ABB RELION 670 Series Applications Manual
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ABB RELION 670 Series Applications Manual

ABB RELION 670 Series Applications Manual

Busbar protection
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R E L I O N ® 670 SERIES
Busbar protection REB670
Version 2.1 ANSI
Application manual

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Summary of Contents for ABB RELION 670 Series

  • Page 1 — R E L I O N ® 670 SERIES Busbar protection REB670 Version 2.1 ANSI Application manual...
  • Page 3 Document ID: 1MRK 505 337-UUS Issued: March 2019 Revision: A Product version: 2.1 © Copyright 2016 ABB. All rights reserved...
  • 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 In case any errors are detected, the reader is kindly requested to notify the manufacturer. Other than under explicit contractual commitments, in no event shall ABB be responsible or liable for any loss or damage resulting from the use of this manual or the application of the equipment.
  • Page 6 Directive 2004/108/EC) and concerning electrical equipment for use within specified voltage limits (Low-voltage directive 2006/95/EC). This conformity is the result of tests conducted by ABB in accordance with the product standard EN 60255-26 for the EMC directive, and with the product standards EN 60255-1 and EN 60255-27 for the low voltage directive.

  • Page 7: Table Of Contents

    Table of contents Table of contents Section 1 Introduction......................17 This manual.............................. 17 Intended audience..........................17 Product documentation........................18 1.3.1 Product documentation set......................18 1.3.2 Document revision history....................... 19 1.3.3 Related documents..........................19 Document symbols and conventions....................20 1.4.1 Symbols..............................20 1.4.2 Document conventions........................
  • Page 8 Table of contents 4.2.2.3 Example 3............................59 4.2.2.4 Examples on how to connect, configure and set CT inputs for most commonly used CT connections........................63 4.2.2.5 Example on how to connect a wye connected three-phase CT set to the IED....64 4.2.2.6 Example how to connect delta connected three-phase CT set to the IED......
  • Page 9 Table of contents 6.1.3.9 CT disconnection for bus section and bus coupler current transformer cores....102 6.1.3.10 End fault protection........................107 6.1.3.11 Zone interconnection (Load transfer)..................109 6.1.3.12 Tripping circuit arrangement......................113 6.1.3.13 Trip arrangement with one-phase version................113 6.1.3.14 Centralized trip unit........................114 6.1.3.15 Decentralized trip arrangement....................114 6.1.3.16 Mechanical lock-out function......................114...
  • Page 10 Table of contents 7.2.3.1 Settings for each step (x = 1-4)....................156 7.2.3.2 Second harmonic restrain......................158 Four step residual overcurrent protection, (Zero sequence or negative sequence directionality) EF4PTOC (51N/67N)....................163 7.3.1 Identification.............................163 7.3.2 Setting guidelines..........................163 7.3.2.1 Settings for each step (x = 1, 2, 3 and 4)...................163 7.3.2.2 Common settings for all steps....................166 7.3.2.3...
  • Page 11 Table of contents Section 8 Voltage protection....................201 Two step undervoltage protection UV2PTUV (27)................. 201 8.1.1 Identification.............................201 8.1.2 Setting guidelines..........................201 8.1.2.1 Equipment protection, such as for motors and generators..........201 8.1.2.2 Disconnected equipment detection..................201 8.1.2.3 Power supply quality ........................202 8.1.2.4 Voltage instability mitigation....................
  • Page 12 Table of contents 9.1.2 Application............................217 9.1.3 Setting guidelines..........................217 Overfrequency protection SAPTOF (81)................... 218 9.2.1 Identification.............................218 9.2.2 Application............................218 9.2.3 Setting guidelines..........................219 Rate-of-change frequency protection SAPFRC (81)...............219 9.3.1 Identification.............................219 9.3.2 Application............................219 9.3.3 Setting guidelines..........................220 Section 10 Multipurpose protection..................221 10.1 General current and voltage protection CVGAPC................221 10.1.1 Identification.............................
  • Page 13 Table of contents Section 12 Control........................243 12.1 Synchronism check, energizing check, and synchronizing SESRSYN (25)........ 243 12.1.1 Identification............................ 243 12.1.2 Application............................243 12.1.2.1 Synchronizing..........................243 12.1.2.2 Synchronism check........................244 12.1.2.3 Energizing check...........................246 12.1.2.4 Voltage selection.......................... 247 12.1.2.5 External fuse failure........................247 12.1.3 Application examples........................248 12.1.3.1...
  • Page 14 Table of contents 12.2.3.1 Configuration..........................270 12.2.3.2 Auto-recloser parameter settings.....................276 12.3 Apparatus control APC........................279 12.3.1 Application............................279 12.3.1.1 Bay control (QCBAY)........................282 12.3.1.2 Switch controller (SCSWI)......................283 12.3.1.3 Switches (SXCBR/SXSWI)......................284 12.3.1.4 Reservation function (QCRSV and RESIN)................284 12.3.2 Interaction between modules....................... 286 12.3.3 Setting guidelines..........................288 12.3.3.1...
  • Page 15 Table of contents 12.4.7.2 Signals in single breaker arrangement..................315 12.4.7.3 Signals in double-breaker arrangement...................319 12.4.7.4 Signals in breaker and a half arrangement................320 12.4.8 Interlocking for double CB bay DB (3)..................320 12.4.8.1 Application............................. 320 12.4.8.2 Configuration setting........................321 12.4.9 Interlocking for breaker-and-a-half diameter BH (3)..............322 12.4.9.1 Application.............................
  • Page 16 Table of contents 13.3 Logic for group alarm WRNCALH...................... 332 13.3.1 Logic for group warning WRNCALH..................... 332 13.3.1.1 Identification..........................332 13.3.1.2 Application............................. 332 13.3.1.3 Setting guidelines.........................332 13.4 Logic for group indication INDCALH....................332 13.4.1 Logic for group indication INDCALH....................332 13.4.1.1 Identification..........................
  • Page 17 Table of contents Section 14 Monitoring......................345 14.1 Measurement............................345 14.1.1 Identification............................ 345 14.1.2 Application............................345 14.1.3 Zero clamping........................... 347 14.1.4 Setting guidelines..........................347 14.1.4.1 Setting examples..........................350 14.2 Gas medium supervision SSIMG (63)....................356 14.2.1 Identification............................ 356 14.2.2 Application............................356 14.3 Liquid medium supervision SSIML (71)....................
  • Page 18 Table of contents 14.9.3 Setting guidelines..........................369 Section 15 Metering........................ 371 15.1 Pulse-counter logic PCFCNT....................... 371 15.1.1 Identification............................. 371 15.1.2 Application............................371 15.1.3 Setting guidelines..........................371 15.2 Function for energy calculation and demand handling ETPMMTR..........372 15.2.1 Identification.............................372 15.2.2 Application............................372 15.2.3 Setting guidelines..........................373 Section 16 Station communication..................375 16.1 Communication protocols........................375...
  • Page 19 Table of contents 17.1.1 Identification............................ 393 17.1.2 Application............................393 17.1.2.1 Communication hardware solutions..................393 17.1.2.2 Application possibility with one-phase REB670..............394 17.1.3 Setting guidelines..........................395 Section 18 Security......................... 401 18.1 Authority status ATHSTAT........................401 18.1.1 Application............................401 18.2 Self supervision with internal event list INTERRSIG..............401 18.2.1 Application............................
  • Page 20 Table of contents 19.8.2 Setting guidelines........................... 409 19.9 Signal matrix for binary outputs SMBO ..................410 19.9.1 Application............................410 19.9.2 Setting guidelines..........................410 19.10 Signal matrix for mA inputs SMMI....................410 19.10.1 Application............................410 19.10.2 Setting guidelines..........................410 19.11 Signal matrix for analog inputs SMAI....................410 19.11.1 Application............................
  • Page 21 Table of contents Section 21 Glossary.........................431 Application manual...

  • Page 23: Introduction

    1MRK 505 337-UUS A 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 24: Product Documentation

    Section 1 1MRK 505 337-UUS A 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 25: Document Revision History

    1MRK 505 337-UUS A Section 1 Introduction The operation manual contains instructions on how to operate the IED once it has been commissioned. The manual provides instructions for the monitoring, controlling and setting of the IED. The manual also describes how to identify disturbances and how to view calculated and measured power grid data to determine the cause of a fault.

  • Page 26: Document Symbols And Conventions

    Section 1 1MRK 505 337-UUS A Introduction 670 series manuals Document numbers Communication protocol manual, IEC 61850 Edition 2 1MRK 511 350-UEN Point list manual, DNP3 1MRK 511 354-UUS Accessories guide 1MRK 514 012-BUS Connection and Installation components 1MRK 513 003-BEN Test system, COMBITEST 1MRK 512 001-BEN Document symbols and conventions...

  • Page 27: Document Conventions

    1MRK 505 337-UUS A Section 1 Introduction performance leading to personal injury or death. It is important that the user fully complies with all warning and cautionary notices. 1.4.2 Document conventions GUID-96DFAB1A-98FE-4B26-8E90-F7CEB14B1AB6 v8 • Abbreviations and acronyms in this manual are spelled out in the glossary. The glossary also contains definitions of important terms.
  • Page 28 Section 1 1MRK 505 337-UUS A Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes BUSPTRC_B2 BUSPTRC BUSPTRC BUSPTRC_B3 BUSPTRC BUSPTRC BUSPTRC_B4 BUSPTRC BUSPTRC BUSPTRC_B5 BUSPTRC BUSPTRC BUSPTRC_B6 BUSPTRC BUSPTRC BUSPTRC_B7 BUSPTRC BUSPTRC BUSPTRC_B8 BUSPTRC BUSPTRC BUSPTRC_B9 BUSPTRC BUSPTRC BUSPTRC_B10...
  • Page 29 1MRK 505 337-UUS A Section 1 Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes BZNTPDIF_A BZNTPDIF BZATGAPC BZATPDIF BZNTGAPC BZNTPDIF BZNTPDIF_B BZNTPDIF BZBTGAPC BZBTPDIF BZNTGAPC BZNTPDIF CBPGAPC CBPLLN0 CBPMMXU CBPMMXU CBPPTRC CBPPTRC HOLPTOV HOLPTOV HPH1PTOV HPH1PTOV PH3PTOC PH3PTUC PH3PTUC...
  • Page 30 Section 1 1MRK 505 337-UUS A Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes EF4PTOC EF4LLN0 EF4PTRC EF4PTRC EF4RDIR EF4RDIR GEN4PHAR GEN4PHAR PH1PTOC PH1PTOC EFPIOC EFPIOC EFPIOC EFRWPIOC EFRWPIOC EFRWPIOC ETPMMTR ETPMMTR ETPMMTR FDPSPDIS FDPSPDIS FDPSPDIS FMPSPDIS FMPSPDIS FMPSPDIS...
  • Page 31 1MRK 505 337-UUS A Section 1 Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes LCCRPTRC LCCRPTRC LCCRPTRC LCNSPTOC LCNSPTOC LCNSPTOC LCNSPTOV LCNSPTOV LCNSPTOV LCP3PTOC LCP3PTOC LCP3PTOC LCP3PTUC LCP3PTUC LCP3PTUC LCPTTR LCPTTR LCPTTR LCZSPTOC LCZSPTOC LCZSPTOC LCZSPTOV LCZSPTOV LCZSPTOV LD0LLN0...
  • Page 32 Section 1 1MRK 505 337-UUS A Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes OV2PTOV GEN2LLN0 OV2PTOV OV2PTOV PH1PTRC PH1PTRC PAPGAPC PAPGAPC PAPGAPC PCFCNT PCGGIO PCFCNT PH4SPTOC GEN4PHAR GEN4PHAR OCNDLLN0 PH1BPTOC PH1BPTOC PH1PTRC PH1PTRC PHPIOC PHPIOC PHPIOC PRPSTATUS RCHLCCH...
  • Page 33 1MRK 505 337-UUS A Section 1 Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes SSIMG SSIMG SSIMG SSIML SSIML SSIML STBPTOC STBPTOC BBPMSS STBPTOC STEFPHIZ STEFPHIZ STEFPHIZ STTIPHIZ STTIPHIZ STTIPHIZ SXCBR SXCBR SXCBR SXSWI SXSWI SXSWI T2WPDIF T2WPDIF T2WGAPC...
  • Page 34 Section 1 1MRK 505 337-UUS A Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes ZC1WPSCH ZPCWPSCH ZPCWPSCH ZCLCPSCH ZCLCPLAL ZCLCPSCH ZCPSCH ZCPSCH ZCPSCH ZCRWPSCH ZCRWPSCH ZCRWPSCH ZCVPSOF ZCVPSOF ZCVPSOF ZGVPDIS ZGVLLN0 PH1PTRC PH1PTRC ZGVPDIS ZGVPDIS ZGVPTUV ZGVPTUV ZMCAPDIS ZMCAPDIS...

  • Page 35: Application

    1MRK 505 337-UUS A Section 2 Application Section 2 Application General IED application SEMOD121007-5 v7 The IED is designed for the selective, reliable and fast differential protection of busbars, T- connections and meshed corners. It can be used for protection of single and double busbar with or without transfer bus, double circuit breaker or breaker-and-a-half stations.
  • Page 36 Section 2 1MRK 505 337-UUS A Application limited to a certain level, typically between 300A and 2000A primary by a neutral point reactor or resistor). Alternatively this sensitive pickup can be used when high sensitivity is required from busbar differential protection (that is, energizing of the bus via long line). Overall operating characteristic of the differential function in the IED is shown in figure 2.

  • Page 37: Main Protection Functions

    1MRK 505 337-UUS A Section 2 Application Optionally available circuit breaker failure protection, one for every CT input into the IED, offers secure local back-up protection for the circuit breakers in the station. Optionally available four-stage, non-directional overcurrent protections, one for every CT input into the IED, provide remote backup functionality for connected feeders and remote-end stations.

  • Page 38: Back-Up Protection Functions

    Section 2 1MRK 505 337-UUS A Application IEC 61850 ANSI Function description Busbar Busbar REB670 (Customized) Differential protection BUTPTRC, Busbar differential protection, 2 zones, three BCZTPDIF, phase/4 bays BZNTPDIF, BZITGGIO, BUTSM4 BUTPTRC, Busbar differential protection, 2 zones, three BCZTPDIF, phase/8 bays BZNTPDIF, BZITGGIO, BUTSM8...

  • Page 39: Control And Monitoring Functions

    1MRK 505 337-UUS A Section 2 Application IEC 61850 ANSI Function description Busbar Busbar REB670 (Customized) GUPPDUP Directional underpower protection GOPPDOP Directional overpower protection CBPGAPC Capacitor bank protection Voltage protection UV2PTUV Two step undervoltage protection OV2PTOV Two step overvoltage protection ROV2PTOV Two step residual overvoltage protection VDCPTOV...
  • Page 40 Section 2 1MRK 505 337-UUS A Application IEC 61850 ANSI Function description Busbar Busbar REB670 SLGAPC Logic rotating switch for function selection and LHMI presentation VSGAPC Selector mini switch DPGAPC Generic communication function for Double Point indication SPC8GAPC Single point generic control 8 signals AUTOBITS AutomationBits, command function for DNP3.0...
  • Page 41 1MRK 505 337-UUS A Section 2 Application IEC 61850 ANSI Function description Busbar Busbar REB670 ANDQT, Configurable logic blocks Q/T (see Table 0–1 INDCOMBSPQT, INDEXTSPQT, INVALIDQT, INVERTERQT, ORQT, PULSETIMERQT, RSMEMORYQT, SRMEMORYQT, TIMERSETQT, XORQT AND, GATE, INV, Extension logic package (see Table 5) 0–1 LLD, OR, PULSETIMER,...
  • Page 42 Section 2 1MRK 505 337-UUS A Application IEC 61850 ANSI Function description Busbar Busbar REB670 MVGAPC Generic communication function for Measured Value BINSTATREP Logical signal status report RANGE_XP Measured value expander block SSIMG Gas medium supervision SSIML Liquid medium supervision SSCBR Circuit breaker monitoring I103MEAS...
  • Page 43 1MRK 505 337-UUS A Section 2 Application Basic configurable logic block Total number of instances SRMEMORY TIMERSET Table 4: Total number of instances for configurable logic blocks Q/T Configurable logic blocks Q/T Total number of instances ANDQT INDCOMBSPQT INDEXTSPQT INVALIDQT INVERTERQT ORQT PULSETIMERQT...

  • Page 44: Communication

    Section 2 1MRK 505 337-UUS A Application Communication GUID-5F144B53-B9A7-4173-80CF-CD4C84579CB5 v12 IEC 61850 ANSI Function description Busbar Busbar REB670 (Customized) Station communication LONSPA, SPA SPA communication protocol LON communication protocol HORZCOMM Network variables via LON PROTOCOL Operation selection between SPA and IEC 60870-5-103 for SLM RS485PROT Operation selection for RS485...

  • Page 45: Basic Ied Functions

    1MRK 505 337-UUS A Section 2 Application IEC 61850 ANSI Function description Busbar Busbar REB670 (Customized) OPTICAL103 IEC 60870-5-103 Optical serial communication 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...
  • Page 46 Section 2 1MRK 505 337-UUS A Application IEC 61850 or function Description name IRIG-B Time synchronization SETGRPS Number of setting groups ACTVGRP Parameter setting groups TESTMODE Test mode functionality CHNGLCK Change lock function SMBI Signal matrix for binary inputs SMBO Signal matrix for binary outputs SMMI Signal matrix for mA inputs...
  • Page 47 1MRK 505 337-UUS A Section 2 Application IEC 61850 or function ANSI Description name FNKEYTY1–FNKEYTY5 Parameter setting function for HMI in PCM600 FNKEYMD1– FNKEYMD5 LEDGEN General LED indication part for LHMI OPENCLOSE_LED LHMI LEDs for open and close keys GRP1_LED1– Basic part for CP HW LED indication module GRP1_LED15 GRP2_LED1–...

  • Page 49: Configuration

    1MRK 505 337-UUS A Section 3 Configuration Section 3 Configuration Description of configuration REB670 SEMOD129261-1 v2 3.1.1 Available ACT configurations for pre-configured REB670 SEMOD129275-87 v5 Three configurations have been made available for pre-configured REB670 IED. It shall be noted that all three configurations include the following features: •...

