Page 1 — R E L I O N ® 670 SERIES Bay control REC670 Version 2.1 ANSI Application manual...
Page 4 Copyright This document and parts thereof must not be reproduced or copied without written permission from ABB, and the contents thereof must not be imparted to a third party, nor used for any unauthorized purpose. The software and hardware described in this document is furnished under a license and may be used or disclosed only in accordance with the terms of such license.
Page 5 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......................19 This manual.............................. 19 Intended audience..........................19 Product documentation........................20 1.3.1 Product documentation set......................20 1.3.2 Document revision history........................21 1.3.3 Related documents..........................21 Document symbols and conventions....................22 1.4.1 Symbols..............................22 1.4.2 Document conventions........................23 IEC61850 edition 1 / edition 2 mapping.....................23 Section 2 Application......................
Page 8 Table of contents Introduction.............................67 Setting guidelines...........................67 4.2.1 Setting of the phase reference channel..................67 4.2.1.1 Example............................68 4.2.2 Setting of current channels......................68 4.2.2.1 Example 1............................68 4.2.2.2 Example 2............................69 4.2.2.3 Example 3............................69 4.2.2.4 Examples on how to connect, configure and set CT inputs for most commonly used CT connections........................
Page 9 Table of contents 6.1.4 Setting guidelines..........................112 6.1.4.1 Configuration..........................112 6.1.4.2 Settings of protection function....................112 6.1.4.3 T-feeder protection........................113 6.1.4.4 Tertiary reactor protection......................116 6.1.4.5 Alarm level operation........................118 Section 7 Current protection....................119 Instantaneous phase overcurrent protection PHPIOC (50)............119 7.1.1 Identification............................. 119 7.1.2 Application............................
Page 10 Table of contents 7.6.2 Application............................155 7.6.3 Setting guidelines..........................156 Thermal overload protection, one time constant Fahrenheit/Celsius LFPTTR/ LCPTTR (26)............................164 7.7.1 Identification.............................164 7.7.2 Application............................164 7.7.3 Setting guideline..........................165 Thermal overload protection, two time constants TRPTTR (49)..........165 7.8.1 Identification.............................166 7.8.2 Application............................
Page 11 Table of contents 7.16.3 Setting guidelines..........................193 7.16.3.1 Restrike detection........................196 7.17 Voltage-restrained time overcurrent protection VRPVOC (51V)..........196 7.17.1 Identification.............................196 7.17.2 Application............................196 7.17.2.1 Base quantities..........................197 7.17.2.2 Application possibilities......................197 7.17.2.3 Undervoltage seal-in........................197 7.17.3 Setting guidelines..........................198 7.17.3.1 Explanation of the setting parameters..................198 7.17.3.2 Voltage-restrained overcurrent protection for generator and step-up transformer..199 7.17.3.3...
Page 12 Table of contents Voltage differential protection VDCPTOV (60)................213 8.4.1 Identification............................. 213 8.4.2 Application............................213 8.4.3 Setting guidelines..........................214 Loss of voltage check LOVPTUV (27)....................215 8.5.1 Identification............................. 215 8.5.2 Application............................216 8.5.3 Setting guidelines..........................216 8.5.3.1 Advanced users settings......................216 Section 9 Frequency protection..................
Page 13 Table of contents Section 11 System protection and control................239 11.1 Multipurpose filter SMAIHPAC......................239 11.1.1 Identification............................ 239 11.1.2 Application............................239 11.1.3 Setting guidelines..........................240 11.1.3.1 Setting example..........................240 Section 12 Secondary system supervision................245 12.1 Current circuit supervision (87)......................245 12.1.1 Identification............................ 245 12.1.2 Application............................
Page 14 Table of contents 13.2 Autorecloser for 1 phase, 2 phase and/or 3 phase operation SMBRREC (79)......270 13.2.1 Identification............................ 270 13.2.2 Application............................270 13.2.2.1 Auto-reclosing operation OFF and ON..................273 13.2.2.2 Initiate auto-reclosing and conditions for initiation of a reclosing cycle......273 13.2.2.3 Initiate auto-reclosing from CB open information..............
Page 15 Table of contents 13.4.2 Interlocking for line bay ABC_LINE (3)..................302 13.4.2.1 Application............................. 302 13.4.2.2 Signals from bypass busbar.......................302 13.4.2.3 Signals from bus-coupler......................303 13.4.2.4 Configuration setting........................306 13.4.3 Interlocking for bus-coupler bay ABC_BC (3)................307 13.4.3.1 Application............................. 307 13.4.3.2 Configuration..........................308 13.4.3.3 Signals from all feeders.......................308 13.4.3.4...
Page 16 Table of contents 13.6.1 Identification.............................373 13.6.2 Application............................373 13.6.3 Setting guidelines..........................373 13.7 Selector mini switch VSGAPC......................374 13.7.1 Identification.............................374 13.7.2 Application............................374 13.7.3 Setting guidelines..........................375 13.8 Generic communication function for Double Point indication DPGAPC........375 13.8.1 Identification.............................375 13.8.2 Application............................375 13.8.3 Setting guidelines..........................
Page 17 Table of contents 14.2.2.1 Current reversal logic........................388 14.2.2.2 Weak-end infeed logic......................... 389 14.2.3 Setting guidelines..........................390 14.2.3.1 Current reversal logic........................390 14.2.3.2 Weak-end infeed logic......................... 390 14.3 Local acceleration logic ZCLCPSCH....................391 14.3.1 Identification.............................391 14.3.2 Application............................391 14.3.3 Setting guidelines..........................391 14.4 Scheme communication logic for residual overcurrent protection ECPSCH (85)....392 14.4.1 Identification............................
Page 18 Table of contents 15.4.1.1 Identification..........................402 15.4.1.2 Application.............................403 15.4.1.3 Setting guidelines........................403 15.5 Logic for group indication INDCALH....................403 15.5.1 Logic for group indication INDCALH................... 403 15.5.1.1 Identification..........................403 15.5.1.2 Application.............................403 15.5.1.3 Setting guidelines........................403 15.6 Configurable logic blocks........................403 15.6.1 Application............................404 15.6.2.1 Configuration..........................404 15.7 Fixed signal function block FXDSIGN....................405 15.7.1...
Page 19 Table of contents 16.1.1 Identification.............................417 16.1.2 Application............................417 16.1.3 Zero clamping........................... 419 16.1.4 Setting guidelines..........................419 16.1.4.1 Setting examples.......................... 422 16.2 Gas medium supervision SSIMG (63)....................428 16.2.1 Identification............................ 428 16.2.2 Application............................428 16.3 Liquid medium supervision SSIML (71).................... 428 16.3.1 Identification............................
Page 20 Table of contents 16.10.1 Identification............................ 444 16.10.2 Application............................444 16.10.3 Setting guidelines........................... 444 Section 17 Metering....................... 445 17.1 Pulse-counter logic PCFCNT......................445 17.1.1 Identification............................ 445 17.1.2 Application............................445 17.1.3 Setting guidelines..........................445 17.2 Function for energy calculation and demand handling ETPMMTR..........446 17.2.1 Identification............................
