Page 1 — R E L I O N ® 670 SERIES Line differential protection RED670 Version 2.1 IEC Application manual...
Page 4 Copyright This document and parts thereof must not be reproduced or copied without written permission from ABB, and the contents thereof must not be imparted to a third party, nor used for any unauthorized purpose. The software and hardware described in this document is furnished under a license and may be used or disclosed only in accordance with the terms of such license.
Page 5 This document has been carefully checked by ABB but deviations cannot be completely ruled out. In case any errors are detected, the reader is kindly requested to notify the manufacturer.
Page 6 (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...
Page 7: Table Of Contents
Table of contents Table of contents Section 1 Introduction.......................23 This manual............................23 Intended audience........................... 23 Product documentation......................... 24 1.3.1 Product documentation set...................... 24 1.3.2 Document revision history......................25 1.3.3 Related documents........................25 Document symbols and conventions...................26 1.4.1 Symbols............................26 1.4.2 Document conventions.......................27 IEC61850 edition 1 / edition 2 mapping..................
Page 8 Table of contents 4.2.2.7 Example how to connect single-phase CT to the IED............72 4.2.3 Relationships between setting parameter Base Current, CT rated primary current and minimum pickup of a protection IED..............73 4.2.4 Setting of voltage channels.......................74 4.2.4.1 Example............................74 4.2.4.2 Examples how to connect, configure and set VT inputs for most commonly used VT connections.......................
Page 9 Table of contents 6.2.2.6 CT earthing direction......................113 6.2.3 Setting guidelines........................113 6.2.3.1 Setting and configuration.....................113 6.2.3.2 Settings............................ 114 Line differential protection......................115 6.3.1 Identification..........................115 6.3.2 Application..........................115 6.3.2.1 Power transformers in the protected zone............... 116 6.3.2.2 Small power transformers in a tap..................117 6.3.2.3 Charging current compensation..................117 6.3.2.4...
Page 10 Table of contents 7.1.3.4 Setting of reverse zone......................181 7.1.3.5 Series compensated and adjacent lines................181 7.1.3.6 Setting of zones for parallel line application..............185 7.1.3.7 Setting of reach in resistive direction................187 7.1.3.8 Load impedance limitation, without load encroachment function......187 7.1.3.9 Load impedance limitation, with load encroachment function activated....
Page 11 Table of contents 7.4.2.4 Load encroachment....................... 223 7.4.2.5 Short line application......................224 7.4.2.6 Long transmission line application..................225 7.4.2.7 Parallel line application with mutual coupling..............225 7.4.2.8 Tapped line application......................229 7.4.3 Setting guidelines........................231 7.4.3.1 General............................231 7.4.3.2 Setting of zone 1........................232 7.4.3.3 Setting of zone 2........................232 7.4.3.4...
Page 12 Table of contents 7.7.2 Application..........................262 7.7.3 Setting guidelines........................263 Faulty phase identification with load encroachment FMPSPDIS.........263 7.8.1 Identification..........................263 7.8.2 Application..........................263 7.8.3 Setting guidelines........................264 7.8.3.1 Load encroachment.......................265 Distance protection zone, quadrilateral characteristic, separate settings ZMRPDIS, ZMRAPDIS and ZDRDIR......................... 266 7.9.1 Identification..........................266 7.9.2 Application..........................266...
Page 13 Table of contents 7.11.3.2 Resistive reach with load encroachment characteristic..........301 7.11.3.3 Minimum operate currents....................301 7.12 High speed distance protection ZMFPDIS................302 7.12.1 Identification..........................302 7.12.2 Application..........................302 7.12.2.1 System earthing........................302 7.12.2.2 Fault infeed from remote end..................... 305 7.12.2.3 Load encroachment......................306 7.12.2.4 Short line application......................306 7.12.2.5...
Page 14 Table of contents 7.13.4.7 Setting of reach in resistive direction................359 7.13.4.8 Load impedance limitation, without load encroachment function......360 7.13.4.9 Zone reach setting higher than minimum load impedance.......... 361 7.13.4.10 Parameter setting guidelines....................362 7.14 Power swing detection ZMRPSB ....................364 7.14.1 Identification..........................364 7.14.2...
Page 15 Table of contents 8.2.3.1 Settings for each step......................407 8.2.3.2 2nd harmonic restrain......................410 Instantaneous residual overcurrent protection EFPIOC ............414 8.3.1 Identification..........................415 8.3.2 Application..........................415 8.3.3 Setting guidelines........................415 Four step residual overcurrent protection, (Zero sequence or negative sequence directionality) EF4PTOC ......................
Page 16 Table of contents 8.11.2 Application..........................450 8.11.3 Setting guidelines........................452 8.12 Directional overpower protection GOPPDOP ................. 455 8.12.1 Identification..........................455 8.12.2 Application..........................455 8.12.3 Setting guidelines........................457 8.13 Broken conductor check BRCPTOC ..................460 8.13.1 Identification..........................460 8.13.2 Application..........................460 8.13.3 Setting guidelines........................460 8.14 Voltage-restrained time overcurrent protection VRPVOC............
Page 17 Table of contents 9.3.3.1 Equipment protection, such as for motors, generators, reactors and transformers...........................474 9.3.3.2 Equipment protection, capacitors..................474 9.3.3.3 Power supply quality......................474 9.3.3.4 High impedance earthed systems..................474 9.3.3.5 Direct earthed system......................475 9.3.3.6 Settings for Two step residual overvoltage protection..........476 Overexcitation protection OEXPVPH ..................478 9.4.1 Identification..........................478...
Page 18 Table of contents 11.1.2.1 Current and voltage selection for CVGAPC function............494 11.1.2.2 Base quantities for CVGAPC function................496 11.1.2.3 Application possibilities.......................496 11.1.2.4 Inadvertent generator energization...................497 11.1.3 Setting guidelines........................498 11.1.3.1 Directional negative sequence overcurrent protection..........498 11.1.3.2 Negative sequence overcurrent protection..............499 11.1.3.3 Generator stator overload protection in accordance with IEC or ANSI standards..
Page 19 Table of contents 14.1.2.3 Energizing check........................522 14.1.2.4 Voltage selection........................522 14.1.2.5 External fuse failure....................... 523 14.1.3 Application examples....................... 524 14.1.3.1 Single circuit breaker with single busbar................524 14.1.3.2 Single circuit breaker with double busbar, external voltage selection....... 525 14.1.3.3 Single circuit breaker with double busbar, internal voltage selection......525 14.1.3.4 Double circuit breaker......................526 14.1.3.5...
Page 20 Table of contents 14.3.3.1 Bay control (QCBAY)......................558 14.3.3.2 Switch controller (SCSWI)....................559 14.3.3.3 Switch (SXCBR/SXSWI)......................560 14.3.3.4 Bay Reserve (QCRSV)......................560 14.3.3.5 Reservation input (RESIN)....................560 14.4 Interlocking ............................560 14.4.1 Configuration guidelines......................561 14.4.2 Interlocking for line bay ABC_LINE ..................561 14.4.2.1 Application..........................562 14.4.2.2 Signals from bypass busbar....................
Page 21 Table of contents 14.6 Selector mini switch VSGAPC...................... 592 14.6.1 Identification..........................592 14.6.2 Application..........................592 14.6.3 Setting guidelines........................592 14.7 Generic communication function for Double Point indication DPGAPC......593 14.7.1 Identification..........................593 14.7.2 Application..........................593 14.7.3 Setting guidelines........................594 14.8 Single point generic control 8 signals SPC8GAPC..............594 14.8.1 Identification..........................594 14.8.2...
Page 22 Table of contents 15.2.3.4 Intertrip scheme........................610 15.3 Current reversal and Weak-end infeed logic for distance protection 3-phase ZCRWPSCH ............................. 610 15.3.1 Identification..........................610 15.3.2 Application..........................610 15.3.2.1 Current reversal logic......................610 15.3.2.2 Weak-end infeed logic......................611 15.3.3 Setting guidelines........................612 15.3.3.1 Current reversal logic......................612 15.3.3.2 Weak-end infeed logic......................
Page 23 Table of contents 15.8.6 Carrier receive logic LCCRPTRC....................627 15.8.6.1 Identification...........................627 15.8.6.2 Application..........................627 15.8.6.3 Setting guidelines........................627 15.8.7 Negative sequence overvoltage protection LCNSPTOV............627 15.8.7.1 Identification.......................... 628 15.8.7.2 Application..........................628 15.8.7.3 Setting guidelines........................628 15.8.8 Zero sequence overvoltage protection LCZSPTOV............628 15.8.8.1 Identification.......................... 628 15.8.8.2 Application..........................
Page 24 Table of contents 16.3.3 Setting guidelines........................638 16.4 Logic for group alarm WRNCALH....................638 16.4.1 Logic for group warning WRNCALH..................638 16.4.1.1 Identification.......................... 638 16.4.1.2 Application..........................638 16.4.1.3 Setting guidelines........................638 16.5 Logic for group indication INDCALH..................638 16.5.1 Logic for group indication INDCALH..................638 16.5.1.1 Identification..........................
Page 25 Table of contents 17.1.1 Identification..........................651 17.1.2 Application..........................651 17.1.3 Zero clamping..........................652 17.1.4 Setting guidelines........................653 17.1.4.1 Setting examples........................655 17.2 Gas medium supervision SSIMG....................661 17.2.1 Identification..........................661 17.2.2 Application..........................661 17.3 Liquid medium supervision SSIML..................... 661 17.3.1 Identification..........................661 17.3.2 Application..........................662 17.4...
Page 26 Table of contents Section 18 Metering......................677 18.1 Pulse-counter logic PCFCNT......................677 18.1.1 Identification..........................677 18.1.2 Application..........................677 18.1.3 Setting guidelines........................677 18.2 Function for energy calculation and demand handling ETPMMTR........678 18.2.1 Identification..........................678 18.2.2 Application..........................678 18.2.3 Setting guidelines........................679 Section 19 Station communication................. 681 19.1 Communication protocols......................
Page 27 Table of contents Section 20 Remote communication.................707 20.1 Binary signal transfer........................707 20.1.1 Identification..........................707 20.1.2 Application..........................707 20.1.2.1 Communication hardware solutions..................707 20.1.3 Setting guidelines........................708 Section 21 Security......................713 21.1 Authority status ATHSTAT......................713 21.1.1 Application..........................713 21.2 Self supervision with internal event list INTERRSIG..............713 21.2.1 Application..........................
Page 28 Table of contents 22.9.1 Application..........................721 22.9.2 Setting guidelines........................722 22.10 Signal matrix for mA inputs SMMI....................722 22.10.1 Application..........................722 22.10.2 Setting guidelines........................722 22.11 Signal matrix for analog inputs SMAI..................722 22.11.1 Application..........................722 22.11.2 Frequency values........................722 22.11.3 Setting guidelines........................723 22.12 Test mode functionality TEST.....................
Page 29: Introduction
1MRK 505 343-UEN B Section 1 Introduction Section 1 Introduction This manual GUID-AB423A30-13C2-46AF-B7FE-A73BB425EB5F v19 The application manual contains application descriptions and setting guidelines sorted per function. The manual can be used to find out when and for what purpose a typical protection function can be used.
Page 30: Product Documentation
Section 1 1MRK 505 343-UEN B Introduction Product documentation 1.3.1 Product documentation set GUID-3AA69EA6-F1D8-47C6-A8E6-562F29C67172 v15 Engineering manual Installation manual Commissioning manual Operation manual Application manual Technical manual Communication protocol manual Cyber security deployment guideline IEC07000220-4-en.vsd IEC07000220 V4 EN-US Figure 1: The intended use of manuals throughout the product lifecycle The engineering manual contains instructions on how to engineer the IEDs using the various tools available within the PCM600 software.
Page 31: Document Revision History
1MRK 505 343-UEN B Section 1 Introduction The application manual contains application descriptions and setting guidelines sorted per function. The manual can be used to find out when and for what purpose a typical protection function can be used. The manual can also provide assistance for calculating settings. The technical manual contains operation principle descriptions, and lists function blocks, logic diagrams, input and output signals, setting parameters and technical data, sorted per function.
Page 32: Document Symbols And Conventions
Section 1 1MRK 505 343-UEN B Introduction 670 series manuals Document numbers Cyber security deployment guideline 1MRK 511 356-UEN Connection and Installation components 1MRK 513 003-BEN Test system, COMBITEST 1MRK 512 001-BEN 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 electrical shock.
Page 33: Document Conventions
1MRK 505 343-UEN B Section 1 Introduction 1.4.2 Document conventions GUID-96DFAB1A-98FE-4B26-8E90-F7CEB14B1AB6 v8 • 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 icons.
Page 34 Section 1 1MRK 505 343-UEN B Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes BUSPTRC_B8 BUSPTRC BUSPTRC BUSPTRC_B9 BUSPTRC BUSPTRC BUSPTRC_B10 BUSPTRC BUSPTRC BUSPTRC_B11 BUSPTRC BUSPTRC BUSPTRC_B12 BUSPTRC BUSPTRC BUSPTRC_B13 BUSPTRC BUSPTRC BUSPTRC_B14 BUSPTRC BUSPTRC BUSPTRC_B15 BUSPTRC BUSPTRC BUSPTRC_B16...
Page 35 1MRK 505 343-UEN B Section 1 Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes CBPGAPC CBPLLN0 CBPMMXU CBPMMXU CBPPTRC CBPPTRC HOLPTOV HOLPTOV HPH1PTOV HPH1PTOV PH3PTOC PH3PTUC PH3PTUC PH3PTOC RP3PDOP RP3PDOP CCPDSC CCRPLD CCPDSC CCRBRF CCRBRF CCRBRF CCRWRBRF CCRWRBRF CCRWRBRF...
Page 36 Section 1 1MRK 505 343-UEN B Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes GENPDIF GENPDIF GENGAPC GENPDIF GENPHAR GENPTRC GOOSEBINRCV BINGREC GOOSEDPRCV DPGREC GOOSEINTLKRCV INTGREC GOOSEINTRCV INTSGREC GOOSEMVRCV MVGREC GOOSESPRCV BINSGREC GOOSEVCTRRCV VCTRGREC GOPPDOP GOPPDOP GOPPDOP PH1PTRC GRPTTR...
Page 37 1MRK 505 343-UEN B Section 1 Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes LPHD LPHD LPTTR LPTTR LPTTR LT3CPDIF LT3CPDIF LT3CGAPC LT3CPDIF LT3CPHAR LT3CPTRC LT6CPDIF LT6CPDIF LT6CGAPC LT6CPDIF LT6CPHAR LT6CPTRC MVGAPC MVGGIO MVGAPC NS2PTOC NS2LLN0 NS2PTOC NS2PTOC NS2PTRC...
Page 38 Section 1 1MRK 505 343-UEN B Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes SAPTOF SAPTOF SAPTOF SAPTUF SAPTUF SAPTUF SCCVPTOC SCCVPTOC SCCVPTOC SCILO SCILO SCILO SCSWI SCSWI SCSWI SDEPSDE SDEPSDE SDEPSDE SDEPTOC SDEPTOV SDEPTRC SESRSYN RSY1LLN0 AUT1RSYN AUT1RSYN...
Page 39 1MRK 505 343-UEN B Section 1 Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes U2RWPTUV GEN2LLN0 PH1PTRC PH1PTRC U2RWPTUV U2RWPTUV UV2PTUV GEN2LLN0 PH1PTRC PH1PTRC UV2PTUV UV2PTUV VDCPTOV VDCPTOV VDCPTOV VDSPVC VDRFUF VDSPVC VMMXU VMMXU VMMXU VMSQI VMSQI VMSQI VNMMXU...
Page 41: Application
1MRK 505 343-UEN B Section 2 Application Section 2 Application General IED application M13635-3 v6 The IED is used for the protection, control and monitoring of overhead lines and cables in all types of networks. The IED can be used from distribution up to the highest voltage levels. It is suitable for the protection of heavily loaded lines and multi-terminal lines where the requirement for tripping is one-, two-, and/or three-phase.
Page 42: Main Protection Functions
Section 2 1MRK 505 343-UEN B Application If IEC 61850-9-2LE communication is interrupt, data from the merging units (MU) after the time for interruption will be incorrect. Both data stored in the IED and displayed on the local HMI will be corrupt. For this reason it is important to connect signal from respective MU units (SMPLLOST) to the disturbance recorder.
Page 43 1MRK 505 343-UEN B Section 2 Application IEC 61850 ANSI Function description Line Differential RED670 (Customized) LT6CPDIF 87LT Line differential protection, 1-A06 1-A06 1-A06 1-A06 6 CT sets, with inzone transformers, 3–5 line ends LDLPSCH Line differential protection logic LDRGFC 11REL Additional security logic for differential protection...
Page 44: Back-Up Protection Functions
Section 2 1MRK 505 343-UEN B Application IEC 61850 ANSI Function description Line Differential RED670 (Customized) ZMRPSB Power swing detection 1-B11 1-B11 1-B11 1-B11 1-B16 1-B16 1-B16 1-B16 PSLPSCH Power swing logic 1-B03 1-B03 1-B03 1-B03 PSPPPAM Pole slip/out-of-step 1-B22 1-B22 1-B22 1-B22...
Page 45 1MRK 505 343-UEN B Section 2 Application IEC 61850 ANSI Function description Line Differential RED670 (Customized) STBPTOC 50STB Stub protection 1-B11 1-B11 1-B11 1-B11 CCPDSC 52PD Pole discordance protection GUPPDUP Directional 1-C17 1-C17 1-C17 1-C17 underpower protection GOPPDOP Directional 1-C17 1-C17 1-C17 1-C17...
Page 46: Control And Monitoring Functions
Section 2 1MRK 505 343-UEN B Application 2) 67N requires voltage Control and monitoring functions GUID-E3777F16-0B76-4157-A3BF-0B6B978863DE v12 IEC 61850 ANSI Function description Line Differential RED670 Control SESRSYN Synchrocheck, energizing check and synchronizing SMBRREC Autorecloser 1-H04 2-H05 1-H04 2-H05 APC10 Apparatus control for 1-H27 1-H27 single bay, max 10...
Page 47 1MRK 505 343-UEN B Section 2 Application IEC 61850 ANSI Function description Line Differential RED670 I103IEDCMD IED commands for IEC 60870-5-103 I103USRCMD Function commands user defined for IEC 60870-5-103 Secondary system supervision CCSSPVC Current circuit supervision FUFSPVC Fuse failure supervision VDSPVC Fuse failure supervision 1-G03...
Page 48 Section 2 1MRK 505 343-UEN B Application IEC 61850 ANSI Function description Line Differential RED670 IB16 Integer to Boolean 16 conversion ITBGAPC Integer to Boolean 16 conversion with Logic Node representation TEIGAPC Elapsed time integrator with limit transgression and overflow supervision INTCOMP Comparator for integer inputs...
Page 49 1MRK 505 343-UEN B Section 2 Application IEC 61850 ANSI Function description Line Differential RED670 I103AR Function status auto- recloser for IEC 60870-5-103 I103EF Function status earth- fault for IEC 60870-5-103 I103FLTPROT Function status fault protection for IEC 60870-5-103 I103IED IED status for IEC 60870-5-103 I103SUPERV...
Page 50: Communication
Section 2 1MRK 505 343-UEN B Application Configurable logic blocks Q/T Total number of instances INVALIDQT INVERTERQT ORQT PULSETIMERQT RSMEMORYQT SRMEMORYQT TIMERSETQT XORQT Table 5: Total number of instances for extended logic package Extended configurable logic block Total number of instances GATE PULSETIMER SLGAPC...
Page 51 1MRK 505 343-UEN B Section 2 Application IEC 61850 ANSI Function description Line Differential RED670 (Customized) DNPGEN DNP3.0 communication general protocol DNPGENTCP DNP3.0 communication general TCP protocol CHSERRS485 DNP3.0 for EIA-485 communication protocol CH1TCP, CH2TCP, DNP3.0 for TCP/IP CH3TCP, CH4TCP communication protocol CHSEROPT...
Page 52 Section 2 1MRK 505 343-UEN B Application IEC 61850 ANSI Function description Line Differential RED670 (Customized) RS485103 IEC 60870-5-103 serial communication for RS485 AGSAL Generic security application component LD0LLN0 IEC 61850 LD0 LLN0 SYSLLN0 IEC 61850 SYS LLN0 LPHD Physical device information PCMACCS IED Configuration...
Page 53: Basic Ied Functions
1MRK 505 343-UEN B Section 2 Application IEC 61850 ANSI Function description Line Differential RED670 (Customized) ZCRWPSCH Current reversal and 1-B11 1-B11 1-B11 1-B11 weak-end infeed logic 1-B16 1-B16 1-B16 1-B16 for distance protection ZC1WPSCH Current reversal and 1-B05 1-B05 weak-end infeed logic for phase segregated communication...
Page 54 Section 2 1MRK 505 343-UEN B Application IEC 61850 or function Description name 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 password SPACOMMMAP SPA communication mapping SPATD...
Page 55: Configuration
On request, ABB is available to support the re-configuration work, either directly or to do the design checking.
Page 56: Description Of Configuration Red670
Section 3 1MRK 505 343-UEN B Configuration Description of configuration RED670 IP14804-1 v2 3.2.1 Introduction IP14805-1 v1 3.2.1.1 Description of configuration A31 M15201-3 v5 The configuration of the IED is shown in Figure 2. This configuration is used in applications with single breakers with single or double busbars. The protection scheme includes a 3–phase tripping and 3–phase autoreclosing scheme with a synchronism check.
Page 57: Description Of Configuration A32
1MRK 505 343-UEN B Section 3 Configuration RED670 A31 – Single Breaker with Three phase tripping 12AI (6I+6U) WA2_VT VN MMXU WA1_VT VN MMXU 1→0 5(0→1) SC/VC SMP PTRC SMB RREC SES RSYN LINE_CT θ> 50BF 3I>BF 3I>> Iub> CC RBRF PH PIOC BRC PTOC LC PTTR...
Page 58 Section 3 1MRK 505 343-UEN B Configuration The differential protection for up to 3 CT sets, 2–3 line ends is the main protection function. It is available with communication modules for single or redundant channels and can be used in two- or multi-terminal arrangements.
Page 59: Description Of Configuration B31
1MRK 505 343-UEN B Section 3 Configuration RED670 A32 – Single Breaker with Single phase tripping 12AI (6I+6U) WA2_VT VN MMXU WA1_VT VN MMXU 1→0 5(0→1) SC/VC SMP PTRC SMB RREC SES RSYN LINE_CT θ> 50BF 3I>BF 3I>> 52PD Iub> CC PDSC CC RBRF PH PIOC...
Page 60 Section 3 1MRK 505 343-UEN B Configuration two auto-reclosers and two synchronism check devices with a priority circuit to allow one to close first. The differential protection for up to 6 CT sets, 3–5 line ends is the main protection function. It is available with communication modules for single or redundant channels and can be used in two or multi-terminal arrangements.
Page 61: Description Of Configuration B32
1MRK 505 343-UEN B Section 3 Configuration RED670 B31 – Multi Breaker with Three phase tripping 12AI (6I+6U) WA1_VT WA1_CT 50BF 3I>BF CC RBRF VN MMXU 50BF 3I>BF WA1_QA1 CC RBRF REM CT1 REM CT2 WA1_QB6 3Id/I> LINE1_QB9 Σ LDL PSCH L6C PDIF LINE1_VT Usqi...
Page 62 Section 3 1MRK 505 343-UEN B Configuration there are two autoreclosers and two synchronism check devices with a priority circuit to allow one to close first. The differential protection for up to 6 CT sets, 3–5 line ends is the main protection function. It is available with communication modules for single or redundant channels and can be used in two- or multi-terminal arrangements.
Page 63 1MRK 505 343-UEN B Section 3 Configuration RED670 B32 – Multi Breaker with Single phase tripping 12AI (6I+6U) WA1_VT WA1_CT 50BF 3I>BF 52PD CC RBRF CC PDSC VN MMXU 50BF 3I>BF 52PD WA1_QA1 CC RBRF CC PDSC REM CT1 REM CT2 WA1_QB6 3Id/I>...
Page 65: Analog Inputs
1MRK 505 343-UEN B Section 4 Analog inputs Section 4 Analog inputs Introduction SEMOD55003-5 v10 Analog input channels must be configured and set properly in order to get correct measurement results and correct protection operations. For power measuring and all directional and differential functions the directions of the input currents must be defined in order to reflect the way the current transformers are installed/connected in the field ( primary and secondary connections ).
Page 66: Example
Section 4 1MRK 505 343-UEN B Analog inputs 4.2.1.1 Example SEMOD55055-11 v4 Usually the L1 phase-to-earth voltage connected to the first VT channel number of the transformer input module (TRM) is selected as the phase reference. The first VT channel number depends on the type of transformer input module.
Page 67: Example 2
1MRK 505 343-UEN B Section 4 Analog inputs Line Transformer Line Reverse Forward Definition of direction for directional functions Transformer protection Line protection Setting of current input: Setting of current input: Setting of current input: Set parameter Set parameter Set parameter CTStarPoint with CTStarPoint with CTStarPoint with...
Page 68: Example 3
Section 4 1MRK 505 343-UEN B Analog inputs Transformer Line Reverse Forward Definition of direction for directional functions Transformer protection Line protection Setting of current input: Setting of current input: Setting of current input: Set parameter Set parameter Set parameter CTStarPoint with CTStarPoint with CTStarPoint with...
Page 69 1MRK 505 343-UEN B Section 4 Analog inputs Transformer Line Forward Reverse Definition of direction for directional Transformer and line functions Line protection Setting of current input: Setting of current input: Set parameter Set parameter CTStarPoint with CTStarPoint with Transformer as Transformer as reference object.
Page 70 Section 4 1MRK 505 343-UEN B Analog inputs Transformer Line Reverse Forward Definition of direction for directional Transformer and line functions Line protection Setting of current input for line functions: Set parameter CTStarPoint with Line as reference object. Setting of current input Setting of current input Correct setting is for transformer functions:...
Page 71 1MRK 505 343-UEN B Section 4 Analog inputs Busbar Busbar Protection en06000196.vsd IEC06000196 V2 EN-US Figure 11: Example how to set CTStarPoint parameters in the IED CTStarPoint parameters in two ways. For busbar protection it is possible to set the The first solution will be to use busbar as a reference object.
Page 72: Examples On How To Connect, Configure And Set Ct Inputs For Most Commonly Used Ct Connections
Section 4 1MRK 505 343-UEN B Analog inputs 4.2.2.4 Examples on how to connect, configure and set CT inputs for most commonly used CT connections SEMOD55055-296 v5 Figure defines the marking of current transformer terminals commonly used around the world: In the SMAI function block, you have to set if the SMAI block is measuring AnalogInputType : Current/ current or voltage.
Page 73: Example On How To Connect A Star Connected Three-Phase Ct Set To The Ied
1MRK 505 343-UEN B Section 4 Analog inputs 4.2.2.5 Example on how to connect a star connected three-phase CT set to the SEMOD55055-352 v9 Figure gives an example about the wiring of a star connected three-phase CT set to the IED. It gives also an overview of the actions which are needed to make this measurement available to the built-in protection and control functions within the IED as well.
Page 74 Section 4 1MRK 505 343-UEN B Analog inputs These three connections are the links between the three current inputs and the three input channels of the preprocessing function block 4). Depending on the type of functions, which need this current information, more than one preprocessing block might be connected in parallel to the same three physical CT inputs.
Page 75 1MRK 505 343-UEN B Section 4 Analog inputs In the example in figure 14 case everything is done in a similar way as in the above described example (figure 13). The only difference is the setting of the parameter CTStarPoint of the used current inputs on the TRM (item 2 in the figure): CTprim =600A •...
Page 76: Example How To Connect Delta Connected Three-Phase Ct Set To The Ied
Section 4 1MRK 505 343-UEN B Analog inputs 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 •...
Page 77 1MRK 505 343-UEN B Section 4 Analog inputs IL1-IL2 SMAI2 BLOCK AI3P IL2-IL3 REVROT ^GRP2L1 IL3-IL1 ^GRP2L2 ^GRP2L3 ^GRP2N IEC11000027-3-en.vsdx Protected Object IEC11000027 V3 EN-US Figure 16: Delta DAB connected three-phase CT set Where: shows how to connect three individual phase currents from a delta connected three-phase CT set to three CT inputs of the IED.
Page 78: Example How To Connect Single-Phase Ct To The Ied
Section 4 1MRK 505 343-UEN B Analog inputs Another alternative is to have the delta connected CT set as shown in figure 17: IL1-IL3 SMAI2 BLOCK AI3P REVROT IL2-IL1 ^GRP2L1 ^GRP2L2 IL3-IL2 ^GRP2L3 ^GRP2N IEC11000028-3-en.vsdx Protected Object IEC11000028 V3 EN-US Figure 17: Delta DAC connected three-phase CT set In this case, everything is done in a similar way as in the above described example, except that...
Page 79: Relationships Between Setting Parameter Base Current, Ct Rated Primary Current And Minimum Pickup Of A Protection Ied
1MRK 505 343-UEN B Section 4 Analog inputs Protected Object SMAI2 BLOCK AI3P REVROT ^GRP2L1 ^GRP2L2 ^GRP2L3 ^GRP2N IEC11000029-4-en.vsdx IEC11000029 V4 EN-US Figure 18: Connections for single-phase CT input Where: shows how to connect single-phase CT input in the IED. is TRM where these current inputs are located.
Page 80: Setting Of Voltage Channels
Section 4 1MRK 505 343-UEN B Analog inputs CTs involved in the protection scheme. The rated CT primary current value is set as parameter CTPrim under the IED TRM settings. For all other protection applications (e.g. generator, shunt reactor, shunt capacitor and IBase parameter equal to the rated transformer protection) it is typically desirable to set current of the protected object.
Page 81: Examples On How To Connect A Three Phase-To-Earth Connected Vt To The Ied
1MRK 505 343-UEN B Section 4 Analog inputs (X1) (X1) (X1) (H1) (H1) (H1) (H2) (X2) (H2) (X2) (H2) (X2) en06000591.vsd IEC06000591 V1 EN-US Figure 19: Commonly used markings of VT terminals Where: 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 is the equivalent symbol and terminal marking used by IEC (ANSI) standard for phase-to-earth connected VTs...
Page 82 Section 4 1MRK 505 343-UEN B Analog inputs SMAI2 BLOCK AI3P REVROT ^GRP2L1 ^GRP2L2 ^GRP2L3 ^GRP2N #Not used IEC06000599-4-en.vsdx IEC06000599 V4 EN-US Figure 20: A Three phase-to-earth connected VT Where: shows how to connect three secondary phase-to-earth voltages to three VT inputs on the IED is the TRM where these three voltage inputs are located.
Page 83: Example On How To Connect A Phase-To-Phase Connected Vt To The Ied
1MRK 505 343-UEN B Section 4 Analog inputs are three connections made in Signal Matrix Tool (SMT), which connect these three voltage inputs to first three input channels of the preprocessing function block 5). Depending on the type of functions which need this voltage information, more then one preprocessing block might be connected in parallel to these three VT inputs.
Page 84 Section 4 1MRK 505 343-UEN B Analog inputs 13.8 13.8 SMAI2 BLOCK AI3P REVROT ^GRP2L1 ^GRP2L2 ^GRP2L3 #Not Used ^GRP2N IEC06000600-5-en.vsdx IEC06000600 V5 EN-US Figure 21: A Two phase-to-phase connected VT Where: shows how to connect the secondary side of a phase-to-phase VT to the VT inputs on the IED is the TRM where these three voltage inputs are located.
Page 85: Example On How To Connect An Open Delta Vt To The Ied For High Impedance Earthed Or Unearthed Netwoeks
1MRK 505 343-UEN B Section 4 Analog inputs 4.2.4.5 Example on how to connect an open delta VT to the IED for high impedance earthed or unearthed netwoeks SEMOD55055-163 v8 Figure gives an example about the wiring of an open delta VT to the IED for high impedance earthed or unearthed power systems.
Page 86: Example How To Connect The Open Delta Vt To The Ied For Low Impedance Earthed Or Solidly Earthed Power Systems
Section 4 1MRK 505 343-UEN B Analog inputs Where: shows how to connect the secondary side of the open delta VT to one VT input on the IED. +3U0 shall be connected to the IED is the TRM where this voltage input is located. It shall be noted that for this voltage input the following setting values shall be entered: ×...
Page 87 1MRK 505 343-UEN B Section 4 Analog inputs Ph Ph Ph E (Equation 7) EQUATION1926 V1 EN-US The primary rated voltage of such VT is always equal to UPh-E Therefore, three series connected VT secondary windings will give the secondary voltage equal only to one individual VT secondary winding rating.
Page 88: Example On How To Connect A Neutral Point Vt To The Ied
Section 4 1MRK 505 343-UEN B Analog inputs Where: shows how to connect the secondary side of open delta VT to one VT input in the IED. +3Uo shall be connected to the IED. is TRM where this voltage input is located. It shall be noted that for this voltage input the following setting values shall be entered: ×...