  • Page 50: Description Of 3 Ph Package A20A

    Section 3 1MRK 505 337-UUS A Configuration circuit breakers. Thus full disconnector/breaker supervision is available. This configuration is available for only three REB670 variants (that is A31, B21 and B31). In order to use X03 configuration, optional breaker failure and overcurrent functions must be ordered.

  • Page 51: Description Of 3 Ph Package A31A

    1MRK 505 337-UUS A Section 3 Configuration REB670(A20-X01) / REB670(A31-X01) DFR/SER DR DRP RDRE 3Id/I 3Id/I BZIT GGIO BCZT PDIF Isqi 3Id/I 3Id/I C MMXU C MSQI BZNT PDIF BUT PTRC Isqi 3Id/I 3Id/I C MMXU C MSQI BZNT PDIF BUT PTRC Other Functions in Library BDC GAPC...
  • Page 52 Section 3 1MRK 505 337-UUS A Configuration REB670 ANSI(A20A-X00) / REB670 ANSI(A31A-X00) DFR/SER DR HW LOGIC DRP RDRE C MMXU AC LOGIC 3Id/I 3Id/I BZIT GGIO BCZT PDIF 3Id/I BUT PTRC 3Id/I 3Id/I BZNT PDIF BUT PTRC REB670 ANSI(A20A-X00) / REB670 ANSI(A31A-X00) DFR/SER DR DRP RDRE C MMXU...
  • Page 53 1MRK 505 337-UUS A Section 3 Configuration REB670(A31-X01) DFR/SER DR DRP RDRE C MMXU HW LOGIC 3Id/I 3Id/I AC LOGIC BZIT GGIO BCZT PDIF 3Id/I BUT PTRC 3Id/I 3Id/I BZNT PDIF BUT PTRC 3Id/I 3Id/I BZNT PDIF BUT PTRC Other Functions in Library SWS GGIO Optional Functions 51/67...
  • Page 54 Section 3 1MRK 505 337-UUS A Configuration GUID-1264BCF9-F245-423C-B620-3D66F3292F41 V2 EN-US Figure 6: Configuration diagram for A31, configuration X01_1 Application manual...
  • Page 55 1MRK 505 337-UUS A Section 3 Configuration GUID-33AD6AD4-3315-4A4C-AB05-C1C04E815866 V2 EN-US Figure 7: Configuration diagram for A31, configuration X02 Application manual...

  • Page 56: Description Of 1 Ph Package B20A

    Section 3 1MRK 505 337-UUS A Configuration REB670(A31-X03) BDC GAPC DFR/SER DR BDC GAPC DRP RDRE BDC GAPC BDC GAPC BDC GAPC BDC GAPC BDC GAPC 3Id/I BZIT GGIO Isqi C MMXU C MSQI 51_67 4(3I>) 50BF 3I>BF 3Id/I OC4 PTOC CC RBRF BUT PTRC 3Id/I...
  • Page 57 1MRK 505 337-UUS A Section 3 Configuration • This version can be used with external auxiliary 3-phase to 1-phase summation current transformers with different turns ratio for each phase. REB670(B20-X01) / REB670(B21-X01) / REB670(B31-X01) PHASE L3 REB670(B20-X01) / REB670(B21-X01) / REB670(B31-X01) PHASE L2 REB670(B20-X01) / REB670(B21-X01) / REB670(B31-X01) PHASE L1...

  • Page 58: Description Of 1 Ph Package B31A

    Section 3 1MRK 505 337-UUS A Configuration REB670(B20-X01) /REB670(B21-X01) / REB670(B31-X01) PHASE L3 REB670(B20-X01) /REB670(B21-X01) / REB670(B31-X01) PHASE L2 REB670(B20-X01) /REB670(B21-X01) / REB670(B31-X01) PHASE L1 DFR/SER DR DRP RDRE HW LOGIC Id/I Id/I AC LOGIC BZIS GGIO BCZS PDIF Id/I C MMXU BUS PTRC Id/I...
  • Page 59 1MRK 505 337-UUS A Section 3 Configuration • The IED is intended for busbar protection applications in big substations where dynamic Zone Selection, quite large number of binary inputs and outputs and many CT inputs are needed. The IED includes two differential zones and twenty-four CT inputs. Note that binary inputs can be shared between phases by including the LDCM communication module.
  • Page 60 Section 3 1MRK 505 337-UUS A Configuration REB670(B20-X01) / REB670(B21-X01) / REB670(B31-X01) PHASE L3 REB670(B20-X01) / REB670(B21-X01) / REB670(B31-X01) PHASE L2 REB670(B20-X01) / REB670(B21-X01) / REB670(B31-X01) PHASE L1 DFR/SER DR HW LOGIC DRP RDRE AC LOGIC Id/I Id/I BZIS GGIO BCZS PDIF Id/I C MMXU...
  • Page 61 1MRK 505 337-UUS A Section 3 Configuration REB670(B21-X02)/REB670(B31-X02)- PHASE L3 REB670(B21-X02)/REB670(B31-X02)- PHASE L2 REB670(B21-X02)/REB670(B31-X02)- PHASE L1 BDC GAPC DFR/SER DR DRP RDRE BDC GAPC BDC GAPC BDC GAPC BDC GAPC BDC GAPC BDC GAPC Id/I BZIS GGIO Id/I C MMXU BUS PTRC Id/I BZNS PDIF...
  • Page 62 Section 3 1MRK 505 337-UUS A Configuration REB670(B21-X03)/REB670(B31-X03)- PHASE L3 REB670(B21-X03)/REB670(B31-X03)- PHASE L2 REB670(B21-X03)/REB670(B31-X03)- PHASE L1 BDC GAPC DFR/SER DR BDC GAPC DRP RDRE BDC GAPC BDC GAPC BDC GAPC BDC GAPC Id/I BDC GAPC BZIS GGIO C MMXU I> 50BF I>BF Id/I...

  • Page 63: Analog Inputs

    1MRK 505 337-UUS A 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 64: Example

