...660 ...

Page 667: ...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 calcula...

Page 668: ...cies 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 mult...

Page 669: ... 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 302 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 Hz EQUA...

Page 670: ...n 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 495 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 496 Thus if the following rules are followed when multi purpose ove...

Page 671: ...vel2nd 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 504 163 UUS A Section 13 System protection ...

Page 672: ...666 ...

Page 673: ...ion 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 sensitive...

Page 674: ...s 14 2 Fuse failure supervision FUFSPVC IP14556 1 v3 14 2 1 Identification M14869 1 v4 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Fuse failure supervision FUFSPVC 14 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 impedan...

Page 675: ...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 14 2 3 Setting guidelines IP15000 1 v1 1...

Page 676: ...ents 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 conditio...

Page 677: ...or the function according to the setting GlobalBaseSel 14 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 499 100 3 0 3 0 3 VBase V PU V EQUATION1759 ANSI V4 EN US Equation 499 where 3V0 is the maximal zero sequence voltage during ...

Page 678: ...mary 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 501 and equation 502 DVPU VSet VBase prim 100 EQUATION1765 ANSI V2 EN US Equation 501 DIPU ISet IBase prim 100 ANSIEQUATION2385 V2 EN US Equation 502 The voltage thresholds VPPU is used to identify low voltage condition in the system Set VPPU ...

Page 679: ...VDSPVC VTS 60 14 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 kind o...

Page 680: ... 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 14 1MRK 504 163 UUS A Secondary system supervision 674 Transformer p...

Page 681: ...ed 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 503 Vdif Main block or Vdif Pilot alarm SetPrim Base V V 100 ANSI13000279 V1 EN US Equation 503 VSetPrim is defined as phase to neutral or phase to phase voltage dependent of the selected ConTypeMain and ConTypePilot If ConTypeMain and ConTypePilo...

Page 682: ...676 ...

Page 683: ...ns across the breaker are satisfied in order to avoid stress on the network and its components The systems are defined as asynchronous when the frequency difference between bus and line is larger than an adjustable parameter If the frequency difference is less than this threshold value the system is defined to have a parallel circuit and the synchronism check function is used The synchronizing fun...

Page 684: ...ed 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 maximum ...

Page 685: ... 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 vsd A...

Page 686: ...fter the fault clearance a highspeed auto reclosing takes place This can cause a power swing in the net and the phase angle difference may begin to oscillate Generally the frequency difference is the time derivative of the phase angle difference and will typically oscillate between positive and negative values When the circuit breaker needs to be closed by auto reclosing after fault clearance some...

Page 687: ...ate 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 306 shows two substations where one 1 is energized and the other 2 is not energized The line...

Page 688: ...SelLine 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 high ...

Page 689: ...vision 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 VL1FF ...

Page 690: ...rrangements 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 must h...

Page 691: ...FA FRDIFFM PHDIFFM INADVCLS VDIFFME FRDIFFME PHDIFFME Vbus VLine MODEAEN MODEMEN ANSI10000093 V1 EN US Figure 308 Connection of SESRSYN 25 function block in a single busbar arrangement Figure 308 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 strai...

Page 692: ...IFFSC FRDIFFA PHDIFFA FRDIFFM PHDIFFM INADVCLS VDIFFME FRDIFFME PHDIFFME Vbus VLine MODEAEN MODEMEN ANSI10000094 V1 EN US Figure 309 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 according ...

Page 693: ...N FRDIFFOK FRDERIVA VOKSC VDIFFSC FRDIFFA PHDIFFA FRDIFFM PHDIFFM INADVCLS VDIFFME FRDIFFME PHDIFFME Vbus VLine MODEAEN MODEMEN ANSI10000095 V1 EN US Figure 310 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 310 T...

Page 694: ...FA 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 VSELFA...

Page 695: ...15 1 3 5 Breaker and a half M12330 3 v8 Figure 312 describes a breaker and a half arrangement with three SESRSYN functions in the same IED each of them handling voltage selection for WA1_QA1 TIE_QA1 and WA2_QA1 breakers respectively The voltage from busbar 1 VT is connected to V3PB1 on all three function blocks and the voltage from busbar 2 VT is connected to V3PB2 on all three function blocks The...

Page 696: ...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 V...

Page 697: ..._OP CL Position of WA1_QA1 breaker and belonging disconnectors BUS2_OP CL Position of WA2_QA1 breaker and belonging disconnectors LINE1_OP CL Position of LINE1_QB9 disconnector LINE2_OP CL Position of LINE2_QB9 disconnector VB1OK FF Supervision of WA1_MCB fuse VB2OK FF Supervision of WA2_MCB fuse VL1OK FF Supervision of LINE1_MCB fuse VL2OK FF Supervision of LINE2_MCB fuse Setting CBConfig Tie CB ...

Page 698: ...N 25 SC VC X has been divided into four different setting groups General Synchronizing Synchrocheck and Energizingcheck General settings Operation The operation mode can be set Enabled or Disabled The setting Disabled disables the whole function GblBaseSelBus and GblBaseSelLine These configuration settings are used for selecting one of twelve GBASVAL functions which then is used as base value refe...

Page 699: ...on 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 Setti...

Page 700: ...een 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 components...

Page 701: ...n 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 differe...

Page 702: ...rg Two different settings can be used for automatic and manual closing of the circuit breaker The settings for each of them are Disabled the energizing function is disabled DLLB Dead Line Live Bus the line voltage is below set value of VDeadLineEnerg and the bus voltage is above set value of VLIveBusEnerg DBLL Dead Bus Live Line the bus voltage is below set value of VDeadBusEnerg and the line volt...

Page 703: ...tAutoEnerg and tManEnerg The purpose of the timer delay settings tAutoEnerg and tManEnerg is to ensure that the dead side remains de energized and that the condition is not due to a temporary interference Should the conditions not persist for the specified time the delay timer is reset and the procedure is restarted when the conditions are fulfilled again Circuit breaker closing is thus not permit...

Page 704: ...N ANSI08000227 V1 EN US Figure 313 Overview of the apparatus control functions Features in the apparatus control function Operation of primary apparatuses Select Execute principle to give high security Selection and reservation function to prevent simultaneous operation Selection and supervision of operator place Command supervision Block deblock of operation Block deblock of updating of position ...

Page 705: ...IN and Bay reserve QCRSV also are included in the apparatus control function The application 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 devi...

Page 706: ...SWI 189 989 IEC 61850 QCBAY 152 ANSI05000116 V1 EN US Figure 314 Signal flow between apparatus control function blocks when all functions are situated within the IED Section 15 1MRK 504 163 UUS A Control 700 Transformer protection RET670 2 2 ANSI Application manual ...