Page 89 1MRK 505 343-UEN B Section 4 Analog inputs In case of a solid earth fault in high impedance earthed or unearthed systems the primary value of Uo voltage will be equal to: (Equation 11) EQUATION1931 V2 EN-US Figure 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 as well.
Page 90 Section 4 1MRK 505 343-UEN B Analog inputs Where: shows how to connect the secondary side of neutral point VT to one VT input in the IED. shall be connected to the IED. is the TRM or AIM where this voltage input is located. For this voltage input the following setting values shall be entered: VTprim 3.81...
Page 91: Local Hmi
1MRK 505 343-UEN B Section 5 Local HMI Section 5 Local HMI AMU0600442 v14 IEC13000239-2-en.vsd IEC13000239 V2 EN-US Figure 25: Local human-machine interface The LHMI of the IED contains the following elements: • Keypad • Display (LCD) • LED indicators •...
Page 92: Display
Section 5 1MRK 505 343-UEN B Local HMI Display GUID-55739D4F-1DA5-4112-B5C7-217AAF360EA5 v10 The LHMI includes a graphical monochrome liquid crystal display (LCD) with a resolution of 320 x 240 pixels. The character size can vary. The amount of characters and rows fitting the view depends on the character size and the view that is shown.
Page 93: Leds
1MRK 505 343-UEN B Section 5 Local HMI IEC13000281-1-en.vsd GUID-C98D972D-D1D8-4734-B419-161DBC0DC97B V1 EN-US Figure 27: Function button panel The indication LED panel shows on request the alarm text labels for the indication LEDs. Three indication LED pages are available. IEC13000240-1-en.vsd GUID-5157100F-E8C0-4FAB-B979-FD4A971475E3 V1 EN-US Figure 28: Indication LED panel The function button and indication LED panels are not visible at the same time.
Page 94: Keypad
Section 5 1MRK 505 343-UEN B Local HMI three LED groups. The LEDs are lit according to priority, with red being the highest and green the lowest priority. For example, if on one panel there is an indication that requires the green LED to be lit, and on another panel there is an indication that requires the red LED to be lit, the red LED takes priority and is lit.
Page 95 1MRK 505 343-UEN B Section 5 Local HMI IEC15000157-1-en.vsd IEC15000157 V1 EN-US Figure 29: LHMI keypad with object control, navigation and command push-buttons and RJ-45 communication port 1...5 Function button Close Open Escape Left Down Right Enter Remote/Local Uplink LED Not in use Multipage Menu...
Page 96: Local Hmi Functionality
Section 5 1MRK 505 343-UEN B Local HMI IED status LEDs Local HMI functionality 5.4.1 Protection and alarm indication GUID-09CCB9F1-9B27-4C12-B253-FBE95EA537F5 v15 Protection indicators The protection indicator LEDs are Ready, Start and Trip. The start and trip LEDs are configured via the disturbance recorder. The yellow and red status LEDs are configured in the disturbance recorder function, DRPRDRE, by connecting a start or trip signal from the actual function to a BxRBDR binary input function block using the PCM600 and configure the...
Page 97: Parameter Management
1MRK 505 343-UEN B Section 5 Local HMI Alarm indicators The 15 programmable three-color LEDs are used for alarm indication. An individual alarm/ status signal, connected to any of the LED function blocks, can be assigned to one of the three LED colors when configuring the IED.
Page 98 Section 5 1MRK 505 343-UEN B Local HMI IEC13000280-1-en.vsd GUID-AACFC753-BFB9-47FE-9512-3C4180731A1B V1 EN-US Figure 30: 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 255.255.255.0.
Page 99: Differential Protection
1MRK 505 343-UEN B Section 6 Differential protection Section 6 Differential protection High impedance differential protection, single phase HZPDIF IP14239-1 v4 6.1.1 Identification M14813-1 v4 IEC 61850 IEC 60617 ANSI/IEEE C37.2 Function description identification identification device number High impedance differential HZPDIF protection, single phase SYMBOL-CC V2 EN-US...
Page 100: The Basics Of The High Impedance Principle
Section 6 1MRK 505 343-UEN B Differential protection 3·Id 3·Id 3·Id 3·Id 3·Id IEC05000163-4-en.vsd IEC05000163 V4 EN-US Figure 31: Different applications of a 1Ph High impedance differential protection HZPDIF function 6.1.2.1 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 documented in literature publicly available.
Page 101 1MRK 505 343-UEN B Section 6 Differential protection 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. Metrosil IEC05000164-2-en.vsd IEC05000164 V3 EN-US...
Page 102 Section 6 1MRK 505 343-UEN B Differential protection the connection point from each CT, it is advisable to do all the CT core summations in the switchgear to have shortest possible loops. This will give lower setting values and also a better balanced scheme.
Page 103 1MRK 505 343-UEN B Section 6 Differential protection Table 13: 5 A channels: input with minimum operating down to 100 mA Operating Stabilizing Operating Stabilizing Operating Stabilizing Operating voltage resistor R1 current level resistor R1 current level resistor R1 current level U>Trip ohms ohms...
Page 104 Section 6 1MRK 505 343-UEN B Differential protection Rres I> Protected Object a) Through load situation b) Through fault situation c) Internal faults IEC05000427-2-en.vsd IEC05000427 V2 EN-US Figure 33: The high impedance principle for one phase with two current transformer inputs Application manual...
Page 105: Connection Examples For High Impedance Differential Protection
1MRK 505 343-UEN B Section 6 Differential protection 6.1.3 Connection examples for high impedance differential protection GUID-8C58A73D-7C2E-4BE5-AB87-B4C93FB7D62B v5 WARNING! USE EXTREME CAUTION! Dangerously high voltages might be present on this equipment, especially on the plate with resistors. De-energize the primary object protected with this equipment before connecting or disconnecting wiring or performing any maintenance.
Page 106: Connections For 1Ph High Impedance Differential Protection Hzpdif
Section 6 1MRK 505 343-UEN B Differential protection Necessary connection for setting resistors. Factory-made star point on a three-phase setting resistor set. The star point connector must be removed for installations with 670 series IEDs. This star point is required for RADHA schemes only. Connections of three individual phase currents for high impedance scheme to three CT inputs in the IED.
Page 107: Setting Guidelines
1MRK 505 343-UEN B Section 6 Differential protection 6.1.4 Setting guidelines IP14945-1 v1 M13076-3 v2 The setting calculations are individual for each application. Refer to the different application descriptions below. 6.1.4.1 Configuration M13076-5 v4 The configuration is done in the Application Configuration tool. 6.1.4.2 Settings of protection function M13076-10 v6...
Page 108 Section 6 1MRK 505 343-UEN B Differential protection 3·Id IEC05000165-2-en.vsd IEC05000165 V2 EN-US Figure 36: The protection scheme utilizing the high impedance function for the T-feeder Normally this scheme is 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.
Page 109: Tertiary Reactor Protection
1MRK 505 343-UEN B Section 6 Differential protection Calculation: (Equation 16) EQUATION1207 V2 EN-US Select a setting of U>Trip =200 V. The current transformer saturation voltage must be at least twice the set operating voltage U>Trip . > × 20 6.2 20 524 (Equation 17) EQUATION1208 V1 EN-US U>Trip...
Page 110 Section 6 1MRK 505 343-UEN B Differential protection 3·Id IEC05000176-3-en.vsd IEC05000176 V3 EN-US Figure 37: Application of the1Ph High impedance differential protection HZPDIF function on a reactor Setting example It is strongly recommended to use the highest tap of the CT whenever high impedance protection is used.
Page 111: Restricted Earth Fault Protection
1MRK 505 343-UEN B Section 6 Differential protection Basic data: Current transformer ratio: 100/5 A (Note: Must be the same at all locations) CT Class: 10 VA 5P20 Secondary resistance: 0.26 ohms Cable loop resistance: <50 m 2.5mm (one way) gives 1 ˣ 0.4 ohm at 75° C Note! Only one way as the tertiary power system earthing is limiting the earth-fault current.
Page 112 Section 6 1MRK 505 343-UEN B Differential protection The connection of a restricted earth fault function is shown in Figure 38. It is connected across each directly or low impedance earthed transformer winding. IEC05000177-2-en.vsd IEC05000177 V2 EN-US Figure 38: Application of HZPDIF function as a restricted earth fault protection for a star connected winding of an YNd transformer Setting example It is strongly recommended to use the highest tap of the CT whenever high...
Page 113: Alarm Level Operation
1MRK 505 343-UEN B Section 6 Differential protection Calculation: > × × 0.66 0.8 18.25 (Equation 22) EQUATION1219 V1 EN-US Select a setting of U>Trip =40 V. The current transformer saturation voltage at 5% error can roughly be calculated from the rated values.
Page 114: Low Impedance Restricted Earth Fault Protection Refpdif
Section 6 1MRK 505 343-UEN B Differential protection IEC05000749 V1 EN-US Figure 39: Current voltage characteristics for the non-linear resistors, in the range 10-200 V, the average range of current is: 0.01–10 mA Low impedance restricted earth fault protection REFPDIF IP14640-1 v6 6.2.1 Identification...
Page 115: Transformer Winding, Solidly Earthed
1MRK 505 343-UEN B Section 6 Differential protection A restricted earth-fault protection is the fastest and the most sensitive protection, a power transformer winding can have and will detect faults such as: • earth faults in the transformer winding when the network is earthed through an impedance •...
Page 116: Transformer Winding, Earthed Through Zig-Zag Earthing Transformer
Section 6 1MRK 505 343-UEN B Differential protection 6.2.2.2 Transformer winding, earthed through zig-zag earthing transformer M13048-8 v11 A common application is for low reactance earthed transformer where the earthing is through separate zig-zag earthing transformers. The fault current is then limited to typical 800 to 2000 A for each transformer.
Page 117: Reactor Winding, Solidly Earthed
1MRK 505 343-UEN B Section 6 Differential protection REFPDIF HV (W1) I3PW1CT1 I3PW2CT1 IdN/I LV (W2) Auto transformer IEC09000111-4-EN.vsd IEC09000111-4-EN V2 EN-US Figure 42: Connection of restricted earth fault, low impedance function REFPDIF for an autotransformer, solidly earthed 6.2.2.4 Reactor winding, solidly earthed M13048-18 v10 Reactors can be protected with restricted earth-fault protection, low impedance function REFPDIF.
Page 118: Multi-Breaker Applications
Section 6 1MRK 505 343-UEN B Differential protection REFPDIF I3PW1CT1 IdN/I Reactor IEC09000112-4.vsd IEC09000112-4 V2 EN-US Figure 43: Connection of restricted earth-fault, low impedance function REFPDIF for a solidly earthed reactor 6.2.2.5 Multi-breaker applications M13048-23 v9 Multi-breaker arrangements including ring, one and a half breaker, double breaker and mesh corner arrangements have two sets of current transformers on the phase side.
Page 119: Ct Earthing Direction
1MRK 505 343-UEN B Section 6 Differential protection REFPDIF I3PW1CT1 Protected winding IdN/I I3PW1CT2 IEC09000113-3.vsd IEC09000113-3 V2 EN-US Figure 44: Connection of Restricted earth fault, low impedance function REFPDIF in multi-breaker arrangements 6.2.2.6 CT earthing direction M13048-29 v12 To make the restricted earth-fault protection REFPDIF operate correctly, the main CTs are always supposed to be star -connected.
Page 120: Settings
Section 6 1MRK 505 343-UEN B Differential protection BLOCK: The input will block the operation of the function. Can be used, for example, to block for a limited time the operation during special service conditions. Recommendation for output signals M13052-21 v8 Refer to pre-configured configurations for details.
Page 121: Line Differential Protection
1MRK 505 343-UEN B Section 6 Differential protection Line differential protection IP13934-1 v1 6.3.1 Identification M14844-1 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Line differential protection, 3 CT 3Id/I> L3CPDIF sets, 2-3 line ends SYMBOL-HH V1 EN-US Line differential protection, 6 CT 3Id/I>...
Page 122: Power Transformers In The Protected Zone
Section 6 1MRK 505 343-UEN B Differential protection With 1½ breaker configurations, normally the line protection is fed from two CTs. Avoiding to add the currents from the two CTs externally before entering the IED is important as this will enable possible bias current from both CTs to be considered in the current differential algorithm, and in that way assuring that the correct restrain will be possible, as shown in figure 45.
Page 123: Small Power Transformers In A Tap
1MRK 505 343-UEN B Section 6 Differential protection auxiliary transformers are necessary. Instead it is necessary to eliminate the zero-sequence current by proper setting of the parameter ZerSeqCurSubtr . If the power transformer is of the type Dyn, where yn-windings currents are measured, then the zero-sequence component will be subtracted when these currents are transformed to the HV-side.
Page 124 Section 6 1MRK 505 343-UEN B Differential protection diff,false Communication en05000436.vsd IEC05000436 V1 EN-US Figure 48: Charging currents The magnitude of the charging current is dependent of the line capacitance and the system voltage. For earth cables and long overhead lines, the magnitude can be such that it affects the possibility to achieve the wanted sensitivity of the differential protection.
Page 125: Time Synchronization
1MRK 505 343-UEN B Section 6 Differential protection Operate current [ in pu of IBase] Operate unconditionally UnrestrainedLimit Operate IdMinHigh conditionally Section 1 Section 2 Section 3 SlopeSection3 IdMin SlopeSection2 Restrain EndSection1 Restrain current [ in pu of IBase] EndSection2 en05000300.vsd IEC05000300 V1 EN-US Figure 49: Overestimated charging current...
Page 126: Configuration Of Analog Signals
Section 6 1MRK 505 343-UEN B Differential protection Protected zone 64 kbit/s en05000437.vsd IEC05000437 V1 EN-US Figure 50: Two-terminal line In case of 1½ breaker arrangements or ring buses, a line end has two CTs, as shown in Figure 51. Protected zone 64 kbit/s 64 kbit/s...
Page 127: Configuration Of Ldcm Output Signals
1MRK 505 343-UEN B Section 6 Differential protection Configuration of this data flow is made in the SMT tool as shown in Figure 52. Currents from local CT Currents from remote end 1 LDCM 1 Currents to remote end 1 Currents from remote end 2 LDCM 2...
Page 128: Open Ct Detection
Section 6 1MRK 505 343-UEN B Differential protection SMBI IEC06000638-2-en.vsd IEC06000638 V2 EN-US Figure 53: Example of LDCM signals as seen in the Signal matrix tool 6.3.2.8 Open CT detection GUID-DB3841A9-5B55-490E-8A2D-EBF0CB263378 v7 Line differential protection has a built-in, advanced open CT detection feature. This feature can block the unwanted operation created by the Line differential protection function in case of an open CT secondary circuit under a normal load condition.
Page 129: Setting Guidelines
1MRK 505 343-UEN B Section 6 Differential protection • OPENCT: Open CT detected • OPENCTAL: Alarm issued after the setting delay Outputs (positive integer) for information on the local HMI: • OPENCTIN: Open CT in CT group inputs (1 for input 1 and 2 for input 2) •...
Page 130: Percentage Restrained Differential Operation
Section 6 1MRK 505 343-UEN B Differential protection 6.3.3.2 Percentage restrained differential operation M12541-104 v4 Line differential protection is phase-segregated where the operate current is the vector sum of all measured currents taken separately for each phase. The restrain current, on the other hand, is considered the greatest phase current in any line end and it is common for all three phases.
Page 131 1MRK 505 343-UEN B Section 6 Differential protection Operate current [ in pu of IBase] Operate unconditionally UnrestrainedLimit Operate IdMinHigh conditionally Section 1 Section 2 Section 3 SlopeSection3 IdMin SlopeSection2 Restrain EndSection1 Restrain current [ in pu of IBase] EndSection2 en05000300.vsd IEC05000300 V1 EN-US Figure 55: Restrained differential function characteristic (reset ratio 0.95)
Page 132 Section 6 1MRK 505 343-UEN B Differential protection × × × (Equation 26) EQUATION1417 V2 EN-US where: is system voltage is capacitive positive sequence reactance of the line is system frequency is positive sequence line capacitance IdMin must be: IdMin ≥ 1.2 × If the charging current compensation is enabled, the setting of ICharge, concidering some margin in the setting.
Page 133: The 2Nd And 5Th Harmonic Analysis
1MRK 505 343-UEN B Section 6 Differential protection protection zone, due to long duration of transformer inrush current the parameter should be set to 60 s. Otherwise a setting of 1 s is sufficient. IdUnre M12541-180 v5 IdUnre is set as a multiple of IBase . Values of differential currents above the unrestrained limit generate a trip disregarding all other criteria, that is, irrespective of the internal or external fault discriminator and any presence of harmonics.
Page 134: Internal/External Fault Discriminator
Section 6 1MRK 505 343-UEN B Differential protection IBase . • If the bias current is lower than 1.25 times • Under external fault conditions. NegSeqDiffEn = Off (the default is On ) • When the harmonic content is above the set level, the restrained differential operation is blocked.
Page 135: Power Transformer In The Protected Zone
1MRK 505 343-UEN B Section 6 Differential protection 90 deg 120 deg If one or the Internal/external other of fault boundary currents is too low, then no measurement NegSeqROA is done, and (Relay 120 degrees Operate is mapped Angle) 180 deg 0 deg IMinNegSeq External...
Page 136 Section 6 1MRK 505 343-UEN B Differential protection Protected zone en04000209.vsd IEC04000209 V1 EN-US Figure 58: One two–winding transformer in the protected zone An alternative with two two-winding transformers in the protected zone is shown in figure 59. Protected zone en04000210.vsd IEC04000210 V1 EN-US Figure 59: Two two–winding transformers in the protected zone...
Page 137 1MRK 505 343-UEN B Section 6 Differential protection Protected zone IEC15000451-1-en.vsd IEC15000451 V1 EN-US Figure 61: One three–winding transformer in the protected zone TraAOnInpCh M12541-239 v6 This parameter is used to indicate that a power transformer is included in the protection zone at current terminal X.
Page 138 Section 6 1MRK 505 343-UEN B Differential protection RatVoltW2TraB M12541-298 v3 The rated voltage (kV) of the secondary side (non-line side = low voltage side) of the power transformer B. ClockNumTransB M12541-301 v2 This is the phase shift from primary to secondary side for power transformer B. The phase shift is given in intervals of 30 degrees, where 1 is -30 degrees, 2 is -60 degrees and so on.
Page 139: Settings Examples
1MRK 505 343-UEN B Section 6 Differential protection æ ö ç ÷ ç ÷ = × ç ÷ æ ö ç ÷ Measured ç ÷ ç ÷ è ø IMaxAddDelay è ø (Equation 27) EQUATION1418 V1 EN-US where: is operate time is time multiplier of the inverse time curve a, b, c, p are settings that will model the inverse time characteristic 6.3.3.6...
Page 140 Section 6 1MRK 505 343-UEN B Differential protection Zsource 1 Zsource 2/3 en05000444.vsd IEC05000444 V1 EN-US Figure 63: System impedances where: Line data is » 15.0 EQUATION1419 V1 EN-US 10 220 Transformer data is Þ × % 10% 24.2 100 200 EQUATION1420 V1 EN-US Source impedance is Source...
Page 141 1MRK 505 343-UEN B Section 6 Differential protection Setting IED 1 IED 2 Remarks TraBWind2Volt 70 kV 70 kV Transformer B, d-side voltage in kV ClockNumTransB LV d-side lags Y-side by 30 degrees ZerSeqCurSubtr Zero-sequence currents are subtracted from differential and bias currents (Remark 3) Table 15: Setting group N...
Page 142 Section 6 1MRK 505 343-UEN B Differential protection Setting IED 1 IED 2 Remarks IBase IBase IminNegSeq 0.04 · 0.04 · Minimum value of negative-sequence current, as multiple of IBase NegSeqROA 60.0 deg 60.0 deg Internal/external fault discriminator operate angle (ROA), in degrees (Default) AddDelay Additional delay Off...
Page 143 1MRK 505 343-UEN B Section 6 Differential protection IdMinHigh is active is set to 60 s because a power transformer is The interval when included in the protected circuit. As both IEDs process the same currents, both must have the same value set for IdMinHigh .
Page 144 Section 6 1MRK 505 343-UEN B Differential protection Apparent power of transformer: S = 10 MVA Short circuit impedance of transformer: e = 10% Nominal voltage on transformer high voltage winding: U = 138 kV Calculating of fault current at HV (High Voltage) side of the taped transformer for three phase fault on LV side For convenience we choose calculation voltage to 138 kV.
Page 145 1MRK 505 343-UEN B Section 6 Differential protection The numerical value for input in the formula for gives = 403 A To avoid unwanted operation of the differential protection for fault on LV side of the IdMin must be set to: transformer, the setting of >...
Page 146 Section 6 1MRK 505 343-UEN B Differential protection IEC14000047 -1-en.ai IEC14000047 V1 EN-US Figure 66: Selectivity chart Setting example for two transformers in the zone, Master- Slave differential operation IEC13000295-1-en.vsd IEC13000295 V1 EN-US Figure 67: Master- Slave differential operation Settings Station A Station B Station C...
Page 147: Additional Security Logic For Differential Protection Ldrgfc
1MRK 505 343-UEN B Section 6 Differential protection IEC13000296-1-en.vsd IEC13000296 V1 EN-US Figure 68: Three-winding transformer in the zone Settings Station A Station B PDIF L3TC PDIF L3TC PDIF NoOfUsedCTs raAOnInpCh TraBOnInpCh The currents from the secondary and tertiary windings of the power transformer are connected to one RED670.
Page 148: Setting Guidelines
Section 6 1MRK 505 343-UEN B Differential protection Phase-to-phase current variation takes the current samples (IL1–IL2, IL2–IL3, etc.) as input and it calculates the variation using the sampling value based algorithm. Phase-to-phase current variation function is major one to fulfil the objectives of the start up element. Zero sequence criterion takes the zero sequence current as input.
Page 149 1MRK 505 343-UEN B Section 6 Differential protection Settings for phase-phase current variation subfunction are described below. OperationCV : On / Off , is set On in most applications 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.
Page 151: Impedance Protection
1MRK 505 343-UEN B Section 7 Impedance protection Section 7 Impedance protection Distance measuring zone, quadrilateral characteristic for series compensated lines ZMCPDIS, ZMCAPDIS, ZDSRDIR SEMOD168167-1 v3 7.1.1 Identification SEMOD168165-2 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Distance measuring zone, ZMCPDIS...
Page 152 Section 7 1MRK 505 343-UEN B Impedance protection IEC05000215 V2 EN-US Figure 70: Solidly earthed network The earth 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 earth fault current.
Page 153: Fault Infeed From Remote End
1MRK 505 343-UEN B Section 7 Impedance protection Another definition for effectively earthed network is when the following relationships between the symmetrical components of the network impedances are valid, as shown in equation and equation 45. ≤ ⋅ (Equation 44) EQUATION1269 V4 EN-US £...
Page 154: Load Encroachment
Section 7 1MRK 505 343-UEN B Impedance protection The effect of fault current infeed from remote end is one of the most driving factors to justify complementary protection to distance protection. 7.1.2.4 Load encroachment SEMOD168232-97 v3 Sometimes the load impedance might enter the zone characteristic without any fault on the protected line.
Page 155: Parallel Line Application With Mutual Coupling
1MRK 505 343-UEN B Section 7 Impedance protection Definition of long lines with respect to the performance of distance protection can generally be described as in table 17, long lines have SIR’s less than 0.5. Table 17: Definition of long lines Line category 110 kV 500 kV...
Page 156 Section 7 1MRK 505 343-UEN B Impedance protection 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. Those are: • Parallel line with common positive and zero sequence network •...
Page 157 1MRK 505 343-UEN B Section 7 Impedance protection Where: is phase-to-earth voltage at the IED point is phase current in the faulty phase is earth-fault current is positive sequence impedance is zero sequence impedance Z< Z< en05000221.vsd IEC05000221 V1 EN-US Figure 74: Class 1, parallel line in service The equivalent circuit of the lines can be simplified, as shown in figure 75.
Page 158 Section 7 1MRK 505 343-UEN B Impedance protection 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 function overreaches.
Page 159 1MRK 505 343-UEN B Section 7 Impedance protection Z< Z< en05000222.vsd DOCUMENT11520-IMG867 V1 EN-US Figure 76: The parallel line is out of service and earthed When the parallel line is out of service and earthed at both ends on the bus bar side of the line CT 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 76.
Page 160 Section 7 1MRK 505 343-UEN B Impedance protection Parallel line out of service and not earthed SEMOD168232-243 v3 Z< Z< en05000223.vsd IEC05000223 V1 EN-US Figure 78: Parallel line is out of service and not earthed When the parallel line is out of service and not earthed, the zero sequence on that line can only flow through the line admittance to the earth.
Page 161: Tapped Line Application
1MRK 505 343-UEN B Section 7 Impedance protection The real component of the KU factor is equal to equation 61. ⋅         (Equation 61) EQUATION1287 V3 EN-US The imaginary component of the same factor is equal to equation 62. ×...
Page 162 Section 7 1MRK 505 343-UEN B Impedance protection ·Z (Equation 63) DOCUMENT11524-IMG3509 V3 EN-US     ⋅  ⋅        (Equation 64) DOCUMENT11524-IMG3510 V3 EN-US 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.
Page 163: Series Compensation In Power Systems
1MRK 505 343-UEN B Section 7 Impedance protection RFPE ) and phase-to-phase In practice, the setting of fault resistance for both phase-to-earth ( RFPP ) must be as high as possible without interfering with the load impedance to obtain reliable fault detection. 7.1.2.8 Series compensation in power systems SEMOD168320-4 v2...
Page 164 Section 7 1MRK 505 343-UEN B Impedance protection limit 1000 1200 1400 1600 1800 P[MW] en06000586.vsd IEC06000586 V1 EN-US Figure 82: Voltage profile for a simple radial power line with 0, 30, 50 and 70% of compensation Increased power transfer capability by raising the first swing stability limit SEMOD168320-32 v2 Consider the simple one-machine and infinite bus system shown in figure 83.
Page 165 1MRK 505 343-UEN B Section 7 Impedance protection without SC with SC Mech Mech en06000588.vsd IEC06000588 V1 EN-US Figure 84: Equal area criterion and first swing stability without and with series compensation This means that the system is stable if A ≤...
Page 166 Section 7 1MRK 505 343-UEN B Impedance protection Increase in power transfer SEMOD168320-45 v2 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 86. The power transfer on the transmission line is given by the equation 68: ×...
Page 167 1MRK 505 343-UEN B Section 7 Impedance protection Line 1 Line 2 en06000593.vsd IEC06000593 V1 EN-US Figure 88: Two parallel lines with series capacitor for optimized load sharing and loss reduction To minimize the losses, the series capacitor must be installed in the transmission line with the lower resistance.
Page 168 Section 7 1MRK 505 343-UEN B Impedance protection en06000595.vsd IEC06000595 V1 EN-US Figure 90: Thyristor switched series capacitor en06000596.vsd IEC06000596 V1 EN-US Figure 91: Thyristor controlled series capacitor Line current Current through the thyristor Voltage over the series capacitor Rated reactance of the series capacitor A thyristor controlled series capacitor (TCSC) allows continuous control of the series capacitor reactance.
Page 169: Challenges In Protection Of Series Compensated And Adjacent Power Lines
1MRK 505 343-UEN B Section 7 Impedance protection 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 93. This high apparent reactance will mainly be used for damping of power oscillations.
Page 170 Section 7 1MRK 505 343-UEN B Impedance protection be on the bus side, so that series capacitor appears between the IED point and fault on the protected line. Figure presents the corresponding phasor diagrams for the cases with bypassed and fully inserted series capacitor. Voltage distribution on faulty lossless serial compensated line from fault point F to the bus is linearly dependent on distance from the bus, if there is no capacitor included in scheme (as shown in figure 95).
Page 171 1MRK 505 343-UEN B Section 7 Impedance protection It is obvious that voltage U will lead the fault current I as long as X > X . This situation corresponds, from the directionality point of view, to fault conditions on line without series capacitor.
Page 172 Section 7 1MRK 505 343-UEN B Impedance protection The first case corresponds also to conditions 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 97.
Page 173 1MRK 505 343-UEN B Section 7 Impedance protection performances for the same network with and without series capacitor. Possible effects of spark gap flashing or MOV conducting are neglected. The time dependence of fault currents and the difference between them are of interest. en06000609.vsd IEC06000609 V1 EN-US Figure 98: Simplified equivalent scheme of SC network during fault conditions...
Page 174 Section 7 1MRK 505 343-UEN B Impedance protection The solution over line current is in this case presented by group of equations 79. The fault current consists also here from the steady-state part and the transient part. The difference with non-compensated conditions is that •...
Page 175 1MRK 505 343-UEN B Section 7 Impedance protection 0.02 0.04 0.06 0.08 0.12 0.14 0.16 0.18 t[ms ] en06000610.vsd IEC06000610 V1 EN-US Figure 99: 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...
Page 176 Section 7 1MRK 505 343-UEN B Impedance protection Distance IEDs are exposed especially to voltage inversion for close-in reverse faults, which decreases the security. The effect of negative apparent reactance must be studied seriously in case of reverse directed distance protection zones used by distance IEDs for teleprotection schemes.
Page 177 1MRK 505 343-UEN B Section 7 Impedance protection M OV MOV protected series capacitor Line current as a function of time Capacitor voltage as a function of time Capacitor current as a function of time MOV current as a function of time en06000614.vsd IEC06000614 V1 EN-US Figure 103: MOV protected capacitor with examples of capacitor voltage and...
Page 178: Impact Of Series Compensation On Protective Ied Of Adjacent Lines
Section 7 1MRK 505 343-UEN B Impedance protection (Equation 80) EQUATION1910 V1 EN-US Where is the maximum instantaneous voltage expected between the capacitor immediately before the MOV has conducted or during operation of the MOV, divaded by √2 is the rated voltage in RMS of the series capacitor £...
Page 179 1MRK 505 343-UEN B Section 7 Impedance protection en06000616.vsd IEC06000616 V1 EN-US Figure 105: Voltage inversion in series compensated network due to fault current infeed Voltage at the B bus (as shown in figure 105) is calculated for the loss-less system according to the equation below.
Page 180: Distance Protection
Section 7 1MRK 505 343-UEN B Impedance protection Application of MOVs as non-linear elements for capacitor overvoltage protection makes simple calculations often impossible. Different kinds of steady-state network simulations are in such cases unavoidable. 7.1.2.11 Distance protection SEMOD168320-338 v3 Distance protection due to its basic characteristics, is the most used protection principle on series compensated and adjacent lines worldwide.
Page 181 1MRK 505 343-UEN B Section 7 Impedance protection separately that compensation degree K in figure relates to total system reactance, inclusive line and source impedance reactance. The same setting applies regardless MOV or spark gaps are used for capacitor overvoltage protection. Equation is applicable for the case when the VTs are located on the bus side of series capacitor.
Page 182 Section 7 1MRK 505 343-UEN B Impedance protection Distance protections of adjacent power lines shown in figure are influenced by this negative impedance. If the intermediate infeed of short circuit power by other lines is taken into consideration, the negative voltage drop on X is amplified and a protection far away from the faulty line can maloperate by its instantaneous operating distance zone, if no precaution is taken.
Page 183 1MRK 505 343-UEN B Section 7 Impedance protection 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 and the negative impedance will be sustained.
Page 184 Section 7 1MRK 505 343-UEN B Impedance protection in figure and a fault occurs behind the capacitor, the resultant reactance becomes negative and the fault current will have an opposite direction compared with fault current in a power line without a capacitor (current inversion). The negative direction of the fault current will persist until the spark gap has flashed.
Page 185 1MRK 505 343-UEN B Section 7 Impedance protection en06000628.vsd IEC06000628 V1 EN-US Figure 113: Zero sequence equivalent circuit of a series compensated double circuit line with one circuit disconnected and earthed at both IEDs Zero sequence mutual impedance may disturb also correct operation of distance protection for external evolving faults, when one circuit has already been disconnected in one phase and runs non-symmetrical during dead time of single pole autoreclosing cycle.
Page 186: Setting Guidelines
Section 7 1MRK 505 343-UEN B Impedance protection 7.1.3 Setting guidelines SEMOD168241-1 v2 7.1.3.1 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 convert the measured secondary input signals to primary values used in the distance protection function.
Page 187: Setting Of Reverse Zone
1MRK 505 343-UEN B Section 7 Impedance protection down during faults. The zone2 must not 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 with a simple example below.
Page 188 Section 7 1MRK 505 343-UEN B Impedance protection Directional control SEMOD168247-145 v2 The directional function (ZDSRDIR) which is able to cope with the condition at voltage reversal, shall be used in all IEDs with conventional distance protection (ZMCPDIS,ZMCAPDIS). This function is necessary in the protection on compensated lines as well as all non-compensated lines connected to this busbar (adjacent lines).
Page 189 1MRK 505 343-UEN B Section 7 Impedance protection æ ö c degree of compensation ç ÷ ç ÷ è ø (Equation 96) EQUATION1894 V1 EN-US is the reactance of the series capacitor p is the maximum allowable reach for an under-reaching zone with respect to the sub- harmonic swinging related to the resulting fundamental frequency reactance the zone is not allowed to over-reach.