    Section 4 1MRK 505 337-UUS A Analog inputs 4.2.1.1 Example SEMOD55055-11 v4 Usually the A phase-to-ground 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 65 1MRK 505 337-UUS A 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 CT_WyePoint with CT_WyePoint with CT_WyePoint with...
  • Page 66 Section 4 1MRK 505 337-UUS A 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 CT_WyePoint with CT_WyePoint with Transformer as Transformer as reference object.
  • Page 67 1MRK 505 337-UUS A Section 4 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 CT_WyePoint with Line as reference object. Setting of current input Setting of current input Correct setting is for transformer functions:...
  • Page 68 Section 4 1MRK 505 337-UUS A Analog inputs Busbar Busbar Protection en06000196_ansi.vsd ANSI06000196 V1 EN-US Figure 19: Example how to set CT_WyePoint parameters in the IED CT_WyePoint 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 69 1MRK 505 337-UUS A Section 4 Analog inputs CTprim = 1000 (value in A) • CTsec = 5 (value in A). • 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 current or...
  • Page 70 Section 4 1MRK 505 337-UUS A Analog inputs It is recommended to: • use 1A rated CT input into the IED in order to connect CTs with 1A and 2A secondary rating • use 5A rated CT input into the IED in order to connect CTs with 5A and 10A secondary rating 4.2.2.5 Example on how to connect a wye connected three-phase CT set to the IED...
  • Page 71 1MRK 505 337-UUS A Section 4 Analog inputs Where: The drawing shows how to connect three individual phase currents from a wye connected three-phase CT set to the three CT inputs of the IED. The current inputs are located in the TRM. It shall be noted that for all these current inputs the following setting values shall be entered for the example shown in Figure21.
  • Page 72 Section 4 1MRK 505 337-UUS A Analog inputs SMAI_20_2 BLOCK AI3P REVROT ^GRP2L1 ^GRP2L2 ^GRP2L3 CT 800/1 ^GRP2N Star Connected ANSI11000026-4-en.vsd Protected Object ANSI11000026 V4 EN-US Figure 22: Wye connected three-phase CT set with its star point away from the protected object In the example in figure 22 case everything is done in a similar way as in the above described...
  • Page 73 1MRK 505 337-UUS A Section 4 Analog inputs SMAI2 BLOCK AI3P AI 01 (I) ^GRP2_A ^GRP2_B ^GRP2_C AI 02 (I) ^GRP2N TYPE AI 03 (I) CT 800/1 Wye Connected AI 04 (I) AI 05 (I) AI 06 (I) Protected Object ANSI06000644-2-en.vsd ANSI06000644 V2 EN-US Figure 23: Wye connected three-phase CT set with its star point away from the protected object and the...
  • Page 74 Section 4 1MRK 505 337-UUS A Analog inputs is a connection made in the Signal Matrix tool (SMT), Application configuration tool (ACT), which connects the residual/neutral current input to the fourth input channel of the preprocessing function block 6). Note that this connection in SMT shall not be done if the residual/neutral current is not connected to the IED.
  • Page 75 1MRK 505 337-UUS A Section 4 Analog inputs SMAI_20 IA-IB IB-IC IC-IA ANSI11000027-2-en.vsd Protected Object ANSI11000027 V2 EN-US Figure 24: 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 76 Section 4 1MRK 505 337-UUS A Analog inputs Another alternative is to have the delta connected CT set as shown in figure 25: SMAI_20 IA-IC IB-IA IC-IB ANSI11000028-2-en.vsd Protected Object ANSI11000028 V2 EN-US Figure 25: 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 for all used current inputs on the TRM the following setting parameters shall be entered: =800A...
  • Page 77 1MRK 505 337-UUS A Section 4 Analog inputs Protected Object SMAI_20_2 BLOCK AI3P REVROT ^GRP2_A ^GRP2_B ^GRP2_C ^GRP2_N ANSI11000029-3-en.vsd ANSI11000029 V3 EN-US Figure 26: 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 78 Section 4 1MRK 505 337-UUS A Analog inputs 4.2.3 Relationships between setting parameter Base Current, CT rated primary current and minimum pickup of a protection IED GUID-8EB19363-9178-4F04-A6AC-AF0C2F99C5AB v1 Note that for all line protection applications (e.g. distance protection or line differential protection) the parameter Base Current (i.e.
  • Page 79 1MRK 505 337-UUS A Section 4 Analog inputs 4.2.4.2 Examples how to connect, configure and set VT inputs for most commonly used VT connections SEMOD55055-60 v5 Figure defines the marking of voltage transformer terminals commonly used around the world. (X1) (X1) (X1) (H1)
  • Page 80 Section 4 1MRK 505 337-UUS A Analog inputs AI 07 (I) SMAI2 BLOCK AI3P AI 08 (V) ^GRP2_A ^GRP2_B AI 09 (V) ^GRP2_C ^GRP2N #Not used AI 10 (V) TYPE AI 11 (V) AI 12 (V) ANSI06000599-2-en.vsd ANSI06000599 V2 EN-US Figure 28: A Three phase-to-ground connected VT Where: shows how to connect three secondary phase-to-ground voltages to three VT inputs on the IED...
  • Page 81 1MRK 505 337-UUS A 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 82 Section 4 1MRK 505 337-UUS A Analog inputs 13.8 13.8 AI 07(I) SMAI2 BLOCK AI3P AI 08 (V) ^GRP2_A (A-B) ^GRP2_B (B-C) AI 09 (V) ^GRP2_C (C-A) ^GRP2N #Not Used TYPE AI 10(V) AI 11(V) AI 12(V) ANSI06000600-3-en.vsd ANSI06000600 V3 EN-US Figure 29: 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...
  • Page 83 1MRK 505 337-UUS A Section 4 Analog inputs are three connections made in the Signal Matrix tool (SMT), Application configuration tool (ACT), which connects 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 than one preprocessing block might be connected in parallel to these three VT inputs shows that in this example the fourth (that is, residual) input channel of the preprocessing block is not connected in SMT.
  • Page 84 Section 4 1MRK 505 337-UUS A Analog inputs AI 07 (I) AI 08 (V) SMAI2 AI 09 (V) BLOCK AI3P ^GRP2_A # Not Used AI 10 (V) ^GRP2_B # Not Used ^GRP2_C # Not Used AI 11 (V) +3Vo ^GRP2N TYPE AI 12 (V) ANSI06000601-2-en.vsd...
  • Page 85 1MRK 505 337-UUS A Section 4 Analog inputs Where: shows how to connect the secondary side of the open delta VT to one VT input on the IED. +3Vo 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 86 Section 4 1MRK 505 337-UUS A Analog inputs In case of a solid ground fault close to the VT location the primary value of 3Vo will be equal to: Ph Ph Ph Gnd (Equation 7) EQUATION1927-ANSI V1 EN-US The primary rated voltage of such VT is always equal to VPh-Gnd. Therefore, three series connected VT secondary windings will give the secondary voltage equal only to one individual VT secondary winding rating.
  • Page 87 1MRK 505 337-UUS A Section 4 Analog inputs Where: shows how to connect the secondary side of open delta VT to one VT input in the IED. +3Vo 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 88 Section 4 1MRK 505 337-UUS A Analog inputs 4.2.4.7 Example on how to connect a neutral point VT to the IED SEMOD55055-232 v7 Figure gives an example on how to connect a neutral point VT to the IED. This type of VT connection presents secondary voltage proportional to V to the IED.
  • Page 89 1MRK 505 337-UUS A Section 4 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 1MRK 505 337-UUS A Section 5 Local HMI Section 5 Local HMI AMU0600442 v14 ANSI13000239-2-en.vsd ANSI13000239 V2 EN-US Figure 33: Local human-machine interface The LHMI of the IED contains the following elements: • Keypad • Display (LCD) • LED indicators •...
  • Page 92 Section 5 1MRK 505 337-UUS A Local HMI The LHMI is used for setting, monitoring and controlling. 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 display view is divided into four basic areas.
  • Page 93 1MRK 505 337-UUS A Section 5 Local HMI IEC13000281-1-en.vsd GUID-C98D972D-D1D8-4734-B419-161DBC0DC97B V1 EN-US Figure 35: 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 36: Indication LED panel The function button and indication LED panels are not visible at the same time.
  • Page 94 Section 5 1MRK 505 337-UUS A Local HMI There are 15 programmable indication LEDs on the front of the LHMI. Each LED can indicate three states with the colors: green, yellow and red. The texts related to each three-color LED are divided into three panels.
  • Page 95 1MRK 505 337-UUS A Section 5 Local HMI ANSI15000157-1-en.vsdx ANSI15000157 V1 EN-US Figure 37: 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 Section 5 1MRK 505 337-UUS A Local HMI Communication port Programmable indication LEDs 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 Normal, Pickup and Trip. Table 8: Normal LED (green) LED state Description Auxiliary supply voltage is disconnected.
  • Page 97 1MRK 505 337-UUS A 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 505 337-UUS A Local HMI IEC13000280-1-en.vsd GUID-94AF2358-6905-4782-B37B-ACD3DCBF7F9C V1 EN-US Figure 38: 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 1MRK 505 337-UUS A Section 6 Differential protection Section 6 Differential protection Busbar differential protection SEMOD121185-1 v2 6.1.1 Identification SEMOD130380-4 v3 Busbar differential protection, 3-phase version IEC 61850 IEC 60617 ANSI/IEEE C37.2 Function description identification identification device number Busbar differential protection, 2 BUTPTRC 3Id/I zones, three phase/4 bays...
  • Page 100 Section 6 1MRK 505 337-UUS A Differential protection SEMOD130384-4 v5 Busbar differential protection, 1-phase version Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Busbar differential protection, 2 3Id/I BUSPTRC zones, single phase/12 or 24 bays SYMBOL-JJ V1 EN-US Busbar differential protection, 2 3Id/I BCZSPDIF...
  • Page 101 1MRK 505 337-UUS A Section 6 Differential protection 6.1.2.2 Meshed corner application and T-connection application M12098-3 v4 The REB670 general differential function is suitable for application on mesh-corner arrangements. Mesh corners might have four or even up to six CT inputs and are basically simple single busbar arrangements.
  • Page 102 Section 6 1MRK 505 337-UUS A Differential protection security against misoperation must be extremely high due to the heavy impact on the overall network service. Must have as short tripping time as possible in order to minimize the damage, minimize the danger and possible injury to the people who might be working in the station at the moment of internal fault, and secure the network stability.
  • Page 103 IED, the IED algorithm would be quite complex. Thus, it was decided to re-use the ABB excellent experience from the analog percentage restrained differential protection IED (that is, RADSS and REB 103), and use only the following three quantities:...
  • Page 104 Section 6 1MRK 505 337-UUS A Differential protection 6.1.3.4 Zone selection (CT switching) M12107-3 v3 The so-called CT switching (that is, zone selection) is required in situation when one particular circuit (that is, bay) can be connected to different busbars by individual disconnectors. Typical example is a station with double busbars with or without transfer bus as shown in figure figure 61, where any feeder bay can be connected to any of the two buses.
  • Page 105 1MRK 505 337-UUS A Section 6 Differential protection Scheme1_RADSS "If not OPEN then CLOSED" SEMOD127523-24 v2 As the name of the scheme suggests, only when the auxiliary contacts signal clean open position ("normally open auxiliary (NO) contact input" = inactive and "normally closed auxiliary (NC) contact input"...
  • Page 106 Section 6 1MRK 505 337-UUS A Differential protection arcing possible closed open N.O. input „closed“ N.C. input „open“ current assignment 1) disconnector supervision running en06000084.vsd IEC06000084 V1 EN-US Figure 40: Scheme_1 RADSS arcing possible closed open N.O. input „closed“ N.C. input „open“...
  • Page 107 1MRK 505 337-UUS A Section 6 Differential protection Line disconnector replica SEMOD127523-82 v3 The line disconnector position from a feeder bay might be required for busbar protection under certain circumstances. Typical example is when the line disconnector 989 and associated grounding switch QC1 are located between CT and protected busbar as indicated in figure 42.
  • Page 108 Section 6 1MRK 505 337-UUS A Differential protection ZoneSel is set to FIXEDtoZA , then this CT input will If for a particular CT input setting parameter be only included to the differential zone A. This setting is typically used for simple single zone application such as: single busbar staions, breaker-and-a-half stations or double breaker stations.
  • Page 109 1MRK 505 337-UUS A Section 6 Differential protection en01000013_ansi.vsd ANSI01000013 V1 EN-US Figure 43: Example of station with two sets of main CTs in the bus-section bay This is the most expensive, but good solution for busbar protection. Two differential zones overlapping across the bus-section or bus-coupler circuit breaker.
  • Page 110 Section 6 1MRK 505 337-UUS A Differential protection Blind Zone en01000014_ansi.vsd ANSI01000014 V1 EN-US Figure 44: Example of station with just one main CT in the bus-section bay For this type of solution just one main CT is located on only one side of the circuit breaker. Thus, there is no zone overlapping across the section/coupler circuit breaker as shown in figure 43.
  • Page 111 1MRK 505 337-UUS A Section 6 Differential protection Zone A Zone B REB 670 t=1s Bxxx BLKTR TRIP CTRLZA CB Closing CONNZA CTRLZB Signal CONNZB External or Internal ZEROCUR Bus-Coupler BFP Bus-Coupler TRZONE Backup Trip Command TRBAY I3PB1 Bus-Coupler Backup OC Trip Parameter ZoneSel must CT Input...
  • Page 112 Section 6 1MRK 505 337-UUS A Differential protection en04000283_ansi.vsd ANSI04000283 V1 EN-US Figure 46: Example of station without main CTs in the bus-section bay In such case two separate zones can be maintained only while bus coupler breaker is open. As soon as bus coupler breaker is going to be closed the zone interconnection feature must be activated and complete busbars will be automatically protected with just one overall differential zone.
  • Page 113 1MRK 505 337-UUS A Section 6 Differential protection 6.1.3.10 End fault protection SEMOD127750-31 v3 When Live tank CBs or GIS are involved, there is a physical separation between the CT and the CB. primary faults between main CT and CB in a feeder bay. End Fault Protection is related to Therefore, it is directly related to the position of the main CT in feeder bay.
  • Page 114 Section 6 1MRK 505 337-UUS A Differential protection xx06000139_ansi.vsd ANSI06000139 V1 EN-US Figure 49: Busbar protection measuring and fault clearing boundaries where: is Busbar Protection measuring boundary determined by feeder CT locations is Busbar Protection internal fault clearing boundary determined by feeder CB locations is End fault region for feeders as shown in figure 48/B is End fault region for feeders as shown in figure 48/C In figure...
  • Page 115 1MRK 505 337-UUS A Section 6 Differential protection protection is often called end fault protection in relay literature. It shall be noted that at the same time busbar protection will remain stable (that is, selective) for such fault. • For feeders with CT on the bus side of the circuit breaker (that is, two feeders on the right- hand side in figure 49), the current measurement can be disconnected from the busbar protection zone some time after feeder CB opening (that is, after 400 ms).
  • Page 116 Section 6 1MRK 505 337-UUS A Differential protection be activated either externally via binary input or derived internally by built-in logic. Internally, this “zone switching” feature will be activated if the following conditions are met: ZoneSel set to either CtrlInclude or CtrlExcludes •...
  • Page 117 1MRK 505 337-UUS A Section 6 Differential protection blocked as soon as the total incoming current exceeds the pre-set level. By appropriate setting then it can be insured that this sensitive level is blocked for external phase-to-phase or three- phase faults, which can cause CT saturation. Comparison between these two characteristics is shown in figure 50.
  • Page 118 Section 6 1MRK 505 337-UUS A Differential protection Operate region Oper Level s=0.0-0.90 (settable) [Primary Amps] en06000062.vsd IEC06000062 V1 EN-US Figure 51: Check zone operation characteristic Note that the check zone minimum differential operational level OperLevel shall be set equal to or less than the corresponding operating level of the usual discriminating zones.
  • Page 119 1MRK 505 337-UUS A Section 6 Differential protection By using the reset menu on the local HMI By energizing the dedicated binary input called “Reset OCT” via communication links By energizing the dedicated binary input called “Reset OCT” via logic done in the internal configuration For more details about the working principles of the Open CT Detection algorithm, refer to Technical reference manual.
  • Page 120 Section 6 1MRK 505 337-UUS A Differential protection GOOSE for ZoneA ZoneA Trip IED 670 GOOSE for ZoneB ZoneB Trip 50 ms Ext ZoneA Trip Switch IED 670 50 ms Ext ZoneB Trip 50 ms Ext ZoneA Trip IED 670 50 ms Ext ZoneB Trip en06000227.vsd...
  • Page 121 1MRK 505 337-UUS A Section 6 Differential protection M12119-4 v3 It is sometimes required to use lock-out relays for busbar protection operation. The IED has built-in feature to provide either self-reset or latched tripping in case of busbar protection operation. Which type of trip signal each zone will issue is determined by a parameter DiffTripOut which can be set either to SelfReset or Latched .
  • Page 122 Section 6 1MRK 505 337-UUS A Differential protection 6.1.4.2 Single busbar arrangements M6641-3 v4 The simplest form of busbar protection is a one-zone protection for single busbar configuration, as shown in figure 53. When different CT ratios exist in the bays compensation is done by setting the CT ratio individually for each bay.
  • Page 123 1MRK 505 337-UUS A Section 6 Differential protection ANSI11000238-1-en.vsd ANSI11000238 V1 EN-US Figure 54: Example of two single busbar sections with bus-sectionalizing disconnector and eight feeder bays per each busbar section The most common setups for this type of station are described in the following table. Table 14: Typical solutions for stations with two single busbar sections with bus-sectionalizing disconnector Version of REB670 IED...
  • Page 124 Section 6 1MRK 505 337-UUS A Differential protection xx06000088_ansi.vsd ANSI06000088 V1 EN-US Figure 55: Example of two single busbar sections with bus-section circuit breaker and eight feeder bays per each busbar section This type of busbar arrangement can be quite easily protected. The most common setups for this type of station are described in the following table.
  • Page 125 1MRK 505 337-UUS A Section 6 Differential protection xx06000121_ansi.vsd ANSI06000121 V1 EN-US Figure 56: Example of H-type station The requirement for the busbar protection scheme for this type of station may differ from utility to utility. It is possible to apply just one overall differential zone, which protects both busbar sections.
  • Page 126 Section 6 1MRK 505 337-UUS A Differential protection For station with double zone protection and just one set of CTs in the bus-section bay, it might be required, depending on the client requirements, to provide the special scheme for disconnection of bus-section CT when the bus-section CB is open.
  • Page 127 1MRK 505 337-UUS A Section 6 Differential protection REB 670 Bxxx BBP & Zone A BLKTR TRIP TRIP CTRLZA 152 Internal BFP CONNZA Backup Trip Command CTRLZB CONNZB TRZONE CT Input Parameter ZoneSel must TRBAY be set to "FixedToZA" I3PB1 Other Equipment CT Input...
  • Page 128 Section 6 1MRK 505 337-UUS A Differential protection ANSI11000240-1-en.vsd ANSI11000240 V1 EN-US Figure 59: Example of breaker-and-a-half station All breakers are normally closed. The requirement for the busbar protection scheme is that the scheme must have two independent differential zones, one for each busbar. In case of an internal fault on one of the two buses, all circuit breakers associated with the faulty busbar have to be tripped, but the supply to any load will not be interrupted.
  • Page 129 1MRK 505 337-UUS A Section 6 Differential protection REB 670 Remote Inter- Bxxx Trip Zone A BLKTR Feeder 1 TRIP CTRLZA 152 Internal BFP CONNZA BBP & Backup Trip Command CTRLZB CONNZB TRIP TRZONE CT Input TRBAY Parameter ZoneSel must be set to "FixedToZA"...
  • Page 130 Section 6 1MRK 505 337-UUS A Differential protection ANSI11000239-1-en.vsd ANSI11000239 V1 EN-US Figure 61: Example of double busbar station This type of busbar arrangement is very common. It is often preferred for larger installations. It provides good balance between maintenance work requirements and security of supply. If needed, two busbars can be split during normal service.
  • Page 131 1MRK 505 337-UUS A Section 6 Differential protection Disconnector aux. contact timing (Aux. contact a timing is only crucial when Scheme2_INX is used) Zone A Main Open Closed contact Zone B Aux. a Open Closed contact Aux. b Closed Open contact SSxx REB 670...
  • Page 132 Section 6 1MRK 505 337-UUS A Differential protection Zone A Disconnector aux. contact timing Zone B Main Open Closed contact Aux . b Closed Open contact REB 670 Set Parameter ZoneSel=" CtrlExcludes" External or Internal Bxxx Feeder BFP Backup Trip Command BLKTR TRIP CTRLZA...
  • Page 133 1MRK 505 337-UUS A Section 6 Differential protection Zone A Zone B REB 670 Parameter ZoneSel must be set to "FixedToZA" Bxxx BLKTR TRIP CTRLZA CONNZA Other CTRLZB CONNZB Equipment TRZONE CT Input TRBAY I3PB1 External or Internal Bus-Coupler BFP Backup Trip Command Bus-Coupler Bxxx...
  • Page 134 Section 6 1MRK 505 337-UUS A Differential protection Zone A Zone B REB 670 CB Closing Signal t=1s SSxx DISABLE CLOSED OPEN Bxxx ALARM BLKTR TRIP FORCED CTRLZA CONNZA CTRLZB CONNZB External or Internal ZEROCUR Bus-Coupler BFP Bus-Coupler TRZONE Backup Trip Command TRBAY I3PB1 Bus-Coupler Backup...
  • Page 135 1MRK 505 337-UUS A Section 6 Differential protection Zone A Zone B REB 670 t=1s Bxxx BLKTR TRIP CTRLZA CB Closing CONNZA CTRLZB Signal CONNZB External or Internal ZEROCUR Bus-Coupler BFP Bus-Coupler TRZONE Backup Trip Command TRBAY I3PB1 Bus-Coupler Backup OC Trip Parameter ZoneSel must CT Input...
  • Page 136 Section 6 1MRK 505 337-UUS A Differential protection Table 20: Possible solutions for a typical GIS station Version of REB670 IED Number of feeders on Number of REB670 IEDs required for the each side of the scheme station (excluding bus-coupler & bus- section bays) 3PH;...
  • Page 137 1MRK 505 337-UUS A Section 6 Differential protection The requirement for busbar protection scheme is that the scheme must have two independent differential zones, one for each busbar. In case of an internal fault on one of the two buses, bus- coupler circuit breaker and all feeder circuit breakers associated with the faulty bus have to be tripped, leaving other busbar still in normal operation.
  • Page 138 Section 6 1MRK 505 337-UUS A Differential protection xx06000123_ansi.vsd ANSI06000123 V1 EN-US Figure 69: Combination between one-and-half and double breaker station layouts This type of stations can be encountered very often in practice. Usually the station is arranged in such a way that double breaker bays can be, at a later stage, transformed into one-and-half breaker setup.
  • Page 139 1MRK 505 337-UUS A Section 6 Differential protection Accordingly the following solutions are possible: Table 22: Typical solutions for combination between double breaker and double busbar station layouts Version of REB670 IED Number of double Number of REB670 IEDs required for the breaker feeders / scheme Number of double...
  • Page 140 Section 6 1MRK 505 337-UUS A Differential protection 6.1.5 Summation principle SEMOD127509-1 v1 6.1.5.1 Introduction M12135-3 v3 A simplified bus differential protection for phase and ground faults can be obtained by using a single, one-phase IED with external auxiliary summation current transformers. By using this approach, more cost effective bus differential protection can be obtained.
  • Page 141 1MRK 505 337-UUS A Section 6 Differential protection Main CTs A-bus Summation CTs . . . CT24 with 1A CT inputs ANSI06000127_2_en.vsd ANSI06000127 V2 EN-US Figure 73: Principle CT connections for the complete station This summation type bus differential protection still has the same main CT requirements as outlined in section "Rated equivalent secondary e.m.f.
  • Page 142 Section 6 1MRK 505 337-UUS A Differential protection • Only one measuring circuit is utilized for all fault types (that is, no redundancy for multi-phase faults) • Primary fault sensitivity varies depending on the type of fault and involved phase(s), see table •...
  • Page 143 1MRK 505 337-UUS A Section 6 Differential protection • main CT rated primary current is not important for ASCT selection • possible main CT ratio differences will be compensated by a parameter setting in the IED • rated secondary current of ASCT is 1A for all types. That means that secondary ASCT winding should be always connected to the IED with 1A CT inputs, irrespective of the rated secondary current of the main CT All of these features simplify the ordering of the ASCTs.
  • Page 144 Section 6 1MRK 505 337-UUS A Differential protection Auxiliary Summation CT Main CT type SLCE 8; 2000/1A or 2000/5A 1/1A or 5/1A or 2/1A or 2000/2A SUMM REB 670 with 1A CTs Other relays en06000128_ansi.vsd ANSI06000128 V1 EN-US Figure 75: End-connection with ASCT connected to CT3 input It is important to notice that even in the case of 5A or 2A main CTs, secondary current of the summation CTs shall be connected to the IED with 1A CT inputs (as shown in figure 75).
  • Page 145 1MRK 505 337-UUS A Section 6 Differential protection Refer to section "SLCE 8/ASCT characteristics for series-connection"for detailed ASCT current calculation for series-connection. 6.1.5.4 Main CT ratio mismatch correction M12138-3 v2 As stated before, three types of ASCTs for REB670 are available. The first type shall be used for main CTs with 1A rated secondary current.
  • Page 146 Section 6 1MRK 505 337-UUS A Differential protection This means that if 722.5 primary amperes is injected only in phase C of any of the connected main CTs, the IED shall display the differential current of 1250A (primary) and should be on the point of the pickup (that is, trip).
  • Page 147 1MRK 505 337-UUS A Section 6 Differential protection Functions Comment DRPRDRE function Trip Value Recording feature will be connected to the individual summated bay current. Therefore recorded trip current values will not correspond to any actual primary currents. However such records can still be used to evaluate internal busbar protection, CCRBRF/CCSRBRF and OC4PTOC/PHS4PTOC protections operation.
  • Page 148 Section 6 1MRK 505 337-UUS A Differential protection é ù é ù é ù ê ú ê ú ê ú × ê ú ê ú ê ú ê ú ê ú ê ú ë û ë û ë û (Equation 19) EQUATION1786-ANSI V1 EN-US where: is complex constant (that is, a=-0.5+j0.866).
  • Page 149 1MRK 505 337-UUS A Section 6 Differential protection × × (Equation 24) EQUATION1110 V1 EN-US where: is a constant, which depends on the type of ASCT (that is, k=1, for 1/1A ASCT or k=5 for 5/1A ASCT or k=2 for 2/1A ASCT). The well-known relationship, between positive, negative and zero sequence current components and individual phase current quantities is shown in equation 25: é...
  • Page 151 1MRK 505 337-UUS A Section 7 Current protection Section 7 Current protection Four step phase overcurrent protection OC4PTOC(51/67) SEMOD129998-1 v7 7.1.1 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...
  • Page 152 Section 7 1MRK 505 337-UUS A Current protection function time delays of the different protections. To enable optimal co-ordination between all overcurrent protections, they should have the same time delay characteristic. Therefore a wide range of standardized inverse time characteristics are available: IEC and ANSI. It is also possible to tailor make the inverse time characteristic.
  • Page 153 1MRK 505 337-UUS A Section 7 Current protection AngleROA : Angle value, given in degrees, to define the angle sector of the directional function, shown in Figure 77. NumPhSel : Number of phases, with high current, required for operation. The setting possibilities 1 out of 3 , 2 out of 3 and 3 out of 3 .
  • Page 154 Section 7 1MRK 505 337-UUS A Current protection 7.1.3.1 Settings for each step M12982-19 v10.1.1 x means step 1, 2, 3 and 4. DirModeSelx : The directional mode of step x . Possible settings are Disabled / Non-directional / Forward / Reverse . Characteristx : Selection of time characteristic for step x .
  • Page 155 1MRK 505 337-UUS A Section 7 Current protection IMinx : Minimum operate current in % of IB for all inverse time characteristics, below which no operation takes place. IMinx : Minimum pickup current for step x in % of IBase . Set IMinx below Pickupx for every step to IMinx is set above Pickupx for any step achieve ANSI reset characteristic according to standard.
  • Page 156 Section 7 1MRK 505 337-UUS A Current protection Technical manual . There are some restrictions regarding The delay characteristics are described in the choice of the reset delay. For the definite time delay characteristics, the possible delay time setting instantaneous (1) and IEC (2 = set constant time reset).
  • Page 157 1MRK 505 337-UUS A Section 7 Current protection HarmRestrainx : This parameter can be set Disabled / Enabled , to disable or enable the 2nd harmonic restrain. The four step phase overcurrent protection 3-phase output can be used in different ways, depending on the application where the protection is used.
  • Page 158 Section 7 1MRK 505 337-UUS A Current protection values are updated not more often than once every five years. In many cases this time interval is still longer. Investigate the maximum load current that different equipment on the line can withstand.
  • Page 159 1MRK 505 337-UUS A Section 7 Current protection can be chosen in a graphical way. This is mostly used in the case of inverse time overcurrent protection. Figure shows how the time-versus-current curves are plotted in a diagram. The time setting is chosen to get the shortest fault time with maintained selectivity.
  • Page 160 Section 7 1MRK 505 337-UUS A Current protection overcurrent protection of IED B1 has a magnitude so that the protection will have instantaneous function. The overcurrent protection of IED A1 must have a delayed function. The sequence of events during the fault can be described using a time axis, see figure 81. Feeder Time axis The fault...
  • Page 161 1MRK 505 337-UUS A Section 7 Current protection Four step single phase overcurrent protection PH4SPTOC (51) SEMOD127812-1 v2 7.2.1 Identification SEMOD127810-2 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Four step single phase overcurrent PH4SPTOC protection I>...
  • Page 162 Section 7 1MRK 505 337-UUS A Current protection motor. Therefore there is a possibility to give a setting of a multiplication factor to the current pick-up level. This multiplication factor is activated from a binary input signal to the function. Power transformers can have a large inrush current, when being energized.
  • Page 163 1MRK 505 337-UUS A Section 7 Current protection Curve name ANSI Long Time Inverse IEC Normal Inverse IEC Very Inverse IEC Inverse IEC Extremely Inverse IEC Short Time Inverse IEC Long Time Inverse IEC Definite Time User Programmable ASEA RI RXIDG (logarithmic) Technical reference manual ”.
  • Page 164 Section 7 1MRK 505 337-UUS A Current protection For ANSI inverse time delay characteristics all three types of reset time characteristics are available; instantaneous (1), IEC (2 = set constant time reset) and ANSI (3 = current dependent reset time). For IEC inverse time delay characteristics the possible delay time settings are instantaneous (1) and IEC (2 = set constant time reset).
  • Page 165 1MRK 505 337-UUS A Section 7 Current protection cause protection operation. Here consideration also has to be taken to the protection reset current, so that a short peak of overcurrent does not cause operation of the protection even when the overcurrent has ceased. This phenomenon is described in figure 82. Current I Line phase current Operate current...
  • Page 166 Section 7 1MRK 505 337-UUS A Current protection There is also a demand that all faults, within the zone that the protection shall cover, must be detected by the phase overcurrent protection. The minimum fault current I , to be detected by scmin the protection, must be calculated.