Page 707: ...LO XLNPROXY GOOSEXLNRCV XLNPROXY QA1 QB1 QB9 GOOSEover process bus IEC16000070 1 EN vsdx IEC16000070 V1 EN US Figure 315 Signal flow between apparatus control functions with XCBR and XSWI located in a breaker IED 1MRK 504 163 UUS A Section 15 Control Transformer protection RET670 2 2 ANSI 701 Application manual ...

Page 708: ...riginator categories for each PSTO value are shown in Table 53 Table 53 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 Accor...

Page 709: ...ossible 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 altern...

Page 710: ... 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 erro...

Page 711: ...tch SXSWI with mandatory functionality 15 2 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 functi...

Page 712: ... Figure 317 Configuration with XLNPROXY and GOOSEXLNRCV where all the IEC 61850 modelled data is used including selection Section 15 1MRK 504 163 UUS A Control 706 Transformer protection RET670 2 2 ANSI Application manual ...

Page 713: ...ch 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 considered f...

Page 714: ... 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 15 2 1 5 Reservation function QCRSV and RESIN M16609 3 v4 The purpose of the reservation function is primarily to transfer interlocking information between IEDs in a safe way and to prevent double operation in a ba...

Page 715: ...of involved bays up to 60 instances are available The received signals are either the request for reservation from another bay or the acknowledgment from each bay respectively which have received a request from this bay Also the information of valid transmission over the station bus must be received en 05000117 _ansi vsd IED IED From other SCSWI in the bay To other SCSWI in the bay 3 Station bus 3...

Page 716: ...ution in Figure 319 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 321 Application principle for an alternative reservation solution 15 2 2 Interaction between modules M16626 3 v8 A typical bay with appa...

Page 717: ...ansmitted to SXCBR The Autorecloser SMBRREC 79 consists of the facilities to automatically close a tripped breaker with respect to a number of configurable conditions The logical node Interlocking SCILO 3 provides the information to SCSWI whether it is permitted to operate due to the switchyard topology The interlocking conditions are evaluated with separate logic and connected to SCILO 3 The Sync...

Page 718: ...onizer 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 IEC050...

Page 719: ... 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 322 Example overview of the interactions betwee...

Page 720: ...ording 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 additional...

Page 721: ...s 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 Interlo...

Page 722: ...switches Value Breaker operating capability CbOpCap Switch operating capability SwOpCap 1 None None 2 Open Open 3 Close Open Close 4 Open Close Open Close and Open 5 Close Open Close Open Larger values handled as 4 both Close and Open 6 Open Close Open Close Open 7 more tStartMove is the supervision time for the apparatus to start moving after a command execution is done from the SCSWI function Wh...

Page 723: ... 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 limited ...

Page 724: ...me which in the case of disconnectors may be up to 10 seconds Should both indications stay low for a longer period the position indication will be interpreted as unknown If both indications stay high something is wrong and the state is again treated as unknown In both cases an alarm is sent to the operator Indications from position sensors shall be self checked and system faults indicated by a fau...

Page 725: ... 289G 989 989G WA1 A WA2 B WA7 C 789 en04000478_ansi vsd 152 ANSI04000478 V1 EN US Figure 323 Switchyard layout ABC_LINE 3 M13560 4 v5 The signals from other bays connected to the module ABC_LINE 3 are described below 15 3 2 2 Signals from bypass busbar M13560 6 v5 To derive the signals Signal BB7_D_OP All line disconnectors on bypass WA7 except in the own bay are open VP_BB7_D The switch status o...

Page 726: ...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 324 Signals from bypass busbar in line bay n 15 3 2 3 Signals from bus coupler M13560 31 v4 If the busbar is divided by bus section disconnectors into bus sections the busbar busbar connection could exist via the bus section disconnector and bu...

Page 727: ...id 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 WA1 ...

Page 728: ... the signals from the bus section coupler bay A1A2_BS rather than the bus section disconnector bay A1A2_DC must be used For B1B2_BS corresponding signals from busbar B are used The same type of module A1A2_BS is used for different busbars that is for both bus section circuit breakers A1A2_BS and B1B2_BS Signal S1S2OPTR No bus section coupler connection between bus sections 1 and 2 S1S2CLTR A bus s...

Page 729: ...t 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 326 Signals to a line bay in section 1 from the bus coupler bays in each section For a line bay in section 2 the same conditions as above are ...

Page 730: ...L 0 BB7_D_OP 1 BC_17_OP 1 BC_17_CL 0 BC_27_OP 1 BC_27_CL 0 EXDU_BPB 1 VP_BB7_D 1 VP_BC_17 1 VP_BC_27 1 If there is no second busbar WA2 and therefore no 289 disconnector then the interlocking for 289 is not used The state for 289 2189G BC_12 BC_27 are set to open by setting the appropriate module inputs as follows In the functional block diagram 0 and 1 are designated 0 FALSE and 1 TRUE 289_OP 1 2...

Page 731: ...layout ABC_BC 3 15 3 3 2 Configuration M13553 138 v4 The signals from the other bays connected to the bus coupler module ABC_BC are described below 15 3 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 transmiss...

Page 732: ...4000481 V1 EN US Figure 328 Signals from any bays in bus coupler bay n If the busbar is divided by bus section disconnectors into bus sections the signals BBTR are connected in parallel if both bus section disconnectors are closed So for the basic project specific logic for BBTR above add this logic Section 1 Section 2 A1A2_DC BS B1B2_DC BS ABC_LINE ABC_BC ABC_LINE ABC_BC WA1 A1 WA2 B1 WA7 C C B2 ...

Page 733: ... used for different busbars that is for both bus section circuit breakers A1A2_BS and B1B2_BS Signal S1S2OPTR No bus section coupler connection between bus sections 1 and 2 VPS1S2TR The switch status of bus section coupler BS is valid EXDU_BS No transmission error from the bay that contains the above information For a bus coupler bay in section 1 these conditions are valid en04000483_ansi vsd AND ...

Page 734: ... bay BC These signals from each bus coupler bay ABC_BC except the own bay are needed Signal BC12CLTR A bus coupler connection through the own bus coupler exists between busbar WA1 and WA2 VPBC12TR The switch status of BC_12 is valid EXDU_BC No transmission error from the bay that contains the above information These signals from each bus section disconnector bay A1A2_DC are also needed For B1B2_DC...

Page 735: ...XDU_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 332 Signals to a bus coupler bay in section 1 from a bus coupler bay in another section For a bus coupler bay in section 2 the same conditions as above are valid by changing section 1 to section 2 and vice versa 15 ...

Page 736: ... VP_BC_12 1 BBTR_OP 1 VP_BBTR 1 15 3 4 Interlocking for transformer bay AB_TRAFO 3 IP14149 1 v2 15 3 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 333 The function is used when there is no disconnector between circuit breaker and transformer Otherwise the interlocking f...