Page 21 Table of contents 18.5.1 Application............................467 18.5.2 Setting guidelines..........................468 18.6 IEC 60870-5-103 communication protocol..................469 18.6.1 Application............................469 18.7 DNP3 Communication protocol......................475 18.7.1 Application............................475 Section 19 Remote communication..................477 19.1 Binary signal transfer...........................477 19.1.1 Identification.............................477 19.1.2 Application............................477 19.1.2.1 Communication hardware solutions..................477 19.1.3 Setting guidelines..........................478 Section 20 Security.........................
Page 22 Table of contents 21.6.2 Setting guidelines........................... 490 21.7 Global base values GBASVAL......................490 21.7.1 Identification.............................491 21.7.2 Application............................491 21.7.3 Setting guidelines..........................491 21.8 Signal matrix for binary inputs SMBI....................491 21.8.1 Application............................491 21.8.2 Setting guidelines..........................491 21.9 Signal matrix for binary outputs SMBO ..................492 21.9.1 Application............................
Page 23 Table of contents 22.1.7.1 Current transformers according to IEC 61869-2, class P, PR..........508 22.1.7.2 Current transformers according to IEC 61869-2, class PX, PXR (and old IEC 60044-6, class TPS and old British Standard, class X)............508 22.1.7.3 Current transformers according to ANSI/IEEE..............509 22.2 Voltage transformer requirements....................510 22.3...
Page 25: Introduction
1MRK 511 358-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 26: Product Documentation
Section 1 1MRK 511 358-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 27: Document Revision History
1MRK 511 358-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 28: Document Symbols And Conventions
Section 1 1MRK 511 358-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 29: Document Conventions
1MRK 511 358-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 30 Section 1 1MRK 511 358-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 31 1MRK 511 358-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 32 Section 1 1MRK 511 358-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 33 1MRK 511 358-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 34 Section 1 1MRK 511 358-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 35 1MRK 511 358-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 36 Section 1 1MRK 511 358-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 37: Application
1MRK 511 358-UUS A Section 2 Application Section 2 Application General IED application M13637-3 v12 The IED is used for the control, protection and monitoring of different types of bays in power networks. The IED is especially suitable for applications in control systems where the IEC 61850–8– 1 Ed 1 or Ed 2 station bus features of the IED can be fully utilized.
Page 38 Section 2 1MRK 511 358-UUS A Application Forcing of binary inputs and outputs is a convenient way to test wiring in substations as well as testing configuration logic in the IEDs. Basically it means that all binary inputs and outputs on the IED I/O modules (BOM, BIM, IOM &...
Page 39 1MRK 511 358-UUS A Section 2 Application Overall operating characteristic of the differential function in the IED is shown in figure 2. Sensitive differential protection Operate region Differential protection operation characteristic Diff Oper Level Sens Iin Block Sensitive Oper Level s=0.53 [Primary Amps] en06000142.vsd...
Page 40: Main Protection Functions
Section 2 1MRK 511 358-UUS A Application It is normal practice to have just one busbar protection IED per busbar. Nevertheless some utilities do apply two independent busbar protection IEDs per zone of protection. This IED fits both solutions. A simplified bus differential protection for multi-phase faults and ground faults can be obtained by using a single, one-phase IED with external auxiliary summation current transformers.
Page 41 1MRK 511 358-UUS A Section 2 Application IEC 61850 ANSI Function description REC670 (Customized) NS4PTOC 46I2 Four step directional negative phase sequence overcurrent protection SDEPSDE Sensitive directional residual overcurrent and power protection LCPTTR Thermal overload protection, one time constant, 0–6 Celsius LFPTTR Thermal overload protection, one time constant,...
Page 42: Control And Monitoring Functions
Section 2 1MRK 511 358-UUS A Application Control and monitoring functions GUID-E3777F16-0B76-4157-A3BF-0B6B978863DE v12 IEC 61850 ANSI Function description Bay control REC670 Control SESRSYN Synchrocheck, energizing check and 0-6, 0-2 synchronizing SMBRREC Autorecloser 0-6, 0-4 APC10 Apparatus control for single bay, max 10 apparatuses (1CB) incl.
Page 43 1MRK 511 358-UUS A Section 2 Application IEC 61850 ANSI Function description Bay control REC670 CCSSPVC Current circuit supervision FUFSPVC Fuse failure supervision VDSPVC Fuse failure supervision based on voltage difference Logic SMPPTRC Tripping logic TMAGAPC Trip matrix logic ALMCALH Logic for group alarm WRNCALH Logic for group warning...
Page 44 Section 2 1MRK 511 358-UUS A Application IEC 61850 ANSI Function description Bay control REC670 CMMXU Measurements AISVBAS Function block for service value presentation of secondary analog inputs EVENT Event function DRPRDRE, Disturbance report A1RADR-A4RADR, B1RBDR- B22RBDR SPGAPC Generic communication function for Single Point indication SP16GAPC Generic communication function for Single...
Page 45 1MRK 511 358-UUS A Section 2 Application Table 3: Total number of instances for basic configurable logic blocks Basic configurable logic block Total number of instances GATE PULSETIMER RSMEMORY SRMEMORY TIMERSET Table 4: Total number of instances for configurable logic blocks Q/T Configurable logic blocks Q/T Total number of instances ANDQT...
Page 46: Communication
Section 2 1MRK 511 358-UUS A Application Communication GUID-5F144B53-B9A7-4173-80CF-CD4C84579CB5 v12 IEC 61850 ANSI Function description Bay control REC670 (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 47 1MRK 511 358-UUS A Section 2 Application IEC 61850 ANSI Function description Bay control REC670 (Customized) LD0LLN0 IEC 61850 LD0 LLN0 SYSLLN0 IEC 61850 SYS LLN0 LPHD Physical device information PCMACCS IED Configuration Protocol SECALARM Component for mapping security events on protocols such as DNP3 and IEC103 FSTACCS Field service tool access via SPA protocol over ethernet...
Page 48: Basic Ied Functions
Section 2 1MRK 511 358-UUS A Application Basic IED functions GUID-C8F0E5D2-E305-4184-9627-F6B5864216CA v9 Table 6: Basic IED functions IEC 61850 or function Description name INTERRSIG SELFSUPEVLST Self supervision with internal event list TIMESYNCHGEN Time synchronization module BININPUT, SYNCHCAN, Time synchronization SYNCHGPS, SYNCHCMPPS, SYNCHLON, SYNCHPPH,...
Page 49 1MRK 511 358-UUS A Section 2 Application IEC 61850 or function Description name PRODINF Product information RUNTIME IED Runtime Comp CAMCONFIG Central account management configuration CAMSTATUS Central account management status TOOLINF Tools Information component SAFEFILECOPY Safe file copy function Table 7: Local HMI functions IEC 61850 or function ANSI...
Page 51: Configuration
1MRK 511 358-UUS A Section 3 Configuration Section 3 Configuration Introduction SEMOD120082-1 v1 SEMOD120089-4 v8 Description of configuration REC670 IP14799-1 v2 3.2.1 Introduction IP14800-1 v1 3.2.1.1 Description of configuration A30 M15200-3 v7 The configuration of the IED is shown in Figure 3. This configuration is used in single breaker arrangements with single or double busbar.
Page 52: Description Of Configuration A31
Section 3 1MRK 511 358-UUS A Configuration REC670 A30 – Double busbar in single breaker arrangement 12AI (6I + 6U) Control Control Control S CILO S CSWI S XSWI Control Control Control S CILO S CSWI S XSWI WA2_VT VN MMXU WA1_VT Control Control...