  • Page 167: Example 1

    1MRK 505 337-UUS A Section 7 Current protection en05000204.wmf IEC05000204 V1 EN-US Figure 83: Fault time with maintained selectivity The operation time can be set individually for each overcurrent protection. To assure selectivity between different protective protections, in the radial network, there have to be a minimum time difference Dt between the time delays of two protections.
  • Page 168 Section 7 1MRK 505 337-UUS A 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 84: Sequence of events during fault where: is the fault occurs, is the trip signal from the overcurrent protection at IED B1 is sent.
  • Page 169 1MRK 505 337-UUS A Section 7 Current protection Four step residual overcurrent protection, (Zero sequence or negative sequence directionality) EF4PTOC (51N/67N) IP14509-1 v6 7.3.1 Identification M14881-1 v5 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Four step residual overcurrent EF4PTOC 51N_67N 4(IN>)
  • Page 170 Section 7 1MRK 505 337-UUS A Current protection Inverse time characteristic enables fast fault clearance of high current faults at the same time as selectivity to other inverse time phase overcurrent protections can be assured. This is mainly used in radial fed networks but can also be used in meshed networks. In meshed networks, the settings must be based on network fault calculations.
  • Page 171 1MRK 505 337-UUS A Section 7 Current protection Trip time txMin Pickup current ANSI10000058-1-en.vsdx ANSI10000058 V1 EN-US Figure 85: Minimum pickup current and trip time for inverse time characteristics txMin shall be set to the In order to fully comply with the curves definition, the setting parameter value which is equal to the operate time of the selected IEC inverse curve for measured current of twenty times the set current pickup value.
  • Page 172 Section 7 1MRK 505 337-UUS A Current protection 7.3.2.2 Common settings for all steps M15282-81 v9 AngleRCA : Relay characteristic angle given in degree. This angle is defined as shown in figure 86. The angle is defined positive when the residual current lags the reference voltage (Vpol = 3V or V V pol = 3V or V...
  • Page 173 1MRK 505 337-UUS A Section 7 Current protection Pickupx or the product 3I When the dual polarizing method is used it is important that the setting · ZNpol is not greater than 3V . If so, there is a risk for incorrect operation for faults in the reverse direction.
  • Page 174 Section 7 1MRK 505 337-UUS A Current protection Power System en05000136_ansi.vsd ANSI05000136 V1 EN-US Figure 87: Application for parallel transformer inrush current logic BlkParTransf function is activated the 2 If the harmonic restrain signal will latch as long as the residual current measured by the relay is larger than a selected step current level.
  • Page 175 1MRK 505 337-UUS A Section 7 Current protection StepForSOTF : If this parameter is set on the step 3 pickup signal will be used as current set level. If set disabled step 2 pickup signal will be used as current set level. t4U : Time interval when the SOTF function is active after breaker closing.
  • Page 176 Section 7 1MRK 505 337-UUS A Current protection well suited to operate in teleprotection communication schemes, which enables fast clearance of unsymmetrical faults on transmission lines. The directional function uses the voltage polarizing quantity. Choice of time characteristics: There are several types of time characteristics available such as definite time delay and different types of inverse time characteristics.
  • Page 177 1MRK 505 337-UUS A Section 7 Current protection 7.4.3 Setting guidelines GUID-460D6C58-598C-421E-AA9E-FD240210A6CC v3 The parameters for Four step negative sequence overcurrent protection NS4PTOC (46I2) are set via the local HMI or Protection and Control Manager (PCM600). The following settings can be done for the four step negative sequence overcurrent protection: Operation : Sets the protection to Enabled or Disabled .
  • Page 178 Section 7 1MRK 505 337-UUS A Current protection Curve name IEC Definite Time User Programmable ASEA RI RXIDG (logarithmic) The different characteristics are described in the Technical Reference Manual (TRM). Pickupx : Operation negative sequence current level for step x given in % of IBase . tx : Definite time delay for step x .
  • Page 179 1MRK 505 337-UUS A Section 7 Current protection Curve name Instantaneous IEC Reset (constant time) ANSI Reset (inverse time) The different reset characteristics are described in the Technical Reference Manual (TRM). There are some restrictions regarding the choice of reset delay. For the independent time delay characteristics the possible delay time settings are instantaneous (1) and IEC (2 = set constant time reset).
  • Page 180 Section 7 1MRK 505 337-UUS A Current protection Reverse Area Vpol=-V2 AngleRCA Forward Area Iop = I2 ANSI10000031-1-en.vsd ANSI10000031 V1 EN-US Figure 89: Relay characteristic angle given in degree In a transmission network a normal value of RCA is about 80°. VPolMin : Minimum polarization (reference) voltage % of VBase .
  • Page 181 1MRK 505 337-UUS A Section 7 Current protection 7.5.2 Application M15341-3 v5 Transformers in the power system are designed for a certain maximum load current (power) level. If the current exceeds this level the losses will be higher than expected. As a consequence the temperature of the transformer will increase.
  • Page 182 Section 7 1MRK 505 337-UUS A Current protection Operation : Sets the mode of operation. Disabled switches off the complete function. GlobalBaseSel : Selects the global base value group used by the function to define (IBase), (UBase) and (SBase). IRef : Reference level of the current given in % of IBase . When the current is equal to IRef the final (steady state) heat content is equal to 1.
  • Page 183 1MRK 505 337-UUS A Section 7 Current protection Tau1High : Multiplication factor to adjust the time constant Tau1 if the current is higher than the IHighTau1 . IHighTau1 is set in % of IBase1 . set value Tau1Low : Multiplication factor to adjust the time constant Tau1 if the current is lower than the set ILowTau1 .
  • Page 184 Section 7 1MRK 505 337-UUS A Current protection 7.6.1 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 7.6.2 Application M13916-3 v6 In the design of the fault clearance system the N-1 criterion is often used.
  • Page 185 1MRK 505 337-UUS A Section 7 Current protection Contact means re-trip is done when circuit breaker is closed (breaker breaker position check) and No CBPos Check means re-trip is done without check of breaker position. position is used). Table 32: Dependencies between parameters RetripMode and FunctionMode RetripMode FunctionMode...
  • Page 186 Section 7 1MRK 505 337-UUS A Current protection t1 : Time delay of the re-trip. The setting can be given within the range 0 – 60s in steps of 0.001 s. Typical setting is 0 – 50ms. 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.
  • Page 187 1MRK 505 337-UUS A Section 7 Current protection there is a possibility to reduce the back-up trip delay for multi-phase faults. Typical setting is 90 – 150 ms. t3 : Additional time delay to t2 for a second back-up trip TRBU2. In some applications there might be a requirement to have separated back-up trip functions, tripping different back-up circuit breakers.
  • Page 188 Section 7 1MRK 505 337-UUS A Current protection 7.7.3 Setting guidelines SEMOD127980-4 v5 The parameters for Breaker failure protection, single phase version (CCSRBRF,50BF) are set via the local HMI or PCM600. The following settings can be done for the breaker failure protection. GlobalBaseSel : Selects the global base value group used by the function to define ( IBase ), ( VBase ) SBase ).
  • Page 189 1MRK 505 337-UUS A Section 7 Current protection where: is the maximum opening time for the circuit breaker cbopen is the maximum time for breaker failure protection to detect correct breaker function BFP_reset (the current criteria reset) is a safety margin margin It is often required that the total fault clearance time shall be less than a given critical time.
  • Page 190 Section 7 1MRK 505 337-UUS A Current protection Directional underpower protection GUPPDUP (37) SEMOD156693-1 v4 7.8.1 Identification SEMOD158941-2 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Directional underpower protection GUPPDUP P < SYMBOL-LL V2 EN-US 7.8.2 Application SEMOD151283-4 v5...
  • Page 191 1MRK 505 337-UUS A Section 7 Current protection Power to the power plant auxiliaries may come from a station service transformer connected to the secondary side of the step-up transformer. Power may also come from a start-up service transformer connected to the external network. One has to design the reverse power protection so that it can detect reverse power independent of the flow of power to the power plant auxiliaries.
  • Page 192 Section 7 1MRK 505 337-UUS A Current protection 7.8.3 Setting guidelines SEMOD172134-4 v7 GlobalBaseSel : Selects the global base value group used by the function to define ( IBase ), ( VBase ) SBase ). and ( Operation : With the parameter Operation the function can be set Enabled / Disabled . Mode : The voltage and current used for the power measurement.
  • Page 193 1MRK 505 337-UUS A Section 7 Current protection Angle1(2) is The function gives trip if the power component in the direction defined by the setting Power1(2) smaller than the set pick up power value Power1(2) Angle1(2) Operate en06000441.vsd IEC06000441 V1 EN-US Figure 93: Underpower mode Power1(2) gives the power component pick up value in the Angle1(2) direction.
  • Page 194 Section 7 1MRK 505 337-UUS A Current protection Operate ° Angle1(2) = 0 Power1(2) en06000556.vsd IEC06000556 V1 EN-US Figure 94: 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 195 1MRK 505 337-UUS A Section 7 Current protection The calibration factors for current and voltage measurement errors are set % of rated current/ voltage: IMagComp5, IMagComp30, IMagComp100 VMagComp5, VMagComp30, VMagComp100 IMagComp5, IMagComp30, IMagComp100 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.
  • Page 196 Section 7 1MRK 505 337-UUS A Current protection would cause an acceleration of the turbine generator at all routine shutdowns. This should have caused overspeed and high centrifugal stresses. 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.
  • Page 197 1MRK 505 337-UUS A Section 7 Current protection Underpower IED Overpower IED Operate Operate Line Line Margin Margin Operating point Operating point without without turbine torque turbine torque IEC06000315-2-en.vsd IEC06000315 V2 EN-US Figure 95: Reverse power protection with underpower IED and overpower IED 7.9.3 Setting guidelines SEMOD172150-4 v7...
  • Page 198 Section 7 1MRK 505 337-UUS A Current protection Mode Set value Formula used for complex power calculation = × × S 3 V (Equation 64) EQUATION2044 V1 EN-US = × × (Equation 65) EQUATION2045 V1 EN-US = × × (Equation 66) EQUATION2046 V1 EN-US The function has two stages that can be set independently.
  • Page 199 1MRK 505 337-UUS A Section 7 Current protection × × 3 VBase IBase (Equation 67) EQUATION2047 V1 EN-US Angle1(2) gives the characteristic angle giving maximum sensitivity of the power The setting protection function. The setting is given in degrees. For active power the set angle should be 0° or 180°.
  • Page 200 Section 7 1MRK 505 337-UUS A Current protection S TD S TD S ⋅ − ⋅ Calculated (Equation 69) EQUATION1893-ANSI V1 EN-US Where is a new measured value to be used for the protection function is the measured value given from the function in previous execution cycle is the new calculated value in the present execution cycle Calculated is settable parameter...
  • Page 201 1MRK 505 337-UUS A Section 7 Current protection (240V to 25kV) and sizes (2.5kVAr to about 1000kVAr). Capacitor unit can be designed with one or two bushings. The high-voltage SCB is normally constructed using individual capacitor units connected in series and/or parallel to obtain the required voltage and MVAr rating.
  • Page 202 Section 7 1MRK 505 337-UUS A Current protection Which type of fusing is used may depend on can manufacturer or utility preference and previous experience. Because the SCBs are built from the individual capacitor units the overall connections may vary. Typically used SCB configurations are: Delta-connected banks (generally used only at distribution voltages) Single wye-connected banks...
  • Page 203 1MRK 505 337-UUS A Section 7 Current protection current. The voltage capability of any series element of a capacitor unit shall be considered to be its share of the total capacitor unit voltage capability. Capacitor units should not give less than 100% nor more than 110% of rated reactive power at rated sinusoidal voltage and frequency, measured at a uniform case and internal temperature of 25°C.
  • Page 204 Section 7 1MRK 505 337-UUS A Current protection 400kV Preprocessing Capacitor bank Function Block protection function SMAI CBPGAPC 500/1 200MVAr 400kV IEC09000754-1-en.vsd IEC09000754 V1 EN-US Figure 99: Single line diagram for the application example From figure it is possible to calculate the following rated fundamental frequency current for this SCB: ×...
  • Page 205 1MRK 505 337-UUS A Section 7 Current protection IRecInhibit = 10% (of IBase ); Current level under which function will detect that SCB is disconnected from the power system tReconnInhibit = 300s ; Time period under which SCB shall discharge remaining residual voltage to less than 5%.
  • Page 206 Section 7 1MRK 505 337-UUS A Current protection tMin_HOL_IDMT = 0.1s ; Minimum time delay for IDMT stage. Selected value gives operate time in accordance with international standards 7.10.3.1 Restrike detection GUID-114747A5-0F7C-4F48-A32D-0C13BFF6ADCE v1 Opening of SCBs can be quite problematic for certain types of circuit breakers (CBs). Typically such problems are manifested as CB restrikes.
  • Page 207 1MRK 505 337-UUS A Section 8 Voltage protection Section 8 Voltage protection Two step undervoltage protection UV2PTUV (27) IP14544-1 v3 8.1.1 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 208 Section 8 1MRK 505 337-UUS A Voltage protection 8.1.2.3 Power supply quality M13851-56 v3 The setting must be below the lowest occurring "normal" voltage and above the lowest acceptable voltage, due to regulation, good practice or other agreements. 8.1.2.4 Voltage instability mitigation M13851-59 v3 This setting is very much dependent on the power system characteristics, and thorough studies have to be made to find the suitable levels.
  • Page 209 1MRK 505 337-UUS A Section 8 Voltage protection 2 out of 3 can be chosen. In (27) shall be insensitive for single phase-to-ground faults, subtransmission and transmission networks the undervoltage function is mainly a system supervision function and 3 out of 3 is selected. Pickupn : Set operate undervoltage operation value for step n , given as % of the parameter VBase .
  • Page 210 Section 8 1MRK 505 337-UUS A Voltage protection Two step overvoltage protection OV2PTOV (59) IP14545-1 v3 8.2.1 Identification M17002-1 v7 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Two step overvoltage protection OV2PTOV 3U> SYMBOL-C-2U-SMALLER-THAN V2 EN-US 8.2.2 Application M13799-3 v8...
  • Page 211 1MRK 505 337-UUS A Section 8 Voltage protection 8.2.3 Setting guidelines M13852-4 v9 The parameters for Two step overvoltage protection (OV2PTOV ,59) are set via the local HMI or PCM600. All the voltage conditions in the system where OV2PTOV (59) performs its functions should be considered.
  • Page 212 Section 8 1MRK 505 337-UUS A Voltage protection 8.2.3.5 The following settings can be done for the two step overvoltage protection M13852-22 v8 ConnType : Sets whether the measurement shall be phase-to-ground fundamental value, phase-to- phase fundamental value, phase-to-ground RMS value or phase-to-phase RMS value. Operation : Disabled / Enabled .
  • Page 213 1MRK 505 337-UUS A Section 8 Voltage protection t1Min longer than the operation time for other time. This might lead to unselective trip. By setting protections such unselective tripping can be avoided. ResetTypeCrvn : This parameter for inverse time characteristic can be set: Instantaneous , Frozen time , Linearly decreased .
  • Page 214 Section 8 1MRK 505 337-UUS A Voltage protection The residual voltage can also be calculated internally, based on measurement of the three-phase voltages. In high impedance grounded systems the residual voltage will increase in case of any fault connected to ground. Depending on the type of fault and fault resistance the residual voltage will reach different values.
  • Page 215 1MRK 505 337-UUS A Section 8 Voltage protection 8.3.3.4 High impedance grounded systems M13853-18 v9 In high impedance grounded systems, ground faults cause a neutral voltage in the feeding transformer neutral. Two step residual overvoltage protection ROV2PTOV (59N) is used to trip the transformer, as a backup protection for the feeder ground fault protection, and as a backup for the transformer primary ground fault protection.
  • Page 216 Section 8 1MRK 505 337-UUS A Voltage protection ANSI07000190-1-en.vsd ANSI07000190 V1 EN-US Figure 100: Ground fault in Non-effectively grounded systems 8.3.3.5 Direct grounded system GUID-EA622F55-7978-4D1C-9AF7-2BAB5628070A v7 In direct grounded systems, an ground fault on one phase indicates a voltage collapse in that phase.
  • Page 217 1MRK 505 337-UUS A Section 8 Voltage protection ANSI07000189-1-en.vsd ANSI07000189 V1 EN-US Figure 101: Ground fault in Direct grounded system 8.3.3.6 Settings for Two step residual overvoltage protection M13853-21 v12 Operation : Disabled or Enabled VBase (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-ground voltages within the protection.
  • Page 218 Section 8 1MRK 505 337-UUS A Voltage protection Pickupn : Set operate overvoltage operation value for step n , given as % of residual voltage VBase : corresponding to > × VBase kV (Equation 78) ANSIEQUATION2290 V1 EN-US The setting is dependent of the required sensitivity of the protection and the system grounding. In non-effectively grounded systems the residual voltage can be maximum the rated phase-to- ground voltage, which should correspond to 100%.
  • Page 219 1MRK 505 337-UUS A Section 8 Voltage protection Voltage differential protection VDCPTOV (60) SEMOD153860-1 v2 8.4.1 Identification SEMOD167723-2 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Voltage differential protection VDCPTOV 8.4.2 Application SEMOD153893-5 v3 The Voltage differential protection VDCPTOV (60) functions can be used in some different applications.
  • Page 220 Section 8 1MRK 505 337-UUS A Voltage protection VDCPTOV (60) function has a block input (BLOCK) where a fuse failure supervision (or MCB tripped) can be connected to prevent problems if one fuse in the capacitor bank voltage transformer set has opened and not the other (capacitor voltage is connected to input V2). It will also ensure that a fuse failure alarm is given instead of a Undervoltage or Differential voltage alarm and/or tripping.
  • Page 221 1MRK 505 337-UUS A Section 8 Voltage protection number of elements per phase in series and parallel. Normally values required are given by capacitor bank supplier. For fuse supervision normally only this alarm level is used and a suitable voltage level is 3-5% if the ratio correction factor has been properly evaluated during commissioning.
  • Page 223 1MRK 505 337-UUS A Section 9 Frequency protection Section 9 Frequency protection Underfrequency protection SAPTUF (81) IP15746-1 v3 9.1.1 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 9.1.2 Application M13350-3 v4...
  • Page 224 Section 9 1MRK 505 337-UUS A Frequency protection The under frequency PICKUP 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 225 1MRK 505 337-UUS A Section 9 Frequency protection 9.2.3 Setting guidelines M14959-3 v7 All the frequency and voltage magnitude conditions in the system where SAPTOF (81) performs its functions must be considered. The same also applies to the associated equipment, its frequency and time characteristic.