Page 737: ...ignals from other bays connected to the module AB_TRAFO are described below 15 3 4 2 Signals from bus coupler M13566 6 v4 If the busbar is divided by bus section disconnectors into bus sections the busbar busbar connection could exist via the bus section disconnector and bus coupler within the other bus section 1MRK 504 163 UUS A Section 15 Control Transformer protection RET670 2 2 ANSI 731 Applic...

Page 738: ...us 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 15 3 4 3 Configuration setting M13566 22 v5 If there are no second busbar B and therefore no 289 disconnector then the interlocking for 289 is not used The state for 289 2189G BC_12 are set to open by setting the appropriate module inputs as ...

Page 739: ...ncludes 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 335 Switchyard layout A1A2_BS 3 M15111 4 v3 The signals from other bays connected to the module A1A2_BS are described below 15 3 5 2 Signals from all feeders M15111 6 v4 If the busbar is divided by bus section circuit breakers into bus sections and both circu...

Page 740: ...er bay AB_TRAFO and bus coupler bay ABC_BC are needed Signal 1289OPTR 189 or 289 or both are open VP1289TR The switch status of 189 and 289 are valid EXDU_12 No transmission error from the bay that contains the above information These signals from each bus coupler bay ABC_BC are needed Signal BC12OPTR No bus coupler connection through the own bus coupler between busbar WA1 and WA2 VPBC12TR The swi...

Page 741: ...ct 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 ANSI040004...

Page 742: ... 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 338 Signals from any bays for a bus section circuit breaker between sections B1 and B2 15 3 5 3 Configuration setting M15111 57 v3 If there is no other busbar via the busbar loops that are possible then either the interlocking for the 152 open...

Page 743: ...w 15 3 6 2 Signals in single breaker arrangement M13542 6 v5 If the busbar is divided by bus section disconnectors the condition no other disconnector connected to the bus section must be made by a project specific logic The same type of module A1A2_DC is used for different busbars that is for both bus section disconnector A1A2_DC and B1B2_DC But for B1B2_DC corresponding signals from busbar B are...

Page 744: ...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 circui...

Page 745: ...ection 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 342 Signals from any bays in section A2 to a bus section disconnector...

Page 746: ...2DC_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 344 Signals from any bays in section B2 to a bus section disconnector 15 3 6 3 Signals in double breaker arrangement M13542 80 v5 If the busbar is divided by b...

Page 747: ...disconnectors on bus section 1 is valid VPS2_DC The switch status of all disconnectors on bus section 2 is valid EXDU_BB No transmission error from double breaker bay DB that contains the above information These signals from each double breaker bay DB_BUS are needed Signal 189OPTR 189 is open 289OPTR 289 is open VP189TR The switch status of 189 is valid VP289TR The switch status of 289 is valid EX...

Page 748: ...se 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 347 Signals from double breaker bays in section A2 to a bus section disconnector For a bus section disconnector these conditions fro...

Page 749: ... sect B2 EXDU_DB bay 1 sect B2 EXDU_DB bay n sect B2 AND AND ANSI04000502 V1 EN US Figure 349 Signals from double breaker bays in section B2 to a bus section disconnector 15 3 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 made ...

Page 750: ...id 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 15 3 7 Interlocking for busbar grounding switch BB_ES 3 IP14164 1 v4 15 3 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 according t...

Page 751: ...se signals from each line bay ABC_LINE each transformer bay AB_TRAFO and each bus coupler bay ABC_BC are needed Signal 189OPTR 189 is open 289OPTR 289 is open AB_TRAFO ABC_LINE 22089OTR 289 and 2089 are open ABC_BC 789OPTR 789 is open VP189TR The switch status of 189 is valid VP289TR The switch status of 289 is valid V22089TR The switch status of 289and 2089 is valid VP789TR The switch status of 7...

Page 752: ...ignal 189OPTR 189 is open 289OPTR 289 is open VP189TR The switch status of 189 is valid VP289TR The switch status of 289 is valid EXDU_BS No transmission error from the bay BS bus section coupler bay that contains the above information For a busbar grounding switch these conditions from the A1 busbar section are valid en04000506_ansi vsd 189OPTR bay 1 sect A1 BB_DC_OP VP_BB_DC EXDU_BB 189OPTR bay ...

Page 753: ... A2 AND DCOPTR A1 A2 EXDU_BB bay 1 sect A2 EXDU_DC A1 A2 AND AND ANSI04000507 V1 EN US Figure 354 Signals from any bays in section A2 to a busbar grounding switch in the same section For a busbar grounding switch these conditions from the B1 busbar section are valid 1MRK 504 163 UUS A Section 15 Control Transformer protection RET670 2 2 ANSI 747 Application manual ...

Page 754: ... 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 356 Signals ...

Page 755: ... 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 358 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 are ...

Page 756: ...on described in section Signals in single breaker arrangement 15 3 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 359 Busbars divided by bus sec...

Page 757: ...le 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 must b...

Page 758: ...hen set the corresponding inputs as follows VOLT_OFF 1 VOLT_ON 0 15 3 9 Interlocking for breaker and a half diameter BH 3 IP14173 1 v3 15 3 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 361 Section 15 1MRK 504 163 UUS A Control 752 Transformer...

Page 759: ...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 15 3 9 2 Configuration setting M13569 6 v5 For application without 989 and 989G just set the appropriate inputs to open state and disregard the outputs In the functional block diagram 0 a...

Page 760: ...ap changer control and supervision 6 binary inputs TCMYLTC 84 Tap changer control and supervision 32 binary inputs TCLYLTC 84 15 4 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 the p...

Page 761: ...ormers 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 includin...

Page 762: ...on 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 parallel c...

Page 763: ...nts 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 any c...

Page 764: ...ent 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 analog inpu...

Page 765: ...ower Cmd ANSI06000489 2 en vsd D D V V DVin DVin ANSI06000489 V2 EN US Figure 363 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 363 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 will sta...

Page 766: ... 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 in the...

Page 767: ...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 364 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 accordin...

Page 768: ... 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 security r...

Page 769: ... 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 adjustment of...

Page 770: ...C 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 end up ...

Page 771: ...ulate 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 genera...

Page 772: ...ith the reverse reactance method SEMOD159053 145 v4 Consider Figure 367 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 367 Parallel transformers with equal rated data In the re...

Page 773: ...ively this means that whereas the line voltage drop compensation in figure 365 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 368 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 up to...

Page 774: ...ower 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 different tu...

Page 775: ...n 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 prese...

Page 776: ...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 the ...

Page 777: ...ap 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 greatest ...

Page 778: ...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 breaker...

Page 779: ...tionAdapt 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 autom...

Page 780: ...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 370 Capacitor bank on the LV side From figure 370 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 current...

Page 781: ... 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 reacti...

Page 782: ... 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 made via...

Page 783: ... 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 Automatic vo...

Page 784: ...sformer 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 58 Analog signals Signal Explanation voltageBusbar Measured busbar voltage for this transformer ...