Page 190 Section 7 1MRK 505 343-UEN B Impedance protection line LLOC en06000584-2.vsd IEC06000584 V2 EN-US Figure 118: Measured impedance at voltage inversion Forward direction: Where equals line reactance up to the series capacitor(in the picture LLoc approximate 33% of XLine) is set to (XLindex-XC) · p/100. is defined according to figure is safety factor for fast operation of Zone 1 Compensated line with the series...
Page 191: Setting Of Zones For Parallel Line Application
1MRK 505 343-UEN B Section 7 Impedance protection When the calculation of XFw gives a negative value the zone 1 must be permanently blocked. Fault resistance SEMOD168247-201 v2 The resistive reach is, for all affected applications, restricted by the set reactive reach and the load impedance and same conditions apply as for a non-compensated network.
Page 192 Section 7 1MRK 505 343-UEN B Impedance protection Parallel line in service – Setting of zone1 SEMOD168247-50 v2 With reference to section "Parallel line application with mutual coupling", the zone reach can be set to 85% of protected line. Parallel line in service – setting of zone2 SEMOD168247-53 v2 Overreaching zones (in general, zones 2 and 3) must overreach the protected circuit in all cases.
Page 193: Setting Of Reach In Resistive Direction
1MRK 505 343-UEN B Section 7 Impedance protection æ ö × ------------------------- - ç – ÷ è ø (Equation 103) EQUATION562 V1 EN-US 7.1.3.7 Setting of reach in resistive direction SEMOD168247-76 v2 Set the resistive reach independently for each zone, and separately for phase-to-phase ( R1PP ), R1PE ) measurement.
Page 194 Section 7 1MRK 505 343-UEN B Impedance protection ------ - loadmin (Equation 108) EQUATION571 V1 EN-US Where: is the minimum phase-to-phase voltage in kV 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: --------------------- - load...
Page 195: Load Impedance Limitation, With Load Encroachment Function Activated
1MRK 505 343-UEN B Section 7 Impedance protection £ × RFPP 1.6 Z load (Equation 112) EQUATION579 V2 EN-US Equation is applicable only when the loop characteristic angle for the phase-to-phase faults is more than three times as large as the maximum expected load-impedance angle. More accurate calculations are necessary according to equation 113.
Page 196: Phase Selection, Quadrilateral Characteristic With Fixed Angle Fdpspdis
Section 7 1MRK 505 343-UEN B Impedance protection tPE ) and for the ph-ph ( tPP ) measuring loops in each distance protection zone separately, to further increase the total flexibility of a distance protection. Phase selection, quadrilateral characteristic with fixed angle FDPSPDIS IP12400-1 v3 7.2.1...
Page 197 1MRK 505 343-UEN B Section 7 Impedance protection arctan (Equation 114) EQUATION2115 V1 EN-US In some applications, for instance cable lines, the angle of the loop might be less than 60°. In these applications, the settings of fault resistance coverage in forward and reverse direction, RFFwPE and RFRvPE for phase-to-earth faults and RFFwPP and RFRvPP for phase-to-phase faults have to be increased to avoid that FDPSPDIS characteristic shall cut off some part of the zone characteristic.
Page 198 Section 7 1MRK 505 343-UEN B Impedance protection ( / loop) 60° 60° ( / loop) IEC09000043_1_en.vsd IEC09000043 V1 EN-US Figure 119: Relation between distance protection phase selection (FDPSPDIS) and impedance zone (ZMQPDIS) for phase-to-earth fault φloop>60° (setting parameters in italic) FDPSPDIS (phase selection)(red line) 2 ZMQPDIS (Impedance protection zone) RFltRevPG...
Page 199 1MRK 505 343-UEN B Section 7 Impedance protection ³ × 1.44 X0 (Equation 116) EQUATION1310 V1 EN-US where: is the reactive reach for the zone to be covered by FDPSPDIS, and the constant 1.44 is a safety margin is the zero-sequence reactive reach for the zone to be covered by FDPSPDIS The reactive reach in reverse direction is automatically set to the same reach as for forward direction.
Page 200 Section 7 1MRK 505 343-UEN B Impedance protection Fault resistance reach M13142-176 v7 The fault resistance reaches in forward direction RFFwPP , must cover RFPP with at least 25% margin. RFPP is the setting of fault resistance for phase-to-phase fault for the longest overreaching zone to be covered by FDPSPDIS, see Figure 120.
Page 201 1MRK 505 343-UEN B Section 7 Impedance protection ( / phase) 60° 60° ( / phase) IEC09000257_1_en.vsd IEC09000257 V1 EN-US Figure 120: Relation between distance protection (ZMQPDIS) and FDPSPDIS characteristic for phase-to-phase fault for φline>60° (setting parameters in italic) FDPSPDIS (phase selection) (red line) 2 ZMQPDIS (Impedance protection zone) RFRvPP 3 0.5 ·...
Page 202: Resistive Reach With Load Encroachment Characteristic
Section 7 1MRK 505 343-UEN B Impedance protection 7.2.3.2 Resistive reach with load encroachment characteristic M13142-312 v4 The procedure for calculating the settings for the load encroachment consist basically to ArgLd , the blinder RLdFw in forward direction and blinder RLdRv in define the load angle reverse direction, as shown in figure 121.
Page 203: Distance Measuring Zones, Quadrilateral Characteristic Zmqpdis, Zmqapdis, Zdrdir
1MRK 505 343-UEN B Section 7 Impedance protection Distance measuring zones, quadrilateral characteristic ZMQPDIS, ZMQAPDIS, ZDRDIR IP14498-1 v4 7.3.1 Identification M14852-1 v6 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Distance protection zone, ZMQPDIS quadrilateral characteristic (zone 1) S00346 V1 EN-US Distance protection zone, ZMQAPDIS...
Page 204 Section 7 1MRK 505 343-UEN B Impedance protection IEC05000215 V2 EN-US Figure 122: Solidly earthed network The earth-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 earth-fault current.
Page 205 1MRK 505 343-UEN B Section 7 Impedance protection Where: is the highest fundamental frequency voltage on one of the healthy phases at single phase-to-earth fault. is the phase-to-earth fundamental frequency voltage before fault. Another definition for effectively earthed network is when the following relationships between the symmetrical components of the network impedances are valid, see equation equation 125.
Page 206: Fault Infeed From Remote End
Section 7 1MRK 505 343-UEN B Impedance protection Where: is the earth-fault current (A) is the current through the neutral point resistor (A) is the current through the neutral point reactor (A) is the total capacitive earth-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: ×...
Page 207: Load Encroachment
1MRK 505 343-UEN B Section 7 Impedance protection If we divide U by I we get Z present to the IED at A side. = p ·Z ·R (Equation 129) EQUATION1274-IEC-650 V1 EN-US The infeed factor (I can be very high, 10-20 depending on the differences in source impedances at local and remote end.
Page 208: Short Line Application
Section 7 1MRK 505 343-UEN B Impedance protection could preferably be switched off. See section "Load impedance limitation, without load encroachment function". The settings of the parameters for load encroachment are done in FDPSPDIS function. Load impedance ArgLd area in forward direction RLdRv RLdFw...
Page 209: Parallel Line Application With Mutual Coupling
1MRK 505 343-UEN B Section 7 Impedance protection What can be recognized as long lines with respect to the performance of distance protection can generally be described as in table 19, long lines have Source impedance ratio (SIR’s) less than 0.5. Table 19: Definition of long and very long lines Line category...
Page 210 Section 7 1MRK 505 343-UEN B Impedance protection 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: Parallel line with common positive and zero sequence network Parallel circuits with common positive but isolated zero sequence network Parallel circuits with positive and zero sequence sources isolated.
Page 211 1MRK 505 343-UEN B Section 7 Impedance protection Where: is phase to earth voltage at the relay point is phase current in the faulty phase is earth fault current is positive sequence impedance is zero sequence impedance Z< Z< IEC09000250_1_en.vsd IEC09000250 V1 EN-US Figure 127: Class 1, parallel line in service The equivalent circuit of the lines can be simplified, see figure 128.
Page 212 Section 7 1MRK 505 343-UEN B Impedance protection 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 function will overreach.
Page 213 1MRK 505 343-UEN B Section 7 Impedance protection Z< Z< IEC09000251_1_en.vsd IEC09000251 V1 EN-US Figure 129: The parallel line is out of service and earthed When the parallel line is out of service and earthed 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 130.
Page 214 Section 7 1MRK 505 343-UEN B Impedance protection Parallel line out of service and not earthed M17048-537 v5 Z< Z< IEC09000254_1_en.vsd IEC09000254 V1 EN-US Figure 131: Parallel line is out of service and not earthed When the parallel line is out of service and not earthed, the zero sequence on that line can only flow through the line admittance to the earth.
Page 215: Tapped Line Application
1MRK 505 343-UEN B Section 7 Impedance protection ⋅         (Equation 143) EQUATION1287 V3 EN-US The imaginary component of the same factor is equal to equation 144. × é ù é ù ë û...
Page 216 Section 7 1MRK 505 343-UEN B Impedance protection     ⋅  ⋅        (Equation 146) DOCUMENT11524-IMG3510 V3 EN-US Where: and Z is the line impedance from the A respective C station to the T point. and I is fault current from A respective C station for fault between T and B.
Page 217: Setting Guidelines
1MRK 505 343-UEN B Section 7 Impedance protection RFPE and phase-to-phase In practice, the setting of fault resistance for both phase-to-earth RFPP should be as high as possible without interfering with the load impedance in order to obtain reliable fault detection. However for zone1 it is necessary to limit the reach according to setting instructions in order to avoid overreach.
Page 218: Setting Of Reverse Zone
Section 7 1MRK 505 343-UEN B Impedance protection • 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.
Page 219: Setting Of Zones For Parallel Line Application
1MRK 505 343-UEN B Section 7 Impedance protection In many applications it might be necessary to consider the enlarging factor due to fault current infeed from adjacent lines in the reverse direction in order to obtain certain sensitivity. 7.3.3.5 Setting of zones for parallel line application SEMOD55087-50 v2 Parallel line in service –...
Page 220: Setting Of Reach In Resistive Direction
Section 7 1MRK 505 343-UEN B Impedance protection æ ö × ç ------------------------- - ÷ è ø (Equation 155) EQUATION561 V1 EN-US æ ö × ------------------------- - ç – ÷ è ø (Equation 156) EQUATION562 V1 EN-US 7.3.3.6 Setting of reach in resistive direction SEMOD55087-84 v7 R1 independently for each zone.
Page 221 1MRK 505 343-UEN B Section 7 Impedance protection ensure that there is a sufficient setting margin between the boundary and the minimum load impedance. The minimum load impedance (Ω/phase) is calculated as: ------ - loadmin (Equation 161) EQUATION571 V1 EN-US Where: is the minimum phase-to-phase voltage in kV is the maximum apparent power in MVA.
Page 222: Load Impedance Limitation, With Phase Selection With Load Encroachment, Quadrilateral Characteristic Function Activated
Section 7 1MRK 505 343-UEN B Impedance protection ≤ 1 6 . ⋅ RFFwPE load (Equation 165) IEC13000275 V1 EN-US Equation is applicable only when the loop characteristic angle for the phase-to-phase faults is more than three times as large as the maximum expected load-impedance angle. More accurate calculations are necessary according to equation 166.
Page 223 1MRK 505 343-UEN B Section 7 Impedance protection × × < < ArgDir L L M ArgNeg (Equation 168) EQUATION726 V2 EN-US where: ArgDir is the setting for the lower boundary of the forward directional characteristic, by default set to 15 (= -15 degrees) and ArgNegRes is the setting for the upper boundary of the forward directional characteristic, by default set to...
Page 224: Setting Of Timers For Distance Protection Zones
Section 7 1MRK 505 343-UEN B Impedance protection ArgNegRes ArgDir en05000722.vsd IEC05000722 V1 EN-US Figure 135: Setting angles for discrimination of forward and reverse fault in Directional impedance quadrilateral function ZDRDIR The reverse directional characteristic is equal to the forward characteristic rotated by 180 degrees.
Page 225: Full-Scheme Distance Measuring, Mho Characteristic Zmhpdis
1MRK 505 343-UEN B Section 7 Impedance protection Full-scheme distance measuring, Mho characteristic ZMHPDIS SEMOD154227-1 v4 7.4.1 Identification SEMOD154447-2 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE identification identification C37.2 device number Full-scheme distance protection, ZMHPDIS mho characteristic S00346 V1 EN-US 7.4.2 Application SEMOD154444-1 v1...
Page 226 Section 7 1MRK 505 343-UEN B Impedance protection The earth-fault current at single phase-to-earth in phase L1 can be calculated as equation 169: × (Equation 169) EQUATION1267 V3 EN-US Where: is the phase to earth voltage (kV) in the faulty phase before fault is the positive sequence impedance (Ω/phase) is the negative sequence impedance (Ω/phase)
Page 227 1MRK 505 343-UEN B Section 7 Impedance protection Where is the zero sequence resistance is the zero sequence reactance is the positive sequence reactance The magnitude of the earth-fault current in effectively earthed networks is high enough for impedance measuring element to detect earth fault. However, in the same way as for solid earthed 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.
Page 228: Fault Infeed From Remote End
Section 7 1MRK 505 343-UEN B Impedance protection IEC05000216 V2 EN-US Figure 137: High impedance earthing network The operation of high impedance earthed networks is different compared to solid earthed networks where all major faults have to be cleared very fast. In high impedance earthed networks, some system operators do not clear single phase-to-earth faults immediately;...
Page 229: Load Encroachment
1MRK 505 343-UEN B Section 7 Impedance protection p*ZL (1-p)*ZL Z < Z < IEC09000247-1-en.vsd IEC09000247 V1 EN-US Figure 138: Influence of fault current infeed from remote end. The effect of fault current infeed from remote end is one of the most driving factors for justify complementary protection to distance protection.
Page 230: Short Line Application
Section 7 1MRK 505 343-UEN B Impedance protection RLdFw ArgLd ArgLd ArgLd ArgLd RLdRv IEC09000127-1-en.vsd IEC09000127 V1 EN-US Figure 140: Load encroachment of Faulty phase identification with load encroachment for mho function FMPSPDIS characteristic The use of the load encroachment feature is essential for long heavy loaded lines, where there might be a conflict between the necessary emergency load transfer and necessary sensitivity of the distance protection.
Page 231: Long Transmission Line Application
1MRK 505 343-UEN B Section 7 Impedance protection Table 20: Definition of short and very short line Line category 110 kV 500 kV Very short line 1.1-5.5 km 5-25 km Short line 5-11 km 25-50 km The use of load encroachment algorithm in Full-scheme distance protection, mho characteristic function (ZMHPDIS) improves the possibility to detect high resistive faults without conflict with the load impedance (see to the right of figure 139).
Page 232 Section 7 1MRK 505 343-UEN B Impedance protection It can be shown from analytical calculations of line impedances that the mutual impedances for positive and negative sequence are very small and it is a practice to neglect them. Mutual coupling effect The mutual coupling is based on the known induction law, that a current induces a longitudinal voltage in the parallel circuit.
Page 233 1MRK 505 343-UEN B Section 7 Impedance protection 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 practice to neglect them.
Page 234 Section 7 1MRK 505 343-UEN B Impedance protection The short circuit voltage can be calculated as: × × × × × (Equation 181) IECEQUATION14006 V1 EN-US Where I is the ground current in the parallel line. As explained above, the distance relay phase-to-earth measures: ×...
Page 235: Tapped Line Application
1MRK 505 343-UEN B Section 7 Impedance protection From the above it can be deduced: • Error is proportional to the mutual coupling factor K • The error increases with the parallel line earth current in relation to the relay current •...
Page 236 Section 7 1MRK 505 343-UEN B Impedance protection SEMOD154453-267 v4 IEC09000160-3-en.vsd IEC09000160 V3 EN-US Figure 143: 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 will ×...
Page 237: Setting Guidelines
1MRK 505 343-UEN B Section 7 Impedance protection current from B might go in reverse direction from B to C depending on the system parameters (see the dotted line in figure 143), given that the distance protection in B to T will measure wrong direction.
Page 238: Setting Of Zone 1
Section 7 1MRK 505 343-UEN B Impedance protection When Directional impedance element for mho characteristic (ZDMRDIR) is used together with Fullscheme distance protection, mho characteristic (ZMHPDIS) DirEvalType in ZDMRDIR is vital: the following settings for parameter Comparator is strongly recommended •...
Page 239: Setting Of Reverse Zone
1MRK 505 343-UEN B Section 7 Impedance protection 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 lines at remote end is considerable higher than the fault current at the IED location.
Page 240 Section 7 1MRK 505 343-UEN B Impedance protection ³ × Zrev Z rem (Equation 190) EQUATION1525 V5 EN-US Where: is the protected line impedance Z2rem is zone 2 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 direction in order to obtain certain sensitivity.
Page 241 1MRK 505 343-UEN B Section 7 Impedance protection is the ratio of distance to fault and length of the line × (Equation 192) IECEQUATION14005 V1 EN-US ⋅ (Equation 193) IEC13000297 V1 EN-US Case 2: Parallel line switched off and not earthed or earthed at one line end Z<...
Page 242 Section 7 1MRK 505 343-UEN B Impedance protection Some observations from above equations for case 1, 2, and 3 GUID-6B411616-EB82-4447-BC2D-375D042BE110 v1 In case 1, the lowest impedance is measured, that is, the highest reach occurs due to the parallel connection of the zero-sequence systems of both lines. In case 3, the highest impedance is measured, which corresponds to the shortest reach.
Page 243 1MRK 505 343-UEN B Section 7 Impedance protection For case 2, when the parallel line is out of operation but not earthed, the zone 1 nominal reach for earth faults is reduced. The measured impedance can be calculated: × = × (Equation 197) IECEQUATION14015 V1 EN-US The reduced reach must be taken into account when using a permissive underreaching...
Page 244 Section 7 1MRK 505 343-UEN B Impedance protection × = × (Equation 201) IECEQUATION14016 V1 EN-US For both case 1 and 2, the overreach would be much higher. For case 3, the function measures the correct impedance. The normal influence of infeeds is to be added to these influences of the mutual coupling for setting of remote backup zones.
Page 245: Load Impedance Limitation, Without Load Encroachment Function
1MRK 505 343-UEN B Section 7 Impedance protection 7.4.3.7 Load impedance limitation, without load encroachment function SEMOD154469-91 v5 The following instruction is valid when the load encroachment function or blinder function is BlinderMode = Off ).The load encroachment function will not be activated if not activated ( RLdFw and RLdRv is set to a value higher than expected minimal load impedance.
Page 246: Load Impedance Limitation, With Load Encroachment Function Activated
Section 7 1MRK 505 343-UEN B Impedance protection ZPE/2 (Ref) φ ArgLd ß Load Ohm/phase en06000406.vsd IEC06000406 V1 EN-US Figure 148: Definition of the setting condition to avoid load encroachment for earth-fault loop The maximum setting for phase-to-phase fault can be defined by trigonometric analyze of the same figure 148.
Page 247: Setting Of Directional Mode
1MRK 505 343-UEN B Section 7 Impedance protection The minimum operate fault current is automatically reduced to 75% of its set value, if the distance protection zone has been set for the operation in reverse direction. 7.4.3.10 Setting of directional mode SEMOD154469-176 v3 DirMode Setting of the directional mode is by default set to forward by setting the parameter...
Page 248: Full-Scheme Distance Protection, Quadrilateral For Earth Faults Zmmpdis, Zmmapdis
Section 7 1MRK 505 343-UEN B Impedance protection Full-scheme distance protection, quadrilateral for earth faults ZMMPDIS, ZMMAPDIS SEMOD154561-1 v2 7.5.1 Identification SEMOD154542-2 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Fullscheme distance protection, ZMMPDIS quadrilateral for earth faults (zone 1) S00346 V1 EN-US Fullscheme distance protection, ZMMAPDIS...
Page 249 1MRK 505 343-UEN B Section 7 Impedance protection very limited influence on the earth fault current. The shunt admittance may, however, have some marginal influence on the earth fault current in networks with long transmission lines. The earth fault current at single phase-to-earth in phase L1 can be calculated as equation207: ×...
Page 250 Section 7 1MRK 505 343-UEN B Impedance protection £ (Equation 210) EQUATION1270 V4 EN-US The magnitude of the earth fault current in effectively earthed networks is high enough for impedance measuring element to detect fault. However, in the same way as for solid earthed 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.
Page 251: Fault Infeed From Remote End
1MRK 505 343-UEN B Section 7 Impedance protection IEC05000216 V2 EN-US Figure 150: High impedance earthing network The operation of high impedance earthed networks is different compare to solid earthed networks where all major faults have to be cleared very fast. In high impedance earthed networks, some system operators do not clear single phase-to-earth faults immediately;...
Page 252: Load Encroachment
Section 7 1MRK 505 343-UEN B Impedance protection p*ZL (1-p)*ZL Z < Z < en05000217.vsd IEC05000217 V1 EN-US Figure 151: Influence of fault infeed from remote end. The effect of fault current infeed from remote end is one of the most driving factors for justify complementary protection to distance protection.
Page 253: Short Line Application
1MRK 505 343-UEN B Section 7 Impedance protection Load impedance ARGLd ARGLd area in forward direction ARGLd ARGLd RLdRv RLdFw en05000495.vsd IEC05000495 V1 EN-US Figure 152: Load encroachment phenomena and shaped load encroachment characteristic 7.5.2.5 Short line application SEMOD154680-105 v2 In short line applications, the major concern is to get sufficient fault resistance coverage.
Page 254: Parallel Line Application With Mutual Coupling
Section 7 1MRK 505 343-UEN B Impedance protection Table 24: Definition of long lines Line category 110 kV 500 kV Long lines 77 km - 99 km 350 km - 450 km Very long lines > 99 km > 450 km As mentioned in the previous chapter, 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-earth fault together with load encroachment algorithm...
Page 255 1MRK 505 343-UEN B Section 7 Impedance protection Most multi circuit lines have two parallel operating circuits. The application guide mentioned below recommends in more detail the setting practice for this particular type of line. The basic principles also apply to other multi circuit lines. Parallel line applications SEMOD154680-168 v2 This type of networks are defined as those networks where the parallel transmission lines...
Page 256 Section 7 1MRK 505 343-UEN B Impedance protection Z0 m 99000038.vsd IEC99000038 V1 EN-US Figure 154: Equivalent zero sequence impedance circuit of the double-circuit, parallel, operating line with a single phase-to-earth fault at the remote busbar When mutual coupling is introduced, the voltage at the IED point A will be changed. If the current on the parallel line have negative sign compare to the current on the protected line that is, the current on the parallel line has an opposite direction compare to the current on the protected line, the distance function will overreach.
Page 257 1MRK 505 343-UEN B Section 7 Impedance protection Z m0 99000039.vsd DOCUMENT11520-IMG7100 V1 EN-US Figure 156: Equivalent zero-sequence impedance circuit for the double-circuit line that operates with one circuit disconnected and earthed at both 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 216.
Page 258 Section 7 1MRK 505 343-UEN B Impedance protection When the parallel line is out of service and not earthed, the zero sequence on that line can only flow through the line admittance to the earth. The line admittance is high which limits the zero sequence current on the parallel line to very low values.
Page 259: Tapped Line Application
1MRK 505 343-UEN B Section 7 Impedance protection × é ù é ù ë û ë û (Equation 223) EQUATION1288 V2 EN-US Ensure that the underreaching zones from both line ends will overlap a sufficient amount (at least 10%) in the middle of the protected circuit. 7.5.2.8 Tapped line application SEMOD154680-265 v1...
Page 260 Section 7 1MRK 505 343-UEN B Impedance protection 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. U2/U1 Transformation ratio for transformation of impedance at U1 side of the transformer to the measuring side U2 (it is assumed that current and voltage...
Page 261: Setting Guidelines
1MRK 505 343-UEN B Section 7 Impedance protection 7.5.3 Setting guidelines SEMOD154701-1 v1 7.5.3.1 General SEMOD154704-4 v2 The settings for the Full-scheme distance protection, quadrilateral for earth faults (ZMMPDIS) function are done in primary values. The instrument transformer ratio that has been set for the analogue input card is used to automatically convert the measured secondary input signals to primary values used in ZMMPDIS function.
Page 262: Setting Of Reverse Zone
Section 7 1MRK 505 343-UEN B Impedance protection faults. The zone2 must not 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.
Page 263 1MRK 505 343-UEN B Section 7 Impedance protection 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.
Page 264: Setting Of Reach In Resistive Direction
Section 7 1MRK 505 343-UEN B Impedance protection æ ö × ------------------------- - ç – ÷ è ø (Equation 235) EQUATION562 V1 EN-US 7.5.3.6 Setting of reach in resistive direction SEMOD154704-76 v1 RIPE ) Set the resistive reach independently for each zone, for phase-to-earth loop ( measurement.
Page 265: Load Impedance Limitation, With Load Encroachment Function Activated
1MRK 505 343-UEN B Section 7 Impedance protection --------------------- - load × (Equation 240) EQUATION574 V1 EN-US Minimum voltage U and maximum current Imax are related to the same operating conditions. Minimum load impedance occurs normally under emergency conditions. Because a safety margin is required to avoid load encroachment under three- phase conditions and to guarantee correct healthy phase IED operation under combined heavy three-phase load and earth faults, consider both: phase-to- phase and phase-to-earth fault operating characteristics.
Page 266: Setting Of Timers For Distance Protection Zones
Section 7 1MRK 505 343-UEN B Impedance protection sensitivity by reducing the minimum operating current down to 10% of the IED base current. This happens especially in cases, when the IED serves as a remote back-up protection on series of very long transmission lines. IMinOpIN that will If the load current compensation is activated, there is an additional criteria IMinOpIN .
Page 267 1MRK 505 343-UEN B Section 7 Impedance protection • Zero-sequence voltage polarized (-U • Negative-sequence voltage polarized (-U2) • Zero-sequence current (I • Dual polarization (-U • Zero-sequence voltage with zero-sequence current compensation (-U0Comp) • Negative-sequence voltage with negative-sequence current compensation (-U2Comp) The zero-sequence voltage polarized earth directional unit compares the phase angles of zero sequence current I with zero sequence voltage -U...
Page 268: Mho Impedance Supervision Logic Zsmgapc
Section 7 1MRK 505 343-UEN B Impedance protection difference must exist in the magnitudes of the zero sequence currents for close-up forward and reverse faults, that is, it is a requirement that |U0| >> |k · I0| for reverse faults, otherwise there is a risk that reverse faults can be seen as forward.
Page 269: Setting Guidelines
1MRK 505 343-UEN B Section 7 Impedance protection 7.7.3 Setting guidelines SEMOD174968-1 v1 SEMOD154558-7 v4 GlobalBaseSel : Selects the global base value group used by the function to define ( IBase ), UBase ) and ( SBase ). PilotMode : Set PilotMode to On when pilot scheme is to be used. In this mode fault inception function will send a block signal to remote end to block the overreaching zones, when operated.
Page 270: Setting Guidelines
Section 7 1MRK 505 343-UEN B Impedance protection The heavy load transfer that is common in many transmission networks may in some cases be in opposite to the wanted fault resistance coverage. Therefore, FMPSPDIS has an built-in algorithm for load encroachment, which gives the possibility to enlarge the resistive setting of both the Phase selection with load encroachment and the measuring zones without interfering with the load.
Page 271: Load Encroachment
1MRK 505 343-UEN B Section 7 Impedance protection ILoad × ULmn (Equation 246) EQUATION1615 V1 EN-US where: Smax is the maximal apparent power transfer during emergency conditions and ULmn is the phase-to-phase voltage during the emergency conditions at the IED location. 7.8.3.1 Load encroachment SEMOD154782-39 v4...
Page 272: Distance Protection Zone, Quadrilateral Characteristic, Separate Settings Zmrpdis, Zmrapdis And Zdrdir
Section 7 1MRK 505 343-UEN B Impedance protection æ ö ArgLd ç ÷ è ø (Equation 249) EQUATION1623 V1 EN-US where: Pmax is the maximal active power transfer during emergency conditions and Smax is the maximal apparent power transfer during emergency conditions. RLd can be calculated according to equation 250: ×...
Page 273: System Earthing
1MRK 505 343-UEN B Section 7 Impedance protection 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 be used on distribution levels. 7.9.2.1 System earthing GUID-AA9E698B-D0B5-45FC-ABA5-6A2CD988E16D v1 The type of system earthing plays an important role when designing the protection system.
Page 274 Section 7 1MRK 505 343-UEN B Impedance protection Effectively earthed networks GUID-5F4CCC18-2BAC-4140-B56C-B9002CD36318 v1 A network is defined as effectively earthed if the earth-fault factor f is less than 1.4. The earth- fault factor is defined according to equation 252. (Equation 252) EQUATION1268 V4 EN-US Where: is the highest fundamental frequency voltage on one of the healthy phases at single...
Page 275: Fault Infeed From Remote End
1MRK 505 343-UEN B Section 7 Impedance protection (Equation 255) EQUATION1271 V3 EN-US Where: is the earth-fault current (A) is the current through the neutral point resistor (A) is the current through the neutral point reactor (A) is the total capacitive earth-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: ×...
Page 276: Load Encroachment
Section 7 1MRK 505 343-UEN B Impedance protection × × × I p Z (Equation 257) EQUATION1273 V1 EN-US If we divide U by I we get Z present to the IED at A side. × × (Equation 258) EQUATION1274 V2 EN-US The infeed factor (I can be very high, 10-20 depending on the differences in source impedances at local and remote end.
Page 277: Short Line Application
1MRK 505 343-UEN B Section 7 Impedance protection The use of the load encroachment feature is essential for long heavy loaded lines, where there might be a conflict between the necessary emergency load transfer and necessary sensitivity of the distance protection. The function can also preferably be used on heavy loaded medium long lines.
Page 278: Long Transmission Line Application
Section 7 1MRK 505 343-UEN B Impedance protection 7.9.2.5 Long transmission line application GUID-40F06841-F192-4159-87BA-7BC7E4B014AA v1 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-earth fault at remote line end of a long line when the line is heavy loaded.
Page 279 1MRK 505 343-UEN B Section 7 Impedance protection The reach of the distance protection zone 1 will be different depending on the operation condition of the parallel line. This can be handled by the use of different setting groups for handling the cases when the parallel line is in operation and out of service and earthed at both ends.
Page 280 Section 7 1MRK 505 343-UEN B Impedance protection Z< Z< IEC09000250_1_en.vsd IEC09000250 V1 EN-US Figure 166: Class 1, parallel line in service. The equivalent zero sequence circuit of the lines can be simplified, see figure 167. IEC09000253_1_en.vsd IEC09000253 V1 EN-US Figure 167: Equivalent zero sequence impedance circuit of the double-circuit, parallel, operating line with a single phase-to-earth fault at the remote busbar.
Page 281 1MRK 505 343-UEN B Section 7 Impedance protection × × × p Z1 I K 3I (Equation 262) EQUATION2313 V1 EN-US One can also notice that the following relationship exists between the zero sequence currents: ⋅ ⋅ − (Equation 263) EQUATION1279 V3 EN-US Simplification of equation 263, solving it for 3I0p and substitution of the result into equation gives that the voltage can be drawn as:...
Page 282 Section 7 1MRK 505 343-UEN B Impedance protection IEC09000252_1_en.vsd IEC09000252 V1 EN-US Figure 169: Equivalent zero sequence impedance circuit for the double-circuit line that operates with one circuit disconnected and earthed at both ends. Here the equivalent zero sequence impedance is equal to Z m in parallel with (Z which is equal to equation 266.
Page 283: Tapped Line Application
1MRK 505 343-UEN B Section 7 Impedance protection sequence impedance circuit for faults at the remote bus bar can be simplified to the circuit shown in figure The line zero sequence mutual impedance does not influence the measurement of the distance protection in a faulty circuit.
Page 284 Section 7 1MRK 505 343-UEN B Impedance protection     ⋅  ⋅        (Equation 270) DOCUMENT11524-IMG3510 V3 EN-US Where: and Z is the line impedance from the A respective C station to the T point. and I is fault current from A respective C station for fault between T and B.
Page 285: Setting Guidelines
1MRK 505 343-UEN B Section 7 Impedance protection RFPE and phase-to-phase In practice, the setting of fault resistance for both phase-to-earth RFPP should be as high as possible without interfering with the load impedance in order to obtain reliable fault detection. 7.9.3 Setting guidelines IP14962-1 v1...
Page 286: Setting Of Reverse Zone
Section 7 1MRK 505 343-UEN B Impedance protection Larger overreach than the mentioned 80% can often be acceptable due to fault current infeed from other lines. This requires however analysis by means of fault calculations. If any of the above indicates a zone 2 reach less than 120%, the time delay of zone 2 must be increased by approximately 200ms to avoid unwanted operation in cases when the telecommunication for the short adjacent line at remote end is down during faults.