Page 53: Description Of Configuration B30
1MRK 511 358-UUS A Section 3 Configuration Control, measuring and interlocking is fully configured. The following should be noted. The configuration is made with the binary input and binary output boards in the basic delivery. In many cases this is sufficient, in other cases, for example with full control of all apparatuses included, more IO cards are required.
Page 54 Section 3 1MRK 511 358-UUS A Configuration This configuration is used in double breaker arrangements. Control, measuring and interlocking is fully configured, including communication with other bays such as other lines and the bus coupler over GOOSE. The following should be noted. The configuration is made with the binary input and binary output boards in the basic IED delivery.
Page 55: Description Of Configuration C30
1MRK 511 358-UUS A Section 3 Configuration REC670 B30 - Double breaker arrangement 12AI (6I + 6U) Control Control Control S CILO S CSWI S XSWI WA2_VT Control Control Control SC/VC S CILO S CSWI S XSWI VN MMXU SES RSYN WA1_VT SC/VC Control...
Page 56 Section 3 1MRK 511 358-UUS A Configuration This configuration is used in breaker-and-a-half arrangements for a full diameter. The configuration can also be used for a section of the diameter with utilization of a part of the apparatuses only. Control, measuring and interlocking is fully configured, including communication with other bays such as other lines and the bus coupler over GOOSE.
Page 57 1MRK 511 358-UUS A Section 3 Configuration REC670C30 – Complete one-and a half breaker diameter arrangement 24AI (6I + 6U, 6I+6U) Control Control Control S CILO S CSWI S XSWI WA1_VT WA1_QA1 Control Control Control SC/VC S CILO S CSWI S XCBR VN MMXU SES RSYN...
Page 58: Description Of Configuration Reb670
Section 3 1MRK 511 358-UUS A Configuration Optional functions are available in PCM600 Application Configuration Tool and can be configured by the user. Interface to analog and binary IO:s are configurable without need of configuration changes. Analog and control circuits have been pre-defined. Other signals need to be applied as required for each application.
Page 59: Description Of 3 Ph Package A20A
1MRK 511 358-UUS A Section 3 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 60: Description Of 3 Ph Package A31A
Section 3 1MRK 511 358-UUS A 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 61 1MRK 511 358-UUS A Section 3 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 62 Section 3 1MRK 511 358-UUS A 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 63 1MRK 511 358-UUS A Section 3 Configuration GUID-1264BCF9-F245-423C-B620-3D66F3292F41 V2 EN-US Figure 10: Configuration diagram for A31, configuration X01_1 Application manual...
Page 64 Section 3 1MRK 511 358-UUS A Configuration GUID-33AD6AD4-3315-4A4C-AB05-C1C04E815866 V2 EN-US Figure 11: Configuration diagram for A31, configuration X02 Application manual...
Page 65: Description Of 1 Ph Package B20A
1MRK 511 358-UUS A Section 3 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 66 Section 3 1MRK 511 358-UUS A 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 67: Description Of 1 Ph Package B31A
1MRK 511 358-UUS A Section 3 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 68 Section 3 1MRK 511 358-UUS A 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 69 1MRK 511 358-UUS A Section 3 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 70 Section 3 1MRK 511 358-UUS A 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 71 1MRK 511 358-UUS A Section 3 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 73: Analog Inputs
1MRK 511 358-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 74: Example
Section 4 1MRK 511 358-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 75: Example 2
1MRK 511 358-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 76 Section 4 1MRK 511 358-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 77 1MRK 511 358-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 78 Section 4 1MRK 511 358-UUS A Analog inputs Busbar Busbar Protection en06000196_ansi.vsd ANSI06000196 V1 EN-US Figure 23: 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 79: Examples On How To Connect, Configure And Set Ct Inputs For Most Commonly Used Ct Connections
1MRK 511 358-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 80: Example On How To Connect A Wye Connected Three-Phase Ct Set To The Ied
Section 4 1MRK 511 358-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 81 1MRK 511 358-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 Figure25.
Page 82 Section 4 1MRK 511 358-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 26: Wye connected three-phase CT set with its star point away from the protected object In the example in figure 26 case everything is done in a similar way as in the above described...
Page 83 1MRK 511 358-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 27: Wye connected three-phase CT set with its star point away from the protected object and the...
Page 84: Example How To Connect Delta Connected Three-Phase Ct Set To The Ied
Section 4 1MRK 511 358-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 85 1MRK 511 358-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 28: 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 86: Example How To Connect Single-Phase Ct To The Ied
Section 4 1MRK 511 358-UUS A Analog inputs Another alternative is to have the delta connected CT set as shown in figure 29: SMAI_20 IA-IC IB-IA IC-IB ANSI11000028-2-en.vsd Protected Object ANSI11000028 V2 EN-US Figure 29: 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 87 1MRK 511 358-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 30: 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 88: Relationships Between Setting Parameter Base Current, Ct Rated Primary Current And Minimum Pickup Of A Protection Ied
Section 4 1MRK 511 358-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 89: Examples How To Connect, Configure And Set Vt Inputs For Most Commonly Used Vt Connections
1MRK 511 358-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 90 Section 4 1MRK 511 358-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 32: 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 91: Example On How To Connect A Phase-To-Phase Connected Vt To The Ied
1MRK 511 358-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 92 Section 4 1MRK 511 358-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 33: 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 93: Example On How To Connect An Open Delta Vt To The Ied For High Impedance Grounded Or Ungrounded Netwoeks
1MRK 511 358-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 94 Section 4 1MRK 511 358-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 95: Example How To Connect The Open Delta Vt To The Ied For Low Impedance Grounded Or Solidly Grounded Power Systems
1MRK 511 358-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 96 Section 4 1MRK 511 358-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 97 1MRK 511 358-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 98: Example On How To Connect A Neutral Point Vt To The Ied
Section 4 1MRK 511 358-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 99 1MRK 511 358-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 101: Local Hmi
1MRK 511 358-UUS A Section 5 Local HMI Section 5 Local HMI AMU0600442 v14 ANSI13000239-2-en.vsd ANSI13000239 V2 EN-US Figure 37: Local human-machine interface The LHMI of the IED contains the following elements: • Keypad • Display (LCD) • LED indicators •...
Page 102: Display
Section 5 1MRK 511 358-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 103: Leds
1MRK 511 358-UUS A Section 5 Local HMI IEC13000281-1-en.vsd GUID-C98D972D-D1D8-4734-B419-161DBC0DC97B V1 EN-US Figure 39: 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 40: Indication LED panel The function button and indication LED panels are not visible at the same time.
Page 104: Keypad
Section 5 1MRK 511 358-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 105 1MRK 511 358-UUS A Section 5 Local HMI ANSI15000157-1-en.vsdx ANSI15000157 V1 EN-US Figure 41: 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 106: Local Hmi Functionality
Section 5 1MRK 511 358-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 107: Parameter Management
1MRK 511 358-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 108 Section 5 1MRK 511 358-UUS A Local HMI IEC13000280-1-en.vsd GUID-94AF2358-6905-4782-B37B-ACD3DCBF7F9C V1 EN-US Figure 42: 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 109: Differential Protection
1MRK 511 358-UUS A Section 6 Differential protection Section 6 Differential protection High impedance differential protection, single phase HZPDIF (87) IP14239-1 v4 6.1.1 Identification M14813-1 v4 IEC 61850 IEC 60617 ANSI/IEEE C37.2 Function description identification identification device number High impedance differential HZPDIF protection, single phase SYMBOL-CC V2 EN-US...