Page 785: ...is 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 372 would then be according to the table 59 Table 59 Setting of TxRXOP TrfId T1 T1RXOP Off T2RXOP On T3RXOP On T4RXOP Off T5RXOP Off T6RXOP Off T7RXOP Off T8RXOP...

Page 786: ...ee figure 363 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 will be...

Page 787: ... 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 error ...

Page 788: ...AL 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 Automati...

Page 789: ...d 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 condi...

Page 790: ...et 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 62 Table 62 Blocking via binary inputs Input name Activation Descripti...

Page 791: ...e 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 Operatio...

Page 792: ...d 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 conditions ...

Page 793: ...ing 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 337 v1...

Page 794: ... 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 voltage c...

Page 795: ...ion 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 activa...

Page 796: ...d 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 under...

Page 797: ...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 TapChgBk...

Page 798: ... 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 enab...

Page 799: ...mmand 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 etc co...

Page 800: ...iagram 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 ANSI060...

Page 801: ...o 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 375 shows an example of this where the settings of Rline and Xline for j 11 from figure 374 has bee...

Page 802: ...ormers 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 balance...

Page 803: ...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 action ac...

Page 804: ... pickup for all values to the right of the setting Reference is made to figure 371 for definition of forward and reverse direction of power through the transformer en06000634_2_en vsd P P IEC06000634 V2 EN US Figure 376 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 be no...

Page 805: ... 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 If the ...

Page 806: ...he 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 for ev...

Page 807: ... 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 disables ...

Page 808: ... 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 established by ...

Page 809: ... 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 as wel...

Page 810: ... the single line diagram SLD this function block has two control modes settable through CtlModel Dir Norm and SBO Enh 15 7 Generic communication function for Double Point indication DPGAPC SEMOD55384 1 v4 15 7 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 funct...

Page 811: ...ON 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 64 for the description of the input output relationship in te...

Page 812: ...nction 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 15 8 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 Oper...

Page 813: ...f 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 15 9 3 Setting guidelines SEMOD158639 5 ...

Page 814: ...figuration 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 379 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 check Conf...

Page 815: ...1 User defined conditions Configuration logic circuits en04000208_ansi vsd AND ANSI04000208 V2 EN US Figure 381 Application example showing a logic diagram for control of external devices via configuration logic circuits 15 10 3 Setting guidelines M12448 3 v2 The parameters for Single command 16 signals SINGLECMD are set via the local HMI or PCM600 1MRK 504 163 UUS A Section 15 Control Transformer...

Page 816: ...e 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 function ...

Page 817: ...ctly 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 same t...

Page 818: ...n 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 internal ...

Page 819: ...ibited 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 prote...

Page 820: ...issive 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 signal to ...

Page 821: ...he 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 signal...

Page 822: ...ne 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 or eve...

Page 823: ... 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 unbloc...

Page 824: ...me applications the equipment shall be able to receive while transmitting and commands may be transmitted over longer time period than for other teleprotection systems 16 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 by usin...

Page 825: ...reaching 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 16 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 16 1 3 5 Unblocking schem...

Page 826: ...ommunication channels For the Phase segregated scheme communication logic for distance protection ZC1PPSCH 85 three channels in each direction which can transmit an on off signal is required The performance and security of this function is directly related to the transmission channels speed and security against false or lost signals Special communication channels are used for this purpose When pow...

Page 827: ...multaneous faults occur the phase selectors at the remote protection IED relative to the faults see the A side in figure 386 cannot discriminate between the fault on the protected line and on the parallel line The phase selector must be set to cover the whole line with a margin and will also detect a fault on the parallel line Instantaneous phase selective tripping for simultaneous faults close to...

Page 828: ...edia PLC The scheme can be used on all types of line length The blocking scheme is very dependable because it will operate for faults anywhere on the protected line if the communication channel is out of service Conversely 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 Inade...

Page 829: ...efore the overreaching zone has operated at the remote IED To assure a sufficient duration of the received signal CR the send signal CS can be prolonged by a tSendMin reset timer The recommended setting of tSendMin is 100 ms Since the received communication signal is combined with the output from an overreaching zone there is less concern about false signal causing an incorrect trip Therefore set ...

Page 830: ...s have a fault 16 2 2 3 Intertrip scheme SEMOD141790 49 v2 In some power system applications there is a need to trip the remote end breaker immediately from local protections This applies for instance when transformers or reactors are connected to the system without circuit breakers or for remote tripping following operation of Breaker failure protection CCRBRF 50BF In intertrip scheme the carrier...

Page 831: ...D141800 6 v1 Set Operation On Set Scheme type Permissive UR Set tCoord 0 ms Set tSendMin 0 1 s 16 2 3 2 Permissive overreach scheme SEMOD141800 9 v1 Set Operation On Set Scheme type Permissive OR Set tCoord 0 ms Set tSendMin 0 1 s 16 2 3 3 Blocking scheme SEMOD141800 12 v1 Set Operation On Set Scheme type Blocking Set tCoord 25 ms 10 ms maximal transmission time Set tSendMin 0 s 16 2 3 4 Intertrip...

Page 832: ...ion A2 at A side will detect a fault in forward direction and send a communication signal to the protection B2 at remote end which is measuring a fault in reverse direction en99000043_ansi vsd Strong source LINE 1 LINE 2 A 1 A 2 B 1 B 2 A B Weak source FAULT CLOSED CLOSED CLOSED CLOSED ANSI99000043 V1 EN US Figure 387 Current distribution for a fault close to B side when all breakers are closed Wh...

Page 833: ...ribution Here the fault current increases when the breaker opens at the strong terminal and a sequential tripping is achieved This requires a detection of the fault by an independent tripping zone 1 To avoid sequential tripping as described and when zone 1 is not available weak end infeed tripping logic is used The weak end infeed function only works together with permissive overreach communicatio...

Page 834: ... reference of base values 16 3 3 1 Current reversal logic M13856 6 v6 Set CurrRev to Enabled to activate the function Set tDelayRev timer at the maximum reset time for the communication equipment that gives the carrier receive CRL signal plus 30 ms A minimum setting of 40 ms is recommended typical 60 ms A long tDelayRev setting increases security against unwanted tripping but delay the fault clear...

Page 835: ...inals overreaching permissive communication schemes can trip unselectable due to current reversal The unwanted tripping affects the healthy line when a fault is cleared on the other line This lack of security results in a total loss of interconnection between the two buses To avoid this kind of disturbances fault current reversal logic transient blocking logic can be used The unwanted operations t...

Page 836: ...n function block ZCPSCH Weak end infeed logic Permissive communication schemes can basically operate only when the protection in the remote IED can detect the fault The detection requires a sufficient minimum fault current normally 20 of Ir The fault current can be too low due to an open breaker or low short circuit power of the source To overcome these conditions weak end infeed WEI echo logic is...