  • Page 226 Section 9 1MRK 505 337-UUS A Frequency protection can be used both for increasing frequency and for decreasing frequency. SAPFRC (81) provides an output signal, suitable for load shedding or generator shedding, generator boosting, HVDC-set- point change, gas turbine start up and so on. Very often SAPFRC (81) is used in combination 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.
  • Page 227 1MRK 505 337-UUS A Section 10 Multipurpose protection Section 10 Multipurpose protection 10.1 General current and voltage protection CVGAPC IP14552-1 v2 10.1.1 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 228 Section 10 1MRK 505 337-UUS A Multipurpose protection • Definite time delay or Inverse Time Overcurrent TOC/IDMT delay for both steps • Second harmonic supervision is available in order to only allow operation of the overcurrent stage(s) if the content of the second harmonic in the measured current is lower than pre-set level •...
  • Page 229 1MRK 505 337-UUS A Section 10 Multipurpose protection Set value for parameter Comment "CurrentInput” 3 · ZeroSeq CVGAPC function will measure internally calculated zero sequence current phasor multiplied by factor 3 MaxPh CVGAPC function will measure current phasor of the phase with maximum magnitude MinPh CVGAPC function will measure current phasor of the phase with minimum...
  • Page 230 Section 10 1MRK 505 337-UUS A Multipurpose protection Set value for parameter Comment "VoltageInput" MinPh CVGAPC function will measure voltage phasor of the phase with minimum magnitude UnbalancePh CVGAPC function will measure magnitude of unbalance voltage, which is internally calculated as the algebraic magnitude difference between the voltage phasor of the phase with maximum magnitude and voltage phasor of the phase with minimum magnitude.
  • Page 231 1MRK 505 337-UUS A Section 10 Multipurpose protection 10.1.2.3 Application possibilities SEMOD53443-136 v2 Due to its flexibility the general current and voltage protection (CVGAPC) function can be used, with appropriate settings and configuration in many different applications. Some of possible examples are given below: Transformer and line applications: •...
  • Page 232 Section 10 1MRK 505 337-UUS A Multipurpose protection to a strong system. Lower current and voltage values (1 to 2 per unit current and 20% to 40% rated voltage) are representative of weaker systems. Since a generator behaves similarly to an induction motor, high currents will develop in the rotor during the period it is accelerating.
  • Page 233 1MRK 505 337-UUS A Section 10 Multipurpose protection but the cable negative-sequence impedance is practically constant. It shall be noted that directional negative sequence OC element offers protection against all unbalance faults (phase-to- phase faults as well). Care shall be taken that the minimum pickup of such protection function shall be set above natural system unbalance level.
  • Page 234 Section 10 1MRK 505 337-UUS A Multipurpose protection RCADir and ROADir settings will be as well applicable for OC2 stage • the set values for DirMode_OC2 shall be set to Reverse • setting PickupCurr_OC2 shall be made more sensitive than pickup value of forward •...
  • Page 235 1MRK 505 337-UUS A Section 10 Multipurpose protection × æ ö ç ÷ × è ø (Equation 82) EQUATION1741-ANSI V1 EN-US In order to achieve such protection functionality with one CVGAPC functions the following must be done: Connect three-phase generator currents to one CVGAPC instance (for example, GF01) CurrentInput to value NegSeq Set parameter Set base current value to the rated generator current in primary amperes...
  • Page 236 Section 10 1MRK 505 337-UUS A Multipurpose protection Proper timing of the CVGAPC function made in this way can easily be verified by secondary injection. All other settings can be left at the default values. If required delayed time reset for OC1 step can be set in order to ensure proper function operation in case of repetitive unbalance conditions.
  • Page 237 1MRK 505 337-UUS A Section 10 Multipurpose protection × æ ö ç ÷ × è ø (Equation 86) EQUATION1744-ANSI V1 EN-US In order to achieve such protection functionality with one CVGAPC functions the following must be done: Connect three-phase generator currents to one CVGAPC instance (for example, GF01) CurrentInput to value PosSeq Set parameter Set base current value to the rated generator current in primary amperes...
  • Page 238 Section 10 1MRK 505 337-UUS A Multipurpose protection Proper timing of CVGAPC function made in this way can easily be verified by secondary injection. All other settings can be left at the default values. If required delayed time reset for OC1 step can be set in order to insure proper function operation in case of repetitive overload conditions.
  • Page 239 1MRK 505 337-UUS A Section 10 Multipurpose protection This functionality can be achieved by using one CVGAPC function. The following shall be done in order to insure proper operation of the function: Connect three-phase generator currents and voltages to one CVGAPC instance (for example, GF05) CurrentInput to value MaxPh VoltageInput to value MinPh-Ph (it is assumed that minimum phase-to-phase voltage shall...
  • Page 240 Section 10 1MRK 505 337-UUS A Multipurpose protection DirMode_OC1 to Forward 13. Set parameter DirPrinc_OC1 to IcosPhi&V 14. Set parameter ActLowVolt1_VM to Block 15. Set parameter Proper operation of the CVGAPC function made in this way can easily be verified by secondary injection.
  • Page 241 1MRK 505 337-UUS A Section 11 Secondary system supervision Section 11 Secondary system supervision 11.1 Fuse failure supervision FUFSPVC IP14556-1 v3 11.1.1 Identification M14869-1 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Fuse failure supervision FUFSPVC 11.1.2 Application...
  • Page 242 Section 11 1MRK 505 337-UUS A Secondary system supervision A criterion based on delta current and delta voltage measurements can be added to the fuse failure supervision function in order to detect a three phase fuse failure. This is beneficial for example during three phase transformer switching.
  • Page 243 1MRK 505 337-UUS A Section 11 Secondary system supervision working in an AND-condition, that is, both algorithms must give condition for block in order to activate the output signals BLKV or BLKZ. 11.1.3.3 Negative sequence based M13683-17 v9 3V2PU is given in percentage of the base voltage VBase and should not be The relay setting value set lower than the value that is calculated according to equation 88.
  • Page 244 Section 11 1MRK 505 337-UUS A Secondary system supervision I PU × IBase (Equation 91) EQUATION2293-ANSI V2 EN-US where: 3I0PU is the maximal zero sequence current during normal operating conditions, plus a margin of 10...20% IBase GlobalBaseSel is the base current for the function according to the setting 11.1.3.5 Delta V and delta I GUID-02336F26-98C0-419D-8759-45F5F12580DE v7...
  • Page 245 1MRK 505 337-UUS A Section 11 Secondary system supervision 11.2 Fuse failure supervision VDSPVC (60) GUID-9C5BA1A7-DF2F-49D4-A13A-C6B483DDFCDC v2 11.2.1 Identification GUID-109434B0-23E5-4053-9E6E-418530A07F9C v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Fuse failure supervision VDSPVC 11.2.2 Application GUID-AD63BF6C-0351-4E48-9FB2-9AB5CF0C521E v2 Some protection functions operate on the basis of measured voltage at the relay point.
  • Page 246 Section 11 1MRK 505 337-UUS A Secondary system supervision Main Vt circuit FuseFailSupvn ANSI12000143-1-en.vsd ANSI12000143 V1 EN-US Figure 104: Application of VDSPVC 11.2.3 Setting guidelines GUID-0D5A517C-1F92-46B9-AC2D-F41ED4E7C39E v1 GUID-52BF4E8E-0B0C-4F75-99C4-0BCB22CDD166 v2 The parameters for Fuse failure supervision VDSPVC are set via the local HMI or PCM600. GUID-0B298162-C939-47E4-A89B-7E6BD7BEBB2C v2 ConTypeMain and The voltage input type (phase-to-phase or phase-to-neutral) is selected using...
  • Page 247 1MRK 505 337-UUS A Section 11 Secondary system supervision Vdif Main block and Vdif Pilot alarm should be set low (approximately 30% of VBase ) The settings 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 249 1MRK 505 337-UUS A Section 12 Control Section 12 Control 12.1 Synchronism check, energizing check, and synchronizing SESRSYN (25) IP14558-1 v4 12.1.1 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...
  • Page 250 Section 12 1MRK 505 337-UUS A 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 the SlipFrequency and the set tBreaker time. To operation pulse sent in advance is using the measured prevent incorrect closing pulses, a maximum closing angle between bus and line is preset tBreaker at the...
  • Page 251 1MRK 505 337-UUS A Section 12 Control en04000179_ansi.vsd ANSI04000179 V1 EN-US Figure 105: Two interconnected power systems Figure shows two interconnected power systems. The cloud means that the interconnection can be further away, that is, a weak connection through other stations. The 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.
  • Page 252 Section 12 1MRK 505 337-UUS A Control SynchroCheck Bus voltage VHighBusSC > 50 – 120% of GblBaseSelBus Fuse fail VHighLineSC >50 – 120% of GblBaseSelLine Line Line Bus Voltage VDiffSC < 0.02 – 0.50 p.u. reference PhaseDiffM < 5 – 90 degrees voltage PhaseDiffA <...
  • Page 253 1MRK 505 337-UUS A Section 12 Control The energizing operation can operate in the dead line live bus (DLLB) direction, dead bus live line (DBLL) direction, or in both directions over the circuit breaker. Energizing from different directions can be different for automatic reclosing and manual closing of the circuit breaker. For manual closing it is also possible to allow closing when both sides of the breaker are dead, Dead Bus Dead Line (DBDL).
  • Page 254 (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. The connection example for selection of the manual energizing mode is shown in figure 108.
  • Page 255 1MRK 505 337-UUS A Section 12 Control 12.1.3.1 Single circuit breaker with single busbar M12324-3 v11 SESRSYN (25) V3PB1* SYNOK Bus 1 V3PB2* AUTOSYOK V3PL1* AUTOENOK V3PL2* MANSYOK BLOCK MANENOK BLKSYNCH TSTSYNOK BLKSC TSTAUTSY BLKENERG TSTMANSY BUS1_OP TSTENOK BUS1_CL VSELFAIL Fuse BUS2_OP B1SEL...
  • Page 256 Section 12 1MRK 505 337-UUS A Control 12.1.3.2 Single circuit breaker with double busbar, external voltage selection M12325-3 v8 SESRSYN (25) V3PB1* SYNOK V3PB2* AUTOSYOK V3PL1* AUTOENOK Bus 1 V3PL2* MANSYOK Bus 2 BLOCK MANENOK BLKSYNCH TSTSYNOK BLKSC TSTAUTSY BLKENERG TSTMANSY BUS1_OP TSTENOK...
  • Page 257 1MRK 505 337-UUS A Section 12 Control 12.1.3.3 Single circuit breaker with double busbar, internal voltage selection M12326-3 v7 SESRSYN (25) V3PB1* SYNOK V3PB2* AUTOSYOK V3PL1* AUTOENOK V3PL2* MANSYOK Bus 1 BLOCK MANENOK Bus 2 BLKSYNCH TSTSYNOK BLKSC TSTAUTSY BLKENERG TSTMANSY BUS1_OP TSTENOK...
  • Page 258 Section 12 1MRK 505 337-UUS A Control 12.1.3.4 Double circuit breaker M12329-3 v7 SESRSYN (25) V3PB1* SYNOK V3PB2* AUTOSYOK V3PL1* AUTOENOK V3PL2* MANSYOK BLOCK MANENOK BLKSYNCH TSTSYNOK BLKSC TSTAUTSY BLKENERG TSTMANSY BUS1_OP TSTENOK BUS1_CL VSELFAIL Fuse BUS2_OP B1SEL Voltage BUS2_CL B2SEL LINE1_OP L1SEL...
  • Page 259 1MRK 505 337-UUS A Section 12 Control 12.1.3.5 Breaker-and-a-half M12330-3 v8 Figure describes a breaker-and-a-half arrangement with three SESRSYN functions in the same IED, each of them handling voltage selection for WA1_QA1, TIE_QA1 and WA2_QA1 breakers respectively. The voltage from busbar 1 VT is connected to V3PB1 on all three function blocks and the voltage from busbar 2 VT is connected to V3PB2 on all three function blocks.
  • Page 260 Section 12 1MRK 505 337-UUS A Control Bus 1 CB Bus 1 SESRSYN (25) Bus 2 V3PB1* SYNOK V3PB2* AUTOSYOK V3PL1* AUTOENOK V3PL2* MANSYOK BLOCK MANENOK BLKSYNCH TSTSYNOK BLKSC TSTAUTSY BLKENERG TSTMANSY Fuse BUS1_OP TSTENOK bus1 Voltage BUS1_CL VSELFAIL VREF1 BUS2_OP B1SEL BUS2_CL...
  • Page 261 1MRK 505 337-UUS A Section 12 Control and configurations must abide by the following rules: Normally apparatus position is connected with contacts showing both open (b-type) and closed positions (a-type). WA1_QA1: • BUS1_OP/CL = Position of TIE_QA1 breaker and belonging disconnectors •...
  • Page 262 Section 12 1MRK 505 337-UUS A Control reference of base values. This means that the reference voltage of bus and line can be set to different values. The settings for the SESRSYN (25) function are found under Main menu/ Settings/IED Settings/Control/Synchronizing(25,SC/VC)/SESRSYN(25,SC/VC):X has been divided into four different setting groups: General, Synchronizing, Synchrocheck and Energizingcheck.
  • Page 263 1MRK 505 337-UUS A Section 12 Control VHighBusSynch and VHighLineSynch The voltage level settings shall be chosen in relation to the bus/line network voltage. The VHighBusSynch and VHighLineSynch have to be set lower than the value where threshold voltages the network is expected to be synchronized. A typical value is 80% of the rated voltage. VDiffSynch Setting of the voltage difference between the line voltage and the bus voltage.
  • Page 264 Section 12 1MRK 505 337-UUS A Control seconds. If the network frequencies are expected to be outside the limits from the start, a margin needs to be added. A typical setting is 600 seconds. tMinSynch tMinSynch is set to limit the minimum time at which the synchronizing closing The setting attempt is given.
  • Page 265 1MRK 505 337-UUS A Section 12 Control tSCA setting is used. A typical value for tSCM can be 1 second and setting is preferable, where the tSCA can be 0.1 seconds. a typical value for Energizingcheck settings AutoEnerg and ManEnerg Two different settings can be used for automatic and manual closing of the circuit breaker.
  • Page 266 Section 12 1MRK 505 337-UUS A Control restarted when the conditions are fulfilled again. Circuit breaker closing is thus not permitted until the energizing condition has remained constant throughout the set delay setting time. 12.2 Autorecloser for 1 phase, 2 phase and/or 3 phase operation SMBRREC (79) IP14559-1 v6 12.2.1...
  • Page 267 1MRK 505 337-UUS A Section 12 Control Line protection Operate Operate time time Closed Circuit breaker Open Break time Closing time Break time Fault duration Fault duration AR open time for breaker Set AR open time Reset time Auto-reclosing function en04000146_ansi.vsd ANSI04000146 V1 EN-US Figure 114: Single-shot automatic reclosing at a permanent fault...
  • Page 268 Section 12 1MRK 505 337-UUS A Control For the individual line breakers and auto-reclosing equipment, the ”auto-reclosing open time” expression is used. This is the dead time setting for the Auto-Recloser. During simultaneous tripping and reclosing at the two line ends, auto-reclosing open time is approximately equal to the line dead time.
  • Page 269 1MRK 505 337-UUS A Section 12 Control be the master and be connected to inhibit the other auto-recloser if it has started. This inhibit can for example be done from Autorecloser for 3-phase operation(SMBRREC ,79) In progress. When Single and/or three phase auto-reclosing is considered, there are a number of cases where the tripping shall be three phase anyway.
  • Page 270 Section 12 1MRK 505 337-UUS A Control also use the input RI_HS (Initiate High-Speed Reclosing). When initiating RI_HS, the auto-reclosing t1 3PhHS is used and the closing is done without checking the open time for three-phase shot 1, synchrocheck condition. A number of conditions need to be fulfilled for the start to be accepted and a new auto-reclosing cycle to be started.
  • Page 271 1MRK 505 337-UUS A Section 12 Control tExtended t1 , can be added to the normal shot 1 An auto-reclosing open time extension delay, delay. It is intended to come into use if the communication channel for permissive line protection is lost.
  • Page 272 Section 12 1MRK 505 337-UUS A Control While any of the auto-reclosing open time timers are running, the output INPROGR is activated. When the "open reset" 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-pole trip is set.
  • Page 273 1MRK 505 337-UUS A Section 12 Control Table 38: Type of reclosing shots at different settings of ARMode or integer inputs to MODEINT MODEINT (integer) ARMode Type of fault 1st shot 2nd-5th shot 1/2/3ph 1/2ph ..1ph + 1*2ph ..
  • Page 274 Section 12 1MRK 505 337-UUS A Control 12.2.2.15 Reclosing reset timer M12391-202 v3 tReset defines the time it takes from issue of the reclosing command, until the The reset timer reclosing function resets. Should a new trip occur during this time, it is treated as a continuation of the first fault.
  • Page 275 1MRK 505 337-UUS A Section 12 Control • Shall back-up time delayed trip give Lock-out (normally yes) • Shall Lock-out be generated when closing onto a fault (mostly) • Shall Lock-out be generated when the Autorecloser was OFF at the fault or for example, in Single phase AR mode and the fault was multi-phase (normally not as no closing attempt has been given) •...
  • Page 276 Section 12 1MRK 505 337-UUS A Control The Auto-Reclosing function will first receive a trip and initiate signal (RI) without any three-phase signal (TR3P). The Auto-Reclosing function will start a single-phase reclosing, if programmed to do so. At the evolving fault clearance there will be a new signal RI and three-pole trip information, t1 3Ph , for TR3P.
  • Page 277 1MRK 505 337-UUS A Section 12 Control StartByCBOpen is used, the CB Open condition shall also be connected to the input RI. RI_HS, Initiate High-speed auto-reclosing It may be used when one wants to use two different dead times in different protection trip t1 3PhHS .
  • Page 278 Section 12 1MRK 505 337-UUS A Control that this have a considerable delay. Input can also be used for other purposes if for some reason the Auto-Reclose shot need to be halted. TR2P and TR3P Signals for two-pole and three-pole trip. They are usually connected to the corresponding output of the TRIP block.
  • Page 279 1MRK 505 337-UUS A Section 12 Control READY Indicates that SMBRREC (79) function is ready for a new and complete reclosing sequence. It can be connected to the zone extension if a line protection should extended zone reach before automatic reclosing. 1PT1 and 2PT1 Indicates that single-phase or two-phase automatic reclosing is in progress.
  • Page 280 Section 12 1MRK 505 337-UUS A Control SMBRREC (79) INPUT OUTPUT BLOCKED SETON BLKON INPROGR ACTIVE BLOCKOFF UNSUCCL INHIBIT SUCCL CBREADY CLOSECMD PLCLOST RESET PERMIT1P PREP3P PROTECTION READY xxxx-TRIP RI_HS 1PT1 2PT1 SKIPHS ZCVPSOF-TRIP 3PT1 TRSOTF ZMQPDIS (21)--TRIP 3PT2 3PT3 THOLHOLD 3PT4 TR2P...
  • Page 281 1MRK 505 337-UUS A Section 12 Control SMBRREC (79) INPUT OUTPUT BLOCKED SETON BLKON INPROGR BLOCKOFF ACTIVE INHIBIT UNSUCCL SUCCL CBREADY PLCLOST CLOSECB PERMIT1P RESET TRIP-P3PTR PREP3P PROTECTION READY GROUND RELAYS xxxx-TRIP 1PT1 BLOCK 2PT1 3PT1 RI_HS 3PT2 SKIPHS 3PT3 ZCVPSOF-TRIP TRSOTF 3PT4...
  • Page 282 Section 12 1MRK 505 337-UUS A Control Terminal ‘‘ Master ” Priority = High SMBRREC (79) BLOCKED SETON BLKON INPROGR BLOCKOFF ACTIVE INHIBIT UNSUCCL RESET SUCCL PLCLOST READY CLOSEMD RI_HS PERMIT1P SKIPHS PREP3P THOLHOLD TRSOTF 1PT1 2PT1 CBREADY 3PT1 3PT2 SYNC 3PT3 3PT4...
  • Page 283 1MRK 505 337-UUS A Section 12 Control types of faults caused by other phenomena, for example wind, a greater number of reclose attempts (shots) can be motivated. First shot and reclosing program There are six different possibilities in the selection of reclosing programs. The type of reclosing used for different kinds of faults depends on the power system configuration and the users practices and preferences.
  • Page 284 Section 12 1MRK 505 337-UUS A Control tReset , Reset time The Reset time sets the time for resetting the function to its original state, after which a line fault and tripping will be treated as an independent new case with a new reclosing cycle. One may consider a nominal CB duty cycle of for instance, O-0.3sec CO- 3 min.
  • Page 285 1MRK 505 337-UUS A Section 12 Control UnsucClByCBCheck , Unsuccessful closing by CB check NoCBCheck . The “auto-reclosing unsuccessful” event is then decided by a The normal setting is new trip within the reset 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 command, UnsucClByCBCheck = CB Check and set tUnsucCl for instance to 1.0 s.