Page 110 Section 6 1MRK 511 358-UUS A Differential protection 3·87 3·87B 3·87 3·87B 3·87T 3·87 3·87T 3·87G ANSI05000163-1-en.vsd ANSI05000163 V2 EN-US 3·87 3·87 ANSI05000738-2-en.vsd ANSI05000738 V2 EN-US Application manual...
Page 111: The Basics Of The High Impedance Principle
1MRK 511 358-UUS A Section 6 Differential protection Figure 43: Different applications of a 1Ph High impedance differential protection HZPDIF (87) function 6.1.2.1 The basics of the high impedance principle SEMOD54734-153 v9 The high impedance differential protection principle has been used for many years and is well documented in literature publicly available.
Page 112 Section 6 1MRK 511 358-UUS A Differential protection are made with the worst situations in mind and a minimum operating voltage V is calculated according to equation > × (Equation 14) EQUATION1531-ANSI V1 EN-US where: IF max is the maximum through fault current at the secondary side of the CT is the current transformer secondary winding resistance and is the maximum loop resistance of the circuit at any CT.
Page 113 1MRK 511 358-UUS A Section 6 Differential protection Table 12: 1 A channels: input with minimum operating down to 40 mA Operating Stabilizing Operating Stabilizing Operating voltage resistor R current level resistor R current level TripPickup ohms ohms 20 V 0.040 A 40 V 1000...
Page 114 Section 6 1MRK 511 358-UUS A Differential protection It should be remembered that the vectorial sum of the currents must be used (IEDs, Metrosil and resistor currents are resistive). The current measurement is insensitive to DC component in fault current to allow the use of only the AC components of the fault current in the above calculations. The voltage dependent resistor (Metrosil) characteristic is shown in Figure 50.
Page 115 1MRK 511 358-UUS A Section 6 Differential protection Rres I> Protected Object a) Through load situation b) Through fault situation c) Internal faults ANSI05000427-2-en.vsd ANSI05000427 V2 EN-US Figure 45: The high impedance principle for one phase with two current transformer inputs Application manual...
Page 116: Connection Examples For High Impedance Differential Protection
Section 6 1MRK 511 358-UUS A Differential protection 6.1.3 Connection examples for high impedance differential protection GUID-8C58A73D-7C2E-4BE5-AB87-B4C93FB7D62B v5 WARNING! USE EXTREME CAUTION! Dangerously high voltages might be present on this equipment, especially on the plate with resistors. De-energize the primary object protected with this equipment before connecting or disconnecting wiring or performing any maintenance.
Page 117: Connections For 1Ph High Impedance Differential Protection Hzpdif (87)
1MRK 511 358-UUS A Section 6 Differential protection Necessary connection for three-phase metrosil set. Position of optional test switch for secondary injection into the high impedance differential IED. Necessary connection for setting resistors. Factory-made star point on a three-phase setting resistor set. The star point connector must be removed for installations with 670 series IEDs.
Page 118: Setting Guidelines
Section 6 1MRK 511 358-UUS A Differential protection One-phase plate with stabilizing resistor and metrosil. Protective ground is a separate 4 mm screw terminal on the plate. Necessary connection for the metrosil. Position of optional test switch for secondary injection into the high impedance differential IED. Necessary connection for stabilizing resistor.
Page 119: T-Feeder Protection
1MRK 511 358-UUS A Section 6 Differential protection 6.1.4.3 T-feeder protection M16850-4 v7 In many busbar arrangements such as breaker-and-a-half, ring breaker, mesh corner, there will be a T-feeder from the current transformer at the breakers up to the current transformers in the feeder circuit (for example, in the transformer bushings).
Page 120 Section 6 1MRK 511 358-UUS A Differential protection en05000165_ansi.vsd ANSI05000165 V1 EN-US 3·87 ANSI05000739-2-en.vsd ANSI05000739 V2 EN-US Figure 48: The protection scheme utilizing the high impedance function for the T-feeder Normally this scheme is set to achieve a sensitivity of around 20 percent of the used CT primary rating so that a low ohmic value can be used for the series resistor.
Page 121 1MRK 511 358-UUS A Section 6 Differential protection It is strongly recommended to use the highest tap of the CT whenever high impedance protection is used. This helps in utilizing maximum CT capability, minimize the secondary fault current, thereby reducing the stability voltage limit. Another factor is that during internal faults, the voltage developed across the selected tap is limited by the non-linear resistor but in the unused taps, owing to auto-transformer action, voltages induced may be much higher than design limits.
Page 122: Tertiary Reactor Protection
Section 6 1MRK 511 358-UUS A Differential protection The magnetizing current is taken from the magnetizing curve for the current transformer cores TripPickup is taken. which should be available. The current value at It can clearly be seen that the sensitivity is not so much influenced by the selected voltage level so a sufficient margin should be used.
Page 123 1MRK 511 358-UUS A Section 6 Differential protection Setting example It is strongly recommended to use the highest tap of the CT whenever high impedance protection is used. This helps in utilizing maximum CT capability, minimize the secondary fault, thereby reducing the stability voltage limit. Another factor is that during internal faults, the voltage developed across the selected tap is limited by the non-linear resistor but in the unused taps, owing to auto- transformer action, voltages much higher than design limits might be induced.
Page 124: Alarm Level Operation
Section 6 1MRK 511 358-UUS A Differential protection × + × £ (200 2 30) approx .5.2 (Equation 21) EQUATION1769-ANSI V1 EN-US Where 200mA is the current drawn by the IED circuit and 50mA is the current drawn by each CT just at pickup.
Page 125: Current Protection
1MRK 511 358-UUS A Section 7 Current protection Section 7 Current protection Instantaneous phase overcurrent protection PHPIOC (50) IP14506-1 v6 7.1.1 Identification M14880-1 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Instantaneous phase overcurrent PHPIOC protection 3-phase output 3I>>...
Page 126: Meshed Network Without Parallel Line
Section 7 1MRK 511 358-UUS A Current protection This protection function must operate only in a selective way. So check all system and transient conditions that could cause its unwanted operation. Only detailed network studies can determine the operating conditions under which the highest possible fault current is expected on the line.
Page 127 1MRK 511 358-UUS A Section 7 Current protection Fault ANSI09000022-1-en.vsd ANSI09000022 V1 EN-US Figure 51: Through fault current from A to B: I Then a fault in A has to be applied and the through fault current I has to be calculated, figure 52. In order to get the maximum through fault current, the minimum value for Z and the maximum value for Z...
Page 128: Meshed Network With Parallel Line
Section 7 1MRK 511 358-UUS A Current protection The protection function can be used for the specific application only if this setting value is equal to or less than the maximum fault current that the IED has to clear, I in figure 53.
Page 129: Four Step Phase Overcurrent Protection Oc4Ptoc(51/67)
1MRK 511 358-UUS A Section 7 Current protection Line 1 Fault Line 2 ANSI09000025_2_en.vsd ANSI09000025 V2 EN-US Figure 54: Two parallel lines. Influence from parallel line to the through fault current: I The minimum theoretical current setting for the overcurrent protection function (Imin) will be: ³...