Page 837: ...mmunication function ZC1WPSCH are set via the local HMI or PCM600 Common base IED values for primary current IBase primary voltage UBase and primary power SBase are set in Global base values for settings function GBASVAL GlobalBaseSel It is used to select a GBASVAL function for reference of base values Current reversal logic Set OperCurrRev to On to activate the function Set tDelayRev timer at the...

Page 838: ... number Scheme communication logic for residual overcurrent protection ECPSCH 85 16 5 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 i...

Page 839: ...RG which must always be present even when no CR signal is received The absence of the CRG signal during the security 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 16 5 3 Setting guidelines M13920 4 v7 The parameters for the scheme communication logic for residual overcurrent protection func...

Page 840: ... typical system condition which can result 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 I...

Page 841: ...t 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 16 6 2 2 Weak end infeed logic M15285 6 v5 Figure 393 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 IED a...

Page 842: ...ed 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 time is ...

Page 843: ...quence of signaling at current reversal 16 6 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 weak end...

Page 844: ...838 ...

Page 845: ... 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 when ext...

Page 846: ...nto 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 breaker e...

Page 847: ...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 follow For...

Page 848: ...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 396 The trip logic function SMPPTRC 94 used for single pole tripping application 17 1 2 3 Single two or three pole tripping M14828 15 v5 The single two three pole tripping mode provides single pole tripping for singl...

Page 849: ...ed 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 input SET...

Page 850: ... 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 397 Example of the connection of directional start logic The Start Matrix SMAGAPC merges start and directional output signals from different app...

Page 851: ...ut 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 selecti...

Page 852: ... 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 off dela...

Page 853: ...evice number Logic for group warning WRNCALH 17 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 17 4 ...

Page 854: ...gate the time stamp and the quality of signals They have the suffix QT at the end of their function block name for example SRMEMORYQT 17 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 functi...

Page 855: ...uration tool with the designation of the function block and the cycle time see example below IEC09000695_2_en vsd IEC09000695 V2 EN US Figure 398 Example designation serial execution number and cycle time for logic function IEC09000310 2 en vsd IEC09000310 V2 EN US Figure 399 Example designation serial execution number and cycle time for logic function that also propagates timestamp and quality of...

Page 856: ...22 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 in FXD...

Page 857: ...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 401 REFPDIF 87N function inputs for normal transformer application 17 8 Boolean 16 to Integer conversion B16I SEMOD175715 1 v1 17 8 1 Identification SEMOD175721 2 v2 Function description IEC 61850 identification IEC 60617 identificatio...

Page 858: ...oolean 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 functio...

Page 859: ...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 65535 is a...

Page 860: ...TIGAPC function block 17 10 Integer to Boolean 16 conversion IB16 SEMOD158367 1 v2 17 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 17 10 2 Application SEMOD158499 5 v4 Integer to boolean 16 conversion function IB16 is used to transform an integer into a set of 16 binar...

Page 861: ... 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 Input 1...

Page 862: ...ode 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 65 If the BLOCK input is activated it freezes the logical outputs at the last value Table 65 Output signals Name of OUTx...

Page 863: ...A87 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 9 seco...

Page 864: ...tion 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 17 13 3 Setting guidelines GUID ADA3E806 BEF1 4D15 B270 207386A0AEE4 v2 For proper operation of comparison the ...

Page 865: ...1982C59 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 between inpu...

Page 866: ...nd 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 comparison when...

Page 867: ... 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 those c...

Page 868: ...862 ...

Page 869: ...N 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 504 163 UUS A Section 18 Monitoring Transf...

Page 870: ...nt 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 reduce...

Page 871: ... 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 18 1 3 Zero clamping GUID 8DABC3F5 6615 493C B839 A5C557A2FAE8 v4 Measuring functions CVMMXN CMMXU VMMXU and VNMMXU have no interconnections regarding any settings or parameters Zero clam...

Page 872: ...ctual 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 taken ...

Page 873: ...is equal to 5 30 or 100 IAngCompY Angle compensation to calibrate angle measurements at Y of In where Y is equal to 5 30 or 100 The following general settings can be set for the Phase phase voltage measurement VMMXU VMagCompY Amplitude compensation to calibrate voltage measurements at Y of Vn where Y is equal to 5 30 or 100 VAngCompY Angle compensation to calibrate angle measurements at Y of Vn wh...

Page 874: ...HiLim 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 range...

Page 875: ...es 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 depe...

Page 876: ...03 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 66 level superv...

Page 877: ...tage level to 25 Voltage below 25 will force S P and Q to zero IGenZeroDb Zero point clamping in of Ibase 3 Set minimum current level to 3 Current below 3 will force S P and Q to zero VBase set in Global base Base setting for voltage level in kV 400 00 Set rated OHL phase to phase voltage IBase set in Global base Base setting for current level in A 1000 Set rated primary CT current used for OHL SB...

Page 878: ... value Comments IMagComp5 Magnitude factor to calibrate current at 5 of In 0 00 IMagComp30 Magnitude factor to calibrate current at 30 of In 0 00 IMagComp100 Magnitude factor to calibrate current at 100 of In 0 00 VAmpComp5 Magnitude factor to calibrate voltage at 5 of Vn 0 00 VMagComp30 Magnitude factor to calibrate voltage at 30 of Vn 0 00 VMagComp100 Magnitude factor to calibrate voltage at 100...

Page 879: ...ssary 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 69 1MRK 504 163 UUS A Section 18 Monitori...

Page 880: ...d 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 Set L...

Page 881: ...ssary 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 504 163 UUS A Section 18 Monit...

Page 882: ...e 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 18 2 Gas medium supervision SSIMG 63 GUID 358AD8F8 AE06 4AEA 9969 46E5299D5B4B v3 18 2 1 Identification GUID AD96C26E C3E5 4B21 9ED6 12E540954AC3 v4 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device ...

Page 883: ...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 used...

Page 884: ...on received information 18 3 3 Setting guidelines GUID 0C8E498B 2A65 44ED 91D6 53EC72F49222 v2 The parameters for Liquid medium supervision SSIML can be set via local HMI or Protection and Control Manager PCM600 Operation This is used to disable enable the operation of liquid medium supervision i e Off On LevelAlmLimit This is used to set the limit for a level alarm condition in the transformer Le...

Page 885: ...ce number Breaker monitoring SSCBR 18 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 condition ...

Page 886: ...ker Every time the breaker operates the circuit breaker life reduces due to wear The wear in a breaker depends on the interrupted current For breaker maintenance or replacement at the right time the remaining life of the breaker must be estimated The remaining life of a breaker can be estimated using the maintenance curve provided by the circuit breaker manufacturer Circuit breaker manufacturers p...