  • Page 286 Section 12 1MRK 505 337-UUS A Control Station HMI Station bus Local Local Local Apparatus Apparatus Apparatus Control Control Control CLOSE/OPEN CLOSE/OPEN CLOSE/OPEN breakers disconnectors grounding switches ANSI08000227.vsd ANSI08000227 V1 EN-US Figure 121: Overview of the apparatus control functions Features in the apparatus control function: •...
  • Page 287 1MRK 505 337-UUS A Section 12 Control Control operation can be performed from the local IED HMI. If the administrator has defined users with the IED Users tool in PCM600, then the local/remote switch is under authority control. If not, the default (factory) user is the SuperUser that can perform control operations from the local IED HMI without LogOn.
  • Page 288 Section 12 1MRK 505 337-UUS A Control 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. orCat attribute in originator category are defined in According to IEC61850 standard the Table 40 Table 40: orCat attribute according to IEC61850...
  • Page 289 1MRK 505 337-UUS A Section 12 Control IEC13000016-2-en.vsd IEC13000016 V2 EN-US Figure 123: APC - Local remote function block 12.3.1.2 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 290 Section 12 1MRK 505 337-UUS A Control At error the command sequence is cancelled. In the case when there are three one-phase switches (SXCBR) connected to the switch controller function, the switch controller will "merge" the position of the three switches to the resulting three-phase position.
  • Page 291 1MRK 505 337-UUS A Section 12 Control To ensure that the interlocking information is correct at the time of operation, a unique reservation method is available in the IEDs. With this reservation method, the bay that wants the reservation sends a reservation request to other bays and then waits for a reservation granted signal from the other bays.
  • Page 292 Section 12 1MRK 505 337-UUS A Control SCSWI RES_ EXT SELECTED Other SCSWI in the bay en 05000118_ ansi. vsd ANSI05000118 V2 EN-US Figure 125: Application principles for reservation with external wiring The solution in Figure can also be realized over the station bus according to the application example in Figure 126.
  • Page 293 1MRK 505 337-UUS A Section 12 Control • The Bay control (QCBAY) fulfils the bay-level functions for the apparatuses, such as operator place selection and blockings for the complete bay. • The Reservation (QCRSV) deals with the reservation function. • The Protection trip logic (SMPPTRC, 94) connects the "trip"...
  • Page 294 Section 12 1MRK 505 337-UUS A Control SMPPTRC ZMQPDIS SECRSYN (Trip logic) (Synchrocheck) (Distance) 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. req. Close CB SMBRREC (Auto-...
  • Page 295 1MRK 505 337-UUS A Section 12 Control RemoteIncStation is set to Yes , commands from IEC61850-8-1 clients at both If the parameter No , the station and remote level are accepted, when the QCBAY function is in Remote. If set to command LocSta controls which operator place is accepted when QCBAY is in Remote.
  • Page 296 Section 12 1MRK 505 337-UUS A Control tPoleDiscord is the allowed time to have discrepancy between the poles at control of three single- phase breakers. At discrepancy an output signal is activated to be used for trip or alarm, and during a command, the control function is reset, and a cause-code is given.
  • Page 297 1MRK 505 337-UUS A Section 12 Control • To avoid the dangerous or damaging operation of switchgear • To enforce restrictions on the operation of the substation for other reasons for example, load configuration. Examples of the latter are to limit the number of parallel transformers to a maximum of two or to ensure that energizing is always from one side, for example, the high voltage side of a transformer.
  • Page 298 Section 12 1MRK 505 337-UUS A Control 12.4.1 Configuration guidelines M13529-4 v4 The following sections describe how the interlocking for a certain switchgear configuration can be realized in the IED by using standard interlocking modules and their interconnections. They also describe the configuration settings.
  • Page 299 1MRK 505 337-UUS A Section 12 Control Signal BB7_D_OP All line disconnectors on bypass WA7 except in the own bay are open. VP_BB7_D The switch status of disconnectors on bypass busbar WA7 are valid. EXDU_BPB No transmission error from any bay containing disconnectors on bypass busbar WA7 These signals from each line bay (ABC_LINE, 3) except that of the own bay are needed: Signal...
  • Page 300 Section 12 1MRK 505 337-UUS A Control Section 1 Section 2 (WA1)A1 (WA2)B1 (WA7)C A1A2_DC(BS) B1B2_DC(BS) ABC_LINE ABC_BC ABC_LINE ABC_BC en04000479_ansi.vsd ANSI04000479 V1 EN-US Figure 130: Busbars divided by bus-section disconnectors (circuit breakers) To derive the signals: Signal BC_12_CL A bus-coupler connection exists between busbar WA1 and WA2. BC_17_OP No bus-coupler connection between busbar WA1 and WA7.
  • Page 301 1MRK 505 337-UUS A Section 12 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 DCOPTR The bus-section disconnector is open.
  • Page 302 Section 12 1MRK 505 337-UUS A Control BC12CLTR (sect.1) BC_12_CL DCCLTR (A1A2) 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) BC17OPTR (sect.2) BC17CLTR (sect.1) BC_17_CL DCCLTR (A1A2) BC17CLTR (sect.2) VPBC17TR (sect.1) VP_BC_17 VPDCTR (A1A2) VPBC17TR (sect.2)
  • Page 303 1MRK 505 337-UUS A Section 12 Control module inputs as follows. In the functional block diagram, 0 and 1 are designated 0=FALSE and 1=TRUE: • 789_OP = 1 • 789_CL = 0 • 7189G_OP = 1 • 7189G_CL = 0 •...
  • Page 304 Section 12 1MRK 505 337-UUS A Control WA1 (A) WA2 (B) WA7 (C) 2089 189G 289G en04000514_ansi.vsd ANSI04000514 V1 EN-US Figure 132: Switchyard layout ABC_BC (3) 12.4.3.2 Configuration M13553-138 v4 The signals from the other bays connected to the bus-coupler module ABC_BC are described below.
  • Page 305 1MRK 505 337-UUS A Section 12 Control 1289OPTR (bay 1) BBTR_OP 1289OPTR (bay 2) ..1289OPTR (bay n-1) VP1289TR (bay 1) VP_BBTR VP1289TR (bay 2) ..VP1289TR (bay n-1) EXDU_12 (bay 1) EXDU_12 EXDU_12 (bay 2) .
  • Page 306 Section 12 1MRK 505 337-UUS A Control Signal S1S2OPTR No bus-section coupler connection between bus-sections 1 and 2. VPS1S2TR The switch status of bus-section coupler BS is valid. EXDU_BS No transmission error from the bay that contains the above information. For a bus-coupler bay in section 1, these conditions are valid: BBTR_OP (sect.1) BBTR_OP...
  • Page 307 1MRK 505 337-UUS A Section 12 Control Signal BC_12_CL Another bus-coupler connection exists between busbar WA1 and WA2. VP_BC_12 The switch status of BC_12 is valid. EXDU_BC No transmission error from any bus-coupler bay (BC). These signals from each bus-coupler bay (ABC_BC), except the own bay, are needed: Signal BC12CLTR A bus-coupler connection through the own bus-coupler exists between busbar...
  • Page 308 Section 12 1MRK 505 337-UUS A Control DCCLTR (A1A2) BC_12_CL DCCLTR (B1B2) BC12CLTR (sect.2) VPDCTR (A1A2) VP_BC_12 VPDCTR (B1B2) VPBC12TR (sect.2) EXDU_DC (A1A2) EXDU_BC EXDU_DC (B1B2) EXDU_BC (sect.2) en04000485_ansi.vsd ANSI04000485 V1 EN-US Figure 137: Signals to a bus-coupler bay in section 1 from a bus-coupler bay in another section For a bus-coupler bay in section 2, the same conditions as above are valid by changing section 1 to section 2 and vice versa.
  • Page 309 1MRK 505 337-UUS A Section 12 Control • BBTR_OP = 1 • VP_BBTR = 1 12.4.4 Interlocking for transformer bay AB_TRAFO (3) IP14149-1 v2 12.4.4.1 Application M13567-3 v7 The interlocking for transformer bay (AB_TRAFO, 3) function is used for a transformer bay connected to a double busbar arrangement according to figure 138.
  • Page 310 Section 12 1MRK 505 337-UUS A Control Section 1 Section 2 (WA1)A1 (WA2)B1 (WA7)C A1A2_DC(BS) B1B2_DC(BS) AB_TRAFO ABC_BC AB_TRAFO ABC_BC en04000487_ansi.vsd ANSI04000487 V1 EN-US Figure 139: Busbars divided by bus-section disconnectors (circuit breakers) The project-specific logic for input signals concerning bus-coupler are the same as the specific logic for the line bay (ABC_LINE): Signal BC_12_CL...
  • Page 311 1MRK 505 337-UUS A Section 12 Control 12.4.5 Interlocking for bus-section breaker A1A2_BS (3) IP14154-1 v2 12.4.5.1 Application M15110-3 v7 The interlocking for bus-section breaker (A1A2_BS ,3) function is used for one bus-section circuit breaker between section 1 and 2 according to figure 140. The function can be used for different busbars, which includes a bus-section circuit breaker.
  • Page 312 Section 12 1MRK 505 337-UUS A Control Signal BBTR_OP No busbar transfer is in progress concerning this bus-section. VP_BBTR The switch status of BBTR is valid. EXDU_12 No transmission error from any bay connected to busbar 1(A) and 2(B). These signals from each line bay (ABC_LINE), each transformer bay (AB_TRAFO), and bus-coupler bay (ABC_BC) are needed: Signal 1289OPTR...
  • Page 313 1MRK 505 337-UUS A Section 12 Control S1S2OPTR (B1B2) BC12OPTR (sect.1) 1289OPTR (bay 1/sect.2) . . . BBTR_OP . . . 1289OPTR (bay n/sect.2) S1S2OPTR (B1B2) BC12OPTR (sect.2) 1289OPTR (bay 1/sect.1) ..1289OPTR (bay n /sect.1) VPS1S2TR (B1B2) VPBC12TR (sect.1) VP1289TR (bay 1/sect.2)
  • Page 314 Section 12 1MRK 505 337-UUS A Control S1S2OPTR (A1A2) BC12OPTR (sect.1) 1289OPTR (bay 1/sect.2) . . . BBTR_OP . . . 1289OPTR (bay n/sect.2) S1S2OPTR (A1A2) BC12OPTR (sect.2) 1289OPTR (bay 1/sect.1) ..1289OPTR (bay n /sect.1) VPS1S2TR (A1A2) VPBC12TR (sect.1) VP1289TR (bay 1/sect.2)
  • Page 315 1MRK 505 337-UUS A Section 12 Control 12.4.6.1 Application M13544-3 v7 The interlocking for bus-section disconnector (A1A2_DC, 3) function is used for one bus-section disconnector between section 1 and 2 according to figure 144. A1A2_DC (3) function can be used for different busbars, which includes a bus-section disconnector.
  • Page 316 Section 12 1MRK 505 337-UUS A Control Signal 189OPTR 189 is open. 289OPTR 289 is open (AB_TRAFO, ABC_LINE). 22089OTR 289 and 2089 are open (ABC_BC). VP189TR The switch status of 189 is valid. VP289TR The switch status of 289 is valid. V22089TR The switch status of 289 and 2089 are valid.
  • Page 317 1MRK 505 337-UUS A Section 12 Control For a bus-section disconnector, these conditions from the A2 busbar section are valid: 189OPTR (bay 1/sect.A2) S2DC_OP ..189OPTR (bay n/sect.A2) DCOPTR (A2/A3) VP189TR (bay 1/sect.A2) VPS2_DC .
  • Page 318 Section 12 1MRK 505 337-UUS A Control 289OPTR (22089OTR)(bay 1/sect.B2) S2DC_OP ..289OPTR (22089OTR)(bay n/sect.B2) DCOPTR (B2/B3) VP289TR(V22089TR) (bay 1/sect.B2) VPS2_DC ..VP289TR(V22089TR) (bay n/sect.B2) VPDCTR (B2/B3) EXDU_BB (bay 1/sect.B2) .
  • Page 319 1MRK 505 337-UUS A Section 12 Control These signals from each double-breaker bay (DB_BUS) are needed: Signal 189OPTR 189 is open. 289OPTR 289 is open. VP189TR The switch status of 189 is valid. VP289TR The switch status of 289 is valid. EXDU_DB No transmission error from the bay that contains the above information.
  • Page 320 Section 12 1MRK 505 337-UUS A Control 289OPTR (bay 1/sect.B1) S1DC_OP ..289OPTR (bay n/sect.B1) VP289TR (bay 1/sect.B1) VPS1_DC ..VP289TR (bay n/sect.B1) EXDU_DB (bay 1/sect.B1) EXDU_BB .
  • Page 321 1MRK 505 337-UUS A Section 12 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 322 Section 12 1MRK 505 337-UUS A Control Signal BB_DC_OP All disconnectors on this part of the busbar are open. VP_BB_DC The switch status of all disconnector on this part of the busbar is valid. EXDU_BB No transmission error from any bay containing the above information. These signals from each line bay (ABC_LINE), each transformer bay (AB_TRAFO), and each bus- coupler bay (ABC_BC) are needed: Signal...
  • Page 323 1MRK 505 337-UUS A Section 12 Control For a busbar grounding switch, these conditions from the A1 busbar section are valid: 189OPTR (bay 1/sect.A1) BB_DC_OP ..189OPTR (bay n/sect.A1) DCOPTR (A1/A2) VP189TR (bay 1/sect.A1) VP_BB_DC .
  • Page 324 Section 12 1MRK 505 337-UUS A Control 289OPTR(22089OTR)(bay 1/sect.B1) BB_DC_OP ..289PTR (22089OTR)(bay n/sect.B1) DCOPTR (B1/B2) VP289TR(V22089TR) (bay 1/sect.B1) VP_BB_DC ..VP289TR(V22089TR) (bay n/sect.B1) VPDCTR (B1/B2) EXDU_BB (bay 1/sect.B1) .
  • Page 325 1MRK 505 337-UUS A Section 12 Control 789OPTR (bay 1) BB_DC_OP ..789OPTR (bay n) VP789TR (bay 1) VP_BB_DC ..VP789TR (bay n) EXDU_BB (bay 1) EXDU_BB .
  • Page 326 Section 12 1MRK 505 337-UUS A 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 disconnectors A1A2_DC and B1B2_DC. Signal DCOPTR The bus-section disconnector is open.
  • Page 327 1MRK 505 337-UUS A Section 12 Control WA1 (A) WA2 (B) 189G 489G DB_BUS_B DB_BUS_A 289G 589G 6189 6289 389G DB_LINE 989G en04000518_ansi.vsd ANSI04000518 V1 EN-US Figure 165: Switchyard layout double circuit breaker Three types of interlocking modules per double circuit breaker bay are defined. DB_BUS_A (3) handles the circuit breaker QA1 that is connected to busbar WA1 and the disconnectors and grounding switches of this section.
  • Page 328 Section 12 1MRK 505 337-UUS A Control 12.4.9 Interlocking for breaker-and-a-half diameter BH (3) IP14173-1 v3 12.4.9.1 Application M13570-3 v6 The interlocking for breaker-and-a-half diameter (BH_CONN(3), BH_LINE_A(3), BH_LINE_B(3)) functions are used for lines connected to a breaker-and-a-half diameter according to figure 166. WA1 (A) WA2 (B) 189G...
  • Page 329 1MRK 505 337-UUS A Section 12 Control • 989G_OP = 1 • 989G_CL = 0 If, in this case, line voltage supervision is added, then rather than setting 989 to open state, specify the state of the voltage supervision: • 989_OP = VOLT_OFF •...
  • Page 330 Section 12 1MRK 505 337-UUS A Control 12.5.3 Setting guidelines SEMOD115063-294 v6 The following settings are available for the Logic rotating switch for function selection and LHMI presentation (SLGAPC) function: Operation : Sets the operation of the function Enabled or Disabled . NrPos : Sets the number of positions in the switch (max.
  • Page 331 1MRK 505 337-UUS A Section 12 Control INPUT VSGAPC PSTO INTONE IPOS1 IPOS2 SMBRREC_79 NAM_POS1 CMDPOS12 SETON Disabled NAM_POS2 CMDPOS21 Enabled ANSI07000112-3-en.vsd ANSI07000112 V3 EN-US Figure 167: Control of Autorecloser from local HMI through Selector mini switch VSGAPC is also provided with IEC 61850 communication so it can be controlled from SA system as well.
  • Page 332 Section 12 1MRK 505 337-UUS A Control When the input signal VALID is active, the values of the OPEN and CLOSE inputs determine the two-bit integer value of the output POSITION. The timestamp of the output POSITION will have the latest updated timestamp of the inputs OPEN and CLOSE.
  • Page 333 1MRK 505 337-UUS A Section 12 Control PSTO is the universal operator place selector for all control functions. Even if PSTO can be configured to allow LOCAL or ALL operator positions, the only functional position usable with the SPC8GAPC function block is REMOTE. 12.8.3 Setting guidelines SEMOD176518-4 v5...
  • Page 334 Section 12 1MRK 505 337-UUS A Control 12.10 Single command, 16 signals SINGLECMD SEMOD119849-1 v2 12.10.1 Identification GUID-2217CCC2-5581-407F-A4BC-266CD6808984 v1 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Single command, 16 signals SINGLECMD 12.10.2 Application M12445-3 v3 Single command, 16 signals (SINGLECMD) is a common function and always included in the IED.
  • Page 335 1MRK 505 337-UUS A Section 12 Control Single command function Function n SINGLECMD Function n CMDOUTy OUTy en04000207.vsd IEC04000207 V2 EN-US Figure 169: Application example showing a logic diagram for control of built-in functions Single command function Configuration logic circuits SINGLESMD Device 1 CMDOUTy...
  • Page 336 Section 12 1MRK 505 337-UUS A Control • Disabled, sets all outputs to 0, independent of the values sent from the station level, that is, the operator station or remote-control gateway. • Steady, sets the outputs to a steady signal 0 or 1, depending on the values sent from the station level.
  • Page 337 1MRK 505 337-UUS A Section 13 Logic Section 13 Logic 13.1 Trip matrix logic TMAGAPC IP15121-1 v4 13.1.1 Identification SEMOD167882-2 v3 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Trip matrix logic TMAGAPC 13.1.2 Application M15321-3 v11 The trip matrix logic TMAGAPC function is used to route trip signals and other logical output signals to different output contacts on the IED.
  • Page 338 Section 13 1MRK 505 337-UUS A Logic 13.2.2 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 339 1MRK 505 337-UUS A Section 13 Logic 13.4.1.2 Application GUID-9BAD30FB-4B75-4E14-82A8-6A59B09FA6EA v1 Group indication logic function INDCALH is used to route indication signals to different LEDs and/or output contacts on the IED. 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.
  • Page 340 Section 13 1MRK 505 337-UUS A Logic For each cycle time, the function block is given an serial execution number. This is shown when using the ACT configuration tool with the designation of the function block and the cycle time, see example below.
  • Page 341 1MRK 505 337-UUS A Section 13 Logic 13.6 Fixed signal function block FXDSIGN IP15080-1 v2 13.6.1 Identification SEMOD167904-2 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Fixed signals FXDSIGN 13.6.2 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 342 Section 13 1MRK 505 337-UUS A Logic REFPDIF (87N) I3PW1CT1 I3PW2CT1 FXDSIGN GRP_OFF ANSI11000084_1_en.vsd ANSI11000084 V1 EN-US Figure 174: REFPDIF (87N) function inputs for normal transformer application 13.7 Boolean 16 to Integer conversion B16I SEMOD175715-1 v1 13.7.1 Identification SEMOD175721-2 v2 Function description IEC 61850 IEC 60617...
  • Page 343 1MRK 505 337-UUS A Section 13 Logic Name of input Type Default Description Value when Value when activated deactivated BOOLEAN Input 1 BOOLEAN Input 2 BOOLEAN Input 3 BOOLEAN Input 4 BOOLEAN Input 5 BOOLEAN Input 6 BOOLEAN Input 7 BOOLEAN Input 8 BOOLEAN...
  • Page 344 Section 13 1MRK 505 337-UUS A Logic The Boolean 16 to integer conversion function (BTIGAPC) will transfer a combination of up to 16 binary inputs INx where 1≤x≤16 to an integer. Each INx represents a value according to the table below from 0 to 32768.
  • Page 345 1MRK 505 337-UUS A Section 13 Logic 13.9.2 Application SEMOD158499-5 v4 Integer to boolean 16 conversion function (IB16) is used to transform an integer into a set of 16 binary (logical) signals. It can be used – for example, to connect integer output signals from one function to binary (logical) inputs to another function.
  • Page 346 Section 13 1MRK 505 337-UUS A Logic 13.10 Integer to Boolean 16 conversion with logic node representation ITBGAPC SEMOD158419-1 v3 13.10.1 Identification SEMOD167944-2 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Integer to boolean 16 conversion ITBGAPC with logic node representation 13.10.2...
  • Page 347 1MRK 505 337-UUS A Section 13 Logic Name of OUTx Type Description Value when activated Value when deactivated OUT14 BOOLEAN Output 14 8192 OUT15 BOOLEAN Output 15 16384 OUT16 BOOLEAN Output 16 32768 The sum of the numbers in column “Value when activated” when all OUTx (1≤x≤16) are active equals 65535.
  • Page 348 Section 13 1MRK 505 337-UUS A Logic The limit for the overflow supervision is fixed at 999999.9 seconds. 13.12 Comparator for integer inputs - INTCOMP 13.12.1 Identification GUID-5992B0F2-FC1B-4838-9BAB-2D2542BB264D v1 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Comparison of integer values INTCOMP Int<=>...
  • Page 349 1MRK 505 337-UUS A Section 13 Logic RefSource = 1 Set the For absolute comparison between input and setting Set the EnaAbs = 1 Set the RefSource = 0 SetValue shall be set between -2000000000 to 2000000000 Similarly for signed comparison between input and setting EnaAbs = 0 Set the RefSource = 0...
  • Page 350 Section 13 1MRK 505 337-UUS A Logic SetValue : This setting is used to set the reference value for comparison when setting RefSource is SetValue . If this setting value is less than 0.2% of the set unit then the output INLOW selected as will never pickups.
  • Page 351 1MRK 505 337-UUS A Section 14 Monitoring Section 14 Monitoring 14.1 Measurement GUID-9D2D47A0-FE62-4FE3-82EE-034BED82682A v1 14.1.1 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 352 Section 14 1MRK 505 337-UUS A Monitoring transformers (CTs and VTs). During normal service by periodic comparison of the measured value from the IED with other independent meters the proper operation of the IED analog measurement chain can be verified. Finally, it can be used to verify proper direction orientation for distance or directional overcurrent protection function.