Page 130: Identification
Section 7 1MRK 511 358-UUS A Current protection 7.2.1 Identification M14885-1 v5 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Four step phase overcurrent OC4PTOC 51_67 protection 3-phase output TOC-REVA V2 EN-US 7.2.2 Application M15335-3 v8 The Four step phase overcurrent protection 3-phase output OC4PTOC (51_67) is used in several applications in the power system.
Page 131: Setting Guidelines
1MRK 511 358-UUS A Section 7 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 132: Settings For Each Step
Section 7 1MRK 511 358-UUS A Current protection ANSI09000636-1-en.vsd ANSI09000636 V1 EN-US Figure 55: Directional function characteristic RCA = Relay characteristic angle ROA = Relay operating angle Reverse Forward 7.2.3.1 Settings for each step M12982-19 v10.1.1 x means step 1, 2, 3 and 4. DirModeSelx : The directional mode of step x .
Page 133 1MRK 511 358-UUS A Section 7 Current protection Table 14: Inverse time characteristics Curve name ANSI Extremely Inverse ANSI Very Inverse ANSI Normal Inverse ANSI Moderately Inverse ANSI/IEEE Definite time ANSI Long Time Extremely Inverse ANSI Long Time Very Inverse ANSI Long Time Inverse IEC Normal Inverse IEC Very Inverse...
Page 134 Section 7 1MRK 511 358-UUS A Current protection MultPUx : Multiplier for scaling of the current setting value. If a binary input signal ENMULTx (enableMultiplier) is activated the current operation level is increased by this setting constant. Setting range: 1.0-10.0 Trip time txMin Pickup current...
Page 135: 2Nd Harmonic Restrain
1MRK 511 358-UUS A Section 7 Current protection For the customer tailor-made inverse time delay characteristics (type 17), all three types of reset time characteristics are available: instantaneous (1), IEC (2 = set constant time reset) and ANSI (3 = pr , tr and cr must current dependent reset time).
Page 136 Section 7 1MRK 511 358-UUS A Current protection Current I Line phase current Pickup current Reset current The IED does not reset Time t ANSI09000146-en-1.vsd ANSI09000146 V1 EN-US Figure 57: Pickup and reset current for an overcurrent protection The lowest setting value can be written according to equation 29. Im ax ³...
Page 137 1MRK 511 358-UUS A Section 7 Current protection £ × 0.7 Isc min (Equation 30) EQUATION1263 V2 EN-US where: is a safety factor Iscmin is the smallest fault current to be detected by the overcurrent protection. As a summary the pickup current shall be chosen within the interval stated in equation 31. Im ax ×...
Page 138 Section 7 1MRK 511 358-UUS A Current protection en05000204.wmf IEC05000204 V1 EN-US Figure 58: Fault time with maintained selectivity The operation time can be set individually for each overcurrent protection. To assure selectivity between different protections, in the radial network, there have to be a minimum time difference Dt between the time delays of two protections.
Page 139 1MRK 511 358-UUS A Section 7 Current protection Feeder Time axis The fault Protection Breaker at Protection occurs B1 trips B1 opens A1 resets en05000205_ansi.vsd ANSI05000205 V1 EN-US Figure 59: Sequence of events during fault where: is when the fault occurs is when the trip signal from the overcurrent protection at IED B1 is sent to the circuit breaker.
Page 140: Instantaneous Residual Overcurrent Protection Efpioc (50N)
Section 7 1MRK 511 358-UUS A Current protection Instantaneous residual overcurrent protection EFPIOC (50N) IP14508-1 v3 7.3.1 Identification M14887-1 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Instantaneous residual overcurrent EFPIOC protection IN>> IEF V1 EN-US 7.3.2 Application M12699-3 v5...
Page 141 1MRK 511 358-UUS A Section 7 Current protection Fault ANSI09000022-1-en.vsd ANSI09000022 V1 EN-US Figure 60: Through fault current from A to B: I Fault ANSI09000023-1-en.vsd ANSI09000023 V1 EN-US Figure 61: Through fault current from B to A: I The function shall not operate for any of the calculated currents to the protection. The minimum theoretical current setting (Imin) will be: ³...
Page 142: Four Step Residual Overcurrent Protection
Section 7 1MRK 511 358-UUS A Current protection Line 1 Fault Line 2 ANSI09000025_2_en.vsd ANSI09000025 V2 EN-US Figure 62: Two parallel lines. Influence from parallel line to the through fault current: I The minimum theoretical current setting (Imin) will in this case be: ³...
Page 143: Identification
1MRK 511 358-UUS A Section 7 Current protection 7.4.1 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>) protection TEF-REVA V2 EN-US 7.4.2 Application M12509-12 v9 The four step residual overcurrent protection EF4PTOC (51N_67N) is used in several applications in the power system.
Page 144 Section 7 1MRK 511 358-UUS A Current protection Table 16: Time characteristics Curve name ANSI Extremely Inverse ANSI Very Inverse ANSI Normal Inverse ANSI Moderately Inverse ANSI/IEEE Definite time ANSI Long Time Extremely Inverse ANSI Long Time Very Inverse ANSI Long Time Inverse IEC Normal Inverse IEC Very Inverse IEC Inverse...
Page 145: Setting Guidelines
1MRK 511 358-UUS A Section 7 Current protection 7.4.3 Setting guidelines IP14988-1 v1 M15282-3 v12 When inverse time overcurrent characteristic is selected, the trip time of the stage will be the sum of the inverse time delay and the set definite time delay. Thus, if only the inverse time delay is required, it is important to set the definite time delay for that stage to zero.
Page 146 Section 7 1MRK 511 358-UUS A Current protection tx : Definite time delay for step x . The definite time tx is added to the inverse time when inverse time characteristic is selected. Note that the value set is the time between activation of the start and the trip outputs.
Page 147: Common Settings For All Steps
1MRK 511 358-UUS A Section 7 Current protection tResetx : Constant reset time delay in s for step x. HarmBlockx : This is used to enable block of step x from 2 harmonic restrain function. tPCrvx, tACrvx, tBCrvx, tCCrvx : Parameters for user programmable of inverse time characteristic curve.
Page 148: 2Nd Harmonic Restrain
Section 7 1MRK 511 358-UUS A Current protection Voltage (3V • or V Current (3I • · ZNpol or 3I ·ZNpol where ZNpol is RNpol + jXNpol), or Dual (dual polarizing, (3V • both currents and voltage, + 3I · ZNpol) or (V ·...
Page 149: Parallel Transformer Inrush Current Logic
1MRK 511 358-UUS A Section 7 Current protection 7.4.3.4 Parallel transformer inrush current logic M15282-97 v5 In case of parallel transformers there is a risk of sympathetic inrush current. If one of the transformers is in operation, and the parallel transformer is switched in, the asymmetric inrush current of the switched in transformer will cause partial saturation of the transformer already in service.
Page 150: Line Application Example
Section 7 1MRK 511 358-UUS A Current protection The function is divided into two parts. The SOTF function will give operation from step 2 or 3 during a set time after change in the position of the circuit breaker. The SOTF function has a set time delay.