Page 887: ...one operation is equivalent to 10000 900 11 operations at the rated current It is assumed that prior to tripping the remaining life of a breaker is 10000 operations Remaining life calculation for three different interrupted current conditions is explained below Breaker interrupts at and below the rated operating current that is 2 kA the remaining life of the CB is decreased by 1 operation and ther...

Page 888: ...les Routine breaker maintenance like lubricating breaker mechanism is based on the number of operations A suitable threshold setting helps in preventive maintenance This can also be used to indicate the requirement for oil sampling for dielectric testing in case of an oil circuit breaker Circuit breaker operation monitoring By monitoring the activity of the number of operations it is possible to c...

Page 889: ...erence 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 travel ...

Page 890: ...nge of status of trip output and start of main contact separation 18 5 Event function EVENT IP14590 1 v2 18 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 18 5 2 Application M12805 6 v11 When using a Substation Automation system with LON or SPA communication time tagged ev...

Page 891: ...e no semantic prefer to be set by the user LONChannelMask or SPAChannelMask M12811 15 v2 Definition of which part of the event function block that shall generate events Disabled Channel 1 8 Channel 9 16 Channel 1 16 MinRepIntVal 1 16 M12811 29 v3 A time interval between cyclic events can be set individually for each input channel This can be set between 0 s to 3600 s in steps of 1 s It should norm...

Page 892: ...ce 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 reco...

Page 893: ...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 Seque...

Page 894: ...re 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 Table ...

Page 895: ... 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 overwrit...

Page 896: ...73 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 retr...

Page 897: ...M600 is used to configure the signals For retrieving remote data from LDCM module the Disturbance report function should be connected to a 8 ms SMAI function block if this is the only intended use for the remote data The analog trigger of Disturbance report is not affected if analog input M is to be included in the disturbance recording or not OperationM Enabled Disabled If OperationM Disabled no ...

Page 898: ...ting 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 inpu...

Page 899: ... 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 parameters ...

Page 900: ...cal diagram 18 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 18 8 Fault locator LMBRFLO IP14592 1 v2 18 8 1 Identification M14892 1 v3 Function description IEC 61...

Page 901: ...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 by usin...

Page 902: ...e 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 because on...

Page 903: ...ator LMBRFLO 18 9 Limit counter L4UFCNT GUID 22E141DB 38B3 462C B031 73F7466DD135 v1 18 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 504 163 UUS A Section 18 Monitoring Transformer protection RET670 2 2 ANSI 897 Application manual ...

Page 904: ... over to zero In this case periodic pulses will be generated at multiple overflow of the function 18 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 18 10 Running hour meter TEILGAPC 18 10 1 Identification GUID 3F9EF4FA 74FA 4D1D 88A0 E948B722B64F v1 Functio...

Page 905: ...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 winding an...

Page 906: ...sformer 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 smaller ...

Page 907: ...rature 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 411 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 On t...

Page 908: ...nvolved in the higher operating temperatures see Figure 412 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 repeti...

Page 909: ...al 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 Continuo...

Page 910: ...timation 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 rise ove...

Page 911: ...e 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 transformer The...

Page 912: ...perature 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 windings ...

Page 913: ...t 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 the use...

Page 914: ...ime 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 winding ti...

Page 915: ...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 transformer N...

Page 916: ...g 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 temperatur...

Page 917: ...ing 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 options...

Page 918: ...imeToUpdate 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 level ...

Page 919: ...e 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 18 11 3 Setting example 18 11 3 1 Transformer Rated Data GUID B3AE440F CC5E 4742 9483 8D6448A476C8 v1 Table 73 Transformer Ra...

Page 920: ...ct 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 RatedVoltageW3...

Page 921: ... 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 as Us...

Page 922: ...pping 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 minimum t...

Page 923: ...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 the calc...

Page 924: ...ble 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 outputs...

Page 925: ...ed via the station bus to the substation automation system or read via the station monitoring system as a service value When using IEC 61850 8 1 a scaled service value is available over the station bus The normal use for this function is the counting of energy pulses from external energy meters An optional number of inputs from an arbitrary input module in IED can be used for this purpose with a f...

Page 926: ...ing also influences the inputs on the same board used for pulse counting 19 2 Function for energy calculation and demand handling ETPMMTR SEMOD153638 1 v2 19 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 19 2 2 Application SEMOD175546 4 v5 En...

Page 927: ...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 total ...

Page 928: ...cPlsQty gives the MWh value in each pulse It should be selected together with the setting of the Pulse counter PCGGIO settings to give the correct total pulse value ERFAccPlsQty and ERVAccPlsQty gives the MVArh value in each pulse It should be selected together with the setting of the Pulse counter PCGGIO settings to give the correct total pulse value For the advanced user there are a number of se...

Page 929: ...rts 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 Redund...

Page 930: ...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 sele...

Page 931: ... 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 availa...

Page 932: ... AP1 PhyPortB PhyPortA AP1 PhyPortA PhyPortB Switch B Device 1 Device 2 Device 3 Device 4 IEC09000758 V4 EN US Figure 414 Parallel Redundancy Protocol PRP Section 20 1MRK 504 163 UUS A Ethernet based communication 926 Transformer protection RET670 2 2 ANSI Application manual ...

Page 933: ...ed when the parameter is set to PRP 0 PRP 1 or HSR The settings for the next access point will be hidden and PhyPortB will show the second port information Redundant communication is activated after a common write to IED is done PRP 1 should be used primarily PRP 0 is intended only for use in existing PRP networks PRP 1 and HSR can be combined in a mixed network If the access point is not taken in...

Page 934: ...s 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 measuring ...

Page 935: ...ot 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 20 4 2 Setting guidelines GUID 2C4A312A 00DC 44C8 B2D9 CD0822E1C806 v1 Routes are configured using the Ethernet configuration tool in PCM600 Operation ...

Page 936: ...cifies the destination Destination subnet mask specifies the subnetwork mask of the destination Section 20 1MRK 504 163 UUS A Ethernet based communication 930 Transformer protection RET670 2 2 ANSI Application manual ...

Page 937: ...mmunication 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 subscribe mech...

Page 938: ... 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 418 SA system with IEC 61850 8 1 M16925 3 v4 Figure419 shows the GOOSE peer to peer communication Section 21 1MRK 504 163 UUS A Station communication 932 Transformer protection RET670 2 2 ANSI Application manual ...

Page 939: ...ion 2 the Ethernet link selection is done with the Ethernet Configuration Tool ECT in PCM600 21 2 3 Horizontal communication via GOOSE 21 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 function ...

Page 940: ... 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 output o...

Page 941: ...xample 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 Inpu...

Page 942: ... 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 75 Specification of the fibre optic connectors Glass fibre Plastic fibre Cable connector ST connector s...