  • Page 353 1MRK 505 337-UUS A Section 14 Monitoring 14.1.3 Zero clamping GUID-8DABC3F5-6615-493C-B839-A5C557A2FAE8 v2 The measuring functions, CVMMXN, CMMXU, VMMXU and VNMMXU have no interconnections regarding any setting or parameter. ZeroDb for each and every signal separately for Zero clampings are also entirely handled by the U12 is handled by UL12ZeroDb in VMMXU, each of the functions.
  • Page 354 Section 14 1MRK 505 337-UUS A Monitoring The following general settings can be set for the Measurement function (CVMMXN). PowMagFact : Magnitude factor to scale power calculations. PowAngComp : Angle compensation for phase shift between measured I & V. Mode : Selection of measured current and voltage. There are 9 different ways of calculating monitored three-phase values depending on the available VT inputs connected to the IED.
  • Page 355 1MRK 505 337-UUS A Section 14 Monitoring XRepTyp : Reporting type. Cyclic ( Cyclic ), magnitude deadband ( Dead band ) or integral deadband Int deadband ). The reporting interval is controlled by the parameter XDbRepInt . XDbRepInt : Reporting deadband setting. Cyclic reporting is the setting value and is reporting interval in seconds.
  • Page 356 Section 14 1MRK 505 337-UUS A Monitoring Magnitude % of In compensation IMagComp5 Measured current IMagComp30 IMagComp100 % of In 0-5%: Constant 5-30-100%: Linear >100%: Constant Angle Degrees compensation Measured IAngComp30 current IAngComp5 IAngComp100 % of In ANSI05000652_3_en.vsd ANSI05000652 V3 EN-US Figure 175: Calibration curves 14.1.4.1 Setting examples...
  • Page 357 1MRK 505 337-UUS A Section 14 Monitoring 380kV Busbar 800/5 A 380kV 120V 380kV OHL ANSI09000039-1-en.vsd ANSI09000039 V1 EN-US Figure 176: Single line diagram for 380kV 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: PhaseAngleRef using PCM600 Set correctly CT and VT data and phase angle reference channel...
  • Page 358 Section 14 1MRK 505 337-UUS A Monitoring Setting Short Description Selected Comments value IGenZeroDb Zero point clamping in % of Set minimum current level to 3%. Current below Ibase 3% will force S, P and Q to zero. VBase (set in Base setting for voltage level 400.00 Set rated OHL phase-to-phase voltage...
  • Page 359 1MRK 505 337-UUS A Section 14 Monitoring Measurement function application for a power transformer SEMOD54481-61 v7 Single line diagram for this application is given in figure 177. 132kV Busbar 200/5 31.5 MVA 500/5 33kV 120V 33kV Busbar ANSI09000040-1-en.vsd ANSI09000040 V1 EN-US Figure 177: Single line diagram for transformer application In order to measure the active and reactive power as indicated in figure 177, it is necessary to do the following:...
  • Page 360 Section 14 1MRK 505 337-UUS A Monitoring Table 46: General settings parameters for the Measurement function Setting Short description Selected Comment value Operation Disabled / Enabled Enabled Enabled Operation Function must be PowAmpFact Magnitude factor to scale 1.000 Typically no scaling is required power calculations PowAngComp Angle compensation for phase...
  • Page 361 1MRK 505 337-UUS A Section 14 Monitoring 230kV Busbar 300/5 100 MVA 15/0.12kV AB , 100 MVA 15.65kV 4000/5 ANSI09000041-1-en.vsd ANSI09000041 V1 EN-US Figure 178: Single line diagram for generator application In order to measure the active and reactive power as indicated in figure 178, it is necessary to do the following: Set correctly all CT and VT data and phase angle reference channel PhaseAngleRef using...
  • Page 362 Section 14 1MRK 505 337-UUS A Monitoring Setting Short description Selected Comment value Low pass filter coefficient for 0.00 Typically no additional filtering is required power measurement, V and I VGenZeroDb Zero point clamping in % of Set minimum voltage level to 25% Vbase IGenZeroDb Zero point clamping in % of...
  • Page 363 1MRK 505 337-UUS A Section 14 Monitoring minimize the risk of internal failures. Binary information based on the oil level in the circuit breaker is used as input signals to the function. In addition to that, the function generates alarms based on received information.
  • Page 364 Section 14 1MRK 505 337-UUS A Monitoring 100000 50000 20000 10000 5000 2000 1000 Interrupted current (kA) IEC12000623_1_en.vsd IEC12000623 V1 EN-US Figure 179: 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 365 1MRK 505 337-UUS A Section 14 Monitoring Accumulated energy Monitoring the contact erosion and interrupter wear has a direct influence on the required maintenance frequency. Therefore, it is necessary to accurately estimate the erosion of the contacts and condition of interrupters using cumulative summation of I .
  • Page 366 Section 14 1MRK 505 337-UUS A Monitoring IBase : Base phase current in primary A. This current is used as reference for current settings. OpenTimeCorr : Correction factor for circuit breaker opening travel time. CloseTimeCorr : Correction factor for circuit breaker closing travel time. tTrOpenAlm : Setting of alarm level for opening travel time.
  • Page 367 1MRK 505 337-UUS A Section 14 Monitoring 14.5.1 Identification SEMOD167950-2 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Event function EVENT S00946 V1 EN-US 14.5.2 Application M12805-6 v9 When using a Substation Automation system with LON or SPA communication, time-tagged events can be sent at change or cyclically from the IED to the station level.
  • Page 368 Section 14 1MRK 505 337-UUS A Monitoring 14.6 Disturbance report DRPRDRE IP14584-1 v2 14.6.1 Identification M16055-1 v7 Function description IEC 61850 identification IEC 60617 ANSI/IEEE C37.2 identification device number Disturbance report DRPRDRE Disturbance report A1RADR - A4RADR Disturbance report B1RBDR - B22RBDR 14.6.2 Application M12152-3 v7...
  • Page 369 1MRK 505 337-UUS A Section 14 Monitoring If the IED is connected to a station bus (IEC 61850-8-1), the disturbance recorder (record made and fault number) and the fault locator information are available as GOOSE or Report Control data. The same information is obtainable if IEC60870-5-103 is used.
  • Page 370 Section 14 1MRK 505 337-UUS A Monitoring Operation = Disabled : • Disturbance reports are not stored. • LED information (yellow - pickup, red - trip) is not stored or changed. Operation = Enabled : • Disturbance reports are stored, disturbance data can be read from the local HMI and from a PC using PCM600.
  • Page 371 1MRK 505 337-UUS A Section 14 Monitoring The function completes current report and starts a new complete report that is, the latter will include: • new pre-fault- and fault-time (which will overlap previous report) • events and indications might be saved in the previous report too, due to overlap •...
  • Page 372 Section 14 1MRK 505 337-UUS A Monitoring NomValueM : Nominal value for input M. OverTrigOpM , UnderTrigOpM : Over or Under trig operation, Disturbance report may trig for Enabled ) or not ( Disabled ). high/low level of analog input M ( OverTrigLeM , UnderTrigLeM : Over or under trig level, Trig high/low level relative nominal value for analog input M in percent of nominal value.
  • Page 373 1MRK 505 337-UUS A Section 14 Monitoring • Should the function record faults only for the protected object or cover more? • How long is the longest expected fault clearing time? • Is it necessary to include reclosure in the recording or should a persistent fault generate a PostRetrig )? second recording ( Minimize the number of recordings:...
  • Page 374 Section 14 1MRK 505 337-UUS A Monitoring 14.7.3 Setting guidelines GUID-BBDA6900-4C1A-4A7C-AEA5-3C49C2749254 v2 t is the only setting for the Logical signal status report (BINSTATREP). Each output The pulse time can be set or reset individually, but the pulse time will be the same for all outputs in the entire BINSTATREP function.
  • Page 375 1MRK 505 337-UUS A Section 14 Monitoring 14.9.2 Application GUID-225D8341-2D31-49F1-9B49-571346C0FE26 v1 The function is used for user-defined logics and it can also be used for different purposes internally in the IED. An application example is to accumulate the total running/energized time of the generator, transformer, reactor, capacitor bank or even line.
  • Page 377 1MRK 505 337-UUS A Section 15 Metering Section 15 Metering 15.1 Pulse-counter logic PCFCNT IP14600-1 v3 15.1.1 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 15.1.2 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 378 Section 15 1MRK 505 337-UUS A Metering for oscillation can be changed on the local HMI and PCM600 under Main menu/Configuration/I/O modules. 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.
  • Page 379 1MRK 505 337-UUS A Section 15 Metering which is selected to the active and reactive component as preferred. Also all Accumulated Active Forward, Active Reverse, Reactive Forward and Reactive Reverse energy values can be presented. Maximum demand values are presented in MWh or MVArh in the same way. Alternatively, the energy values can be presented with use of the pulse counters function EAFAccPlsQty , (PCGGIO).
  • Page 381 1MRK 505 337-UUS A Section 16 Station communication Section 16 Station communication 16.1 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 382 Section 16 1MRK 505 337-UUS A Station communication Engineering Station HSI Workstation Gateway Base System Printer KIOSK 3 KIOSK 1 KIOSK 2 IEC09000135_en.v IEC09000135 V1 EN-US Figure 183: SA system with IEC 61850–8–1 M16925-3 v3 Figure 184 shows the GOOSE peer-to-peer communication. Station HSI MicroSCADA Gateway...
  • Page 383 1MRK 505 337-UUS A Section 16 Station communication 16.2.2 Horizontal communication via GOOSE for interlocking GOOSEINTLKRCV SEMOD173197-1 v2 PID-415-SETTINGS v5 Table 48: GOOSEINTLKRCV Non group settings (basic) Name Values (Range) Unit Step Default Description Operation Disabled Disabled Operation Disabled/Enabled Enabled 16.2.3 Setting guidelines SEMOD55317-5 v6...
  • Page 384 Section 16 1MRK 505 337-UUS A Station communication The high and low limit settings provides limits for the high-high-, high, normal, low and low-low ranges of the measured value. The actual range of the measured value is shown on the range output of MVGAPC function block.
  • Page 385 1MRK 505 337-UUS A Section 16 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 185: Redundant station bus 16.2.6.3 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 386 Section 16 1MRK 505 337-UUS A Station communication are irrelevant when the redundant communication is activated, only PRP IPAdress and IPMask are valid. IEC10000057-2-en.vsd IEC10000057 V2 EN-US Figure 186: PST screen: PRP Operation is set to On, which affect Rear OEM - Port AB and CD which are both set to PRP Application manual...
  • Page 387 1MRK 505 337-UUS A Section 16 Station communication 16.3 LON communication protocol IP14420-1 v1 16.3.1 Application IP14863-1 v1 M14804-3 v3 Control Center Station HSI MicroSCADA Gateway Star coupler RER 111 IEC05000663-1-en.vsd IEC05000663 V2 EN-US Figure 187: Example of LON communication structure for a substation automation system An optical network can be used within the substation automation system.
  • Page 388 Section 16 1MRK 505 337-UUS A Station communication Hardware and software modules M14804-35 v4 The hardware needed for applying LON communication depends on the application, but one very central unit needed is the LON Star Coupler and optical fibers connecting the star coupler to the IEDs.
  • Page 389 1MRK 505 337-UUS A Section 16 Station communication 16.3.2.3 Setting guidelines SEMOD119915-1 v1 Settings M14789-4 v3 The parameters for the multiple command function are set via PCM600. Mode setting sets the outputs to either a Steady or Pulsed mode. 16.4 SPA communication protocol IP14614-1 v1 16.4.1...
  • Page 390 Section 16 1MRK 505 337-UUS A Station communication master can be applied on each fiber optic loop. A program is required in the master computer for interpretation of the SPA-bus codes and for translation of the data that should be sent to the IED. For the specification of the SPA protocol V2.5, refer to SPA-bus Communication Protocol V2.5.
  • Page 391 1MRK 505 337-UUS A Section 16 Station communication 16.5 IEC 60870-5-103 communication protocol IP14615-1 v2 16.5.1 Application IP14864-1 v1 M17109-3 v6 TCP/IP Control Station Center Gateway Star coupler ANSI05000660-4-en.vsd ANSI05000660 V4 EN-US Figure 189: 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 392 Section 16 1MRK 505 337-UUS A Station communication • Event handling • Report of analog service values (measurands) • Fault location • Command handling • Autorecloser ON/OFF • Teleprotection ON/OFF • Protection ON/OFF • LED reset • Characteristics 1 - 4 (Setting groups) •...
  • Page 393 1MRK 505 337-UUS A Section 16 Station communication Function blocks with user defined input signals in monitor direction, I103UserDef. These function blocks include the FUNCTION TYPE parameter for each block in the private range, and the INFORMATION NUMBER parameter for each input signal. •...
  • Page 394 Section 16 1MRK 505 337-UUS A Station communication that are recorded are available for transfer to the master. A file that has been transferred and acknowledged by the master cannot be transferred again. • The binary signals that are included in the disturbance recorder are those that are connected to the disturbance function blocks B1RBDR to B6RBDRB22RBDR.
  • Page 395 1MRK 505 337-UUS A Section 16 Station communication GUID-CD4EB23C-65E7-4ED5-AFB1-A9D5E9EE7CA8 V3 EN GUID-CD4EB23C-65E7-4ED5-AFB1-A9D5E9EE7CA8 V3 EN-US Figure 190: Settings for IEC 60870-5-103 communication The general settings for IEC 60870-5-103 communication are the following: SlaveAddress and BaudRate : Settings for slave number and communication speed (baud rate). •...
  • Page 396 Section 16 1MRK 505 337-UUS A Station communication the disturbance recorder for each input. The user must set these parameters to whatever he connects to the corresponding input. Refer to description of Main Function type set on the local HMI. Recorded analog channels are sent with ASDU26 and ASDU31.
  • Page 397 1MRK 505 337-UUS A Section 16 Station communication DRA#-Input IEC103 meaning Private range Private range Private range Private range Private range Private range Private range Function and information types M17109-145 v4 Product type IEC103mainFunType value Comment: REL 128 Compatible range REC 242 Private range, use default RED 192 Compatible range RET 176 Compatible range...
  • Page 399 1MRK 505 337-UUS A Section 17 Remote communication Section 17 Remote communication 17.1 Binary signal transfer IP12423-1 v2 17.1.1 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 17.1.2 Application...
  • Page 400 Section 17 1MRK 505 337-UUS A Remote communication en06000519-2.vsd IEC06000519 V2 EN-US Figure 191: Direct fiber optical connection between two IEDs with LDCM 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 192.
  • Page 401 1MRK 505 337-UUS A Section 17 Remote communication required optocoupler inputs into every IED it is possible to use LDCM communication modules to effectively share the binary Ios between three units, as shown in figure 193193. <= 192 Binary Signals => Wire status of REB 670, B31 disconnectors...
  • Page 402 Section 17 1MRK 505 337-UUS A Remote communication TerminalNo : This setting shall be used to assign an unique address to each LDCM, in all current differential IEDs. Up to 256 LDCMs can be assigned a unique number. Consider a local IED with two LDCMs: TerminalNo to 1 and RemoteTermNo to 2 •...
  • Page 403 1MRK 505 337-UUS A Section 17 Remote communication LowPower for fibers 0 – 1 km and HighPower for fibers greater than 1 km. Short-range LDCM: Use Medium-range LDCM: Typical distance 80 km for both LowPower and HighPower . Long-range LDCM: Typical distance 120 km for both LowPower and HighPower .
  • Page 404 Section 17 1MRK 505 337-UUS A Remote communication Table 52: Example of calculating the optical budget (maximum distance) 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...
  • Page 405 1MRK 505 337-UUS A Section 17 Remote communication RemAinLatency : Remote analog latency; This parameter corresponds to the LocAinLatency set in the remote IED. MaxTransmDelay : Data for maximum 40 ms transmission delay can be buffered up. Delay times in the range of some ms are common.
  • Page 407 1MRK 505 337-UUS A Section 18 Security Section 18 Security 18.1 Authority status ATHSTAT SEMOD158575-1 v2 18.1.1 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 408 CHNGLCK input, that logic must be designed so that it cannot permanently issue a logical one to the CHNGLCK input. If such a situation would occur in spite of these precautions, then please contact the local ABB representative for remedial action. Application manual...
  • Page 409 1MRK 505 337-UUS A Section 18 Security 18.4 Denial of service DOS 18.4.1 Application GUID-64F4D905-9F73-4073-B8F6-8D373155316A v4 The denial of service functions (DOSFRNT, DOSLANAB and DOSLANCD) are designed to limit the CPU load that can be produced by Ethernet network traffic on the IED. The communication facilities must not be allowed to compromise the primary functionality of the device.
  • Page 411 • 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). 19.2.2 Factory defined settings...
  • Page 412 Section 19 1MRK 505 337-UUS A Basic IED functions REL670 • Describes the type of the IED. Example: • ProductDef 2.1.0 • Describes the release number from the production. Example: • FirmwareVer • Describes the firmware version. • The firmware version can be checked from Main menu/Diagnostics/IED status/Product identifiers •...
  • Page 413 1MRK 505 337-UUS A Section 19 Basic IED functions 19.3.3 Setting guidelines SEMOD113223-4 v1 There are no settable parameters for the measured value expander block function. 19.4 Parameter setting groups IP1745-1 v1 19.4.1 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 414 Section 19 1MRK 505 337-UUS A Basic IED functions 19.5.2 Application M15288-3 v6 The rated system frequency and phase rotation direction are set under Main menu/ Configuration/ Power system/ Primary Values in the local HMI and PCM600 parameter setting tree. 19.5.3 Setting guidelines M15292-3 v2...
  • Page 415 1MRK 505 337-UUS A Section 19 Basic IED functions 19.7.1 Identification GUID-0D5405BE-E669-44C8-A208-3A4C86D39115 v3 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Global base values GBASVAL 19.7.2 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.
  • Page 416 Section 19 1MRK 505 337-UUS A Basic IED functions 19.9 Signal matrix for binary outputs SMBO SEMOD55215-1 v2 19.9.1 Application SEMOD55213-5 v4 The Signal matrix for binary outputs function SMBO is used within the Application Configuration tool in direct relation with the Signal Matrix tool. SMBO represents the way binary outputs are sent from one IED configuration.
  • Page 417 1MRK 505 337-UUS A Section 19 Basic IED functions 19.11.2 Frequency values GUID-B494B93C-B5AA-4FD6-8080-8611C34C2AD8 v5 The SMAI function includes a functionality based on the level of positive sequence voltage, MinValFreqMeas , to validate if the frequency measurement is valid or not. If the positive sequence MinValFreqMeas , the function freezes the frequency output value for 500 ms voltage is lower than and after that the frequency output is set to the nominal value.
  • Page 418 Section 19 1MRK 505 337-UUS A Basic IED functions 19.11.3 Setting guidelines GUID-C8D6C88B-87C6-44C1-804B-CF1594365EE6 v8 The parameters for the signal matrix for analog inputs (SMAI) functions are set via the local HMI or PCM600. Every SMAI function block can receive four analog signals (three phases and one neutral value), either voltage or current.
  • Page 419 1MRK 505 337-UUS A Section 19 Basic IED functions Preprocessing block shall only be used to feed functions within the same execution cycles (e.g. use preprocessing block with cycle 1 to feed transformer differential protection). The only exceptions are measurement functions (CVMMXN, CMMXU,VMMXU, etc.) which shall be fed by preprocessing blocks with cycle 8.
  • Page 420 Section 19 1MRK 505 337-UUS A 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 421: Example 2