Page 287: Setting Of Zones For Parallel Line Application
1MRK 505 343-UEN B Section 7 Impedance protection 7.9.3.5 Setting of zones for parallel line application SEMOD55087-50 v2 Parallel line in service – Setting of zone 1 GUID-F10BF2FF-7B0F-40B0-877B-081E1D5B067B v1 With reference to section "Parallel line applications", the zone reach can be set to 85% of protected line.
Page 288: Setting Of Reach In Resistive Direction
Section 7 1MRK 505 343-UEN B Impedance protection æ ö × ç ------------------------- - ÷ è ø (Equation 279) EQUATION561 V1 EN-US æ ö × ------------------------- - ç – ÷ è ø (Equation 280) EQUATION562 V1 EN-US 7.9.3.6 Setting of reach in resistive direction GUID-3BFE80FD-8A51-4B71-8762-73DFA73AB28B v2 Set the resistive independently for each zone.
Page 289 1MRK 505 343-UEN B Section 7 Impedance protection reach for any zone to ensure that there is a sufficient setting margin between the boundary and the minimum load impedance. The minimum load impedance (Ω/phase) is calculated as: ------ - loadmin (Equation 285) EQUATION571 V1 EN-US Where:...
Page 290: Load Impedance Limitation, With Phase Selection With Load Encroachment, Quadrilateral Characteristic Function Activated
Section 7 1MRK 505 343-UEN B Impedance protection £ × RFPP 1.6 Z load (Equation 289) EQUATION579 V2 EN-US Equation is applicable only when the loop characteristic angle for the phase-to-phase faults is more than three times as large as the maximum expected load-impedance angle. More accurate calculations are necessary according to equation 290.
Page 291: Phase Selection, Quadrilateral Characteristic With Settable Angle Frpspdis
1MRK 505 343-UEN B Section 7 Impedance protection tPP measuring loops in each distance protection zone separately, to further phase-to-phase increase the total flexibility of a distance protection. 7.10 Phase selection, quadrilateral characteristic with settable angle FRPSPDIS GUID-29E9C424-5AF7-40EE-89D9-F6BB4F0A0836 v2 7.10.1 Identification GUID-07DB9506-656C-4E5F-A043-3DAA624313C7 v2 Function description...
Page 292 Section 7 1MRK 505 343-UEN B Impedance protection RLdFw ARGLd ARGLd ARGLd ARGLd RLdRv en05000196.vsd IEC05000196 V1 EN-US Figure 174: Characteristic of load encroachment function The influence of load encroachment function on the operation characteristic is dependent on the chosen operation mode of the FRPSPDIS function. When output signal STCNDZis selected, the characteristic for the FRPSPDIS (and also zone measurement depending on settings) can be reduced by the load encroachment characteristic (as shown in figure 175).
Page 293 1MRK 505 343-UEN B Section 7 Impedance protection "Phase selection" "quadrilateral" zone Distance measuring zone Load encroachment characteristic Directional line en05000673.vsd IEC05000673 V1 EN-US Figure 176: Operation characteristic in forward direction when load encroachment is enabled Figure is valid for phase-to-earth. During a three-phase fault, or load, when the "quadrilateral"...
Page 294 Section 7 1MRK 505 343-UEN B Impedance protection (ohm/phase) Phase selection ”Quadrilateral” zone Distance measuring zone (ohm/phase) en05000674.vsd IEC05000674 V1 EN-US Figure 177: Operation characteristic for FRPSPDIS in forward direction for three-phase fault, ohm/phase domain The result from rotation of the load characteristic at a fault between two phases is presented in fig 178.
Page 295: Load Encroachment Characteristics
1MRK 505 343-UEN B Section 7 Impedance protection IEC08000437.vsd IEC08000437 V1 EN-US Figure 178: Rotation of load characteristic for a fault between two phases This rotation may seem a bit awkward, but there is a gain in selectivity by using the same measurement as for the quadrilateral characteristic since not all phase-to-phase loops will be fully affected by a fault between two phases.
Page 296: Phase-To-Earth Fault In Forward Direction
Section 7 1MRK 505 343-UEN B Impedance protection resistance coverage can be derived from trigonometric evaluation of the basic characteristic for respectively fault type. The following setting guideline considers normal overhead lines applications and provides two different setting alternatives: A recommended characteristic angle of 60 degrees for the phase selection A characteristic angle of 90 and 70 degrees for phase-to-earth and phase-to-phase respectively, like...
Page 297: Phase-To-Earth Fault In Reverse Direction
1MRK 505 343-UEN B Section 7 Impedance protection 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 and equation gives the minimum recommended reactive reach.
Page 298: Phase-To-Phase Fault In Forward Direction
Section 7 1MRK 505 343-UEN B Impedance protection Resistive reach M13142-156 v4 The resistive reach in reverse direction must be set longer than the longest reverse zones. In blocking schemes it must be set longer than the overreaching zone at remote end that is used in the communication scheme.
Page 299: Setting Guidelines
1MRK 505 343-UEN B Section 7 Impedance protection phase R1PP= tan 70° 0 × RFRvPP 0 × RFFwPP 0.5*RFPP 0.5*RFPP phase 0.5*RFPP 0.5*RFPP 0.5*RFPP 0.5*RFPP 0 × RFRvPP R1PP= tan 70° en08000249.vsd IEC08000249 V1 EN-US Figure 180: Relation between measuring zone and FRPSPDIS characteristic for phase-to- phase fault for φline>70°...
Page 300: Minimum Operate Currents
Section 7 1MRK 505 343-UEN B Impedance protection RLdFw ArgLd ArgLd ArgLd ArgLd RLdRv IEC09000050-1-en.vsd IEC09000050 V1 EN-US Figure 181: Load encroachment characteristic ArgLd is the same in forward and reverse direction, so it could be suitable to The load angle begin to calculate the setting for that parameter.
Page 301: Phase Selection, Quadrilateral Characteristic With Fixed Angle Fdpspdis
1MRK 505 343-UEN B Section 7 Impedance protection 7.11 Phase selection, quadrilateral characteristic with fixed angle FDPSPDIS IP12400-1 v3 7.11.1 Identification 7.11.1.1 Identification M14850-1 v5 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Phase selection with load FDPSPDIS encroachment, quadrilateral characteristic...
Page 302 Section 7 1MRK 505 343-UEN B Impedance protection In some applications, for instance cable lines, the angle of the loop might be less than 60°. In these applications, the settings of fault resistance coverage in forward and reverse direction, RFFwPE and RFRvPE for phase-to-earth faults and RFFwPP and RFRvPP for phase-to-phase faults have to be increased to avoid that FDPSPDIS characteristic shall cut off some part of the zone characteristic.
Page 303 1MRK 505 343-UEN B Section 7 Impedance protection ( / loop) 60° 60° ( / loop) IEC09000043_1_en.vsd IEC09000043 V1 EN-US Figure 182: Relation between distance protection phase selection (FDPSPDIS) and impedance zone (ZMQPDIS) for phase-to-earth fault φloop>60° (setting parameters in italic) FDPSPDIS (phase selection)(red line) 2 ZMQPDIS (Impedance protection zone) RFltRevPG...
Page 304 Section 7 1MRK 505 343-UEN B Impedance protection ³ × 1.44 X0 (Equation 303) EQUATION1310 V1 EN-US where: is the reactive reach for the zone to be covered by FDPSPDIS, and the constant 1.44 is a safety margin is the zero-sequence reactive reach for the zone to be covered by FDPSPDIS The reactive reach in reverse direction is automatically set to the same reach as for forward direction.
Page 305 1MRK 505 343-UEN B Section 7 Impedance protection Fault resistance reach M13142-176 v7 The fault resistance reaches in forward direction RFFwPP , must cover RFPP with at least 25% margin. RFPP is the setting of fault resistance for phase-to-phase fault for the longest overreaching zone to be covered by FDPSPDIS, see Figure 183.
Page 306 Section 7 1MRK 505 343-UEN B Impedance protection ( / phase) 60° 60° ( / phase) IEC09000257_1_en.vsd IEC09000257 V1 EN-US Figure 183: Relation between distance protection (ZMQPDIS) and FDPSPDIS characteristic for phase-to-phase fault for φline>60° (setting parameters in italic) FDPSPDIS (phase selection) (red line) 2 ZMQPDIS (Impedance protection zone) RFRvPP 3 0.5 ·...
Page 307: Resistive Reach With Load Encroachment Characteristic
1MRK 505 343-UEN B Section 7 Impedance protection 7.11.3.2 Resistive reach with load encroachment characteristic M13142-312 v4 The procedure for calculating the settings for the load encroachment consist basically to ArgLd , the blinder RLdFw in forward direction and blinder RLdRv in define the load angle reverse direction, as shown in figure 184.
Page 308: High Speed Distance Protection Zmfpdis
Section 7 1MRK 505 343-UEN B Impedance protection 7.12 High speed distance protection ZMFPDIS GUID-CC4F7338-2281-411D-B55A-67BF03F31681 v3 7.12.1 Identification GUID-8ACD3565-C607-4399-89D2-A05657840E6D v3 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number High speed distance protection zone ZMFPDIS S00346 V1 EN-US 7.12.2 Application IP14961-1 v2...
Page 309 1MRK 505 343-UEN B Section 7 Impedance protection Where: is the phase-to-earth voltage (kV) in the faulty phase before fault is the positive sequence impedance (Ω/phase) is the negative sequence impedance (Ω/phase) is the zero sequence impedance (Ω/phase) is the fault impedance (Ω), often resistive is the earth-return impedance defined as (Z The high zero-sequence current in solidly earthed networks makes it possible to use impedance measuring techniques to detect earth faults.
Page 310 Section 7 1MRK 505 343-UEN B Impedance protection earthed 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 earthed networks GUID-02F306F5-1038-42AC-AFAE-3F8423C4C066 v4 In high impedance networks, the neutral of the system transformers are connected to the...
Page 311: Fault Infeed From Remote End
1MRK 505 343-UEN B Section 7 Impedance protection In this type of network, it is mostly not possible to use distance protection for detection and clearance of earth faults. The low magnitude of the earth-fault current might not give start of the zero-sequence measurement elements or the sensitivity will be too low for acceptance.
Page 312: Load Encroachment
Section 7 1MRK 505 343-UEN B Impedance protection 7.12.2.3 Load encroachment GUID-6785BF05-2775-4422-8077-A663D01C6C07 v4 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 external fault is cleared and high emergency load is transferred onto the protected line.
Page 313: Long Transmission Line Application
1MRK 505 343-UEN B Section 7 Impedance protection Table 27: Definition of short and very short line Line category 110 kV 500 kV Very short line 1.1-5.5 km 5-25 km Short line 5.5-11 km 25-50 km The IED's ability 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-earth fault together with load encroachment algorithm improves the possibility to detect high resistive faults without conflict with the load impedance.
Page 314 Section 7 1MRK 505 343-UEN B Impedance protection 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: Parallel line with common positive and zero sequence network Parallel circuits with common positive but isolated zero sequence network Parallel circuits with positive and zero sequence sources isolated.
Page 315 1MRK 505 343-UEN B Section 7 Impedance protection Where: is phase to earth voltage at the relay point is phase current in the faulty phase is earth fault current is positive sequence impedance is zero sequence impedance Z< Z< IEC09000250_1_en.vsd IEC09000250 V1 EN-US Figure 189: Class 1, parallel line in service The equivalent circuit of the lines can be simplified, see figure 190.
Page 316 Section 7 1MRK 505 343-UEN B Impedance protection 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 function will overreach.
Page 317 1MRK 505 343-UEN B Section 7 Impedance protection Z< Z< IEC09000251_1_en.vsd IEC09000251 V1 EN-US Figure 191: The parallel line is out of service and earthed When the parallel line is out of service and earthed 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 192.
Page 318 Section 7 1MRK 505 343-UEN B Impedance protection Parallel line out of service and not earthed GUID-949669D3-8B9F-4ECA-8F09-52A783A494E1 v2 Z< Z< IEC09000254_1_en.vsd IEC09000254 V1 EN-US Figure 193: Parallel line is out of service and not earthed When the parallel line is out of service and not earthed, the zero sequence on that line can only flow through the line admittance to the earth.
Page 319: Tapped Line Application
1MRK 505 343-UEN B Section 7 Impedance protection ⋅         (Equation 330) EQUATION1287 V3 EN-US The imaginary component of the same factor is equal to equation 331. × é ù é ù ë û...
Page 320 Section 7 1MRK 505 343-UEN B Impedance protection     ⋅  ⋅        (Equation 333) DOCUMENT11524-IMG3510 V3 EN-US Where: and Z is the line impedance from the A respective C station to the T point. and I is fault current from A respective C station for fault between T and B.
Page 321: Setting Guidelines
1MRK 505 343-UEN B Section 7 Impedance protection RFPE and phase-to-phase In practice, the setting of fault resistance for both phase-to-earth RFPP should be as high as possible without interfering with the load impedance in order to obtain reliable fault detection. 7.12.3 Setting guidelines IP14962-1 v1...
Page 322: Setting Of Reverse Zone
Section 7 1MRK 505 343-UEN B Impedance protection Larger overreach than the mentioned 80% can often be acceptable due to fault current infeed from other lines. This requires however analysis by means of fault calculations. If any of the above gives a zone 2 reach less than 120%, the time delay of zone 2 must be increased by approximately 200ms to avoid unwanted operation in cases when the telecommunication for the short adjacent line at remote end is down during faults.
Page 323: Setting Of Zones For Parallel Line Application
1MRK 505 343-UEN B Section 7 Impedance protection 7.12.3.5 Setting of zones for parallel line application GUID-4E0C3824-41B6-410F-A10E-AB9C3BFE9B12 v1 Parallel line in service – Setting of zone 1 GUID-8A62367C-2636-4EC1-90FF-397A51F586F7 v1 With reference to section "Parallel line applications", the zone reach can be set to 85% of the protected line.
Page 324: Setting The Reach With Respect To Load
Section 7 1MRK 505 343-UEN B Impedance protection æ ö × ç ------------------------- - ÷ è ø (Equation 342) EQUATION561 V1 EN-US æ ö × ------------------------- - ç – ÷ è ø (Equation 343) EQUATION562 V1 EN-US 7.12.3.6 Setting the reach with respect to load GUID-ED84BDE6-16CD-45ED-A45D-5CFB828A9040 v4 RFPP and for the phase- Set separately the expected fault resistance for phase-to-phase faults...
Page 325: Zone Reach Setting Lower Than Minimum Load Impedance
1MRK 505 343-UEN B Section 7 Impedance protection 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. 7.12.3.7 Zone reach setting lower than minimum load impedance GUID-68C336F4-5285-4167-B3F8-B0963BD85439 v4 Even if the resistive reach of all protection zones is set lower than the lowest expected load RLdFw , RLdRv impedance and there is no risk for load encroachment, it is still necessary to set...
Page 326: Zone Reach Setting Higher Than Minimum Load Impedance
Section 7 1MRK 505 343-UEN B Impedance protection é × ù £ × × × RFPE ê ú ë û load × (Equation 351) EQUATION578 V4 EN-US Where: ∂ is a maximum load-impedance angle, related to the maximum load power. To avoid load encroachment for the phase-to-phase measuring elements, the set resistive reach of any distance protection zone must be less than 160% of the minimum load impedance.
Page 327: Other Settings
1MRK 505 343-UEN B Section 7 Impedance protection this corresponds to the per-phase, or positive-sequence, impedance. For a phase-to-earth fault, it corresponds to the per-loop impedance, including the earth return impedance. RLdFw RLdFw ARGLd ARGLd ARGLd ARGLd ArgLd Possible ARGLd load ARGLd RLdRv...
Page 328 Section 7 1MRK 505 343-UEN B Impedance protection This setting defines 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 198, where the positive impedance corresponds to...
Page 329 1MRK 505 343-UEN B Section 7 Impedance protection TimerModeZx = Enable Ph-Ph, Ph-E PPZx tPPZx PEZx tPEZx BLOCK VTSZ BLKZx BLKTRZx TimerLinksZx LoopLink (tPP-tPE) ZoneLinkStart LoopLink & ZoneLink No Links STPHS Phase Selection 1st starting zone LNKZ1 FALSE (0) LNKZ2 LNKZx LNKZRV LNKZ3...
Page 330: High Speed Distance Protection For Series Compensated Lines Zmfcpdis
Section 7 1MRK 505 343-UEN B Impedance protection leasePE × ³ × (Equation 356) EQUATION2548 V1 EN-US Where: INReleasePE the setting for the minimum residual current needed to enable operation in the phase-to- earth fault loops in % the maximum phase current in any of the three phases phmax By default, this setting is set excessively high to always enable phase-to-phase measurement for phase-to-phase-earth faults.
Page 331 1MRK 505 343-UEN B Section 7 Impedance protection Solidly earthed networks GUID-6870F6A8-EB28-47CF-AF26-7CE758BF934E v1 In solidly earthed systems, the transformer neutrals are connected directly to earth without any impedance between the transformer neutral and earth. IEC05000215 V2 EN-US Figure 200: Solidly earthed network The earth-fault current is as high or even higher than the short-circuit current.
Page 332: Fault Infeed From Remote End
Section 7 1MRK 505 343-UEN B Impedance protection Where: is the highest fundamental frequency voltage on one of the healthy phases at single phase-to-earth fault. is the phase-to-earth fundamental frequency voltage before fault. Another definition for effectively earthed network is when the following relationships between the symmetrical components of the network impedances are valid, see equations and 360: <...
Page 333: Load Encroachment
1MRK 505 343-UEN B Section 7 Impedance protection If we divide U by I we get Z present to the IED at A side: = p ·Z ·R (Equation 362) EQUATION1274-IEC-650 V1 EN-US The infeed factor (I can be very high, 10-20 depending on the differences in source impedances at local and remote end.
Page 334: Short Line Application
Section 7 1MRK 505 343-UEN B Impedance protection according to the expected maximum load since these settings are used internally in the function as reference points to improve the performance of the phase selection. Load impedance ArgLd area in forward direction RLdRv RLdFw...
Page 335: Parallel Line Application With Mutual Coupling
1MRK 505 343-UEN B Section 7 Impedance protection Table 30: Definition of long and very long lines Line category 110 kV 500 kV Long lines 77 km - 99 km 350 km - 450 km Very long lines > 99 km >...
Page 336 Section 7 1MRK 505 343-UEN B Impedance protection The different network configuration classes are: Parallel line with common positive and zero sequence network Parallel circuits with common positive but separated zero sequence network Parallel circuits with positive and zero sequence sources separated. One example of class 3 networks could be the mutual coupling between a 400 kV line and rail road overhead lines.
Page 337 1MRK 505 343-UEN B Section 7 Impedance protection Where: is phase to earth voltage at the relay point. is phase current in the faulty phase. is earth fault current. is positive sequence impedance. is zero sequence impedance. Z< Z< IEC09000250_1_en.vsd IEC09000250 V1 EN-US Figure 204: Class 1, parallel line in service The equivalent circuit of the lines can be simplified, see figure 205.
Page 338 Section 7 1MRK 505 343-UEN B Impedance protection 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 function will overreach.
Page 339 1MRK 505 343-UEN B Section 7 Impedance protection Z< Z< IEC09000251_1_en.vsd IEC09000251 V1 EN-US Figure 206: The parallel line is out of service and earthed When the parallel line is out of service and earthed 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 207.
Page 340 Section 7 1MRK 505 343-UEN B Impedance protection Parallel line out of service and not earthed GUID-DF8B0C63-E6D1-4E11-A8CB-D0C8EAE10FF0 v1 Z< Z< IEC09000254_1_en.vsd IEC09000254 V1 EN-US Figure 208: Parallel line is out of service and not earthed When the parallel line is out of service and not earthed, the zero sequence on that line can only flow through the line admittance to the earth.
Page 341: Tapped Line Application
1MRK 505 343-UEN B Section 7 Impedance protection ⋅         (Equation 376) EQUATION1287 V3 EN-US The imaginary component of the same factor is equal to equation 377. × é ù é ù ë û...
Page 342 Section 7 1MRK 505 343-UEN B Impedance protection     ⋅  ⋅        (Equation 379) DOCUMENT11524-IMG3510 V3 EN-US Where: and Z is the line impedance from the A respective C station to the T point. and I is fault current from A respective C station for fault between T and B.
Page 343: Series Compensation In Power Systems
1MRK 505 343-UEN B Section 7 Impedance protection RFPE and phase-to-phase In practice, the setting of fault resistance for both phase-to-earth RFPP should be as high as possible without interfering with the load impedance in order to obtain reliable fault detection. 7.13.3 Series compensation in power systems GUID-7F3BBF91-4A17-4B31-9828-F2757672C440 v2...
Page 344: Increase In Power Transfer
Section 7 1MRK 505 343-UEN B Impedance protection limit 1000 1200 1400 1600 1800 P[MW] en06000586.vsd IEC06000586 V1 EN-US Figure 212: Voltage profile for a simple radial power line with 0, 30, 50 and 70% of compensation 7.13.3.2 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 213.
Page 345: Voltage And Current Inversion
1MRK 505 343-UEN B Section 7 Impedance protection Multiple of power over a non-compensated line Power transfer with constant angle difference Degree of Degree of series compensation [%] compensation IEC06000592-2-en.vsd IEC06000592 V2 EN-US Figure 214: Increase in power transfer over a transmission line depending on degree of series compensation 7.13.3.3 Voltage and current inversion...
Page 346 Section 7 1MRK 505 343-UEN B Impedance protection With bypassed With inserted capacitor capacitor Source voltage Pre -fault voltage U’ Fault voltage Source Z< en06000605.vsd IEC06000605 V1 EN-US Figure 215: Voltage inversion on series compensated line With bypassed With inserted capacitor capacitor en06000606.vsd...
Page 347 1MRK 505 343-UEN B Section 7 Impedance protection Current inversion GUID-9F7FDF59-D0B4-4972-9CB0-B3D56DACA09E v1 Figure presents part of a series compensated line with corresponding equivalent voltage source. It is generally anticipated that fault current I flows on non-compensated lines from power source towards the fault F on the protected line. Series capacitor may change the situation.
Page 348 Section 7 1MRK 505 343-UEN B Impedance protection With bypassed With inserted capacitor capacitor en06000608.vsd IEC06000608 V1 EN-US Figure 218: Phasor diagrams of currents and voltages for the bypassed and inserted series capacitor during current inversion It is a common practice to call this phenomenon current inversion. Its consequences on operation of different protections in series compensated networks depend on their operating principle.
Page 349 1MRK 505 343-UEN B Section 7 Impedance protection Bus side instrument transformers GUID-B7D1F10A-5467-4F91-9BC1-AB8906357428 v1 CT1 and VT1 on figure represent the case with bus side instrument transformers. The protection devices are in this case exposed to possible voltage and current inversion for line faults, which decreases the required dependability.
Page 350 Section 7 1MRK 505 343-UEN B Impedance protection KC = 80% KC = 50% KC = 2 x 33% KC = 80% KC = 0% LOC = 0% LOC = 50% LOC = 33%, 66% LOC = 100% en06000613.vsd IEC06000613 V1 EN-US Figure 221: Apparent impedances seen by distance IED for different SC locations and spark gaps used for overvoltage protection M OV...
Page 351: Impact Of Series Compensation On Protective Ied Of Adjacent Lines
1MRK 505 343-UEN B Section 7 Impedance protection instantaneous voltage drop over the capacitor becomes higher than the protective voltage level in each half-cycle separately, see figure 222. ref. Goldsworthy, D,L “A Extensive studies at Bonneville Power Administration in USA ( Linearized Model for MOV-Protected series capacitors”...
Page 352 Section 7 1MRK 505 343-UEN B Impedance protection selection of protection devices (mostly distance IEDs) on remote ends of lines adjacent to the series compensated circuit, and sometimes even deeper in the network. en06000616.vsd IEC06000616 V1 EN-US Figure 224: Voltage inversion in series compensated network due to fault current infeed Voltage at the B bus (as shown in figure 224) is calculated for the loss-less system according to the equation below.
Page 353: Distance Protection
1MRK 505 343-UEN B Section 7 Impedance protection 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.
Page 354 Section 7 1MRK 505 343-UEN B Impedance protection × (Equation 392) EQUATION1914 V1 EN-US Here K is a safety factor, presented graphically in figure 226, which covers for possible overreaching due to low frequency (sub-harmonic) oscillations. Here it should be noted separately that compensation degree K in figure relates to total system reactance,...
Page 355 1MRK 505 343-UEN B Section 7 Impedance protection and in figure a three phase fault occurs beyond the capacitor. The resultant IED impedance seen from the IED location to the fault may become negative (voltage inversion) until the spark gap has flashed.
Page 356 Section 7 1MRK 505 343-UEN B Impedance protection adjacent line may be 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 flashover and the negative impedance will be sustained.
Page 357 1MRK 505 343-UEN B Section 7 Impedance protection with fault current in a power line without a capacitor (current inversion). The negative direction of the fault current will persist until the spark gap has flashed. Sometimes there will be no flashover at all, because the fault current is less than the setting value of the spark gap. The negative fault current will cause a high voltage on the network.
Page 358 Section 7 1MRK 505 343-UEN B Impedance protection en06000628.vsd IEC06000628 V1 EN-US Figure 232: Zero sequence equivalent circuit of a series compensated double circuit line with one circuit disconnected and earthed at both IEDs Zero sequence mutual impedance may disturb also correct operation of distance protection for external evolving faults, when one circuit has already been disconnected in one phase and runs non-symmetrical during dead time of single pole autoreclosing cycle.
Page 359: Setting Guidelines
1MRK 505 343-UEN B Section 7 Impedance protection 7.13.4 Setting guidelines IP14962-1 v1 7.13.4.1 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 primary values used in ZMFCPDIS.
Page 360: Setting Of Reverse Zone
Section 7 1MRK 505 343-UEN B Impedance protection If the chosen zone 2 reach gives such a value that it will interfere with zone 2 on adjacent lines, the time delay of zone 2 must be increased by approximately 200 ms to avoid unwanted operation in cases when the telecommunication for the short adjacent line at the remote end is down during faults.
Page 361 1MRK 505 343-UEN B Section 7 Impedance protection Setting of zone 1 GUID-69E8535D-F3E2-483D-8463-089063712C67 v2 A voltage reversal can cause an artificial internal fault (voltage zero) 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.
Page 362 Section 7 1MRK 505 343-UEN B Impedance protection at three phase fault and therefore the calculation need only to be performed for three phase faults. The compensation degree in earth 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 single phase-to-earth fault loops on the other side.
Page 363 1MRK 505 343-UEN B Section 7 Impedance protection X1Fw is set to (XLine-XC · K) · p/100. • X1Rv can be set to the same value as X1Fw • K equals side infeed factor at next busbar. • X1Fw gives a negative value the zone 1 must be When the calculation of permanently blocked.
Page 364: Setting Of Zones For Parallel Line Application
Section 7 1MRK 505 343-UEN B Impedance protection Optional higher distance protection zones GUID-506F93E2-1E1C-4EEC-B260-F362F3897C4F 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. 7.13.4.6 Setting of zones for parallel line application GUID-E1228762-EBF7-4E58-9A52-96C5D22A0F0D v1 Parallel line in service –...
Page 365: Setting Of Reach In Resistive Direction
1MRK 505 343-UEN B Section 7 Impedance protection Set the values of the corresponding zone (zero-sequence resistance and reactance) equal to: æ ö × ç ------------------------- - ÷ è ø (Equation 410) EQUATION561 V1 EN-US æ ö × ------------------------- - ç...
Page 366: Load Impedance Limitation, Without Load Encroachment Function
Section 7 1MRK 505 343-UEN B Impedance protection functionality is not needed (that is, when the load is not encroaching on the distance zones). Always define the load encroachment boundary according to the actual load or in consideration of how far the phase selection must actually reach. 7.13.4.8 Load impedance limitation, without load encroachment function GUID-16C2EB30-7FEA-42E4-98C8-52CCC36644C6 v4...
Page 367: Zone Reach Setting Higher Than Minimum Load Impedance
1MRK 505 343-UEN B Section 7 Impedance protection é × ù £ × × × RFPE ê ú ë û load × (Equation 419) EQUATION578 V4 EN-US Where: is a maximum load-impedance angle, related to the maximum load power. ϑ To avoid load encroachment for the phase-to-phase measuring elements, the set resistive reach of any distance protection zone must be less than 160% of the minimum load impedance.
Page 368: Parameter Setting Guidelines
Section 7 1MRK 505 343-UEN B Impedance protection this corresponds to the per-phase, or positive-sequence, impedance. For a phase-to-earth fault, it corresponds to the per-loop impedance, including the earth return impedance. RLdFw RLdFw ARGLd ARGLd ARGLd ARGLd ArgLd Possible ARGLd load ARGLd RLdRv...
Page 369 1MRK 505 343-UEN B Section 7 Impedance protection 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 below, where positive impedance corresponds to the direction out on the protected line.
Page 370: Power Swing Detection Zmrpsb
Section 7 1MRK 505 343-UEN B Impedance protection measurement is activated (and phase-to-phase measurement is blocked). The relations are defined by the following equation. leasePE × ³ × (Equation 424) EQUATION2548 V1 EN-US Where: INReleasePE is the setting for the minimum residual current needed to enable operation in the phase-to- earth fault loops in % Iphmax is the maximum phase current in any of three phases...
Page 371: Basic Characteristics
1MRK 505 343-UEN B Section 7 Impedance protection locus in an impedance plane, see figure 239. This locus can enter the operating characteristic of a distance protection and cause, if no preventive measures have been considered, its unwanted operation. Operating characteristic Impedance locus at power swing IEC09000224_1_en.vsd...
Page 372 Section 7 1MRK 505 343-UEN B Impedance protection Reduce the power system with protected power line into equivalent two-machine system with positive sequence source impedances Z behind the IED and Z behind the remote end bus B. Observe a fact that these impedances can not be directly calculated from the maximum three-phase short circuit currents for faults on the corresponding busbar.
Page 373 1MRK 505 343-UEN B Section 7 Impedance protection all settings are performed in primary values. The impedance transformation factor is presented for orientation and testing purposes only. 1200 0.11 × × KIMP 0.33 (Equation 425) EQUATION1336 V1 EN-US The minimum load impedance at minimum expected system voltage is equal to equation 426. 144.4 1000 (Equation 426)
Page 374 Section 7 1MRK 505 343-UEN B Impedance protection ArgLd ArgLd (ZMRPSB) (FDPSPDIS) IEC09000225-1-en.vsd IEC09000225 V1 EN-US Figure 241: Impedance diagrams with corresponding impedances under consideration RLdOutFw The outer boundary of oscillation detection characteristic in forward direction should be set with certain safety margin K compared to the minimum expected load resistance R .
Page 375 1MRK 505 343-UEN B Section 7 Impedance protection RLdOutFw obtains in this particular case its value according to 400kV. The outer boundary equation 432. × × RLdOutFw 0.9 137.2 123.5 (Equation 432) EQUATION1343 V1 EN-US RLdInFw of the oscillation detection It is a general recommendation to set the inner boundary characteristic to 80% or less of its outer boundary.
Page 376 Section 7 1MRK 505 343-UEN B Impedance protection 155.75 RLdInFw 75.8 max1 æ ö æ ö 91.5 × × 2 tan 2 tan ç ÷ ç ÷ è ø è ø (Equation 439) EQUATION1350 V1 EN-US RLdInFw 75.8 kLdRFw max1 0.61 RLdOutFw 123.5...
Page 377: Power Swing Logic Pslpsch
1MRK 505 343-UEN B Section 7 Impedance protection then it is necessary to set the load argument in FDPSPDIS or FRPSPDIS function to not less than equation 444. é ù é ° ù ArgLd tan 25 ³ ° ArgLd arc tan arc tan 37.5 ê...
Page 378 Section 7 1MRK 505 343-UEN B Impedance protection • A fault occurs on a so far healthy power line, over which the power swing has been detected and the fast distance protection zone has been blocked by ZMRPSB element. • The power swing occurs over two phases of a protected line during the dead time of a singlepole auto-reclosing after the Ph-E fault has been correctly cleared by the distance protection.
Page 379: Setting Guidelines
1MRK 505 343-UEN B Section 7 Impedance protection Measured impedance at initital fault position Zone 2 Zone 1 Impedance locus at initial power swing after the fault clearance ZMRPSB operating characteristic IEC99000181_2_en.vsd IEC99000181 V2 EN-US Figure 243: Impedance trajectory within the distance protection zones 1 and 2 during and after the fault on line B –...
Page 380 Section 7 1MRK 505 343-UEN B Impedance protection LDCM” and the “Binary signal transfer to remote end” function. It is also possible to include, in an easy 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.
Page 381 1MRK 505 343-UEN B Section 7 Impedance protection Connect the CACC functional input to start output signal of the local overreaching power swing distance protection zone, which serves as a local criteria at receiving of carrier signal during the power swing cycle. The CR signal should be configured to the functional input which provides the logic with information on received carrier signal sent by the remote end power swing distance protection zone.