Page 943: ...th Classic Monitor application library LIB520 is required The HV Control 670 software module is included in the LIB520 high voltage process package which is a part of the Application Software Library in MicroSCADA applications The HV Control 670 software module is used for control functions in the IEDs The module contains a process picture dialogues and a tool to generate a process database for th...

Page 944: ...4790 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 21 3 2 3 Setting guidelines SEMOD119915 1 v1 Settings M14789 4 v3 The parameters for the multiple com...

Page 945: ...C 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 communication i...

Page 946: ... 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 commun...

Page 947: ... 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 21 5 1 1 Functionality M17109 38 v3 IEC 60870 5 103 is an unbalanced master slave protocol for coded bit ser...

Page 948: ... with a Personal Computer PC or a Remote Terminal Unit RTU in the station using the SPA IEC port the only hardware needed is Optical fibres glass plastic Opto electrical converter for the PC RTU PC RTU Commands M17109 62 v4 The commands defined in the IEC 60870 5 103 protocol are represented in dedicated function blocks These blocks have output signals for all available commands according to the p...

Page 949: ...and INFORMATION NUMBER parameter is defined for each input signal Function status indication in monitor direction user defined Function blocks with user defined input signals in monitor direction I103UserDef These function blocks include the FUNCTION TYPE parameter for each block in the private range and the INFORMATION NUMBER parameter for each input signal Supervision indications in monitor dire...

Page 950: ... for each block in the private range and the INFORMATION NUMBER 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...

Page 951: ...ocol 1 The port specific IEC 60870 5 103 protocol parameters are configured under Main menu Configuration Communication Station Communication IEC60870 5 103 config selector SlaveAddress BaudRate RevPolarity optical channel only CycMeasRepTime MasterTimeDomain TimeSyncMode EvalTimeAccuracy EventRepMode CmdMode RepIntermediatePos config selector is OPTICAL103 1 for the optical serial channel on the ...

Page 952: ...der they were generated by BSW The most recent value is the latest value delivered All GI data from a single block will come from the same cycle If EventRepMode HiPriSpont spontaneous events will be delivered prior to GI event To prevent old GI data from being delivered after a new spontaneous event the pending GI event is modified to contain the same value as the spontaneous event As a result the...

Page 953: ...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 informati...

Page 954: ...5 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 21 5 3 Function and information types M17109 145 v6 Product type IEC103mainFunType value Comment REL 128 Compatible range REC 242 Private range use default RED 192 Compatible range RET...

Page 955: ...e 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 21 6 DNP3 Communication protocol 21 6 1 Application GUID EF1F0C38 9FF6 4683 8B10 AAA372D42185 v1 For mor...

Page 956: ...950 ...

Page 957: ...o 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 binary ...

Page 958: ...se 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 revert...

Page 959: ...ission network for example PDH Telecom Network Multiplexer Multiplexer en05000527 2 vsd Converting optical to galvanic G 703 IEC05000527 V2 EN US Figure 427 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 alwa...

Page 960: ...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 communicatio...

Page 961: ...ys 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 cause ...

Page 962: ... 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 inste...

Page 963: ...ip 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 504 163 UUS A Section 22 Remote communication Transformer protection RET670 2 2 ANSI 957 Application manual ...

Page 964: ...958 ...

Page 965: ...ion 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 comm...

Page 966: ...d 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 23 3 Change lock CHNGLCK GUID B48775D0 ACF0 49C6 A7F6 69AF37F1C68F v1 23 3 1 Application GUID 51EEC9C7 8ECF 4546 BC26 326861654340 v4 Change lock function CHNGLCK is used to block further changes to the IED configuration once the commissioning is complete The purpose is to ma...

Page 967: ...K input If such a situation would occur in spite of these precautions then please contact the local ABB representative for remedial action 23 4 Denial of service SCHLCCH RCHLCCH 23 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 facilities...

Page 968: ...ts channel A and B redundant communication LinkStatus indicates the Ethernet link status for the front port 23 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 23 1MRK 504 163 UUS A Security 962 Transformer protection RET670 2 2 ANSI Application manual ...

Page 969: ...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 inform...

Page 970: ...us Product identifiers Firmware version numbers run independently from the release production numbers For every release number there can be one or more firmware versions depending on the small issues corrected in between releases ProductVer Describes the product version Example 2 1 0 1 is the Major version of the manufactured product this means new platform of the product 2 is the Minor version of...

Page 971: ...table parameters for the measured value expander block function 24 4 Parameter setting groups IP1745 1 v1 24 4 1 Application M12007 6 v9 Six sets of settings are available to optimize IED operation for different power system conditions By creating and switching between fine tuned setting sets either from the local HMI or configurable binary inputs results in a highly adaptable IED that can cope wi...

Page 972: ...e 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 24 5 Rated system frequency PRIMVAL IP15064 1 v2 24 5 1 Identification GUID B8B3535D 227B 4151 9E98 BEB85F4D54DE v1 Function description IEC 61850 ...

Page 973: ...ference 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 24 7 Global base values GBASVAL GUID 2FDB0A2C 10FE 4954 B6E4 9...

Page 974: ... 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 24 8 Signal matrix for binary inputs SMBI SEMOD55793 1 v2 24 8 1 Application M15310 3 v2 The Signal matrix for binary inputs function SMBI is used within the Application Configuration tool in direct relation...

Page 975: ... define SMBO function in the Signal Matrix tool 24 10 Signal matrix for mA inputs SMMI SEMOD55233 1 v2 24 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 24 10 2 Setting guidelines SEMOD55...

Page 976: ...ration due to non valid frequency values MinValFreqMeas is set as of VBase 3 If SMAI setting ConnectionType is Ph Ph at least two of the inputs GRPx_A GRPx_B and GRPx_C where 1 x 12 must be connected in order to calculate the positive sequence voltage Note that phase to phase inputs shall always be connected as follows A B to GRPxA B C to GRPxB C A to GRPxC If SMAI setting ConnectionType is Ph N a...

Page 977: ...one neutral value either voltage or current SMAI outputs give information about every aspect of the 3ph analog signals acquired phase angle RMS value frequency and frequency derivates and so on 244 values in total Besides the block group name the analog inputs type voltage or current and the analog input names that can be set directly in ACT Application functions should be connected to a SMAI bloc...

Page 978: ...ExtOut and DFTReference shall be set to default value InternalDFTRef if no VT inputs are available Even if the user sets the AnalogInputType of a SMAI block to Current the MinValFreqMeas is still visible However using the current channel values as base for frequency measurement is not recommendable for a number of reasons not last among them being the low level of currents that one can have in nor...

Page 979: ... 35 11 SMAI12 36 12 Task time group 3 AdDFTRefCh7 AdDFTRefCh4 IEC07000197 V2 EN US Figure 429 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 each ...

Page 980: ...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 429 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 430 SMAI2 2 SMAI12 12 DF...

Page 981: ... 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 429 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 SPFC...

Page 982: ...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 configure...