Page 151 1MRK 511 358-UUS A Section 7 Current protection xx05000149_ansi.vsd ANSI05000149 V1 EN-US Figure 66: Connection of polarizing voltage from an open (ANSI-broken) delta The different steps can be described as follows. Step 1 M15282-123 v5 This step has directional instantaneous function. The requirement is that overreaching of the protected line is not allowed.
Page 152 Section 7 1MRK 511 358-UUS A Current protection As a consequence of the distribution of zero sequence current in the power system, the current to the protection might be larger if one line out from the remote busbar is taken out of service, see figure 68.
Page 153 1MRK 511 358-UUS A Section 7 Current protection In this case the residual current out on the line can be larger than in the case of ground fault on the remote busbar. ³ × 1.2 3I step1 (Equation 41) EQUATION1201 V3 EN-US The current setting for step 1 is chosen as the largest of the above calculated residual currents, measured by the protection.
Page 154 Section 7 1MRK 511 358-UUS A Current protection ³ × × step2 step1 (Equation 43) EQUATION1203 V4 EN-US where: is the current setting for step 1 on the faulted line. step1 Step 3 M15282-164 v6 This step has directional function and a time delay slightly larger than step 2, often 0.8 s. Step 3 shall enable selective trip of ground faults having higher fault resistance to ground, compared to step 2.
Page 155: Four Step Directional Negative Phase Sequence Overcurrent Protection Ns4Ptoc (46I2)
1MRK 511 358-UUS A Section 7 Current protection Four step directional negative phase sequence overcurrent protection NS4PTOC (46I2) GUID-E8CF8AA2-AF54-4FD1-A379-3E55DCA2FA3A v1 7.5.1 Identification GUID-E1720ADA-7F80-4F2C-82A1-EF2C9EF6A4B4 v1 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Four step negative sequence NS4PTOC 46I2 overcurrent protection...
Page 156: Setting Guidelines
Section 7 1MRK 511 358-UUS A Current protection Table 17: Inverse time characteristics Curve name ANSI Extremely Inverse ANSI Very Inverse ANSI Normal Inverse ANSI Moderately Inverse ANSI/IEEE Definite time ANSI Long Time Extremely Inverse ANSI Long Time Very Inverse ANSI Long Time Inverse IEC Normal Inverse IEC Very Inverse...
Page 157: Settings For Each Step
1MRK 511 358-UUS A Section 7 Current protection GUID-F7AA2194-4D1C-4475-8853-C7D064912614 v4 When inverse time overcurrent characteristic is selected, the trip time of the stage will be the sum of the inverse time delay and the set definite time delay. Thus, if only the inverse time delay is required, it is important to set the definite time delay for that stage to zero.
Page 158 Section 7 1MRK 511 358-UUS A Current protection tx : Definite time delay for step x . The definite time tx is added to the inverse time when inverse time characteristic is selected. Note that the value set is the time between activation of the start and the trip outputs.
Page 159: Common Settings For All Steps
1MRK 511 358-UUS A Section 7 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 160: Sensitive Directional Residual Overcurrent And Power Protection Sdepsde (67N)
Section 7 1MRK 511 358-UUS A Current protection Reverse Area Vpol=-V2 AngleRCA Forward Area Iop = I2 ANSI10000031-1-en.vsd ANSI10000031 V1 EN-US Figure 74: 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 161: Application
1MRK 511 358-UUS A Section 7 Current protection 7.6.2 Application SEMOD171959-4 v11 In networks with high impedance grounding, the phase-to-ground fault current is significantly smaller than the short circuit currents. Another difficulty for ground fault protection is that the magnitude of the phase-to-ground fault current is almost independent of the fault location in the network.
Page 162: Setting Guidelines
Section 7 1MRK 511 358-UUS A Current protection Phase currents Phase ground voltages ANSI13000013-1-en.vsd ANSI13000013 V1 EN-US Figure 75: Connection of SDEPSDE to analog preprocessing function block Overcurrent functionality uses true 3I0, i.e. sum of GRPxA, GRPxB and GRPxC. For 3I0 to be calculated, connection is needed to all three phase inputs.
Page 163 1MRK 511 358-UUS A Section 7 Current protection phase × (Equation 46) EQUATION2020-ANSI V1 EN-US Where is the phase voltage in the fault point before the fault, phase is the resistance to ground in the fault point and is the system zero sequence impedance to ground The fault current, in the fault point, can be calculated as: ×...
Page 164 Section 7 1MRK 511 358-UUS A Current protection In many systems there is also a neutral point reactor (Petersen coil) connected to one or more transformer neutral points. In such a system the impedance Z can be calculated as: 9R X X jX // 3R // j3X ×...
Page 165 1MRK 511 358-UUS A Section 7 Current protection phase × + × (Equation 51) EQUATION2023-ANSI V1 EN-US Where is the phase voltage in the fault point before the fault phase is the total positive sequence impedance to the fault point. Z lineAB,1 lineBC,1 is the total zero sequence impedance to the fault point.
Page 166 Section 7 1MRK 511 358-UUS A Current protection The protection will use the power components in the characteristic angle direction for measurement, and as base for the inverse time delay. The inverse time delay is defined as: × × × TDSN (3I 3V cos (reference)) ×...
Page 167 1MRK 511 358-UUS A Section 7 Current protection RCA = -90°, ROA = 90° ) – ang(V = ang(3I en06000649_ansi.vsd ANSI06000649 V1 EN-US Figure 78: Characteristic for RCADir equal to -90° OpModeSel is set to 3I03V0Cosfi the apparent residual power component in the direction is When measured.
Page 168 Section 7 1MRK 511 358-UUS A Current protection DirMode is set Forward or Reverse to set the direction of the operation for the directional function OpModeSel . selected by the INRelPU which is All the directional protection modes have a residual current release level setting IBase .
Page 169 1MRK 511 358-UUS A Section 7 Current protection OpINNonDir is set Enabled to activate the non-directional residual current protection. INNonDirPU is the operate current level for the non-directional function. The setting is given in % IBase . This function can be used for detection and clearance of cross-country faults in a shorter time than for the directional function.
Page 170: Thermal Overload Protection, One Time Constant Fahrenheit/Celsius Lfpttr/ Lcpttr (26)
Section 7 1MRK 511 358-UUS A Current protection tINNonDir is the definite time delay for the non directional ground fault current protection, given in s. OpVN is set Enabled to activate the trip function of the residual over voltage protection. tVN is the definite time delay for the trip function of the residual voltage protection, given in s.
Page 171: Setting Guideline
1MRK 511 358-UUS A Section 7 Current protection dangerous temperatures are reached. If the temperature continues to increase to the trip value TripTemp , the protection initiates trip of the protected line. 7.7.3 Setting guideline IP14994-1 v1 M15094-3 v7 The parameters for the Thermal overload protection, one time constant, Fahrenheit/Celsius LFPTTR/LCPTTR (26) are set via the local HMI or PCM600.
Page 172: Identification
Section 7 1MRK 511 358-UUS A Current protection 7.8.1 Identification M14877-1 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Thermal overload protection, two TRPTTR time constants SYMBOL-A V1 EN-US 7.8.2 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.