Page 382: Blocking And Tripping Logic For Evolving Power Swings
Section 7 1MRK 505 343-UEN B Impedance protection × v tnPE × RFPE (Equation 447) EQUATION1539 V1 EN-US Here is factor 0.8 considered for safety reasons and: RFPE phase-to-earth resistive reach setting for a power swing distance protection zone n in Ω...
Page 383 1MRK 505 343-UEN B Section 7 Impedance protection Configure for this reason the STZMPSD to the functional output signal of ZMRPSB function, which indicates the measured impedance within its external boundaries. & BLKZMH & STZML STZMLL & >1 BLOCK & STMZH &...
Page 384: Pole Slip Protection Pspppam
Section 7 1MRK 505 343-UEN B Impedance protection 7.16 Pole slip protection PSPPPAM SEMOD156709-1 v2 7.16.1 Identification SEMOD158949-2 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Pole slip protection PSPPPAM 7.16.2 Application SEMOD143248-4 v3 Normally, the generator operates synchronously with the power system, that is, all the generators in the system have the same angular velocity and approximately the same phase angle difference.
Page 385 1MRK 505 343-UEN B Section 7 Impedance protection en06000313.vsd IEC06000313 V1 EN-US Figure 246: Relative generator phase angle at a fault and pole slip relative to the external power system The relative angle of the generator is shown for different fault duration at a three-phase short circuit close to the generator.
Page 386 Section 7 1MRK 505 343-UEN B Impedance protection en06000314.vsd IEC06000314 V1 EN-US Figure 247: Undamped oscillations causing pole slip The relative angle of the generator is shown a contingency in the power system, causing un- damped oscillations. After a few periods of the oscillation the swing amplitude gets to large and the stability cannot be maintained.
Page 387: Setting Guidelines
1MRK 505 343-UEN B Section 7 Impedance protection 7.16.3 Setting guidelines SEMOD167596-1 v1 SEMOD167582-4 v4 GlobalBaseSel : Selects the global base value group used by the function to define ( IBase ), UBase ) and ( SBase ). Operation : With the parameter Operation the function can be set On or Off . MeasureMode : The voltage and current used for the impedance measurement is set by the MeasureMode .
Page 388: Setting Example For Line Application
Section 7 1MRK 505 343-UEN B Impedance protection UBase Base IBase (Equation 449) EQUATION1883 V1 EN-US ImpedanceZB is the reverse impedance as show in figure 248. ZB should be equal to the generator transient reactance X'd. The impedance is given in % of the base impedance, see equation 449.
Page 389 1MRK 505 343-UEN B Section 7 Impedance protection Apparent anglePhi impedance at normal load IEC07000015_2_en.vsd IEC07000015 V2 EN-US Figure 250: Impedances to be set for pole slip protection The setting parameters of the protection is: Line + source impedance in the forward direction The source impedance in the reverse direction The line impedance in the forward direction AnglePhi :...
Page 390 Section 7 1MRK 505 343-UEN B Impedance protection UBase ZBase SBase 1000 (Equation 450) EQUATION1960 V1 EN-US Z line Zsc station 5000 (Equation 451) EQUATION1961 V1 EN-US This corresponds to: Ð ° 0.0125 0.325 0.325 88 (Equation 452) EQUATION1962 V1 EN-US Set ZA to 0.32.
Page 391: Setting Example For Generator Application
1MRK 505 343-UEN B Section 7 Impedance protection Zload en07000016.vsd IEC07000016 V1 EN-US Figure 251: Simplified figure to derive StartAngle ³ » angleStart arctan arctan arctan + arctan = 21.8 + 33.0 Zload Zload (Equation 457) EQUATION1968 V2 EN-US In case of minor damped oscillations at normal operation we do not want the protection to start.
Page 392 Section 7 1MRK 505 343-UEN B Impedance protection en07000017.vsd IEC07000017 V1 EN-US Figure 252: Generator application of pole slip protection If the apparent impedance crosses the impedance line ZB – ZA this is the detected criterion of out of step conditions, see figure 253. Apparent anglePhi impedance at...
Page 393 1MRK 505 343-UEN B Section 7 Impedance protection Use the following block transformer data: UBase : 20 kV (low voltage side) SBase set to 200 MVA : 15% Short circuit power from the external network without infeed from the protected line: 5000 MVA (assumed to a pure reactance).
Page 394 Section 7 1MRK 505 343-UEN B Impedance protection Ð 0.15 0.15 90 (Equation 464) EQUATION1975 V2 EN-US AnglePhi to 90°. Set ZC to 0.15 and StartAngle ) should be chosen not to cross into normal operating area. The The warning angle ( maximum line power is assumed to be 200 MVA.
Page 395: Out-Of-Step Protection Oosppam
1MRK 505 343-UEN B Section 7 Impedance protection N1Limit to 1 to get trip at first pole If the centre of pole slip is within the generator block set slip. N2Limit to 3 to get enable split of the system If the centre of pole slip is within the network set before generator trip.
Page 396 Section 7 1MRK 505 343-UEN B Impedance protection The center of the electromechanical oscillation can be in the generator unit (or generator- transformer unit) or outside, somewhere in the power system. When the center of the electromechanical oscillation occurs within the generator it is essential to trip the generator immediately.
Page 397: Setting Guidelines
1MRK 505 343-UEN B Section 7 Impedance protection unstable stable 3-ph ← 3-rd pole-slip fault 260 ms ← 2-nd pole-slip 1.05 ← For 260 ms long 3-phase fault generator loses synchronism. Generator operates in 1-st asynchronous mode at speeds > nominal pole-slip ←...
Page 398 Section 7 1MRK 505 343-UEN B Impedance protection Table 31: An example how to calculate values for the settings ForwardR, ForwardX, ReverseR, and ReverseX Turbine Generator Transformer Double power line Equivalent (hydro) 200 MVA 300 MVA 230 kV, 300 km power system 13.8 kV...
Page 399 1MRK 505 343-UEN B Section 7 Impedance protection • For the synchronous machines as the generator in Table 31, the transient reactance Xd' shall be used. This due to the relatively slow electromechanical oscillations under out-of- step conditions. • Sometimes the equivalent resistance of the generator is difficult to get. A good estimate is 1 percent of transient reactance Xd'.
Page 400: Automatic Switch Onto Fault Logic Zcvpsof
(LV-side) then inversion is not necessary ( Off ), provided that the CT’s star point earthing complies with ABB recommendations, as it is shown in Table 31. If the currents fed to the Out-of-step protection are measured on the...
Page 401: Setting Guidelines
1MRK 505 343-UEN B Section 7 Impedance protection nondirectional distance zones also gives a fast fault clearance when energizing a bus from the line with a short circuit fault on the bus. Other protection functions like time-delayed phase and zero-sequence overcurrent function can be connected to ZCVPSOF to increase the dependability in the scheme.
Page 402: Phase Preference Logic Pplphiz
Section 7 1MRK 505 343-UEN B Impedance protection IPh< and UPh< . The choice of UlLevel gives a faster and more sensitive operation of setting of the function, which is important for reducing the stress that might occur when energizing onto a fault.
Page 403 1MRK 505 343-UEN B Section 7 Impedance protection Figure shows an occurring cross-country fault. Figure shows the achievement of line voltage on healthy phases and an occurring cross-country fault. Load Load en06000550.vsd IEC06000550 V1 EN-US Figure 257: An occurring cross-country fault on different feeders in a sub-transmission network, high impedance (resistance, reactance) earthed en06000551.vsd IEC06000551 V1 EN-US...
Page 404 Section 7 1MRK 505 343-UEN B Impedance protection ZMQAPDIS FDPSPDIS I3P* W2_CT_B_I3P TRIP I3P* TRIP U3P* W2_VT_B_U3P TRL1 U3P* START FALSE BLOCK TRL2 BLOCK STFWL1 PHS_L1 W2_FSD1-BLKZ VTSZ TRL3 DIRCND STFWL2 PHS_L2 FALSE BLKTR START STFWL3 PHS_L3 STCND STL1 STFWPE DIRCND STL2 STRVL1...
Page 405: Setting Guidelines
1MRK 505 343-UEN B Section 7 Impedance protection 7.19.3 Setting guidelines SEMOD167997-4 v5 The parameters for the Phase preference logic function PPLPHIZ are set via the local HMI or PCM600. Phase preference logic function is an intermediate logic between Distance protection zone, quadrilateral characteristic function ZMQPDIS and Phase selection with load encroachment, quadrilateral characteristic function FDPSPDIS.
Page 407: Current Protection
1MRK 505 343-UEN B Section 8 Current protection Section 8 Current protection Instantaneous phase overcurrent protection PHPIOC IP14506-1 v6 8.1.1 Identification M14880-1 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Instantaneous phase overcurrent PHPIOC protection 3-phase output 3I>>...
Page 408: Meshed Network Without Parallel Line
Section 8 1MRK 505 343-UEN B Current protection Only detailed network studies can determine the operating conditions under which the highest possible fault current is expected on the line. In most cases, this current appears during three-phase fault conditions. But also examine single-phase-to-earth and two-phase- to-earth conditions.
Page 409 1MRK 505 343-UEN B Section 8 Current protection Fault IEC09000023-1-en.vsd IEC09000023 V1 EN-US Figure 262: Through fault current from B to A: I The IED must not trip for any of the two through-fault currents. Hence the minimum theoretical current setting (Imin) will be: ³...
Page 410: Meshed Network With Parallel Line
Section 8 1MRK 505 343-UEN B Current protection 8.1.3.2 Meshed network with parallel line M12915-34 v6 In case of parallel lines, the influence of the induced current from the parallel line to the protected line has to be considered. One example is given in figure where the two lines are connected to the same busbars.
Page 411: Four Step Phase Overcurrent Protection Oc4Ptoc
1MRK 505 343-UEN B Section 8 Current protection Four step phase overcurrent protection OC4PTOC SEMOD129998-1 v7 8.2.1 Identification M14885-1 v5 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Four step phase overcurrent OC4PTOC 51_67 protection 3-phase output TOC-REVA V2 EN-US 8.2.2 Application...
Page 412: Setting Guidelines
Section 8 1MRK 505 343-UEN B Current protection to the current pick-up level. This multiplication factor is activated from a binary input signal to the function. Power transformers can have a large inrush current, when being energized. This phenomenon is due to saturation of the transformer magnetic core during parts of the period. There is a risk that inrush current will reach levels above the pick-up current of the phase overcurrent protection.
Page 413: Settings For Each Step
1MRK 505 343-UEN B Section 8 Current protection IEC09000636_1_vsd IEC09000636 V1 EN-US Figure 265: Directional function characteristic RCA = Relay characteristic angle ROA = Relay operating angle Reverse Forward 8.2.3.1 Settings for each step M12982-19 v10.1.1 x means step 1, 2, 3 and 4. DirModex : The directional mode of step x .
Page 414 Section 8 1MRK 505 343-UEN B Current protection Curve name ANSI Moderately Inverse ANSI/IEEE Definite time ANSI Long Time Extremely Inverse ANSI Long Time Very Inverse ANSI Long Time Inverse IEC Normal Inverse IEC Very Inverse IEC Inverse IEC Extremely Inverse IEC Short Time Inverse IEC Long Time Inverse IEC Definite Time...
Page 415 1MRK 505 343-UEN B Section 8 Current protection Operate time txMin IMinx Current IEC10000058 IEC10000058 V2 EN-US Figure 266: Minimum operate current and operate time for inverse time characteristics txMin shall be In order to fully comply with the definition of the curve, the setting parameter set to a value equal to the operating time of the selected inverse curve for twenty times the set current pickup value.
Page 416: 2Nd Harmonic Restrain
Section 8 1MRK 505 343-UEN B Current protection æ ö ç ÷ ç ÷ × IxMult ç ÷ æ ö ç ç ÷ ÷ è è ø ø > (Equation 473) EQUATION1261 V2 EN-US tPRCrvx , tTRCrvx , tCRCrvx : These parameters are used by the customer to create the inverse Technical manual .
Page 417 1MRK 505 343-UEN B Section 8 Current protection Current I Line phase current Operate current Reset current The IED does not reset Time t IEC05000203-en-2.vsd IEC05000203 V3 EN-US Figure 267: Operate and reset current for an overcurrent protection The lowest setting value can be written according to equation 474. Im ax ³...
Page 418 Section 8 1MRK 505 343-UEN B Current protection £ × 0.7 Isc min (Equation 475) EQUATION1263 V2 EN-US where: is a safety factor Iscmin is the smallest fault current to be detected by the overcurrent protection. As a summary the operating current shall be chosen within the interval stated in equation 476. Im ax ×...
Page 419 1MRK 505 343-UEN B Section 8 Current protection en05000204.wmf IEC05000204 V1 EN-US Figure 268: Fault time with maintained selectivity The operation time can be set individually for each overcurrent protection. To assure selectivity between different protections, in the radial network, there have to be a minimum time difference Dt between the time delays of two protections.
Page 420: Instantaneous Residual Overcurrent Protection Efpioc
Section 8 1MRK 505 343-UEN B Current protection Feeder I> I> Time axis The fault Protection Breaker at Protection occurs B1 trips B1 opens A1 resets en05000205.vsd IEC05000205 V1 EN-US Figure 269: Sequence of events during fault where: is when the fault occurs is when the trip signal from the overcurrent protection at IED B1 is sent to the circuit breaker.
Page 421: Identification
1MRK 505 343-UEN B Section 8 Current protection 8.3.1 Identification M14887-1 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Instantaneous residual overcurrent EFPIOC protection IN>> IEF V1 EN-US 8.3.2 Application M12699-3 v5 In many applications, when fault current is limited to a defined value by the object impedance, an instantaneous earth-fault protection can provide fast and selective tripping.
Page 422 Section 8 1MRK 505 343-UEN B Current protection Fault IEC09000023-1-en.vsd IEC09000023 V1 EN-US Figure 271: Through fault current from B to A: I The function shall not operate for any of the calculated currents to the protection. The minimum theoretical current setting (Imin) will be: ³...
Page 423: Four Step Residual Overcurrent Protection
1MRK 505 343-UEN B Section 8 Current protection ³ I m in M A X I (Equation 481) EQUATION287 V1 EN-US Where: and I have been described for the single line case. Considering the safety margins mentioned previously, the minimum setting (Is) is: = 1.3 ×...
Page 424 Section 8 1MRK 505 343-UEN B Current protection In many applications several steps with different current operating levels and time delays are needed. EF4PTOC can have up to four, individual settable steps. The flexibility of each step of EF4PTOC is great. The following options are possible: Non-directional/Directional function: In some applications the non-directional functionality is used.
Page 425: Setting Guidelines
1MRK 505 343-UEN B Section 8 Current protection to the residual current pick-up level. This multiplication factor is activated from a binary input signal ENMULTx to the function. Power transformers can have a large inrush current, when being energized. This inrush current can have residual current components.
Page 426 Section 8 1MRK 505 343-UEN B Current protection Protection operate time: 15-60 ms Protection resetting time: 15-60 ms Breaker opening time: 20-120 ms The different characteristics are described in the technical reference manual. tx : Definite time delay for step x . The definite time tx is added to the inverse time when inverse time characteristic is selected.
Page 427: Common Settings For All Steps
1MRK 505 343-UEN B Section 8 Current protection tResetx : Constant reset time delay in s for step x. HarmBlockx : This is used to enable block of step x from 2 harmonic restrain function. tPCrvx, tACrvx, tBCrvx, tCCrvx : Parameters for user programmable of inverse time characteristic curve.
Page 428: 2Nd Harmonic Restrain
Section 8 1MRK 505 343-UEN B Current protection Voltage (3U • or U Current (3I • · ZNpol or 3I ·ZNpol where ZNpol is RNpol + jXNpol), or Dual (dual polarizing, (3U • both currents and voltage, + 3I · ZNpol) or (U ·...
Page 429: Switch Onto Fault Logic
1MRK 505 343-UEN B Section 8 Current protection of the two transformers will be in phase opposition. The summation of the two currents will thus give a small 2 harmonic current. The residual fundamental current will however be significant. The inrush current of the transformer in service before the parallel transformer energizing, will be a little delayed compared to the first transformer.
Page 430: Line Application Example
Section 8 1MRK 505 343-UEN B Current protection ActivationSOTF : This setting will select the signal to activate SOTF function; CB position open/CB position closed/CB close command . tSOTF : Time delay for operation of the SOTF function. The setting range is 0.000 - 60.000 s in step of 0.001 s.
Page 431 1MRK 505 343-UEN B Section 8 Current protection Step 1 M15282-123 v5 This step has directional instantaneous function. The requirement is that overreaching of the protected line is not allowed. One- or two-phase earth-fault or unsymmetric short circuit without earth connection IEC05000150-3-en.vsd IEC05000150 V4 EN-US Figure 277: Step 1, first calculation...
Page 432 Section 8 1MRK 505 343-UEN B Current protection A higher value of step 1 might be necessary if a big power transformer (Y0/D) at remote bus bar is disconnected. A special case occurs at double circuit lines, with mutual zero-sequence impedance between the parallel lines, see figure 279.
Page 433 1MRK 505 343-UEN B Section 8 Current protection The residual current, out on the line, is calculated at an operational case with minimal earth- fault current. The requirement that the whole line shall be covered by step 2 can be formulated according to equation 487.
Page 434: Four Step Directional Negative Phase Sequence Overcurrent Protection Ns4Ptoc
Section 8 1MRK 505 343-UEN B Current protection ³ × × step3 step2 (Equation 489) EQUATION1204 V4 EN-US where: is the chosen current setting for step 2 on the faulted line. step2 Step 4 M15282-177 v4 This step normally has non-directional function and a relatively long time delay. The task for step 4 is to detect and initiate trip for earth faults with large fault resistance, for example tree faults.
Page 435 1MRK 505 343-UEN B Section 8 Current protection In many applications several steps with different current operating levels and time delays are needed. NS4PTOC can have up to four, individual settable steps. The flexibility of each step of NS4PTOC function is great. The following options are possible: Non-directional/Directional function: In some applications the non-directional functionality is used.
Page 436: Setting Guidelines
Section 8 1MRK 505 343-UEN B Current protection 8.5.3 Setting guidelines GUID-460D6C58-598C-421E-AA9E-FD240210A6CC v3 The parameters for Four step negative sequence overcurrent protection NS4PTOC 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 On or Off .
Page 437 1MRK 505 343-UEN B Section 8 Current protection The different characteristics are described in the Technical Reference Manual (TRM). Ix> : 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.
Page 438: Common Settings For All Steps
Section 8 1MRK 505 343-UEN B Current protection For IEC inverse time delay characteristics the possible delay time settings are instantaneous (1) and IEC (2 = set constant time reset). For the programmable inverse time delay characteristics all three types of reset time characteristics are available;...
Page 439: Sensitive Directional Residual Overcurrent And Power Protection Sdepsde
1MRK 505 343-UEN B Section 8 Current protection Reverse Area Upol=-U2 AngleRCA Forward Area Iop = I2 IEC10000031-1-en.vsd IEC10000031 V1 EN-US Figure 284: Relay characteristic angle given in degree In a transmission network a normal value of RCA is about 80°. UPolMin : Minimum polarization (reference) voltage % of UBase .
Page 440: Application
Section 8 1MRK 505 343-UEN B Current protection 8.6.2 Application SEMOD171959-4 v11 In networks with high impedance earthing, the phase-to-earth fault current is significantly smaller than the short circuit currents. Another difficulty for earth fault protection is that the magnitude of the phase-to-earth fault current is almost independent of the fault location in the network.
Page 441: Setting Guidelines
1MRK 505 343-UEN B Section 8 Current protection Phase currents Phase- ground voltages IEC13000013-1-en.vsd IEC13000013 V1 EN-US Figure 285: Connection of SDEPSDE to analog preprocessing function block Overcurrent functionality uses true 3I0, i.e. sum of GRPxL1, GRPxL2 and GRPxL3. For 3I0 to be calculated, connection is needed to all three phase inputs.
Page 442 Section 8 1MRK 505 343-UEN B Current protection The fault current, in the fault point, can be calculated as: × phase + × (Equation 492) EQUATION1944 V1 EN-US The impedance Z is dependent on the system earthing. In an isolated system (without neutral point apparatus) the impedance is equal to the capacitive coupling between the phase conductors and earth: ×...
Page 443 1MRK 505 343-UEN B Section 8 Current protection Source impedance (pos. seq) (pos. seq) (zero seq) Substation A (pos. seq) lineAB,1 (zero seq) lineAB,0 Substation B (pos. seq) lineBC,1 (zero seq) lineBC,0 Phase to earth fault en06000654.vsd IEC06000654 V1 EN-US Figure 286: Equivalent of power system for calculation of setting The residual fault current can be written: phase...
Page 444 Section 8 1MRK 505 343-UEN B Current protection × (Equation 499) EQUATION1951 V1 EN-US × (Equation 500) EQUATION1952 V1 EN-US The residual power is a complex quantity. The protection will have a maximum sensitivity in the characteristic angle RCA. The apparent residual power component in the characteristic angle, measured by the protection, can be written: ×...
Page 445 1MRK 505 343-UEN B Section 8 Current protection RCADir ROADir ang(3I ) ang(3U × 3I cos IEC06000648-4-en.vsd IEC06000648 V4 EN-US Figure 287: Characteristic for RCADir equal to 0° RCADir equal to -90° is shown in Figure 288. The characteristic is for ...
Page 446 Section 8 1MRK 505 343-UEN B Current protection RCADir = 0º ROADir = 80º Operate area IEC06000652-3-en.vsd IEC06000652 V3 EN-US Figure 289: Characteristic for RCADir = 0° and ROADir = 80° DirMode is set Forward or Reverse to set the direction of the operation for the directional OpMode .
Page 447 1MRK 505 343-UEN B Section 8 Current protection SN> is the operate power level for the directional function when OpMode is set 3I03U0Cosfi . The setting is given in % of SBase . The setting should be based on calculation of the active or capacitive earth fault residual power at required sensitivity of the protection.
Page 448: Thermal Overload Protection, One Time Constant, Celsius/Fahrenheit Lcpttr/Lfpttr
Section 8 1MRK 505 343-UEN B Current protection See chapter “Inverse time characteristics” in Technical Manual for the description of different characteristics tPCrv, tACrv, tBCrv, tCCrv : Parameters for customer creation of inverse time characteristic curve (Curve type = 17). The time characteristic equation is: æ...
Page 449: Setting Guideline
1MRK 505 343-UEN B Section 8 Current protection In stressed situations in the power system it can be required to overload lines and cables for a limited time. This should be done while managing the risks safely. The thermal overload protection provides information that makes a temporary overloading of cables and lines possible.
Page 450: Breaker Failure Protection Ccrbrf
Section 8 1MRK 505 343-UEN B Current protection Breaker failure protection CCRBRF IP14514-1 v6 8.8.1 Identification M14878-1 v5 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Breaker failure protection, 3-phase CCRBRF 50BF activation and output 3I>BF SYMBOL-U V1 EN-US 8.8.2 Application...
Page 451 1MRK 505 343-UEN B Section 8 Current protection CB Pos Check means that a phase current must be larger than the operate level to allow re-trip. (circuit breaker position check) and Contact means re-trip is done when circuit breaker is No CBPos Check means re-trip is done without check of closed (breaker position is used).
Page 452 Section 8 1MRK 505 343-UEN B Current protection t2 : Time delay of the back-up trip. The choice of this setting is made as short as possible at the same time as unwanted operation must be avoided. Typical setting is 90 – 200ms (also dependent of re-trip timer).
Page 453: Stub Protection Stbptoc
1MRK 505 343-UEN B Section 8 Current protection when gas pressure is low in a SF6 circuit breaker, of others. After the set time an alarm is given, so that actions can be done to repair the circuit breaker. The time delay for back-up trip is bypassed when the CBFLT is active.
Page 454: Setting Guidelines
Section 8 1MRK 505 343-UEN B Current protection IEC05000465 V2 EN-US Figure 291: Typical connection for STBPTOC in 1½-breaker arrangement. 8.9.3 Setting guidelines M12909-3 v5 The parameters for Stub protection STBPTOC 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 ), UBase ) and ( SBase ).
Page 455: Identification
1MRK 505 343-UEN B Section 8 Current protection 8.10.1 Identification M14888-1 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Pole discordance protection CCPDSC 52PD SYMBOL-S V1 EN-US 8.10.2 Application M13270-3 v6 There is a risk that a circuit breaker will get discordance between the poles at circuit breaker operation: closing or opening.
Page 456: Directional Underpower Protection Guppdup
Section 8 1MRK 505 343-UEN B Current protection CurrSel : Operation of the current based pole discordance protection. Can be set: Off / CB oper monitor / Continuous monitor . In the alternative CB oper monitor the function is activated only directly in connection to breaker open or close command (during 200 ms).
Page 457 1MRK 505 343-UEN B Section 8 Current protection When the steam ceases to flow through a turbine, the cooling of the turbine blades will disappear. Now, it is not possible to remove all heat generated by the windage losses. Instead, the heat will increase the temperature in the steam turbine and especially of the blades.
Page 458: Setting Guidelines
Section 8 1MRK 505 343-UEN B Current protection Underpower protection Overpower protection Operate Operate Line Line Margin Margin Operating point Operating point without without turbine torque turbine torque IEC09000019-2-en.vsd IEC09000019 V2 EN-US Figure 292: Reverse power protection with underpower or overpower protection 8.11.3 Setting guidelines SEMOD172134-4 v7...
Page 459 1MRK 505 343-UEN B Section 8 Current protection The function has two stages that can be set independently. OpMode1(2) the function can be set On / Off . With the parameter 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) Power1(2) Angle1(2)
Page 460 Section 8 1MRK 505 343-UEN B Current protection Operate ° Angle1(2) = 0 Power1(2) en06000556.vsd IEC06000556 V1 EN-US Figure 294: For low forward power the set angle should be 0° in the underpower function TripDelay1(2) is set in seconds to give the time delay for trip of the stage after pick up. Hysteresis1(2) is given in p.u.
Page 461: Directional Overpower Protection Goppdop
1MRK 505 343-UEN B Section 8 Current protection UAmpComp5, UAmpComp30, UAmpComp100 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.
Page 462 Section 8 1MRK 505 343-UEN B Current protection 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.
Page 463: Setting Guidelines
1MRK 505 343-UEN B Section 8 Current protection 8.12.3 Setting guidelines SEMOD172150-4 v7 GlobalBaseSel : Selects the global base value group used by the function to define ( IBase ), UBase ) and ( SBase ). Operation : With the parameter Operation the function can be set On / Off . Mode : The voltage and current used for the power measurement.
Page 464 Section 8 1MRK 505 343-UEN B Current protection Operate Power1(2) Angle1(2) en06000440.vsd IEC06000440 V1 EN-US Figure 296: Overpower mode Power1(2) gives the power component pick up value in the Angle1(2) direction. The The setting setting is given in p.u. of the generator rated power, see equation 530. Minimum recommended setting is 0.2% of S when metering class CT inputs into the IED are used.
Page 465 1MRK 505 343-UEN B Section 8 Current protection Angle1(2 ) = 180 Operate Power 1(2) IEC06000557-2-en.vsd IEC06000557 V2 EN-US Figure 297: For reverse power the set angle should be 180° in the overpower function TripDelay1(2) is set in seconds to give the time delay for trip of the stage after pick up. Hysteresis1(2) is given in p.u.
Page 466: Broken Conductor Check Brcptoc
Section 8 1MRK 505 343-UEN B Current protection IAmpComp5, IAmpComp30, IAmpComp100 UAmpComp5, UAmpComp30, UAmpComp100 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.
Page 467: Voltage-Restrained Time Overcurrent Protection Vrpvoc
1MRK 505 343-UEN B Section 8 Current protection 8.14 Voltage-restrained time overcurrent protection VRPVOC GUID-613620B1-4092-4FB6-901D-6810CDD5C615 v4 8.14.1 Identification GUID-7835D582-3FF4-4587-81CE-3B40D543E287 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Voltage-restrained time overcurrent VRPVOC I>/U< protection 8.14.2 Application GUID-622CDDDD-6D03-430E-A82D-861A4CBE067C v7 A breakdown of the insulation between phase conductors or a phase conductor and earth results in a short-circuit or an earth fault.
Page 468: Application Possibilities
Section 8 1MRK 505 343-UEN B Current protection UBase shall be entered as rated phase-to-phase voltage of the protected object in primary kV. 8.14.2.2 Application possibilities GUID-5053F964-C2D6-4611-B5EF-AC3DB0889F51 v5 VRPVOC function can be used in one of the following applications: • voltage controlled over-current •...
Page 469: Explanation Of The Setting Parameters
1MRK 505 343-UEN B Section 8 Current protection 8.14.3.1 Explanation of the setting parameters GUID-9B777E6D-602B-4214-9170-A44ED2D725BF v3 Operation : Set to On in order to activate the function; set to Off to switch off the complete function. StartCurr : Operation phase current level given in % of IBase . Characterist : Selection of time characteristic: Definite time delay and different types of inverse time characteristics are available;...
Page 470: Overcurrent Protection With Undervoltage Seal-In
Section 8 1MRK 505 343-UEN B Current protection • Inverse Time Over Current IDMT curve: IEC very inverse, with multiplier k=1 • Start current of 185% of generator rated current at rated generator voltage • Start current 25% of the original start current value for generator voltages below 25% of rated voltage To ensure proper operation of the function: Operation to On...
Page 471 1MRK 505 343-UEN B Section 8 Current protection The other parameters may be left at their default value. Application manual...
Page 473: Voltage Protection
1MRK 505 343-UEN B Section 9 Voltage protection Section 9 Voltage protection Two step undervoltage protection UV2PTUV IP14544-1 v3 9.1.1 Identification M16876-1 v6 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Two step undervoltage protection UV2PTUV 3U<...
Page 474: Equipment Protection, Such As For Motors And Generators
Section 9 1MRK 505 343-UEN B Voltage protection There is a very wide application area where general undervoltage functions are used. All voltage related settings are made as a percentage of the global settings base voltage UBase , which normally is set to the primary rated voltage level (phase-to-phase) of the power system or the high voltage equipment under consideration.
Page 475 1MRK 505 343-UEN B Section 9 Voltage protection < × UBase kV (Equation 533) EQUATION1447 V1 EN-US and operation for phase-to-phase voltage under: < × (%) UBase(kV) (Equation 534) EQUATION1990 V1 EN-US n = 1 or 2). Therefore, The below described setting parameters are identical for the two steps ( the setting parameters are described only once.
Page 476: Two Step Overvoltage Protection Ov2Ptov
Section 9 1MRK 505 343-UEN B Voltage protection CrvSatn × > (Equation 535) EQUATION1448 V1 EN-US IntBlkSeln : This parameter can be set to Off , Block of trip , Block all . In case of a low voltage the undervoltage function can be blocked.
Page 477: Setting Guidelines
1MRK 505 343-UEN B Section 9 Voltage protection overhead line, transformer flash over fault from the high voltage winding to the low voltage winding and so on). Malfunctioning of a voltage regulator or wrong settings under manual control (symmetrical voltage decrease). Low load compared to the reactive power generation (symmetrical voltage decrease).
Page 478: High Impedance Earthed Systems
Section 9 1MRK 505 343-UEN B Voltage protection 9.2.3.4 High impedance earthed systems M13852-19 v5 In high impedance earthed systems, earth-faults cause a voltage increase in the non-faulty phases. Two step overvoltage protection (OV2PTOV) is used to detect such faults. The setting must be above the highest occurring "normal"...
Page 479: Two Step Residual Overvoltage Protection Rov2Ptov
1MRK 505 343-UEN B Section 9 Voltage protection tResetn : Reset time for step n if definite time delay is used, given in s. The default value is 25 tnMin : Minimum operation time for inverse time characteristic for step n , given in s. For very high voltages the overvoltage function, using inverse time characteristic, can give very short t1Min longer than the operation operation time.
Page 480: Setting Guidelines
Section 9 1MRK 505 343-UEN B Voltage protection connection. The residual voltage can also be calculated internally, based on measurement of the three-phase voltages. In high impedance earthed systems the residual voltage will increase in case of any fault connected to earth. Depending on the type of fault and fault resistance the residual voltage will reach different values.
Page 481: Direct Earthed System
1MRK 505 343-UEN B Section 9 Voltage protection occurring "normal" residual voltage, and below the lowest occurring residual voltage during the faults under consideration. A metallic single-phase earth fault causes a transformer neutral to reach a voltage equal to the nominal phase-to-earth voltage. The voltage transformers measuring the phase-to-earth voltages measure zero voltage in the faulty phase.
Page 482: Settings For Two Step Residual Overvoltage Protection
Section 9 1MRK 505 343-UEN B Voltage protection IEC07000189 V1 EN-US Figure 300: Earth fault in Direct earthed system 9.3.3.6 Settings for Two step residual overvoltage protection M13853-21 v12 Operation : Off or On UBase (given in GlobalBaseSel ) is used as voltage reference for the voltage. The voltage can be fed to the IED in different ways: The IED is fed from a normal voltage transformer group where the residual voltage is calculated internally from the phase-to-earth voltages within the protection.