Page 983: ...puts on LNs related to primary equipment are blocked If there is an XCBR the outputs EXC_Open and EXC_Close are blocked When the Beh of a component is set to Blocked all control commands with a test bit are accepted Outputs to the process via a non IEC 61850 link data are blocked by the LN In addition the components can be blocked when their Beh is blocked This can be done if the component has a b...

Page 984: ...he 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 external cloc...

Page 985: ...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 one c...

Page 986: ...RIG 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 the clo...

Page 987: ...n 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 432 Enabling PTP in ECT The PTP VLAN tag must have th...

Page 988: ...SAM600 The REL contains a GTM card which has a PPS output that is used to synchronize merging units that are not PTP compliant As a side effect the GTM contains a GPS receiver and the REL acts as a backup of the GPS on the station bus On all access points the PTP parameter is ON On the REL the parameter FineSyncSource under Configuration Time Synchronization TIMESYNCHGEN 1 General is set to GPS if...

Page 989: ...ccording to many different classes and standards In principle there are three different types of protection CTs These types are related to the design of the iron core and the presence of airgaps Airgaps affects the properties of the remanent flux The following three different types of protection CTs have been specified The High Remanence type with closed iron core and no specified limit of the rem...

Page 990: ... 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 according...

Page 991: ...sses 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 25 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 tran...

Page 992: ...rements are based on the maximum fault current for faults in different positions Maximum fault current will occur for three phase faults or single phase to ground faults The current for a single phase to ground fault will exceed the current for a three phase fault when the zero sequence impedance in the total fault loop is less than the positive sequence impedance When calculating the current tran...

Page 993: ...lity 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 unwan...

Page 994: ... the protection IED A Rct The secondary resistance of the CT W RL The resistance of the secondary wire and additional load W The loop resistance containing the phase and neutral wires must be used for faults in solidly grounded systems The resistance of a single secondary wire should be used for faults in high impedance grounded systems SR The burden of an IED current input channel VA SR 0 020 VA ...

Page 995: ...ward and reverse faults A Ikzone1 Maximum primary fundamental frequency current for faults at the end of zone 1 reach A Ipr The rated primary CT current A Isr The rated secondary CT current A In The nominal current of the protection IED A Rct The secondary resistance of the CT W RL The resistance of the secondary wire and additional load W In solidly grounded systems the loop resistance containing...

Page 996: ...Mho distance ZMHPDIS a 1 for primary time constant Tp 100 ms a 3 for primary time constant Tp 100 and 400 ms k 4 for primary time constant Tp 40 ms k 5 for primary time constant Tp 40 and 150 ms 25 1 6 3 Breaker failure protection M11621 3 v5 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 Ealr...

Page 997: ... EN US Equation 523 Where Irt The rated primary current of the power transformer A Ietf Maximum primary fundamental frequency phase to ground fault current that passes the CTs and the power transformer neutral A Ipr The rated primary CT current A Isr The rated secondary CT current A Ir The rated current of the protection IED A Rct The secondary resistance of the CT Ω RL The resistance of the secon...

Page 998: ...sses the CTs and the power transformer neutral A Ipr The rated primary CT current A Isr The rated secondary CT current A Ir The rated current of the protection IED A Rct The secondary resistance of the CT Ω RL The resistance of the secondary wire and additional load Ω The loop resistance containing the phase and neutral wires shall be used SR The burden of a REx670 current input channel VA SR 0 02...

Page 999: ... currents and unsymmetrical distribution of the phase currents between the CTs The zero sequence fault current level can differ much and is often difficult to calculate or estimate for different cases To cover these cases with summation of zero sequence currents from more than one CT the phase side CTs must fulfill the Requirement 527 below 2 sr R al alreq f ct L pr r I S E E I R R I I æ ö ç è ø E...

Page 1000: ...s PX and PXR EkneeBS for class X and the limiting secondary voltage Val for TPS The value of the Eknee is lower than the corresponding Eal according to IEC 61869 2 It is not possible to give a general relation between the Eknee and the Eal but normally the Eknee is approximately 80 of the Eal Therefore the CTs according to class PX PXR X and TPS must have a rated knee point e m f Eknee that fulfil...

Page 1001: ... according to ANSI IEEE must have a knee point voltage VkneeANSI that fulfills the following kneeANSI alreq V 0 75 maximum of E EQUATION2101 V2 EN US Equation 532 The following guide may also be referred for some more application aspects of ANSI class CTs IEEE C37 110 2007 IEEE Guide for the Application of Current Transformers Used for Protective Relaying Purposes 25 2 Voltage transformer requirem...

Page 1002: ...imary or secondary server in a redundant configuration is not recommended 25 4 PTP requirements GUID 741CC863 D760 49D6 85B2 AFECA222A8C3 v1 For PTP to perform properly the Ethernet equipment that is used needs to be compliant with IEEE1588 The clocks used must follow the IEEE1588 standard BMC Best Master Algorithm and shall for instance not claim class 7 for a longer time than it can guarantee 1u...

Page 1003: ...t G 704 frame structured etc Format No CRC check Synchronization in PDH systems connected to SDH systems Independent synchronization asynchronous mapping The actual SDH port must be set to allow transmission of the master clock from the PDH system via the SDH system in transparent mode Maximum clock deviation 50 ppm nominal 100 ppm operational Jitter and Wander according to ITU T G 823 and G 825 B...

Page 1004: ...998 ...

Page 1005: ...service data unit AWG American Wire Gauge standard BBP Busbar protection BFOC 2 5 Bayonet fibre optic connector BFP Breaker failure protection BI Binary input BIM Binary input module BOM Binary output module BOS Binary outputs status BR External bistable relay BS British Standards BSR Binary signal transfer function receiver blocks BST Binary signal transfer function transmit blocks C37 94 IEEE AN...

Page 1006: ...TRADE 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 Carrier r...

Page 1007: ...ge 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 prote...

Page 1008: ...an 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 protect...

Page 1009: ...tative of a type In the same way an instance of a function in the IED is representative of a type of function IP 1 Internet protocol The network layer for the TCP IP protocol suite widely used on Ethernet networks IP is a connectionless best effort packet switching protocol It provides packet routing fragmentation and reassembly through the data link layer 2 Ingression protection according to IEC ...

Page 1010: ...current 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 balance p...

Page 1011: ... 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 Supervision ...

Page 1012: ... supervision TCP Transmission control protocol The most common transport layer protocol used on Ethernet and the Internet TCP IP Transmission control protocol over Internet Protocol The de facto standard Ethernet protocols incorporated into 4 2BSD Unix TCP IP was developed by DARPA for Internet working and encompasses both network layer and transport layer protocols While TCP and IP specify two pr...

Page 1013: ...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 ship ...

Page 1014: ...1008 ...

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Page 1016: ... 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 504 163 UUS ...

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