    1MRK 505 337-UUS A Section 19 Basic IED functions SMAI1:13 BLOCK SPFCOUT DFTSPFC AI3P ^GRP1_A ^GRP1_B ^GRP1_C SMAI1:1 ^GRP1_N BLOCK SPFCOUT TYPE DFTSPFC AI3P ^GRP1_A ^GRP1_B ^GRP1_C ^GRP1_N TYPE SMAI1:25 BLOCK SPFCOUT DFTSPFC AI3P ^GRP1_A ^GRP1_B ^GRP1_C ^GRP1_N TYPE ANSI07000198.vsd ANSI07000198 V1 EN-US Figure 196: 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...
  • Page 422 Section 19 1MRK 505 337-UUS A Basic IED functions SMAI1:1 BLOCK SPFCOUT DFTSPFC AI3P ^GRP1_A ^GRP1_B ^GRP1_C SMAI1:13 ^GRP1_N BLOCK SPFCOUT TYPE DFTSPFC AI3P ^GRP1_A ^GRP1_B ^GRP1_C ^GRP1_N TYPE SMAI1:25 BLOCK SPFCOUT DFTSPFC AI3P ^GRP1_A ^GRP1_B ^GRP1_C ^GRP1_N TYPE ANSI07000198.vsd ANSI07000199 V1 EN-US Figure 197: Configuration for using an instance in task time group 2 as DFT reference.
  • Page 423 1MRK 505 337-UUS A Section 19 Basic IED functions 19.12.1.1 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 424 Section 19 1MRK 505 337-UUS A Basic IED functions The IEC 61850-7-4 gives a detailed overview over all aspects of the test mode and other states of Beh is shown on the LHMI under the mode and behavior. The status of a function block behavior Main menu/Test/Function status/Function group/Function block descriptive name/LN name/ Outputs.
  • Page 425 1MRK 505 337-UUS A Section 19 Basic IED functions • IRIG-B • • • For IEDs using IEC 61850-9-2LE in "mixed mode" a time synchronization from an external clock is recommended to the IED and all connected merging units. The time synchronization from the clock to the IED can be either optical PPS or IRIG-B.
  • Page 426 Section 19 1MRK 505 337-UUS A Basic IED functions GPS+LON • GPS+BIN • SNTP • GPS+SNTP • IRIG-B • • GPS+IRIG-B • CoarseSyncSrc which can have the following values: Disabled • • • • IEC 60870-5-103 • The function input to be used for minute-pulse synchronization is called BININPUT. For a Technical Manual .
  • Page 427 1MRK 505 337-UUS A Section 20 Requirements Section 20 Requirements 20.1 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 428 Section 20 1MRK 505 337-UUS A Requirements 20.1.2 Conditions M11610-3 v1 M11610-4 v4 The requirements are a result of investigations performed in our network simulator. The current transformer models are representative for current transformers of high remanence 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.
  • Page 429 The characteristic of the non remanence type 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 430 Section 20 1MRK 505 337-UUS A Requirements The high remanence type CT must fulfill æ ö ³ × × × 0.5 I ç ÷ a lre q f ma x è ø (Equation 95) EQUATION1667 V1 EN-US The low remanence type CT must fulfill æ...
  • Page 431 1MRK 505 337-UUS A Section 20 Requirements æ ö × ³ = × × ç ÷ a lre q è ø (Equation 98) EQUATION1677 V1 EN-US where: The primary operate value (A) The rated primary CT current (A) The rated secondary CT current (A) The nominal current of the protection IED (A) The secondary resistance of the CT (W) The resistance of the secondary cable and additional load (W).
  • Page 432 Section 20 1MRK 505 337-UUS A Requirements 20.1.6.4 Non-directional inverse time delayed phase and residual overcurrent protection M11339-3 v5 The requirement according to Equation and Equation does not need to be fulfilled if the high set instantaneous or definitive time stage is used. In this case Equation is the only necessary requirement.
  • Page 433 1MRK 505 337-UUS A Section 20 Requirements secondary e.m.f. E according to the IEC 61869-2 standard. From different standards and available data for relaying applications it is possible to approximately calculate a secondary e.m.f. of the CT comparable with E .
  • Page 434 Section 20 1MRK 505 337-UUS A Requirements The CTs according to class C must have a calculated rated equivalent limiting secondary e.m.f. that fulfils the following: alANSI > maximum of E alANSI alreq (Equation 105) EQUATION1384 V2 EN-US A CT according to ANSI/IEEE is also specified by the knee point voltage V that is graphically kneeANSI defined from an excitation curve.
  • Page 435 1MRK 505 337-UUS A Section 20 Requirements 20.4 Sample specification of communication requirements for the protection and control terminals in digital telecommunication networks GUID-0A9F36AF-3802-42FE-8970-4662798C19D1 v1 The communication requirements are based on echo timing. Bit Error Rate (BER) according to ITU-T G.821, G.826 and G.828 •...
  • Page 436 Section 20 1MRK 505 337-UUS A Requirements IED with GPS clock • Independent of asymmetry. Application manual...
  • Page 437 1MRK 505 337-UUS A Section 21 Glossary Section 21 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 438 Section 21 1MRK 505 337-UUS A Glossary Class C Protection Current Transformer class as per IEEE/ ANSI CMPPS Combined megapulses per second Communication Management tool in PCM600 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...
  • Page 439 1MRK 505 337-UUS A Section 21 Glossary Ethernet configuration tool EHV network Extra high voltage network Electronic Industries Association Electromagnetic compatibility Electromotive force Electromagnetic interference EnFP End fault protection Enhanced performance architecture Electrostatic discharge F-SMA Type of optical fiber connector Fault number Flow control bit;...
  • Page 440 Section 21 1MRK 505 337-UUS A Glossary IDBS Integrating deadband supervision International Electrical Committee IEC 60044-6 IEC Standard, Instrument transformers – Part 6: Requirements for protective current transformers for transient performance IEC 60870-5-103 Communication standard for protection equipment. A serial master/slave protocol for point-to-point communication IEC 61850 Substation automation communication standard...
  • Page 441 1MRK 505 337-UUS A Section 21 Glossary LIB 520 High-voltage software module Liquid crystal display LDCM Line data communication module Local detection device Light-emitting diode LON network tool Local operating network Miniature circuit breaker Mezzanine carrier module Milli-ampere module Main processing module MVAL Value of measurement Multifunction vehicle bus.
  • Page 442 Section 21 1MRK 505 337-UUS A Glossary Power supply module Parameter setting tool within PCM600 Precision time protocol PT ratio Potential transformer or voltage transformer ratio PUTT Permissive underreach transfer trip RASC Synchrocheck relay, COMBIFLEX Relay characteristic angle RISC Reduced instruction set computer RMS value Root mean square value RS422...
  • Page 443 1MRK 505 337-UUS A Section 21 Glossary Starpoint Neutral/Wye point of transformer or generator Static VAr compensation Trip coil Trip circuit supervision Transmission control protocol. The most common transport layer protocol used on Ethernet and the Internet. TCP/IP Transmission control protocol over Internet Protocol. The de facto standard Ethernet protocols incorporated into 4.2BSD Unix.
  • Page 444 Section 21 1MRK 505 337-UUS A Glossary Three times zero-sequence current.Often referred to as the residual or the ground-fault current Three times the zero sequence voltage. Often referred to as the residual voltage or the neutral point voltage Application manual...
  • Page 446 ABB AB Substation Automation Products SE-721 59 Västerås, Sweden Phone +46 (0) 21 32 50 00 Scan this QR code to visit our website www.abb.com/substationautomation © Copyright 2016 ABB. All rights reserved.

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