Page 483 1MRK 505 343-UEN B Section 9 Voltage protection > × UBase kV (Equation 539) IECEQUATION2290 V1 EN-US The setting is dependent of the required sensitivity of the protection and the system earthing. In non-effectively earthed systems the residual voltage can be maximum the rated phase-to- earth voltage, which should correspond to 100%.
Page 484: Overexcitation Protection Oexpvph
Section 9 1MRK 505 343-UEN B Voltage protection Overexcitation protection OEXPVPH IP14547-1 v3 9.4.1 Identification M14867-1 v3 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Overexcitation protection OEXPVPH U/f > SYMBOL-Q V1 EN-US 9.4.2 Application M13785-3 v6 When the laminated core of a power transformer is subjected to a magnetic flux density beyond its design limits, stray flux will flow into non-laminated components not designed to carry flux and cause eddy currents to flow.
Page 485: Setting Guidelines
1MRK 505 343-UEN B Section 9 Voltage protection Heat accumulated in critical parts during a period of overexcitation will be reduced gradually when the excitation returns to the normal value. If a new period of overexcitation occurs after a short time interval, the heating will start from a higher level, therefore, OEXPVPH must have thermal memory.
Page 486: Settings
Section 9 1MRK 505 343-UEN B Voltage protection RESET: OEXPVPH has a thermal memory, which can take a long time to reset. Activation of the RESET input will reset the function instantaneously. Recommendations for Output signals M6496-84 v7 Please see the default factory configuration for examples of configuration. ERROR: The output indicates a measuring error.
Page 487: Service Value Report
1MRK 505 343-UEN B Section 9 Voltage protection CurveType : Selection of the curve type for the inverse delay. The IEEE curves or tailor made curve can be selected depending of which one matches the capability curve best. kForIEEE : The time constant for the inverse characteristic. Select the one giving the best match to the transformer capability.
Page 488: Voltage Differential Protection Vdcptov
Section 9 1MRK 505 343-UEN B Voltage protection Table 41: Settings U/f op (%) Timer Time set (s) 7200 (max) Information on the cooling time constant T should be retrieved from the power cool transformer manufacturer. V/Hz transformer capability curve relay operate characteristic Continous 0.05...
Page 489: Application
1MRK 505 343-UEN B Section 9 Voltage protection 9.5.2 Application SEMOD153893-5 v3 The Voltage differential protection VDCPTOV functions can be used in some different applications. • Voltage unbalance protection for capacitor banks. The voltage on the bus is supervised with the voltage in the capacitor bank, phase- by phase. Difference indicates a fault, either short-circuited or open element in the capacitor bank.
Page 490: Setting Guidelines
Section 9 1MRK 505 343-UEN B Voltage protection The application to supervise the voltage on two voltage transformers in the generator circuit is shown in figure 304. To Protection Ud> To Excitation en06000389.vsd IEC06000389 V1 EN-US Figure 304: Supervision of fuses on generator circuit voltage transformers 9.5.3 Setting guidelines SEMOD153915-5 v3...
Page 491: Loss Of Voltage Check Lovptuv
1MRK 505 343-UEN B Section 9 Voltage protection tTrip : The time delay for tripping is set by this parameter. Normally, the delay does not need to be so short in capacitor bank applications as there is no fault requiring urgent tripping. tReset : The time delay for reset of tripping level element is set by this parameter.
Page 492: Advanced Users Settings
Section 9 1MRK 505 343-UEN B Voltage protection All settings are in primary values or per unit. Set operate level per phase to typically 70% of the global parameter UBase level. Set the time delay tTrip =5-20 seconds. 9.6.3.1 Advanced users settings SEMOD171929-8 v4 For advanced users the following parameters need also to be set.
Page 493 1MRK 505 343-UEN B Section 9 Voltage protection t3Ph : Time delay for three phase operation. IN> : Residual current detection in % of IBase. ResCurrCheck : Enabling of residual current check for delayed operation at single phase faults. Del1PhOp : Enabling of delayed single phase operation. t1Ph : Time delay for single phase operation.
Page 495: Section 10 Frequency Protection
1MRK 505 343-UEN B Section 10 Frequency protection Section 10 Frequency protection 10.1 Underfrequency protection SAPTUF IP15746-1 v3 10.1.1 Identification M14865-1 v5 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Underfrequency protection SAPTUF f < SYMBOL-P V1 EN-US 10.1.2 Application M13350-3 v4...
Page 496: Overfrequency Protection Saptof
Section 10 1MRK 505 343-UEN B Frequency protection The under frequency START value is set in Hz. All voltage magnitude related settings are made as a percentage of a global base voltage parameter. The UBase value should be set as a primary phase-to-phase value.
Page 497: Setting Guidelines
1MRK 505 343-UEN B Section 10 Frequency protection 10.2.3 Setting guidelines M14959-3 v7 All the frequency and voltage magnitude conditions in the system where SAPTOF performs its functions must be considered. The same also applies to the associated equipment, its frequency and time characteristic.
Page 498: Setting Guidelines
Section 10 1MRK 505 343-UEN B Frequency protection with a low frequency signal, especially in smaller power systems, where loss of a fairly large generator will require quick remedial actions to secure the power system integrity. In such situations load shedding actions are required at a rather high frequency level, but in combination with a large negative rate-of-change of frequency the underfrequency protection can be used at a rather high setting.
Page 499: Section 11 Multipurpose Protection
1MRK 505 343-UEN B Section 11 Multipurpose protection Section 11 Multipurpose protection 11.1 General current and voltage protection CVGAPC IP14552-1 v2 11.1.1 Identification M14886-2 v3 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number General current and voltage CVGAPC 2(I>/U<) protection...
Page 500: Current And Voltage Selection For Cvgapc Function
Section 11 1MRK 505 343-UEN B Multipurpose protection • Definite time delay for both steps Two overvoltage steps with the following built-in features • Definite time delay or Inverse Time Overcurrent TOC/IDMT delay for both steps Two undervoltage steps with the following built-in features •...
Page 501 1MRK 505 343-UEN B Section 11 Multipurpose protection Set value for parameter Comment "CurrentInput” phase3 - phase1 CVGAPC function will measure the current phasor internally calculated as the vector difference between the phase L3 current phasor and phase L1 current phasor ( IL3-IL1) MaxPh-Ph CVGAPC function will measure ph-ph current phasor with the maximum magnitude...
Page 502: Base Quantities For Cvgapc Function
Section 11 1MRK 505 343-UEN B Multipurpose protection Set value for parameter Comment "VoltageInput" MaxPh-Ph CVGAPC function will measure ph-ph voltage phasor with the maximum magnitude MinPh-Ph CVGAPC function will measure ph-ph voltage phasor with the minimum magnitude UnbalancePh-Ph CVGAPC function will measure magnitude of unbalance voltage, which is internally calculated as the algebraic magnitude difference between the ph-ph voltage phasor with maximum magnitude and ph-ph voltage phasor with minimum magnitude.
Page 503: Inadvertent Generator Energization
1MRK 505 343-UEN B Section 11 Multipurpose protection • Special thermal overload protection • Open Phase protection • Unbalance protection Generator protection • 80-95% Stator earth fault protection (measured or calculated 3Uo) • Rotor earth fault protection (with external COMBIFLEX RXTTE4 injection unit) •...
Page 504: Setting Guidelines
Section 11 1MRK 505 343-UEN B Multipurpose protection will, with a delay for example 10 s, detect the situation when the generator is not connected to the grid (standstill) and activate the overcurrent function. The overvoltage function will detect the situation when the generator is taken into operation and will disable the overcurrent function.
Page 505: Negative Sequence Overcurrent Protection
1MRK 505 343-UEN B Section 11 Multipurpose protection Enable one overcurrent stage (for example, OC1) 10. By parameter CurveType_OC1 select appropriate TOC/IDMT or definite time delayed curve in accordance with your network protection philosophy StartCurr_OC1 to value between 3-10% (typical values) 11.
Page 506 Section 11 1MRK 505 343-UEN B Multipurpose protection æ ö ç ÷ è ø (Equation 541) EQUATION1372 V1 EN-US where: is the operating time in seconds of the negative sequence overcurrent IED is the generator capability constant in seconds is the measured negative sequence current is the generator rated current By defining parameter x equal to maximum continuous negative sequence rating of the generator in accordance with the following formula...
Page 507: Generator Stator Overload Protection In Accordance With Iec Or Ansi Standards
1MRK 505 343-UEN B Section 11 Multipurpose protection When the equation is compared with the equation for the inverse time characteristic of the OC1 it is obvious that if the following rules are followed: set k equal to the generator negative sequence capability value A_OC1 equal to the value 1/x2 B_OC1 = 0.0, C_OC1 =0.0 and P_OC1 =2.0 StartCurr_OC1 equal to the value x...
Page 508 Section 11 1MRK 505 343-UEN B Multipurpose protection 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 desired pickup for the overload IED in accordance with the following formula: x = 116% = 1.16 pu (Equation 546)
Page 509: Open Phase Protection For Transformer, Lines Or Generators And Circuit Breaker Head Flashover Protection For Generators
1MRK 505 343-UEN B Section 11 Multipurpose protection select positive sequence current as measuring quantity for this CVGAPC function make sure that the base current value for CVGAPC function is equal to the generator rated current set k = 37.5 for the IEC standard or k = 41.4 for the ANSI standard A_OC1 = 1/1.162 = 0.7432 C_OC1 = 1/1.162 = 0.7432 B_OC1 = 0.0 and P_OC1 = 2.0...
Page 510: Voltage Restrained Overcurrent Protection For Generator And Step-Up Transformer
Section 11 1MRK 505 343-UEN B Multipurpose protection 11.1.3.5 Voltage restrained overcurrent protection for generator and step-up transformer M13088-158 v3 Example will be given how to use one CVGAPC function to provide voltage restrained overcurrent protection for a generator. Let us assume that the time coordination study gives the following required settings: •...
Page 511 1MRK 505 343-UEN B Section 11 Multipurpose protection ROADir to value 90 degree Set parameter Set parameter LowVolt_VM to value 5% Enable one overcurrent step (for example, OC1) CurveType_OC1 to value IEC Def. Time 10. Select parameter StartCurr_OC1 to value 38% 11.
Page 513: Section 12 System Protection And Control
1MRK 505 343-UEN B Section 12 System protection and control Section 12 System protection and control 12.1 Multipurpose filter SMAIHPAC GUID-6B541154-D56B-452F-B143-4C2A1B2D3A1F v1 12.1.1 Identification GUID-8224B870-3DAA-44BF-B790-6600F2AD7C5D v1 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Multipurpose filter SMAIHPAC 12.1.2 Application...
Page 514: Setting Guidelines
Section 12 1MRK 505 343-UEN B System protection and control The following figure shoes typical configuration connections required to utilize this filter in conjunction with multi-purpose function as non-directional overcurrent protection. IEC13000179-1-en.vsd IEC13000179 V1 EN-US Figure 306: Required ACT configuration Such overcurrent arrangement can be for example used to achieve the subsynchronous resonance protection for turbo generators.
Page 515 1MRK 505 343-UEN B Section 12 System protection and control In order to properly extract the weak subsynchronous signal in presence of the dominating 50Hz signal the SMAI HPAC filter shall be set as given in the following table: Table 44: Proposed settings for SMAIHPAC I_HPAC_31_5Hz: SMAIHPAC:1 ConnectionType Ph —...
Page 516 Section 12 1MRK 505 343-UEN B System protection and control Setting Group1 Operation CurrentInput MaxPh IBase 1000 VoltageInput MaxPh UBase 20.50 OPerHarmRestr I_2ndI_fund 20.0 BlkLevel2nd 5000 EnRestrainCurr RestrCurrInput PosSeq RestrCurrCoeff 0.00 RCADir ROADir LowVolt_VM Setting Group1 Operation_OC1 StartCurr_OC1 30.0 CurrMult_OC1 CurveType_OC1 Programmable tDef_OC1...
Page 517: Section 13 Secondary System Supervision
1MRK 505 343-UEN B Section 13 Secondary system supervision Section 13 Secondary system supervision 13.1 Current circuit supervision CCSSPVC IP14555-1 v5 13.1.1 Identification M14870-1 v5 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Current circuit supervision CCSSPVC 13.1.2 Application...
Page 518: Fuse Failure Supervision Fufspvc
Section 13 1MRK 505 343-UEN B Secondary system supervision Ip>Block is normally set at 150% to block the function during transient The parameter conditions. The FAIL output is connected to the blocking input of the protection function to be blocked at faulty CT secondary circuits.
Page 519: Setting Guidelines
1MRK 505 343-UEN B Section 13 Secondary system supervision 13.2.3 Setting guidelines IP15000-1 v1 13.2.3.1 General M13683-3 v5 The negative and zero sequence voltages and currents always exist due to different non- symmetries in the primary system and differences in the current and voltage instrument transformers.
Page 520: Zero Sequence Based
Section 13 1MRK 505 343-UEN B Secondary system supervision   UBase (Equation 553) EQUATION1519 V5 EN-US where: is the maximal negative sequence voltage during normal operation conditions, plus a margin of 10...20% UBase GlobalBaseSel is the base voltage for the function according to the setting 3I2<...
Page 521: Delta U And Delta I
1MRK 505 343-UEN B Section 13 Secondary system supervision 13.2.3.5 Delta U and delta I GUID-02336F26-98C0-419D-8759-45F5F12580DE v7 OpDUDI to On if the delta function shall be in operation. Set the operation mode selector The setting of DU> should be set high (approximately 60% of UBase ) and the current threshold DI<...
Page 522: Setting Guidelines
Section 13 1MRK 505 343-UEN B Secondary system supervision and energisation-check function. These functions might mal-operate if there is an incorrect measured voltage due to fuse failure or other kind of faults in voltage measurement circuit. VDSPVC is designed to detect fuse failures or faults in voltage measurement circuit based on comparison of the voltages of the main and pilot fused circuits phase wise.
Page 523 1MRK 505 343-UEN B Section 13 Secondary system supervision UBase is available in the Global Base Value groups; the particular Global Base transformer. Value group, that is used by VDSPVC, is set by the setting parameter GlobalBaseSel . Ud>MainBlock and Ud>PilotAlarm should be set low (approximately 30% of The settings UBase ) so that they are sensitive to the fault on the voltage measurement circuit, since the voltage on both sides are equal in the healthy condition.
Page 525: Section 14 Control
1MRK 505 343-UEN B Section 14 Control Section 14 Control 14.1 Synchrocheck, energizing check, and synchronizing SESRSYN IP14558-1 v4 14.1.1 Identification M14889-1 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Synchrocheck, energizing check, and SESRSYN synchronizing sc/vc SYMBOL-M V1 EN-US...
Page 526: Synchrocheck
Section 14 1MRK 505 343-UEN B Control 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 SlipFrequency and the set tBreaker the operation pulse sent in advance is using the measured time.
Page 527 1MRK 505 343-UEN B Section 14 Control need for a check of synchronization increases if the meshed system decreases since the risk of the two networks being out of synchronization at manual or automatic closing is greater. The synchrocheck function measures the conditions across the circuit breaker and compares them to set limits.
Page 528: Energizing Check
Section 14 1MRK 505 343-UEN B Control 14.1.2.3 Energizing check M12310-3 v11 The main purpose of the energizing check function is to facilitate the controlled re-connection of disconnected lines and buses to energized lines and buses. The energizing check function measures the bus and line voltages and compares them to both high and low threshold values.
Page 529: External Fuse Failure
(B16I). If the PSTO input is used, connected to the Local-Remote switch on the local HMI, the choice can also be from the station HMI system, typically ABB Microscada through IEC 61850–8–1 communication.
Page 530: Application Examples
Section 14 1MRK 505 343-UEN B Control 14.1.3 Application examples M12323-3 v6 The synchronizing function block can also be used in some switchyard arrangements, but with different parameter settings. Below are some examples of how different arrangements are connected to the IED analogue inputs and to the function block SESRSYN. One function block is used per circuit breaker.
Page 531: Single Circuit Breaker With Double Busbar, External Voltage Selection
1MRK 505 343-UEN B Section 14 Control 14.1.3.2 Single circuit breaker with double busbar, external voltage selection M12325-3 v8 WA1_VT/ SESRSYN WA2_VT U3PBB1* GRP_OFF U3PBB2* LINE_VT U3PLN1* WA2_MCB WA1_MCB U3PLN2* WA1_MCB/ WA1_MCB / WA2_MCB WA2_MCB UB1OK UB1FF LINE_MCB ULN1OK WA1_VT / WA2_VT ULN1FF LINE_MCB LINE_VT...
Page 532: Double Circuit Breaker
Section 14 1MRK 505 343-UEN B Control 14.1.3.4 Double circuit breaker M12329-3 v7 WA1_QA1 SESRSYN WA1_VT U3PBB1* U3PBB2* GRP_OFF LINE_VT U3PLN1* U3PLN2* WA2_ WA1_MCB UB1OK WA1_MCB WA2_MCB UB1FF WA1_MCB LINE_MCB ULN1OK WA1_VT ULN1FF WA2_VT WA1_QA1 WA2_QA1 WA2_QA1 SESRSYN WA2_VT U3PBB1* U3PBB2* GRP_OFF LINE_VT...
Page 533 1MRK 505 343-UEN B Section 14 Control Setting parameter CBConfig = 1 ½ bus CB WA1_QA1 WA1_VT SESRSYN U3 PBB1* WA2_VT U3 PBB2* LINE1_VT U3 PLN1* LINE2_VT U3 PLN2* TIE_QA1 B1 QOPEN B1 QCLD WA2_QA1 B2 QOPEN B2 QCLD LINE1_QB9 LN1 QOPEN LN1 QCLD LINE2_QB9...
Page 534: Setting Guidelines
Section 14 1MRK 505 343-UEN B Control WA1_QA1: • B1QOPEN/CLD = Position of TIE_QA1 breaker and belonging disconnectors • B2QOPEN/CLD = Position of WA2_QA1 breaker and belonging disconnectors • LN1QOPEN/CLD = Position of LINE1_QB9 disconnector • LN2QOPEN/CLD = Position of LINE2_QB9 disconnector •...
Page 535 1MRK 505 343-UEN B Section 14 Control General settings Operation : The operation mode can be set On or Off . The setting Off 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 reference voltage, for bus and line respectively.
Page 536 Section 14 1MRK 505 343-UEN B Control Setting of the voltage difference between the line voltage and the bus voltage. The difference is set depending on the network configuration and expected voltages in the two networks running asynchronously. A normal setting is 0.10-0.15 p.u. FreqDiffMin The setting FreqDiffMin is the minimum frequency difference where the systems are defined...
Page 537 1MRK 505 343-UEN B Section 14 Control Synchrocheck settings OperationSC OperationSC setting Off disables the synchrocheck function and sets the outputs On , the function is AUTOSYOK, MANSYOK, TSTAUTSY and TSTMANSY to low. With the setting in the service mode and the output signal depends on the input conditions. UHighBusSC and UHighLineSC The voltage level settings must be chosen in relation to the bus or line network voltage.
Page 538: Autorecloser For 1 Phase, 2 Phase And/Or 3 Phase Operation Smbrrec
Section 14 1MRK 505 343-UEN B Control ManEnergDBDL On , manual closing is also enabled when both line voltage and bus If the parameter is set to ULowLineEnerg and ULowBusEnerg respectively, and ManEnerg is set to voltage are below DLLB , DBLL or Both . UHighBusEnerg and UHighLineEnerg The voltage level settings must be chosen in relation to the bus or line network voltage.
Page 539: Application
1MRK 505 343-UEN B Section 14 Control 14.2.2 Application M12391-3 v7 Automatic reclosing is a well-established method for the restoration of service in a power system after a transient line fault. The majority of line faults are flashover arcs, which are transient by nature.
Page 540 Section 14 1MRK 505 343-UEN B Control To maximize the availability of the power system it is possible to choose single pole tripping and automatic reclosing during single-phase faults and three pole tripping and automatic reclosing during multi-phase faults. Three-phase automatic reclosing can be performed with or without the use of a synchronicity check, and an energizing check, such as dead line or dead busbar check.
Page 541: Auto-Reclosing Operation Off And On
1MRK 505 343-UEN B Section 14 Control check. In order to limit the stress on turbo-generator sets from Auto-Reclosing onto a permanent fault, one can arrange to combine Auto-Reclosing with a synchrocheck on line terminals close to such power stations and attempt energizing from the side furthest away from the power station and perform the synchrocheck at the local end if the energizing was successful.
Page 542: Start Auto-Reclosing And Conditions For Start Of A Reclosing Cycle
Section 14 1MRK 505 343-UEN B Control 14.2.2.2 Start auto-reclosing and conditions for start of a reclosing cycle M12391-94 v4 The usual way to start a reclosing cycle, or sequence, is to start it at selective tripping by line protection by applying a signal to the input START. Starting signals can be either, General Trip signals or, only the conditions for Differential, Distance protection Zone 1 and Distance protection Aided trip.
Page 543: Long Trip Signal
1MRK 505 343-UEN B Section 14 Control t1 1Ph will be used. If one of the phase reclosing is selected, the auto-reclosing open time inputs TR2P or TR3P is activated in connection with the start, the auto-reclosing open time for two-phase or three-phase reclosing is used.
Page 544: Armode = 1/2Ph , 1-Phase Or 2-Phase Reclosing In The First Shot
Section 14 1MRK 505 343-UEN B Control While any of the auto-reclosing open time timers are running, the output INPROGR is activated. When the "open time" timer runs out, the respective internal signal is transmitted to the output module for further checks and to issue a closing command to the circuit breaker. When a CB closing command is issued the output prepare 3-phase trip is set.
Page 545: External Selection Of Auto-Reclose Mode
1MRK 505 343-UEN B Section 14 Control MODEINT (integer) ARMode Type of fault 1st shot 2nd-5th shot 1/2/3ph 1/2ph ..1ph + 1*2ph ....1/2ph + 1*3ph ..1ph + 1*2/3ph ..A start of a new reclosing cycle is blocked during the set “reclaim time” after the selected number of reclosing shots have been made.
Page 546: Pulsing Of The Cb Closing Command And Counter
Section 14 1MRK 505 343-UEN B Control 14.2.2.16 Pulsing of the CB closing command and Counter M12391-205 v3 The CB closing command, CLOSECB is given as a pulse with a duration set by parameter tPulse . For circuit-breakers without an anti-pumping function, close pulse cutting can be used. CutPulse=On .
Page 547: Evolving Fault
1MRK 505 343-UEN B Section 14 Control In figures the logic shows how a closing Lock-out logic can be designed with the Lock-out relay as an external relay alternatively with the Lock-out created internally with the manual closing going through the Synchro-check function. An example of Lock-out logic. SMBRREC BU-TRIP INHIBIT...
Page 548: Automatic Continuation Of The Reclosing Sequence
Section 14 1MRK 505 343-UEN B Control tripping. This signal will, for evolving fault situations be activated a short time after the first trip has reset and will thus ensure that new trips will be three phase. 14.2.2.21 Automatic continuation of the reclosing sequence M12391-223 v4 SMBRREC function can be programmed to proceed to the following reclosing shots (if multiple shots are selected) even if start signals are not received from the protection functions, but the...
Page 549 1MRK 505 343-UEN B Section 14 Control breaker failure protection. When the CB open position is set to start SMBRREC, then manual opening must also be connected here. The inhibit is often a combination of signals from external IEDs via the IO and internal functions. An OR gate is then used for the combination. CBPOS and CBREADY These should be connected to binary inputs to pick-up information from the CB.
Page 550 Section 14 1MRK 505 343-UEN B Control BLKON Used to block the autorecloser for 3-phase operation (SMBRREC) function for example, when certain special service conditions arise. When used, blocking must be reset with BLOCKOFF. BLOCKOFF Used to Unblock SMBRREC function when it has gone to Block due to activating input BLKON or by an unsuccessful Auto-Reclose attempt if the setting BlockByUnsucCl is set to On .
Page 551 1MRK 505 343-UEN B Section 14 Control PREP3P Prepare three-phase trip is usually connected to the trip block to force a coming trip to be a three-phase one. If the function cannot make a single-phase or two-phase reclosing, the tripping should be three-phase. PERMIT1P Permit single-phase trip is the inverse of PREP3P.
Page 552 Section 14 1MRK 505 343-UEN B Control While the reclosing of the master is in progress, it issues the signal WFMASTER. A reset delay of one second ensures that the WAIT signal is kept high for the duration of the breaker closing time.
Page 553: Auto-Recloser Parameter Settings
1MRK 505 343-UEN B Section 14 Control Terminal ‘‘ Master ” Priority = High SMBRREC BLOCKED SETON BLKON INPROGR BLOCKOFF ACTIVE UNSUCCL INHIBIT SUCCL RESET PLCLOST READY START CLOSECB STARTHS PERMIT1P SKIPHS PREP3P THOLHOLD TRSOTF 1PT1 2PT1 CBREADY 3PT1 CBPOS 3PT2 3PT3 SYNC...
Page 554 Section 14 1MRK 505 343-UEN B Control M12399-97 v8 Operation The operation of the Autorecloser for 1/2/3-phase operation (SMBRREC) function can be On and Off . The setting ExternalCtrl makes it possible to switch it On or Off using an switched external switch via IO or communication ports.
Page 555 1MRK 505 343-UEN B Section 14 Control At a setting somewhat longer than the auto-reclosing open time, this facility will not influence the reclosing. A typical setting of tTrip could be close to the auto-reclosing open time. tInhibit , Inhibit resetting delay tInhibit = 5.0 s to ensure reliable interruption and temporary blocking of the A typical setting is tinhibit has been activated.
Page 556: Apparatus Control Apc
Section 14 1MRK 505 343-UEN B Control UnsucClByCBCheck , Unsuccessful closing by CB check NoCBCheck . The “auto-reclosing unsuccessful” event is then decided by The normal setting is a new trip within the reclaim time after the last reclosing shot. If one wants to get the UNSUCCL (Unsuccessful closing) signal in the case the CB does not respond to the closing UnsucClByCBCheck = CB Check and set tUnsucCl for instance command, CLOSECB, one can set...
Page 557 1MRK 505 343-UEN B Section 14 Control Station HMI Station bus Local Local Local Apparatus Apparatus Apparatus Control Control Control breakers disconnectors earthing switches IEC08000227.vsd IEC08000227 V1 EN-US Figure 324: Overview of the apparatus control functions Features in the apparatus control function: •...
Page 558 Section 14 1MRK 505 343-UEN B Control The signal flow between the function blocks is shown in Figure 325. To realize the reservation function, the function blocks Reservation input (RESIN) and Bay reserve (QCRSV) also are included in the apparatus control function. The application description for all these functions can be found below.
Page 559: Bay Control (Qcbay)
1MRK 505 343-UEN B Section 14 Control 2 = Remote 2,3,4,5,6 3 = Faulty 4,5,6 4 = Not in use 4,5,6 5 = All 1,2,3,4,5,6 6 = Station 2,4,5,6 7 = Remote 3,4,5,6 PSTO = All, then it is no priority between operator places. All operator places are allowed to operate.
Page 560: Switch Controller (Scswi)
Section 14 1MRK 505 343-UEN B Control IEC13000016-2-en.vsd IEC13000016 V2 EN-US Figure 326: APC - Local remote function block 14.3.1.2 Switch controller (SCSWI) M16596-3 v4 SCSWI may handle and operate on one three-phase device or three one-phase switching devices. After the selection of an apparatus and before the execution, the switch controller performs the following checks and actions: •...
Page 561: Switches (Sxcbr/Sxswi)
1MRK 505 343-UEN B Section 14 Control 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 discordance situation, that is, the positions of the one-phase switches are not equal for a time longer than a settable time;...
Page 562 Section 14 1MRK 505 343-UEN B Control transferred over the station bus for evaluation in the IED. After the evaluation the operation can be executed with high security. This functionality is realized over the station bus by means of the function blocks QCRSV and RESIN.
Page 563: Interaction Between Modules
1MRK 505 343-UEN B Section 14 Control The solution in Figure can also be realized over the station bus according to the application example in Figure 329. The solutions in Figure and Figure do not have the same high security compared to the solution in Figure 327, but instead have a higher availability, since no acknowledgment is required.
Page 564: Setting Guidelines
Section 14 1MRK 505 343-UEN B Control SMPPTRC SESRSYN Synchronizing (Trip logic) (Synchrocheck & Synchronizer) in progress Trip Synchrocheck QCBAY Operator place (Bay control) selection Open cmd Close cmd Res. req. SCSWI SXCBR (Switching control) Res. granted (Circuit breaker) QCRSV (Reservation) Res.
Page 565: Switch Controller (Scswi)
1MRK 505 343-UEN B Section 14 Control LocSta is true, only commands from station level are accepted, otherwise only commands from remote level are accepted. RemoteIncStation has only effect on the IEC61850-8-1 The parameter communication. Further, when using IEC61850 edition 1 communication, the Yes , since the command LocSta is not defined in parameter should be set to IEC61850-8-1 edition 1.
Page 566: Switch (Sxcbr/Sxswi)
Section 14 1MRK 505 343-UEN B Control 14.3.3.3 Switch (SXCBR/SXSWI) M16675-3 v7 tStartMove is the supervision time for the apparatus to start moving after a command execution. When the time has expired, the switch function is reset, and a cause-code is given. tIntermediate time the position indication is allowed to be in an intermediate (00) During the state.
Page 567: Configuration Guidelines
1MRK 505 343-UEN B Section 14 Control • With basically zero current. The circuit is open on one side and has a small extension. The capacitive current is small (for example, < 5A) and power transformers with inrush current are not allowed. •...
Page 568: Application
Section 14 1MRK 505 343-UEN B Control 14.4.2.1 Application M13561-3 v8 The interlocking for line bay (ABC_LINE) function is used for a line connected to a double busbar arrangement with a transfer busbar according to figure 331. The function can also be used for a double busbar arrangement without transfer busbar or a single busbar arrangement with/without transfer busbar.
Page 569: Signals From Bus-Coupler
1MRK 505 343-UEN B Section 14 Control QB7OPTR (bay 1) BB7_D_OP QB7OPTR (bay 2) & ..QB7OPTR (bay n-1) VPQB7TR (bay 1) VP_BB7_D VPQB7TR (bay 2) & ..VPQB7TR (bay n-1) EXDU_BPB (bay 1) EXDU_BPB EXDU_BPB (bay 2)
Page 570 Section 14 1MRK 505 343-UEN B Control 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 and WA7.
Page 571: Configuration Setting
1MRK 505 343-UEN B Section 14 Control BC12CLTR (sect.1) BC_12_CL DCCLTR (A1A2) >1 & DCCLTR (B1B2) BC12CLTR (sect.2) VPBC12TR (sect.1) VP_BC_12 & VPDCTR (A1A2) VPDCTR (B1B2) VPBC12TR (sect.2) BC17OPTR (sect.1) BC_17_OP & DCOPTR (A1A2) >1 BC17OPTR (sect.2) BC17CLTR (sect.1) BC_17_CL >1 DCCLTR (A1A2) &...
Page 572: Interlocking For Bus-Coupler Bay Abc_Bc
Section 14 1MRK 505 343-UEN B Control • QC71_OP = 1 • QC71_CL = 0 • BB7_D_OP = 1 • BC_17_OP = 1 • BC_17_CL = 0 • BC_27_OP = 1 • BC_27_CL = 0 • EXDU_BPB = 1 • VP_BB7_D = 1 •...
Page 573: Configuration
1MRK 505 343-UEN B Section 14 Control WA1 (A) WA2 (B) WA7 (C) QB20 en04000514.vsd IEC04000514 V1 EN-US Figure 335: Switchyard layout ABC_BC 14.4.3.2 Configuration M13553-138 v4 The signals from the other bays connected to the bus-coupler module ABC_BC are described below.
Page 574 Section 14 1MRK 505 343-UEN B Control QB12OPTR (bay 1) BBTR_OP QB12OPTR (bay 2) & ..QB12OPTR (bay n-1) VPQB12TR (bay 1) VP_BBTR VPQB12TR (bay 2) & ..VPQB12TR (bay n-1) EXDU_12 (bay 1) EXDU_12 EXDU_12 (bay 2)
Page 575: Signals From Bus-Coupler
1MRK 505 343-UEN B Section 14 Control For a bus-coupler bay in section 1, these conditions are valid: BBTR_OP (sect.1) BBTR_OP DCOPTR (A1A2) & >1 DCOPTR (B1B2) BBTR_OP (sect.2) VP_BBTR (sect.1) VP_BBTR & VPDCTR (A1A2) VPDCTR (B1B2) VP_BBTR (sect.2) EXDU_12 (sect.1) EXDU_12 &...
Page 576: Configuration Setting
Section 14 1MRK 505 343-UEN B Control These signals from each bus-section disconnector bay (A1A2_DC) are also needed. For B1B2_DC, corresponding signals from busbar B are used. The same type of module (A1A2_DC) is used for different busbars, that is, for both bus-section disconnector A1A2_DC and B1B2_DC. Signal DCCLTR The bus-section disconnector is closed.