Page 173: Setting Guideline
1MRK 511 358-UUS A Section 7 Current protection heat content using a set cooling time constant. Energizing of the transformer can be blocked until the heat content has reached a set level. 7.8.3 Setting guideline M13250-3 v8 The parameters for the thermal overload protection, two time constants (TRPTTR, 49) are set via the local HMI or Protection and Control IED Manager (PCM600).
Page 174 Section 7 1MRK 511 358-UUS A Current protection DQ - (Equation 61) EQUATION1180 V1 EN-US If the transformer has forced cooling (FOA) the measurement should be made both with and without the forced cooling in operation, giving Tau2 and Tau1 . The time constants can be changed if the current is higher than a set value or lower than a set value.
Page 175: Breaker Failure Protection Ccrbrf(50Bf)
1MRK 511 358-UUS A Section 7 Current protection Warning : If the calculated time to trip factor is below the setting Warning a warning signal is activated. The setting is given in minutes. Breaker failure protection CCRBRF(50BF) IP14514-1 v6 7.9.1 Identification M14878-1 v5 Function description...
Page 176 Section 7 1MRK 511 358-UUS A Current protection Contact mode can be usable in applications where the fault current through the circuit activated. breaker is small. This can be the case for some generator protection application (for example reverse power protection) or in case of line ends with weak end infeed. RetripMode : This setting states how the re-trip function shall operate.
Page 177 1MRK 511 358-UUS A Section 7 Current protection faults in these systems it is necessary to measure the residual current separately. Also in effectively grounded systems the setting of the ground-fault current protection can be chosen to BuTripMode is set 1 out of 4 . The current setting should be chosen relatively low current level.
Page 178 Section 7 1MRK 511 358-UUS A Current protection Protection operate time Normal t cbopen The fault Retrip delay t1 after re-trip cbopen occurs BFPreset Margin Minimum back-up trip delay t2 Critical fault clearance time for stability Time Trip and Pickup CCRBRF (50BF) ANSI05000479_3_en.vsd...
Page 179: Breaker Failure Protection, Single Phase Version Ccsrbrf (50Bf)
1MRK 511 358-UUS A Section 7 Current protection 7.10 Breaker failure protection, single phase version CCSRBRF (50BF) SEMOD127864-1 v2 7.10.1 Identification SEMOD127866-2 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Breaker failure protection, single CCSRBRF 50BF phase version I>BF...
Page 180 Section 7 1MRK 511 358-UUS A Current protection RetripMode : This setting states how the re-trip function shall operate. Retrip Off means that the CB Pos Check (circuit breaker position check) and Current means re-trip function is not activated. CB Pos Check (circuit that a phase current must be larger than the operate level to allow re-trip.
Page 181: Stub Protection Stbptoc (50Stb)
1MRK 511 358-UUS A Section 7 Current protection Protection operate time Normal t cbopen The fault Retrip delay t1 after re-trip cbopen occurs BFPreset Margin Minimum back-up trip delay t2 Critical fault clearance time for stability Time Trip and Pickup CCRBRF (50BF) ANSI05000479_3_en.vsd...
Page 182: Application
Section 7 1MRK 511 358-UUS A Current protection 7.11.2 Application M12904-3 v5 In a breaker-and-a-half switchyard the line protection and the busbar protection normally have overlap when a connected object is in service. When an object is taken out of service it is normally required to keep the diagonal of the breaker-and-a-half switchyard in operation.
Page 183: Pole Discrepancy Protection Ccpdsc(52Pd)
1MRK 511 358-UUS A Section 7 Current protection IPickup : Current level for the Stub protection, set in % of IBase . This parameter should be set so that all faults on the stub can be detected. The setting should thus be based on fault calculations. t : Time delay of the operation.
Page 184: Directional Underpower Protection Guppdup (37)
Section 7 1MRK 511 358-UUS A Current protection The following settings can be done for the pole discrepancy protection. GlobalBaseSel : Selects the global base value group used by the function to define ( IBase ), ( VBase ) SBase ). and ( Operation : Disabled or Enabled tTrip : Time delay of the operation.
Page 185 1MRK 511 358-UUS A Section 7 Current protection machine itself. If the generator under consideration is very large and if it consumes lots of electric power, it may be desirable to disconnect it to ease the task for the rest of the power system. Often, the motoring condition may imply that the turbine is in a very dangerous state.
Page 186: Setting Guidelines
Section 7 1MRK 511 358-UUS A Current protection Gas turbines usually do not require reverse power protection. Figure illustrates the reverse power protection with underpower protection and with overpower protection. The underpower protection gives a higher margin and should provide better dependability.
Page 187 1MRK 511 358-UUS A Section 7 Current protection Mode Set value Formula used for complex power calculation × (Equation 68) EQUATION2058-ANSI V1 EN-US × (Equation 69) EQUATION2059-ANSI V1 EN-US × (Equation 70) EQUATION2060-ANSI V1 EN-US = × × (Equation 71) EQUATION2061-ANSI V1 EN-US = ×...
Page 188 Section 7 1MRK 511 358-UUS A Current protection Power1(2) Angle1(2) Operate en06000441.vsd IEC06000441 V1 EN-US Figure 84: Underpower mode Power1(2) gives the power component pick up value in the Angle1(2) direction. The The setting setting is given in p.u. of the generator rated power, see equation 74. Minimum recommended setting is 0.2% of S when metering class CT inputs into the IED are used.
Page 189 1MRK 511 358-UUS A Section 7 Current protection Operate ° Angle1(2) = 0 Power1(2) en06000556.vsd IEC06000556 V1 EN-US Figure 85: 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 190: Directional Overpower Protection Goppdop (32)
Section 7 1MRK 511 358-UUS A 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 191 1MRK 511 358-UUS A Section 7 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 192: Setting Guidelines
Section 7 1MRK 511 358-UUS A 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 86: Reverse power protection with underpower IED and overpower IED 7.14.3 Setting guidelines SEMOD172150-4 v7...
Page 193 1MRK 511 358-UUS A Section 7 Current protection Mode Set value Formula used for complex power calculation = × × (Equation 84) EQUATION2044 V1 EN-US = × × (Equation 85) EQUATION2045 V1 EN-US = × × (Equation 86) EQUATION2046 V1 EN-US The function has two stages that can be set independently.
Page 194 Section 7 1MRK 511 358-UUS A Current protection × × 3 VBase IBase (Equation 87) 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 195: Broken Conductor Check Brcptoc (46)
1MRK 511 358-UUS A Section 7 Current protection S TD S TD S ⋅ − ⋅ Calculated (Equation 89) 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 196: Setting Guidelines
Section 7 1MRK 511 358-UUS A Current protection 7.15.3 Setting guidelines SEMOD171866-5 v4 Broken conductor check BRCPTOC (46) must be set to detect open phase/s (series faults) with different loads on the line. BRCPTOC (46) must at the same time be set to not operate for maximum asymmetry which can exist due to, for example, not transposed power lines.
Page 197 1MRK 511 358-UUS A Section 7 Current protection Rack Capacitor Unit (Can) IEC09000753_1_en.vsd IEC09000753 V1 EN-US Figure 89: Replacement of a faulty capacitor unit within SCB There are four types of the capacitor unit fusing designs which are used for construction of SCBs: Externally fused where an individual fuse, externally mounted, protects each capacitor unit.