Page 577: Interlocking For Transformer Bay Ab_Trafo
1MRK 505 343-UEN B Section 14 Control • QC71_OP = 1 • QC71_CL = 0 If there is no second busbar B and therefore no QB2 and QB20 disconnectors, then the interlocking for QB2 and QB20 are not used. The states for QB2, QB20, QC21, BC_12, BBTR are set to open by setting the appropriate module inputs as follows.
Page 578: Signals From Bus-Coupler
Section 14 1MRK 505 343-UEN B Control WA1 (A) WA2 (B) AB_TRAFO QA2 and QC4 are not used in this interlocking en04000515.vsd IEC04000515 V1 EN-US Figure 341: Switchyard layout AB_TRAFO M13566-4 v4 The signals from other bays connected to the module AB_TRAFO are described below. 14.4.4.2 Signals from bus-coupler M13566-6 v4...
Page 579: Configuration Setting
1MRK 505 343-UEN B Section 14 Control 14.4.4.3 Configuration setting M13566-22 v5 If there are no second busbar B and therefore no QB2 disconnector, then the interlocking for QB2 is not used. The state for QB2, QC21, BC_12 are set to open by setting the appropriate module inputs as follows.
Page 580 Section 14 1MRK 505 343-UEN B Control connection exists between busbars on one bus-section side and if on the other bus-section side a busbar transfer is in progress: Section 1 Section 2 (WA1)A1 (WA2)B1 (WA7)C A1A2_BS ABC_BC ABC_BC B1B2_BS ABC_LINE AB_TRAFO ABC_LINE AB_TRAFO...
Page 581 1MRK 505 343-UEN B Section 14 Control S1S2OPTR (B1B2) BC12OPTR (sect.1) >1 QB12OPTR (bay 1/sect.2) . . . & & BBTR_OP . . . QB12OPTR (bay n/sect.2) S1S2OPTR (B1B2) BC12OPTR (sect.2) >1 QB12OPTR (bay 1/sect.1) . . . & . . . QB12OPTR (bay n /sect.1) VPS1S2TR (B1B2) VPBC12TR (sect.1)
Page 582: Configuration Setting
Section 14 1MRK 505 343-UEN B Control S1S2OPTR (A1A2) BC12OPTR (sect.1) >1 QB12OPTR (bay 1/sect.2) . . . & & BBTR_OP . . . QB12OPTR (bay n/sect.2) S1S2OPTR (A1A2) BC12OPTR (sect.2) >1 QB12OPTR (bay 1/sect.1) . . . & . . . QB12OPTR (bay n /sect.1) VPS1S2TR (A1A2) VPBC12TR (sect.1)
Page 583: Application
1MRK 505 343-UEN B Section 14 Control 14.4.6.1 Application M13544-3 v7 The interlocking for bus-section disconnector (A1A2_DC) function is used for one bus-section disconnector between section 1 and 2 according to figure 347. A1A2_DC function can be used for different busbars, which includes a bus-section disconnector. WA1 (A1) WA2 (A2) A1A2_DC...
Page 584 Section 14 1MRK 505 343-UEN B Control Signal QB1OPTR QB1 is open. QB2OPTR QB2 is open (AB_TRAFO, ABC_LINE). QB220OTR QB2 and QB20 are open (ABC_BC). VPQB1TR The switch status of QB1 is valid. VPQB2TR The switch status of QB2 is valid. VQB220TR The switch status of QB2 and QB20 are valid.
Page 585 1MRK 505 343-UEN B Section 14 Control QB1OPTR (bay 1/sect.A2) S2DC_OP . . . & ..QB1OPTR (bay n/sect.A2) DCOPTR (A2/A3) VPQB1TR (bay 1/sect.A2) VPS2_DC . . . & ..VPQB1TR (bay n/sect.A2) VPDCTR (A2/A3) EXDU_BB (bay 1/sect.A2)
Page 586: Signals In Double-Breaker Arrangement
Section 14 1MRK 505 343-UEN B Control QB2OPTR (QB220OTR)(bay 1/sect.B2) S2DC_OP . . . & ..QB2OPTR (QB220OTR)(bay n/sect.B2) DCOPTR (B2/B3) VPQB2TR(VQB220TR) (bay 1/sect.B2) VPS2_DC . . . & ..VPQB2TR(VQB220TR) (bay n/sect.B2) VPDCTR (B2/B3) EXDU_BB (bay 1/sect.B2)
Page 587 1MRK 505 343-UEN B Section 14 Control Signal QB1OPTR QB1 is open. QB2OPTR QB2 is open. VPQB1TR The switch status of QB1 is valid. VPQB2TR The switch status of QB2 is valid. EXDU_DB No transmission error from the bay that contains the above information. The logic is identical to the double busbar configuration “Signals in single breaker arrangement”.
Page 588: Signals In 1 1/2 Breaker Arrangement
Section 14 1MRK 505 343-UEN B Control QB2OPTR (bay 1/sect.B1) S1DC_OP . . . & ..QB2OPTR (bay n/sect.B1) VPQB2TR (bay 1/sect.B1) VPS1_DC . . . & ..VPQB2TR (bay n/sect.B1) EXDU_DB (bay 1/sect.B1) EXDU_BB .
Page 589: Interlocking For Busbar Earthing Switch Bb_Es
1MRK 505 343-UEN B Section 14 Control The project-specific logic is the same as for the logic for the double-breaker configuration. Signal S1DC_OP All disconnectors on bus-section 1 are open. S2DC_OP All disconnectors on bus-section 2 are open. VPS1_DC The switch status of disconnectors on bus-section 1 is valid. VPS2_DC The switch status of disconnectors on bus-section 2 is valid.
Page 590 Section 14 1MRK 505 343-UEN B Control These signals from each line bay (ABC_LINE), each transformer bay (AB_TRAFO), and each bus- coupler bay (ABC_BC) are needed: Signal QB1OPTR QB1 is open. QB2OPTR QB2 is open (AB_TRAFO, ABC_LINE) QB220OTR QB2 and QB20 are open (ABC_BC) QB7OPTR QB7 is open.
Page 591 1MRK 505 343-UEN B Section 14 Control QB1OPTR (bay 1/sect.A1) BB_DC_OP . . . & ..QB1OPTR (bay n/sect.A1) DCOPTR (A1/A2) VPQB1TR (bay 1/sect.A1) VP_BB_DC . . . & ..VPQB1TR (bay n/sect.A1) VPDCTR (A1/A2) EXDU_BB (bay 1/sect.A1)
Page 592 Section 14 1MRK 505 343-UEN B Control QB2OPTR(QB220OTR)(bay 1/sect.B1) BB_DC_OP . . . & ..QB2OPTR (QB220OTR)(bay n/sect.B1) DCOPTR (B1/B2) VPQB2TR(VQB220TR) (bay 1/sect.B1) VP_BB_DC . . . & ..VPQB2TR(VQB220TR) (bay n/sect.B1) VPDCTR (B1/B2) EXDU_BB (bay 1/sect.B1) .
Page 593: Signals In Double-Breaker Arrangement
1MRK 505 343-UEN B Section 14 Control QB7OPTR (bay 1) BB_DC_OP . . . & ..QB7OPTR (bay n) VPQB7TR (bay 1) VP_BB_DC . . . & ..VPQB7TR (bay n) EXDU_BB (bay 1) EXDU_BB .
Page 594: Signals In 1 1/2 Breaker Arrangement
Section 14 1MRK 505 343-UEN B Control is used for different busbars, that is, for both bus-section disconnectors A1A2_DC and B1B2_DC. 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. The logic is identical to the double busbar configuration described in section “Signals in single breaker arrangement”.
Page 595: Configuration Setting
1MRK 505 343-UEN B Section 14 Control WA1 (A) WA2 (B) DB_BUS_B DB_BUS_A QB61 QB62 DB_LINE en04000518.vsd IEC04000518 V1 EN-US Figure 368: Switchyard layout double circuit breaker M13584-4 v4 For a double circuit-breaker bay, the modules DB_BUS_A, DB_LINE and DB_BUS_B must be used.
Page 596: Application
Section 14 1MRK 505 343-UEN B Control 14.4.9.1 Application M13570-3 v6 The interlocking for 1 1/2 breaker diameter (BH_CONN, BH_LINE_A, BH_LINE_B) functions are used for lines connected to a 1 1/2 breaker diameter according to figure 369. WA1 (A) WA2 (B) BH_LINE_B BH_LINE_A QB61...
Page 597: Logic Rotating Switch For Function Selection And Lhmi Presentation Slgapc
1MRK 505 343-UEN B Section 14 Control If there is no voltage supervision, then set the corresponding inputs as follows: • VOLT_OFF = 1 • VOLT_ON = 0 14.5 Logic rotating switch for function selection and LHMI presentation SLGAPC SEMOD114936-1 v4 14.5.1 Identification SEMOD167845-2 v3...
Page 598: Selector Mini Switch Vsgapc
Section 14 1MRK 505 343-UEN B Control tDelay : The delay between the UP or DOWN activation signal positive front and the output activation. StopAtExtremes : Sets the behavior of the switch at the end positions – if set to Disabled , when pressing UP while on first position, the switch will jump to the last position;...
Page 599: Generic Communication Function For Double Point Indication Dpgapc
1MRK 505 343-UEN B Section 14 Control tPulse parameter. Also, being accessible on the single line diagram (SLD), this set using the function block has two control modes (settable through CtlModel ): Dir Norm and SBO Enh . 14.7 Generic communication function for Double Point indication DPGAPC SEMOD55384-1 v4 14.7.1...
Page 600: Setting Guidelines
Section 14 1MRK 505 343-UEN B Control 14.7.3 Setting guidelines SEMOD55398-5 v4 The function does not have any parameters available in the local HMI or PCM600. 14.8 Single point generic control 8 signals SPC8GAPC SEMOD176448-1 v3 14.8.1 Identification SEMOD176456-2 v3 Function description IEC 61850 IEC 60617...
Page 601: Identification
1MRK 505 343-UEN B Section 14 Control 14.9.1 Identification GUID-C3BB63F5-F0E7-4B00-AF0F-917ECF87B016 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number AutomationBits, command function AUTOBITS for DNP3 14.9.2 Application SEMOD158637-5 v4 Automation bits, command function for DNP3 (AUTOBITS) is used within PCM600 in order to get into the configuration the commands coming through the DNP3.0 protocol.The AUTOBITS function plays the same role as functions GOOSEBINRCV (for IEC 61850) and MULTICMDRCV (for LON).AUTOBITS function block have 32 individual outputs which each can be mapped as a...
Page 602 Section 14 1MRK 505 343-UEN B Control close operation. An open breaker operation is performed in a similar way but without the synchro-check condition. Single command function Configuration logic circuits SINGLECMD Close CB1 CMDOUTy OUTy User- & defined conditions Synchro- check en04000206.vsd IEC04000206 V2 EN-US...
Page 603: Setting Guidelines
1MRK 505 343-UEN B Section 14 Control Single command function Configuration logic circuits SINGLESMD Device 1 CMDOUTy OUTy & User- defined conditions en04000208.vsd IEC04000208 V2 EN-US Figure 373: Application example showing a logic diagram for control of external devices via configuration logic circuits 14.10.3 Setting guidelines M12448-3 v2...
Page 605: Section 15 Scheme Communication
1MRK 505 343-UEN B Section 15 Scheme communication Section 15 Scheme communication 15.1 Scheme communication logic for distance or overcurrent protection ZCPSCH IP15749-1 v3 15.1.1 Identification M14854-1 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Scheme communication logic for ZCPSCH distance or overcurrent protection...
Page 606: Delta Blocking Scheme
Section 15 1MRK 505 343-UEN B Scheme communication 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. 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.
Page 607: Permissive Schemes
1MRK 505 343-UEN B Section 15 Scheme communication Inadequate speed or dependability can cause spurious tripping for external faults. Inadequate security can cause delayed tripping for internal faults. Since the blocking signal is initiated by the delta based detection which is very fast the time tCoord can be set to zero seconds, except in cases where the transmission channel is delay slow.
Page 608 Section 15 1MRK 505 343-UEN B Scheme communication 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 operated at the remote terminal.
Page 609: Intertrip Scheme
1MRK 505 343-UEN B Section 15 Scheme communication At the permissive overreaching scheme, the send signal (CS) might be issued in parallel both from an overreaching zone and an underreaching, independent tripping zone. The CS signal from the overreaching zone must not be prolonged while the CS signal from zone 1 can be prolonged.
Page 610: Setting Guidelines
Section 15 1MRK 505 343-UEN B Scheme communication tCoord should be set to 10-30 ms dependant on type of sending of signals, the timer communication channel. The general requirement for teleprotection equipment operating in intertripping applications is that it should be very secure and very dependable, since both inadequate security and dependability may cause unwanted operation.
Page 611: Permissive Underreaching Scheme
1MRK 505 343-UEN B Section 15 Scheme communication 15.1.3.3 Permissive underreaching scheme M13869-25 v4 Operation SchemeType Permissive UR tCoord = 0 ms tSendMin = 0.1 s Unblock tSecurity = 0.035 s 15.1.3.4 Permissive overreaching scheme M13869-34 v4 Operation Scheme type Permissive OR tCoord = 0 ms...
Page 612: Application
Section 15 1MRK 505 343-UEN B Scheme communication 15.2.2 Application SEMOD141787-1 v1 SEMOD141790-4 v2 To achieve fast fault clearing for a fault on the part of the line not covered by the instantaneous zone1, the stepped distance protection function can be supported with logic that uses communication channels.
Page 613: Blocking Scheme
1MRK 505 343-UEN B Section 15 Scheme communication Station A Station B Earth IEC06000309_2_en.vsd IEC06000309 V2 EN-US Figure 378: Simultaneous faults on two parallel lines By using phase-segregated channels for the communication scheme, the correct phase information in the protection IED near the faults can be transferred to the other side protection IED.
Page 614: Permissive Schemes
Section 15 1MRK 505 343-UEN B Scheme communication 15.2.2.2 Permissive schemes SEMOD141790-30 v2 In permissive scheme permission to trip is sent from local end to remote end(s) that is, protection at local end have 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 is detected a fault in forward direction.
Page 615: Intertrip Scheme
1MRK 505 343-UEN B Section 15 Scheme communication prolonged. To secure correct operations of current reversal logic in case of parallel lines, when applied, the carrier send signal CS shall not be prolonged. So set the tSendMin to zero in this tCoord case.
Page 616: Blocking Scheme
Section 15 1MRK 505 343-UEN B Scheme communication 15.2.3.3 Blocking scheme SEMOD141800-12 v1 Operation Scheme Blocking type tCoord 25 ms (10 ms + maximal transmission time) tSendMin 15.2.3.4 Intertrip scheme SEMOD141800-15 v1 Operation Scheme Intertrip type tCoord 50 ms (10 ms + maximal transmission time) tSendMin 0.1 s 15.3...
Page 617: Weak-End Infeed Logic
1MRK 505 343-UEN B Section 15 Scheme communication IEC9900043-2.vsd IEC99000043 V3 EN-US Figure 379: Current distribution for a fault close to B side when all breakers are closed When the breaker B1 opens for clearing the fault, the fault current through B2 bay will invert. If the communication signal has not reset at the same time as the distance protection function used in the teleprotection scheme has switched on to forward direction, we will have an unwanted operation of breaker B2 at B side.
Page 618: Setting Guidelines
Section 15 1MRK 505 343-UEN B Scheme communication signal would block the operation of the distance protection at the remote line end and in this way prevents the correct operation of a complete protection scheme. • A separate direct intertrip channel must be arranged from remote end when a trip or accelerated trip is given there.
Page 619: Current Reversal And Weak-End Infeed Logic For Phase Segregated Communication Zc1Wpsch
1MRK 505 343-UEN B Section 15 Scheme communication 15.4 Current reversal and weak-end infeed logic for phase segregated communication ZC1WPSCH SEMOD155635-1 v2 15.4.1 Identification SEMOD156467-2 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Current reversal and weak-end ZC1WPSCH infeed logic for phase segregated communication...
Page 620: Setting Guidelines
Section 15 1MRK 505 343-UEN B Scheme communication protection shall be connected to input IRVLx and the output IRVOPLx shall be connected to input BLKCS on the communication 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.
Page 621: Local Acceleration Logic Zclcpsch
1MRK 505 343-UEN B Section 15 Scheme communication Weak-end infeed logic OperationWEI to Echo , to activate the weak-end infeed function with only echo function. OperationWEI to Echo&Trip to obtain echo with trip. tPickUpWEI to 10 ms, a short delay is recommended to avoid that spurious carrier received signals will activate WEI and cause unwanted communications.
Page 622: Scheme Communication Logic For Residual Overcurrent Protection Ecpsch
Section 15 1MRK 505 343-UEN B Scheme communication LoadCurr must be set below the current that will flow on the healthy phase when one or two of the other phases are faulty and the breaker has opened at remote end (three-phase). Calculate the setting according to equation 560.
Page 623: Setting Guidelines
1MRK 505 343-UEN B Section 15 Scheme communication In the directional scheme, information of the fault current direction must be transmitted to the other line end. With directional comparison in permissive schemes, a short operate time of the protection including a channel transmission time, can be achieved. This short operate time enables rapid autoreclosing function after the fault clearance.
Page 624: Current Reversal And Weak-End Infeed Logic For Residual Overcurrent Protection Ecrwpsch
Section 15 1MRK 505 343-UEN B Scheme communication 15.7 Current reversal and weak-end infeed logic for residual overcurrent protection ECRWPSCH IP14365-1 v4 15.7.1 Identification M14883-1 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Current reversal and weak-end ECRWPSCH infeed logic for residual overcurrent protection...
Page 625: Weak-End Infeed Logic
1MRK 505 343-UEN B Section 15 Scheme communication The IED at A2, where the forward direction element was initially activated, must reset before the send signal is initiated from B2. The delayed reset of output signal IRVL also ensures the send signal from IED B2 is held back till the forward direction element is reset in IED A2.
Page 626: Weak-End Infeed
Section 15 1MRK 505 343-UEN B Scheme communication The principle time sequence of signaling at current reversal is shown. Tele- Tele- Tele- Protection Protection Protection communication Protection Function Function Equipment System Equipment CS initiation to CS from the CR to the CR selection and protection CS propagation,...
Page 627 1MRK 505 343-UEN B Section 15 Scheme communication TRIP TRIP > DIFF source Line Power Source Load Transformer en03000120.vsd IEC03000120 V1 EN-US Figure 387: Usually carrier receive (CR) signal trips the line circuit breaker directly in normal direct transfer trip scheme (DTT) but in such cases security would be compromised, due to the risk of a false communication signal.
Page 628: Setting Guidelines
Section 15 1MRK 505 343-UEN B Scheme communication Impedance protection Low impedance protection Breaker Failure Backup trip of breaker failure protection Three phase overcurrent CarrierReceiveLogic LCCRPTRC Three phase undercurrent Zero sequence overcurrent protection LocalCheck Negative sequence overcurrent protection Zero sequence overvoltage protection Negative sequence overvoltage protection...
Page 629: Application
1MRK 505 343-UEN B Section 15 Scheme communication 15.8.3.2 Application GUID-66A4DE76-7477-4B1A-A214-0BE14E0289F3 v1 Low active power and power factor protection (LAPPGAPC) is one of the local criteria to be checked in direct transfer trip (DTT) scheme. In LAPPGAPC, active power and power factor are calculated from the voltage and current values at this end.
Page 630: Identification
Section 15 1MRK 505 343-UEN B Scheme communication 15.8.4.1 Identification GUID-F5F76C4D-DD25-4695-9FF1-6B45C696CC5E v1 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Compensated over and undervoltage COUVGAPC 59_27 protection 15.8.4.2 Application GUID-49CDDFEF-DB8F-4733-AD7C-0A87E0F6BAA1 v1 Compensated over and undervoltage protection (COUVGAPC) function calculates the remote end voltage of the transmission line utilizing local measured voltage, current and with the help of transmission line parameters, that is, line resistance, reactance, capacitance and local shunt reactor.
Page 631: Setting Guidelines
1MRK 505 343-UEN B Section 15 Scheme communication If there is a transmission line that is opened at the remote end or radial or remote end source is weak, then a fault anywhere on the line can result into undervoltage at the remote end. There can be undervoltage at remote end also due to heavy loading or poor power factor on lagging side.
Page 632: Sudden Change In Current Variation Sccvptoc
Section 15 1MRK 505 343-UEN B Scheme communication GlobalBaseSel : Selects the global base value group used by the function to define ( IBase ), UBase ) and ( SBase ). OperationUV : Used to set the under-voltage function On or Off . U<...
Page 633: Carrier Receive Logic Lccrptrc
1MRK 505 343-UEN B Section 15 Scheme communication GlobalBaseSel : Selects the global base value group used by the function to define ( IBase ), UBase ) and ( SBase ). I> : 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 most remote point where the direct trip scheme shall be active.
Page 634: Identification
Section 15 1MRK 505 343-UEN B Scheme communication 15.8.7.1 Identification GUID-C0F8D64B-FBCD-4115-9A5A-23B252CB7E45 v1 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Negative sequence overvoltage LCNSPTOV protection 15.8.7.2 Application GUID-4FDDBF7D-801B-4C7A-AAE1-8D3ED41D950E v1 Negative sequence symmetrical components are present in all types of fault condition. In case of three phase short circuits the negative sequence voltages and current have transient nature and will therefore decline to zero after some periods.
Page 635: Setting Guidelines
1MRK 505 343-UEN B Section 15 Scheme communication Zero sequence overvoltage protection (LCZSPTOV) is a definite time stage comparator function. The Zero sequence input voltage from the SMAI block is connected as input to the function through a group connection U3P in PCM600. This voltage is compared against the preset value and a start signal will be set high if the input zero sequence voltage is more than 3U0>...
Page 636: Setting Guideline
Section 15 1MRK 505 343-UEN B Scheme communication input will block the complete function. BLKTR will block the trip output. Negative sequence current is available as service value output I2. 15.8.9.3 Setting guideline GUID-377FEADE-375F-4B2D-ADDE-D92C59BDBD41 v2 GlobalBaseSel : Selects the global base value group used by the function to define ( IBase ), UBase ) and ( SBase ).
Page 637: Three Phase Overcurrent Lcp3Ptoc
1MRK 505 343-UEN B Section 15 Scheme communication t3I0 : Time delay for trip in case of high zero sequence current detection. The trip function can be used as stand alone short circuit protection with a long time delay. The choice of time delay is depending on the application of the protection as well as network topology.
Page 638: Setting Guidelines
Section 15 1MRK 505 343-UEN B Scheme communication When the transformer or shunt reactor differential operates and the secondary side circuit breaker is tripped there will be very low current from this end of the line to the remote end. LCP3PTUC detects the above low current condition by monitoring the current and helps to trip the circuit breaker at this end instantaneously or after a time delay according to the requirement.
Page 639: Section 16 Logic
1MRK 505 343-UEN B Section 16 Logic Section 16 Logic 16.1 Tripping logic SMPPTRC IP14576-1 v4 16.1.1 Identification SEMOD56226-2 v6 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Tripping logic SMPPTRC I->O SYMBOL-K V1 EN-US 16.1.2 Application M12252-3 v8 All trip signals from the different protection functions shall be routed through the trip logic.
Page 640: Three-Phase Tripping
Section 16 1MRK 505 343-UEN B Logic To prevent closing of a circuit breaker after a trip the function can block the closing. The two instances of the SMPPTRC function are identical except, for the name of the function block (SMPPTRC1 and SMPPTRC2). References will therefore only be made to SMPPTRC1 in the following description, but they also apply to SMPPTRC2.
Page 641 1MRK 505 343-UEN B Section 16 Logic The inputs are combined with the phase selection logic and the start signals from the phase selector must be connected to the inputs PSL1, PSL2 and PSL3 to achieve the tripping on the respective single-phase trip outputs TRL1, TRL2 and TRL3.
Page 642: Single-, Two- Or Three-Phase Tripping
Section 16 1MRK 505 343-UEN B Logic 16.1.2.3 Single-, two- or three-phase tripping M14828-15 v3 The single-/two-/three-phase tripping mode provides single-phase tripping for single-phase faults, two-phase tripping for two-phase faults and three-phase tripping for multi-phase faults. The operating mode is always used together with an autoreclosing scheme with setting Program = 1/2/3Ph or Program = 1/3Ph attempt.
Page 643: Trip Matrix Logic Tmagapc
1MRK 505 343-UEN B Section 16 Logic tWaitForPHS : Sets a duration after any of the inputs 1PTRZ or 1PTREF has been activated during which a phase selection must occur to get a single phase trip. If no phase selection has been achieved a three-phase trip will be issued after the time has elapsed.
Page 644: Application
Section 16 1MRK 505 343-UEN B Logic 16.3.2 Application GUID-70B268A9-B248-422D-9896-89FECFF80B75 v1 Group alarm logic function ALMCALH is used to route alarm signals to different LEDs and/or output contacts on the IED. ALMCALH output signal and the physical outputs allows the user to adapt the alarm signal to physical tripping outputs according to the specific application needs.
Page 645: Setting Guidelines
1MRK 505 343-UEN B Section 16 Logic INDCALH output signal IND and the physical outputs allows the user to adapt the indication signal to physical outputs according to the specific application needs. 16.5.1.3 Setting guidelines GUID-7E776D39-1A42-4F90-BF50-9B38F494A01E v2 Operation : On or Off 16.6 Configurable logic blocks IP11009-1 v3...
Page 646: Fixed Signal Function Block Fxdsign
Section 16 1MRK 505 343-UEN B Logic IEC09000695_2_en.vsd IEC09000695 V2 EN-US Figure 393: Example designation, serial execution number and cycle time for logic function IEC09000310-1-en.vsd IEC09000310 V1 EN-US Figure 394: Example designation, serial execution number and cycle time for logic function that also propagates timestamp and quality of input signals The execution of different function blocks within the same cycle is determined by the order of their serial execution numbers.
Page 647: Application
1MRK 505 343-UEN B Section 16 Logic 16.7.2 Application M15322-3 v11 The Fixed signals function FXDSIGN generates 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.
Page 648: Boolean 16 To Integer Conversion B16I
Section 16 1MRK 505 343-UEN B Logic 16.8 Boolean 16 to Integer conversion B16I SEMOD175715-1 v1 16.8.1 Identification SEMOD175721-2 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Boolean 16 to integer conversion B16I 16.8.2 Application SEMOD175832-4 v4 Boolean 16 to integer conversion function B16I is used to transform a set of 16 binary (logical) signals into an integer.
Page 649: Boolean To Integer Conversion With Logical Node Representation, 16 Bit Btigapc
1MRK 505 343-UEN B Section 16 Logic The sum of the numbers in column “Value when activated” when all INx (where 1≤x≤16) are active that is=1; is 65535. 65535 is the highest boolean value that can be converted to an integer by the B16I function block.
Page 650: Integer To Boolean 16 Conversion Ib16
Section 16 1MRK 505 343-UEN B Logic Name of input Type Default Description Value when Value when activated deactivated IN12 BOOLEAN Input 12 2048 IN13 BOOLEAN Input 13 4096 IN14 BOOLEAN Input 14 8192 IN15 BOOLEAN Input 15 16384 IN16 BOOLEAN Input 16 32768...
Page 651: Integer To Boolean 16 Conversion With Logic Node Representation Itbgapc
1MRK 505 343-UEN B Section 16 Logic Name of input Type Default Description Value when Value when activated deactivated BOOLEAN Input 6 BOOLEAN Input 7 BOOLEAN Input 8 BOOLEAN Input 9 IN10 BOOLEAN Input 10 IN11 BOOLEAN Input 11 1024 IN12 BOOLEAN Input 12...
Page 652: Elapsed Time Integrator With Limit Transgression And Overflow Supervision Teigapc
Section 16 1MRK 505 343-UEN B Logic Table 50: Output signals Name of OUTx Type Description Value when Value when activated deactivated OUT1 BOOLEAN Output 1 OUT2 BOOLEAN Output 2 OUT3 BOOLEAN Output 3 OUT4 BOOLEAN Output 4 OUT5 BOOLEAN Output 5 OUT6 BOOLEAN...
Page 653: Comparator For Integer Inputs - Intcomp
1MRK 505 343-UEN B Section 16 Logic A resolution of 10 ms can be achieved when the settings are defined within the range 1.00 second ≤ tAlarm ≤ 99 999.99 seconds 1.00 second ≤ tWarning ≤ 99 999.99 seconds. If the values are above this range the resolution becomes lower 99 999.99 seconds ≤...
Page 654: Setting Example
Section 16 1MRK 505 343-UEN B Logic 16.13.4 Setting example GUID-13302FD6-1585-42FE-BD6D-44F231982C59 v1 For absolute comparison between inputs: EnaAbs = 1 Set the RefSource = 1 Set the Similarly for Signed comparison between inputs EnaAbs = 0 Set the Set the RefSource = 1 For absolute comparison between input and setting EnaAbs = 1...
Page 655: Setting Example
1MRK 505 343-UEN B Section 16 Logic RefSource : This setting is used to select the reference source between input and setting for comparison. REF : The function will take reference value from input REF • SetValue : The function will take reference value from setting SetValue •...
Page 656 Section 16 1MRK 505 343-UEN B Logic EqualBandHigh = 5.0 % of reference value EqualBandLow = 5.0 % of reference value . Application manual...
Page 657: Section 17 Monitoring
1MRK 505 343-UEN B Section 17 Monitoring Section 17 Monitoring 17.1 Measurement GUID-9D2D47A0-FE62-4FE3-82EE-034BED82682A v1 17.1.1 Identification SEMOD56123-2 v7 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Measurements CVMMXN P, Q, S, I, U, f SYMBOL-RR V1 EN-US Phase current measurement CMMXU SYMBOL-SS V1 EN-US...
Page 658: Zero Clamping
Section 17 1MRK 505 343-UEN B Monitoring The available measured values of 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.
Page 659: Setting Guidelines
1MRK 505 343-UEN B Section 17 Monitoring Example how CVMMXN is operating: The following outputs can be observed on the local HMI under Monitoring/Servicevalues/ SRV1 Apparent three-phase power Active three-phase power Reactive three-phase power Power factor ILAG I lagging U ILEAD I leading U System mean voltage, calculated according to selected mode...
Page 660 Section 17 1MRK 505 343-UEN B Monitoring UGenZeroDb : Minimum level of voltage in % of UBase used as indication of zero voltage (zero point clamping). If measured value is below UGenZeroDb calculated S, P, Q and PF will be zero. IGenZeroDb : Minimum level of current in % of IBase used as indication of zero current (zero IGenZeroDb calculated S, P, Q and PF will be zero.
Page 661: Setting Examples
1MRK 505 343-UEN B Section 17 Monitoring XLimHyst : Hysteresis value in % of range and is common for all limits. All phase angles are presented in relation to defined reference channel. The parameter PhaseAngleRef defines the reference, see section "". Calibration curves It is possible to calibrate the functions (CVMMXN, CMMXU, VMMXU and VNMMXU) to get class 0.5 presentations of currents, voltages and powers.
Page 662 Section 17 1MRK 505 343-UEN B Monitoring Measurement function application for a 110kV OHL SEMOD54481-12 v9 Single line diagram for this application is given in figure 398: 110kV Busbar 600/1 A 110 0,1 110kV OHL IEC09000039-2-en.vsd IEC09000039-1-EN V2 EN-US Figure 398: Single line diagram for 110kV OHL application In order to monitor, supervise and calibrate the active and reactive power as indicated in figure it is necessary to do the following:...
Page 663 1MRK 505 343-UEN B Section 17 Monitoring Table 52: Settings parameters for level supervision Setting Short Description Selected Comments value PMin Minimum value -100 Minimum expected load PMax Minimum value Maximum expected load PZeroDb Zero point clamping in 0.001% 3000 Set zero point clamping to 45 MW that is, 3% of range of 200 MW...
Page 664 Section 17 1MRK 505 343-UEN B Monitoring 110kV Busbar 200/1 31,5 MVA 110/36,75/(10,5) kV Yy0(d5) 500/5 L1L2 35 / 0,1kV 35kV Busbar IEC09000040-1-en.vsd IEC09000040-1-EN V1 EN-US Figure 399: Single line diagram for transformer application In order to measure the active and reactive power as indicated in figure 399, it is necessary to do the following: PhaseAngleRef (see section Set correctly all CT and VT and phase angle reference channel...
Page 665 1MRK 505 343-UEN B Section 17 Monitoring Table 54: General settings parameters for the Measurement function Setting Short description Selected Comment value Operation Operation Off / On Function must be PowAmpFact Amplitude factor to scale 1.000 Typically no scaling is required power calculations PowAngComp Angle compensation for phase...
Page 666 Section 17 1MRK 505 343-UEN B Monitoring 220kV Busbar 300/1 100 MVA 242/15,65 kV 15 / 0,1kV L1L2 L2L3 100MVA 15,65kV 4000/5 IEC09000041-1-en.vsd IEC09000041-1-EN V1 EN-US Figure 400: Single line diagram for generator application In order to measure the active and reactive power as indicated in figure 400, it is necessary to do the following: PhaseAngleRef (see Set correctly all CT and VT data and phase angle reference channel...
Page 667: Gas Medium Supervision Ssimg
1MRK 505 343-UEN B Section 17 Monitoring Table 55: General settings parameters for the Measurement function Setting Short description Selected Comment value Operation Operation Off/On Function must be PowAmpFact Amplitude factor to scale 1.000 Typically no scaling is required power calculations PowAngComp Angle compensation for phase Typically no angle compensation is required.
Page 668: Application
Section 17 1MRK 505 343-UEN B Monitoring 17.3.2 Application GUID-140AA10C-4E93-4C23-AD57-895FADB0DB29 v5 Liquid medium supervision (SSIML) is used for monitoring the circuit breaker condition. Proper arc extinction by the compressed oil in the circuit breaker is very important. When the level becomes too low, compared to the required value, the circuit breaker operation is blocked to minimize the risk of internal failures.
Page 669 1MRK 505 343-UEN B Section 17 Monitoring 100000 50000 20000 10000 5000 2000 1000 Interrupted current (kA) IEC12000623_1_en.vsd IEC12000623 V1 EN-US Figure 401: An example for estimating the remaining life of a circuit breaker Calculation for estimating the remaining life The graph shows that there are 10000 possible operations at the rated operating current and 900 operations at 10 kA and 50 operations at rated fault current.
Page 670: Setting Guidelines
Section 17 1MRK 505 343-UEN B Monitoring depends on the type of circuit breaker. The energy values were accumulated using the current value and exponent factor for CB contact opening duration. When the next CB opening operation is started, the energy is accumulated from the previous value. The accumulated energy value can be reset to initial accumulation energy value by using the Reset accumulating energy input, RSTIPOW.
Page 671: Event Function Event
1MRK 505 343-UEN B Section 17 Monitoring tTrCloseAlm : Setting of alarm level for closing travel time. OperAlmLevel : Alarm limit for number of mechanical operations. OperLOLevel : Lockout limit for number of mechanical operations. CurrExponent : Current exponent setting for energy calculation. It varies for different types of 0.5 to 3.0 .
Page 672: Setting Guidelines
Section 17 1MRK 505 343-UEN B Monitoring created from any available signal in the IED that is connected to the Event function (EVENT). The event function block is used for LON and SPA communication. Analog and double indication values are also transferred through EVENT function. 17.5.3 Setting guidelines IP14841-1 v1...
Page 673: Application
1MRK 505 343-UEN B Section 17 Monitoring 17.6.2 Application M12152-3 v7 To get fast, complete and reliable information about disturbances in the primary and/or in the secondary system it is very important to gather information on fault currents, voltages and events.
Page 674 Section 17 1MRK 505 343-UEN B Monitoring the analog input function blocks (AxRADR), which is used by Fault locator (FL) after estimation by Trip Value Recorder (TVR). Disturbance report function acquires information from both AxRADR and BxRBDR. Disturbance Report AxRADR DRPRDRE Analog signals Trip value rec...
Page 675: Recording Times
1MRK 505 343-UEN B Section 17 Monitoring Operation M12179-82 v5 The operation of Disturbance report function DRPRDRE has to be set On or Off . If Off is selected, note that no disturbance report is registered, and none sub-function will operate (the only general parameter that influences Event list (EL)).
Page 676: Binary Input Signals
Section 17 1MRK 505 343-UEN B Monitoring PostRetrig = Off The function is insensitive for new trig signals during post fault time. PostRetrig = On The function completes current report and starts a new complete report that is, the latter will include: •...
Page 677: Sub-Function Parameters
1MRK 505 343-UEN B Section 17 Monitoring OperationM = On , waveform (samples) will also be recorded and reported in graph. NomValueM : Nominal value for input M. OverTrigOpM , UnderTrigOpM : Over or Under trig operation, Disturbance report may trig for On ) or not ( Off ).
Page 678: Logical Signal Status Report Binstatrep
Section 17 1MRK 505 343-UEN B Monitoring Minimize the number of recordings: • Binary signals: Use only relevant signals to start the recording that is, protection trip, carrier receive and/or start signals. • Analog signals: The level triggering should be used with great care, since unfortunate settings will cause enormously number of recordings.
Page 679: Fault Locator Lmbrflo
1MRK 505 343-UEN B Section 17 Monitoring 17.8 Fault locator LMBRFLO IP14592-1 v2 17.8.1 Identification M14892-1 v3 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Fault locator LMBRFLO 17.8.2 Application M13752-3 v6 The main objective of line protection and monitoring IEDs is fast, selective and reliable operation for faults on a protected line section.
Page 680: Connection Of Analog Currents
Section 17 1MRK 505 343-UEN B Monitoring analog inputs are currents and next three are voltages in the observed bay (no parallel line expected since chosen input is set to zero). Use the Parameter Setting tool within PCM600 for changing analog configuration. UL1Gain , UL2Gain and The measured phase voltages can be fine tuned with the parameters UL3Gain to further increase the accuracy of the fault locator.
Page 681: Limit Counter L4Ufcnt
1MRK 505 343-UEN B Section 17 Monitoring en07000113-1.vsd IEC07000113 V2 EN-US Figure 405: Example of connection of parallel line IN for Fault locator LMBRFLO 17.9 Limit counter L4UFCNT GUID-22E141DB-38B3-462C-B031-73F7466DD135 v1 17.9.1 Identification GUID-F3FB7B33-B189-4819-A1F0-8AC7762E9B7E v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification...
Page 682: Setting Guidelines
Section 17 1MRK 505 343-UEN B Monitoring after reaching the maximum count value. It is also possible to set the counter to rollover and indicate the overflow as a pulse, which lasts up to the first count after rolling over to zero. In this case, periodic pulses will be generated at multiple overflow of the function.
Page 683: Section 18 Metering
1MRK 505 343-UEN B Section 18 Metering Section 18 Metering 18.1 Pulse-counter logic PCFCNT IP14600-1 v3 18.1.1 Identification M14879-1 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Pulse-counter logic PCFCNT S00947 V1 EN-US 18.1.2 Application M13395-3 v6 Pulse-counter logic (PCFCNT) function counts externally generated binary pulses, for instance pulses coming from an external energy meter, for calculation of energy consumption values.
Page 684: Function For Energy Calculation And Demand Handling Etpmmtr
Section 18 1MRK 505 343-UEN B Metering The setting is common for all input channels on BIM, that is, if limit changes are made for inputs not connected to the pulse counter, the setting also influences the inputs on the same board used for pulse counting. 18.2 Function for energy calculation and demand handling ETPMMTR...
Page 685: Setting Guidelines
1MRK 505 343-UEN B Section 18 Metering 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 energy then is calculated by summation of the energy pulses.
Page 687: Section 19 Station Communication
1MRK 505 343-UEN B Section 19 Station communication Section 19 Station communication 19.1 Communication protocols M14815-3 v12 Each IED is provided with a communication interface, enabling it to connect to one or many substation level systems or equipment, either on the Substation Automation (SA) bus or Substation Monitoring (SM) bus.
Page 688 Section 19 1MRK 505 343-UEN B Station communication Engineering Station HSI Workstation Gateway Base System Printer KIOSK 3 KIOSK 1 KIOSK 2 IEC09000135_en.v IEC09000135 V1 EN-US Figure 407: SA system with IEC 61850–8–1 M16925-3 v3 Figure 408 shows the GOOSE peer-to-peer communication. Station HSI MicroSCADA Gateway...
Page 689: Horizontal Communication Via Goose For Interlocking Gooseintlkrcv
1MRK 505 343-UEN B Section 19 Station communication 19.2.2 Horizontal communication via GOOSE for interlocking GOOSEINTLKRCV SEMOD173197-1 v2 PID-415-SETTINGS v5 Table 56: GOOSEINTLKRCV Non group settings (basic) Name Values (Range) Unit Step Default Description Operation Operation Off/On 19.2.3 Setting guidelines SEMOD55317-5 v6 There are two settings related to the IEC 61850–8–1 protocol: Operation User can set IEC 61850 communication to On or Off .
Page 690: Iec 61850-8-1 Redundant Station Bus Communication
Section 19 1MRK 505 343-UEN B Station communication is connected to the range output, the logical outputs of the RANGE_XP are changed accordingly. 19.2.6 IEC 61850-8-1 redundant station bus communication GUID-FF43A130-7D2D-4BA3-B51C-80398D73228F v2 19.2.6.1 Identification GUID-00C469E6-00D4-4780-BD0D-426647AB8E0F v3.1.1 Function description LHMI and ACT IEC 61850 IEC 60617 ANSI/IEEE C37.2...
Page 691: Setting Guidelines
1MRK 505 343-UEN B Section 19 Station communication Station Control System Redundancy Supervision Data Data Switch A Switch B Data Data Configuration PRPSTATUS =IEC09000758=3=en=Original.vsd IEC09000758 V3 EN-US Figure 409: Redundant station bus 19.2.6.3 Setting guidelines GUID-6AD04F29-9B52-40E7-AA07-6D248EF99FC6 v2 Redundant communication (PRP) is configured in the local HMI under Main menu/ Configuration/Communication/Ethernet configuration/PRP The settings are found in the Parameter Setting tool in PCM600 under IED Configuration/ Communication/Ethernet configuration/PRP.
Page 692: Iec 61850-9-2Le Communication Protocol
Section 19 1MRK 505 343-UEN B Station communication IEC10000057-2-en.vsd IEC10000057 V2 EN-US Figure 410: PST screen: PRP Operation is set to On, which affect Rear OEM - Port AB and CD which are both set to PRP 19.3 IEC 61850-9-2LE communication protocol SEMOD172279 v2 19.3.1 Introduction...
Page 693 1MRK 505 343-UEN B Section 19 Station communication Set the CD-port to 9–2LE communication using only LHMI. All other settings are also available from PCM600. Factors influencing the accuracy of the sampled values from the merging unit are, for example, anti aliasing filters, frequency range, step response, truncating, A/D conversion inaccuracy, time tagging accuracy etc.
Page 694: Setting Guidelines
Section 19 1MRK 505 343-UEN B Station communication Station Wide Station Wide SCADA System GPS Clock IEC61850-8-1 Splitter Electrical-to- Optical Converter IEC61850-8-1 110 V Other 1PPS Relays IEC61850-9-2LE Ethernet Switch IEC61850-9-2LE 1PPS Merging Unit Combi Sensor Conventional VT en08000069-3.vsd IEC08000069 V2 EN-US Figure 412: Example of a station configuration with the IED receiving analog values from both classical measuring transformers and merging units.
Page 695: Specific Settings Related To The Iec 61850-9-2Le Communication
1MRK 505 343-UEN B Section 19 Station communication 19.3.2.1 Specific settings related to the IEC 61850-9-2LE communication SEMOD166590-24 v5 The process bus communication IEC 61850-9-2LE have specific settings, similar to the analog inputs modules. Besides the names of the merging unit channels (that can be edited only from PCM600, not from the local HMI) there are important settings related to the merging units and time synchronization of the signals: When changing the sending (MU unit) MAC address, a reboot of the IED is...
Page 696 Section 19 1MRK 505 343-UEN B Station communication Failure of the MU (sample lost) blocks the sending of binary signals through LDCM. The received binary signals are not blocked and processd normally. →DTT from the remote end is still processed. IEC13000299-1-en.vsd IEC13000299 V1 EN-US Figure 414: MU failed, mixed system...
Page 697 1MRK 505 343-UEN B Section 19 Station communication Function description IEC 61850 identification Function description IEC 61850 identification Breaker failure CCSRBRF Restricted earth fault REFPDIF protection, single phase protection, low version impedance Current circuit CCSSPVC Two step residual ROV2PTOV supervison overvoltage protection Compensated over- and COUVGAPC...
Page 698 Section 19 1MRK 505 343-UEN B Station communication Function description IEC 61850 identification Function description IEC 61850 identification Negative sequence LCNSPTOC Local acceleration logic ZCLCPSCH overcurrent protection Negative sequence LCNSPTOV Scheme communication ZCPSCH overvoltage protection logic for distance or overcurrent protection Three phase overcurrent LCP3PTOC Current reversal and...
Page 699: Setting Examples For Iec 61850-9-2Le And Time Synchronization
1MRK 505 343-UEN B Section 19 Station communication Function description IEC 61850 identification Function description IEC 61850 identification Out-of-step protection OOSPPAM Busbar differential BCZPDIF protection, check zone Busbar differential BDZSGAPC Busbar differential BFPTRC_Fx, (1≤x≤24) protection, dynamic zone protection, single phase selection feeder xx Busbar differential...
Page 700 Section 19 1MRK 505 343-UEN B Station communication HwSyncSrc : set to PPS since this is what is generated by the MU (ABB MU) • • AppSynch : set to Synch , since protection functions should be blocked in case of loss of...
Page 701 1MRK 505 343-UEN B Section 19 Station communication HwSyncSrc : set to PPS/IRIG-B depending on available outputs on the clock • • AppSynch : set to Synch , for blocking protection functions in case of loss of time synchronization SyncAccLevel : could be set to 4us since this correspond to a maximum phase-angle error •...
Page 702: Lon Communication Protocol
Section 19 1MRK 505 343-UEN B Station communication HwSyncSrc : set to Off • • AppSynch : set to NoSynch . This means that protection functions will not be blocked SyncAccLevel : set to unspecified • Settings in PST in PCM600 under: Hardware/Analog modules/Merging units/MU01 SyncMode : set to NoSynch .
Page 703: Multicmdrcv And Multicmdsnd
1MRK 505 343-UEN B Section 19 Station communication Table 58: Specification of the fiber optic connectors Glass fiber Plastic fiber Cable connector ST-connector snap-in connector Cable diameter 62.5/125 m 1 mm Max. cable length 1000 m 10 m Wavelength 820-900 nm 660 nm Transmitted power -13 dBm (HFBR-1414)
Page 704: Identification
Section 19 1MRK 505 343-UEN B Station communication 19.4.2.1 Identification GUID-1A6E066C-6399-4D37-8CA5-3074537E48B2 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Multiple command and receive MULTICMDRCV Multiple command and send MULTICMDSND 19.4.2.2 Application M14790-3 v5 The IED provides two function blocks enabling several IEDs to send and receive signals via the interbay bus.
Page 705: Setting Guidelines
1MRK 505 343-UEN B Section 19 Station communication The SPA communication is mainly used for the Station Monitoring System. It can include different IEDs with remote communication possibilities. Connection to a computer (PC) can be made directly (if the PC is located in the substation) or by telephone modem through a telephone network with ITU (former CCITT) characteristics or via a LAN/WAN connection.
Page 706: Iec 60870-5-103 Communication Protocol
Section 19 1MRK 505 343-UEN B Station communication 19.6 IEC 60870-5-103 communication protocol IP14615-1 v2 19.6.1 Application IP14864-1 v1 M17109-3 v6 TCP/IP Control Center Station HSI Gateway Star coupler IEC05000660-4-en.vsd IEC05000660 V4 EN-US Figure 421: Example of IEC 60870-5-103 communication structure for a substation automation system IEC 60870-5-103 communication protocol is mainly used when a protection IED communicates with a third party control or monitoring system.
Page 707 1MRK 505 343-UEN B Section 19 Station communication • Autorecloser ON/OFF • Teleprotection ON/OFF • Protection ON/OFF • LED reset • Characteristics 1 - 4 (Setting groups) • File transfer (disturbance files) • Time synchronization Hardware M17109-59 v1 When communicating locally with a Personal Computer (PC) or a Remote Terminal Unit (RTU) in the station, using the SPA/IEC port, the only hardware needed is:·...
Page 708 Section 19 1MRK 505 343-UEN B Station communication • Earth fault indications in monitor direction Function block with defined functions for earth fault indications in monitor direction, I103EF. This block includes the FUNCTION TYPE parameter, and the INFORMATION NUMBER parameter is defined for each output signal. •...
Page 709 1MRK 505 343-UEN B Section 19 Station communication Settings for RS485 and optical serial communication M17109-118 v10 General settings SPA, DNP and IEC 60870-5-103 can be configured to operate on the SLM optical serial port while DNP and IEC 60870-5-103 only can utilize the RS485 port. A single protocol can be active on a given physical port at any time.
Page 710 Section 19 1MRK 505 343-UEN B Station communication The slave number can be set to any value between 1 and 254. The communication speed, can be set either to 9600 bits/s or 19200 bits/s. RevPolarity : Setting for inverting the light (or not). Standard IEC 60870-5-103 setting is •...
Page 711 1MRK 505 343-UEN B Section 19 Station communication DRA#-Input IEC103 meaning Private range Private range Private range Private range Private range Private range Private range Private range Private range Private range Private range Private range Private range Private range Private range Private range Private range Private range...
Page 712: Dnp3 Communication Protocol
Section 19 1MRK 505 343-UEN B Station communication REB 207 Private range REG 150 Private range REQ 245 Private range RES 118 Private range Refer to the tables in the Technical reference manual /Station communication, specifying the information types supported by the communication protocol IEC 60870-5-103. To support the information, corresponding functions must be included in the protection IED.
Page 713: Section 20 Remote Communication
1MRK 505 343-UEN B Section 20 Remote communication Section 20 Remote communication 20.1 Binary signal transfer IP12423-1 v2 20.1.1 Identification M14849-1 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Binary signal transfer BinSignReceive Binary signal transfer BinSignTransm 20.1.2 Application...
Page 714: Setting Guidelines
Section 20 1MRK 505 343-UEN B Remote communication The LDCM can also be used together with an external optical to galvanic G.703 converter or with an alternative external optical to galvanic X.21 converter as shown in figure 424. These solutions are aimed for connections to a multiplexer, which in turn is connected to a telecommunications transmission network (for example, SDH or PDH).
Page 715 1MRK 505 343-UEN B Section 20 Remote communication RemoteTermNo : This setting assigns a number to each related LDCM in the remote IED. For each LDCM, the parameter RemoteTermNo shall be set to a different value than parameter TerminalNo , but equal to the TerminalNo of the remote end LDCM. In the remote IED the TerminalNo and RemoteTermNo settings are reversed as follows: •...
Page 716 Section 20 1MRK 505 343-UEN B Remote communication Table 59: Optical budgets with C37.94 protocol Type of LDCM Short range (SR) Short range (SR) Medium range (MR) Long range (LR) Type of fibre Multi-mode fiber Multi-mode fiber Single-mode fiber Single-mode fiber glass 50/125 μm glass 62.5/125 μm glass 9/125 μm...
Page 717 1MRK 505 343-UEN B Section 20 Remote communication Type of LDCM Short range (SR) Short range (SR) Medium range (MR) Long range (LR) Total attenuation 8.6 dB 12.05 dB 26.04 dB 28.56 dB Optical link budget 9 dB 13 dB 26.8 dB 28.7 dB Link margin...
Page 719: Section 21 Security
1MRK 505 343-UEN B Section 21 Security Section 21 Security 21.1 Authority status ATHSTAT SEMOD158575-1 v2 21.1.1 Application SEMOD158527-5 v3 Authority status (ATHSTAT) function is an indication function block, which informs about two events related to the IED and the user authorization: •...
Page 720: Change Lock Chnglck
CHNGLCK input. If such a situation would occur in spite of these precautions, then please contact the local ABB representative for remedial action. 21.4 Denial of service DOS 21.4.1...
Page 721: Setting Guidelines
1MRK 505 343-UEN B Section 21 Security controlled. Heavy network load might for instance be the result of malfunctioning equipment connected to the network. DOSFRNT, DOSLANAB and DOSLANCD measure the IED load from communication and, if necessary, limit it for not jeopardizing the IEDs control and protection functionality due to high CPU load.
Page 723: Section 22 Basic Ied Functions
• IEDProdType The settings are visible on the local HMI , under Main menu/Diagnostics/IED status/Product identifiersand underMain menu/Diagnostics/IED Status/IED identifiers This information is very helpful when interacting with ABB product support (e.g. during repair and maintenance). 22.2.2 Factory defined settings...
Page 724: Measured Value Expander Block Range_Xp
Section 22 1MRK 505 343-UEN B Basic IED functions • Describes the firmware version. • The firmware version can be checked from Main menu/Diagnostics/IED status/ Product identifiers • Firmware version numbers run independently from the release production numbers. For every release number there can be one or more firmware versions depending on the small issues corrected in between releases.
Page 725: Parameter Setting Groups
1MRK 505 343-UEN B Section 22 Basic IED functions 22.4 Parameter setting groups IP1745-1 v1 22.4.1 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 with a variety of power system scenarios.
Page 726: Setting Guidelines
Section 22 1MRK 505 343-UEN B Basic IED functions 22.5.3 Setting guidelines M15292-3 v2 Set the system rated frequency. Refer to section "Signal matrix for analog inputs SMAI" description on frequency tracking. 22.6 Summation block 3 phase 3PHSUM SEMOD55968-1 v2 22.6.1 Application SEMOD56004-4 v3...
Page 727: Application
1MRK 505 343-UEN B Section 22 Basic IED functions 22.7.2 Application GUID-D58ECA9A-9771-443D-BF84-8EF582A346BF v4 Global base values function (GBASVAL) is used to provide global values, common for all applicable functions within the IED. One set of global values consists of values for current, voltage and apparent power and it is possible to have twelve different sets.
Page 728: Setting Guidelines
Section 22 1MRK 505 343-UEN B Basic IED functions 22.9.2 Setting guidelines SEMOD55228-5 v2 There are no setting parameters for the Signal matrix for binary outputs SMBO available to the user in Parameter Setting tool. However, the user must give a name to SMBO instance and SMBO outputs, directly in the Application Configuration tool.
Page 729: Setting Guidelines
1MRK 505 343-UEN B Section 22 Basic IED functions SMAI1 SPFCOUT SAPTOF BLOCK G1AI3P U3P* TRIP SAPTOF(1)_TRIP DFTSPFC UL1L2 START BLOCK REVROT G1AI1 BLKDMAGN BLKTRIP PHASEL1 G1AI2 FREQ ^GRP1L1 G1AI4 TRM_40.CH7(U) PHASEL2 ^GRP1L2 PHASEL3 ^GRP1L3 NEUTRAL ^GRP1N IEC10000060-2-en.vsdx IEC10000060 V2 EN-US Figure 425: Connection example ConnectionType is The above described scenario does not work if SMAI setting...
Page 730 Section 22 1MRK 505 343-UEN B Basic IED functions ConnectionType : Connection type for that specific instance (n) of the SMAI (if it is The setting Ph-N or Ph-Ph ). Depending on connection type setting the not connected Ph-N or Ph-Ph Ph-Ph connection L1, outputs will be calculated as long as they are possible to calculate.
Page 731 1MRK 505 343-UEN B Section 22 Basic IED functions Task time group 1 SMAI instance 3 phase group SMAI1:1 SMAI2:2 SMAI3:3 AdDFTRefCh7 SMAI4:4 SMAI5:5 SMAI6:6 SMAI7:7 SMAI8:8 SMAI9:9 SMAI10:10 SMAI11:11 SMAI12:12 Task time group 2 SMAI instance 3 phase group SMAI1:13 AdDFTRefCh4 SMAI2:14...
Page 732 Section 22 1MRK 505 343-UEN B Basic IED functions SMAI1:13 BLOCK SPFCOUT DFTSPFC AI3P ^GRP1L1 ^GRP1L2 ^GRP1L3 SMAI1:1 ^GRP1N BLOCK SPFCOUT DFTSPFC AI3P ^GRP1L1 ^GRP1L2 ^GRP1L3 ^GRP1N SMAI1:25 BLOCK SPFCOUT DFTSPFC AI3P ^GRP1L1 ^GRP1L2 ^GRP1L3 ^GRP1N IEC07000198-2-en.vsd IEC07000198 V3 EN-US Figure 427: Configuration for using an instance in task time group 1 as DFT reference Assume instance SMAI7:7 in task time group 1 has been selected in the configuration to control the frequency tracking .
Page 733: Test Mode Functionality Test
1MRK 505 343-UEN B Section 22 Basic IED functions SMAI1:1 BLOCK SPFCOUT DFTSPFC AI3P ^GRP1L1 ^GRP1L2 ^GRP1L3 SMAI1:13 ^GRP1N BLOCK SPFCOUT DFTSPFC AI3P ^GRP1L1 ^GRP1L2 ^GRP1L3 ^GRP1N SMAI1:25 BLOCK SPFCOUT DFTSPFC AI3P ^GRP1L1 ^GRP1L2 ^GRP1L3 ^GRP1N IEC07000199-2-en.vsd IEC07000199 V3 EN-US Figure 428: Configuration for using an instance in task time group 2 as DFT reference.
Page 734: Iec 61850 Protocol Test Mode
Section 22 1MRK 505 343-UEN B Basic IED functions 22.12.1.1 IEC 61850 protocol test mode GUID-82998715-6F23-4CAF-92E4-05E1A863CF33 v5 The function block TESTMODE has implemented the extended testing mode capabilities for IEC 61850 Ed2 systems. Operator commands sent to the function block TESTMODE determine the behavior of the functions.
Page 735: Setting Guidelines
1MRK 505 343-UEN B Section 22 Basic IED functions the Main menu/Test/Function status/Function group/Function block descriptive name/LN name/Outputs. Beh of a function block is set to Test , the function block is not blocked and all • When the control commands with a test bit are accepted. Beh of a function block is set to Test/blocked , all control commands with a test •...
Page 736: Setting Guidelines
Section 22 1MRK 505 343-UEN B Basic IED functions For time synchronization of line differential protection RED670 with diff communication in GPS-mode, a GPS-based time synchronization is needed. This can be optical IRIG-B with 1344 from an external GPS-clock or an internal GPS-receiver. For IEDs using IEC 61850-9-2LE in "mixed mode"...
Page 737: Process Bus Iec 61850-9-2Le Synchronization
1MRK 505 343-UEN B Section 22 Basic IED functions IRIG-B • • GPS+IRIG-B • CoarseSyncSrc which can have the following values: • • • • IEC 60870-5-103 • The function input to be used for minute-pulse synchronization is called BININPUT. For a Technical Manual .
Page 738 Section 22 1MRK 505 343-UEN B Basic IED functions and the IED needs to get the time-quality information in IRIG-B, using the 1344 protocol, from the very same clock in order to be able to block in case of failure in the clock source. CourseSyncSrc = Off , FineSyncSource = IRIG-B , The settings for time synchronization should be TimeAdjustRate = Fast .
Page 739: Section 23 Requirements
1MRK 505 343-UEN B Section 23 Requirements Section 23 Requirements 23.1 Current transformer requirements IP15171-1 v2 M11609-3 v2 The performance of a protection function will depend on the quality of the measured current signal. Saturation of the current transformers (CTs) will cause distortion of the current signals and can result in a failure to operate or cause unwanted operations of some functions.
Page 740: Fault Current
Section 23 1MRK 505 343-UEN B Requirements and low remanence type. The results may not always be valid for non remanence type CTs (TPZ). The performances of the protection functions have been checked in the range from symmetrical to fully asymmetrical fault currents. Primary time constants of at least 120 ms have been considered at the tests.
Page 741: General Current Transformer Requirements
CT (TPZ) is not well defined as far as the phase angle error is concerned. If no explicit recommendation is given for a specific function we therefore recommend contacting ABB to confirm that the non remanence type can be used.
Page 742: Distance Protection
Section 23 1MRK 505 343-UEN B Requirements where: Maximum primary fundamental frequency fault current for internal close-in kmax faults (A) Maximum primary fundamental frequency fault current for through fault tmax current for external faults (A) The rated primary CT current (A) The rated secondary CT current (A) The rated current of the protection IED (A) The secondary resistance of the CT (W)
Page 743 1MRK 505 343-UEN B Section 23 Requirements æ ö ³ × × × k max sr ç ÷ alreq è ø (Equation 566) EQUATION1080 V2 EN-US æ ö × ³ × × kzone1 sr ç ÷ alreq è ø (Equation 567) EQUATION1081 V2 EN-US where: Maximum primary fundamental frequency current for close-in forward and...
Page 744: Breaker Failure Protection
Section 23 1MRK 505 343-UEN B Requirements 23.1.6.3 Breaker failure protection M11621-3 v5 The CTs must have a rated equivalent limiting secondary e.m.f. E that is larger than or equal to the required rated equivalent limiting secondary e.m.f. E below: alreq æ...
Page 745 1MRK 505 343-UEN B Section 23 Requirements The rated current of the protection IED (A) The secondary resistance of the CT ( ) The resistance of the secondary wire and additional load (Ω). The loop resistance containing the phase and neutral wires shall be used. The burden of a REx670 current input channel (VA).
Page 746: Current Transformer Requirements For Cts According To Other Standards
Section 23 1MRK 505 343-UEN B Requirements The three individual phase CTs must have a rated equivalent limiting secondary e.m.f. E that is larger than or equal to the maximum of the required rated equivalent limiting secondary e.m.f. E below: alreq æ...
Page 747: Current Transformers According To Iec 61869-2, Class P, Pr
1MRK 505 343-UEN B Section 23 Requirements 23.1.7.1 Current transformers according to IEC 61869-2, class P, PR M11623-6 v3 A CT according to IEC 61869-2 is specified by the secondary limiting e.m.f. E . The value of the is approximately equal to the corresponding E .
Page 748: Voltage Transformer Requirements
Section 23 1MRK 505 343-UEN B Requirements A CT according to ANSI/IEEE is also specified by the knee point voltage U that is kneeANSI graphically defined from an excitation curve. The knee point voltage U normally has a kneeANSI lower value than the knee-point e.m.f. according to IEC and BS. U can approximately be kneeANSI estimated to 75 % of the corresponding E...
Page 749: Iec 61850-9-2Le Merging Unit Requirements
1MRK 505 343-UEN B Section 23 Requirements During disturbed conditions, the trip security function in can cope with high bit error rates up to 10 or even up to 10 . The trip security can be configured to be independent of COMFAIL from the differential protection communication supervision, or blocked when COMFAIL is issued after receive error >100ms.
Page 750 Section 23 1MRK 505 343-UEN B Requirements There are two sample rates defined: 80 samples/cycle (4000 samples/sec. at 50Hz or 4800 samples/sec. at 60 Hz) for a merging unit “type1” and 256 samples/cycle for a merging unit “type2”. The IED can receive data rates of 80 samples/cycle. Note that the IEC 61850-9-2 LE standard does not specify the quality of the sampled values, only the transportation.
Page 751: Section 24 Glossary
1MRK 505 343-UEN B Section 24 Glossary Section 24 Glossary M14893-1 v18 Alternating current Actual channel Application configuration tool within PCM600 A/D converter Analog-to-digital converter ADBS Amplitude deadband supervision Analog digital conversion module, with time synchronization Analog input ANSI American National Standards Institute Autoreclosing ASCT Auxiliary summation current transformer...
Page 752 Section 24 1MRK 505 343-UEN B Glossary CO cycle Close-open cycle Codirectional Way of transmitting G.703 over a balanced line. Involves two twisted pairs making it possible to transmit information in both directions Command COMTRADE Standard Common Format for Transient Data Exchange format for Disturbance recorder according to IEEE/ANSI C37.111, 1999 / IEC 60255-24 Contra-directional...
Page 753 1MRK 505 343-UEN B Section 24 Glossary Electromagnetic interference EnFP End fault protection Enhanced performance architecture Electrostatic discharge F-SMA Type of optical fiber connector Fault number Flow control bit; Frame count bit FOX 20 Modular 20 channel telecommunication system for speech, data and protection signals FOX 512/515 Access multiplexer...
Page 754 Section 24 1MRK 505 343-UEN B Glossary IEEE Institute of Electrical and Electronics Engineers IEEE 802.12 A network technology standard that provides 100 Mbits/s on twisted- pair or optical fiber cable IEEE P1386.1 PCI Mezzanine Card (PMC) standard for local bus modules. References the CMC (IEEE P1386, also known as Common Mezzanine Card) standard for the mechanics and the PCI specifications from the PCI SIG (Special Interest Group) for the electrical EMF (Electromotive force).
Page 755 1MRK 505 343-UEN B Section 24 Glossary National Control Centre Number of grid faults Numerical module OCO cycle Open-close-open cycle Overcurrent protection Optical Ethernet module OLTC On-load tap changer OTEV Disturbance data recording initiated by other event than start/pick-up Overvoltage Overreach A term used to describe how the relay behaves during a fault condition.
Page 756 Section 24 1MRK 505 343-UEN B Glossary Short circuit location Station control system SCADA Supervision, control and data acquisition System configuration tool according to standard IEC 61850 Service data unit SELV circuit Safety Extra-Low Voltage circuit type according to IEC60255-27 Small form-factor pluggable (abbreviation) Optical Ethernet port (explanation) Serial communication module.
Page 757 1MRK 505 343-UEN B Section 24 Glossary Transformer Module. This module transforms currents and voltages taken from the process into levels suitable for further signal processing. Type identification User management tool Underreach A term used to describe how the relay behaves during a fault condition. For example, a distance relay is underreaching when the impedance presented to it is greater than the apparent impedance to the fault applied to the balance point, that is, the set reach.
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