Page 198: Scb Protection
Section 7 1MRK 511 358-UUS A Current protection Delta-connected banks (generally used only at distribution voltages) Single wye-connected banks Double wye-connected banks H-configuration, where each phase is connected in a bridge Additionally, the SCB star point, when available, can be either grounded , grounded via impedance or isolated from ground.
Page 199: Setting Guidelines
1MRK 511 358-UUS A Section 7 Current protection • Voltage in excess of the nameplate rating at fundamental frequency, but not over 110% of rated RMS voltage • Harmonic voltages superimposed on the fundamental frequency • Reactive power manufacturing tolerance of up to 115% of rated reactive power Capacitor units rated above 600 V shall have an internal discharge device to reduce the residual voltage to 50 V or less in 5 or 10 minutes (depending on national standard).
Page 200 Section 7 1MRK 511 358-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 90: Single line diagram for the application example From figure it is possible to calculate the following rated fundamental frequency current for this SCB: ×...
Page 201 1MRK 511 358-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 202: Restrike Detection
Section 7 1MRK 511 358-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 7.16.3.1 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 203: Base Quantities
1MRK 511 358-UUS A Section 7 Current protection VRPVOC (51V) function module has two independent protection each consisting of: • One overcurrent step with the following built-in features: • Selectable definite time delay or Inverse Time IDMT characteristic • Voltage restrained/controlled feature is available in order to modify the pick-up level of the overcurrent stage in proportion to the magnitude of the measured voltage •...
Page 204: Setting Guidelines
Section 7 1MRK 511 358-UUS A Current protection recover above the set value. To ensure a proper reset, the function is blocked two seconds after the trip signal is issued. VRPVOC (51V) Trip output I3P* TRIP V3P* I3P* TROC TRIP V3P* TROC BLOCK...
Page 205: Voltage-Restrained Overcurrent Protection For Generator And Step-Up Transformer
1MRK 511 358-UUS A Section 7 Current protection tDef_UV : Definite time delay. Since it is related to a backup protection function, a long time delay 0.5 s or more) is typically used. Note that the value set is the time between activation (for example of the start and the trip outputs.
Page 206: Overcurrent Protection With Undervoltage Seal-In
Section 7 1MRK 511 358-UUS A Current protection VDepMode to Slope (default value). VDepFact to the value 25% (default value). 10. Set VHighLimit to the value 100% (default value). 11. Set All other settings can be left at the default values. 7.17.3.3 Overcurrent protection with undervoltage seal-in GUID-B58E1CD6-F9AE-4301-ABE7-90DBFC987D69 v6...
Page 207: Voltage Protection
1MRK 511 358-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: Setting Guidelines
Section 8 1MRK 511 358-UUS A Voltage protection 8.1.3 Setting guidelines M13851-3 v8 All the voltage conditions in the system where UV2PTUV (27) performs its functions should be considered. The same also applies to the associated equipment, its voltage and time characteristic.
Page 209 1MRK 511 358-UUS A Section 8 Voltage protection VBase (given in GlobalBaseSel ): Base voltage phase-to-phase in primary kV. This voltage is used as reference for voltage setting. UV2PTUV (27) measures selectively phase-to-ground voltages, or ConnType . The function will operate if the voltage phase-to-phase voltage chosen by the setting VBase .
Page 210: Two Step Overvoltage Protection Ov2Ptov (59)
Section 8 1MRK 511 358-UUS A Voltage protection ACrvn , BCrvn , CCrvn , DCrvn , PCrvn : Parameters to set to create programmable under voltage inverse time characteristic. Description of this can be found in the technical reference manual. CrvSatn : When the denominator in the expression of the programmable curve is equal to zero the time delay will be infinity.
Page 211: Setting Guidelines
1MRK 511 358-UUS A Section 8 Voltage protection OV2PTOV (59) is also used to initiate voltage correction measures, like insertion of shunt reactors, to compensate for low load, and thereby decreasing the voltage. The function has a high measuring accuracy and hysteresis setting to allow applications to control reactive load. OV2PTOV (59) is used to disconnect apparatuses, like electric motors, which will be damaged when subject to service under high voltage conditions.
Page 212: Equipment Protection, Capacitors
Section 8 1MRK 511 358-UUS A Voltage protection 8.2.3.2 Equipment protection, capacitors M13852-13 v1 High voltage will deteriorate the dielectricum and the insulation. The setting has to be well above the highest occurring "normal" voltage and well below the highest acceptable voltage for the capacitor.
Page 213 1MRK 511 358-UUS A Section 8 Voltage protection OpModen : This parameter describes how many of the three measured voltages that should be 1 out of 3 , 2 out of 3 , 3 out of 3 . In most above the set level to give operation.
Page 214: Two Step Residual Overvoltage Protection Rov2Ptov (59N)
Section 8 1MRK 511 358-UUS A Voltage protection Two step residual overvoltage protection ROV2PTOV (59N) IP14546-1 v4 8.3.1 Identification SEMOD54295-2 v5 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Two step residual overvoltage ROV2PTOV protection TRV V1 EN-US 8.3.2 Application M13809-3 v7...
Page 215: Equipment Protection, Such As For Motors, Generators, Reactors And Transformers
1MRK 511 358-UUS A Section 8 Voltage protection 8.3.3.1 Equipment protection, such as for motors, generators, reactors and transformers M13853-9 v7 High residual voltage indicates ground fault in the system, perhaps in the component to which Two step residual overvoltage protection (ROV2PTOV, 59N) is connected. For selectivity reasons to the primary protection for the faulted device ROV2PTOV (59N) must trip the component with some time delay.
Page 216: Direct Grounded System
Section 8 1MRK 511 358-UUS A Voltage protection ANSI07000190-1-en.vsd ANSI07000190 V1 EN-US Figure 92: 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: Settings For Two Step Residual Overvoltage Protection
1MRK 511 358-UUS A Section 8 Voltage protection ANSI07000189-1-en.vsd ANSI07000189 V1 EN-US Figure 93: 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 511 358-UUS A Voltage protection Pickupn : Set operate overvoltage operation value for step n , given as % of residual voltage VBase : corresponding to > × VBase kV (Equation 98) 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: Voltage Differential Protection Vdcptov (60)
1MRK 511 358-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: Setting Guidelines
Section 8 1MRK 511 358-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: Loss Of Voltage Check Lovptuv (27)
1MRK 511 358-UUS A Section 8 Voltage protection different voltage level but the difference can also e.g. be used by voltage drop in the secondary circuits. The setting is normally done at site by evaluating the differential voltage achieved as a RFLx and shall be equal to the V1 voltage.
Page 222: Application
Section 8 1MRK 511 358-UUS A Voltage protection 8.5.2 Application SEMOD171876-4 v3 The trip of the circuit breaker at a prolonged loss of voltage at all the three phases is normally used in automatic restoration systems to facilitate the system restoration after a major blackout. Loss of voltage check (LOVPTUV, 27) generates a TRIP signal only if the voltage in all the three phases is low for more than the set time.
Page 223: Frequency Protection
1MRK 511 358-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: Overfrequency Protection Saptof (81)
Section 9 1MRK 511 358-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: Setting Guidelines
1MRK 511 358-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: Setting Guidelines
Section 9 1MRK 511 358-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: Frequency Time Accumulation Protection Function Ftaqfvr (81A)
1MRK 511 358-UUS A Section 9 Frequency protection Frequency time accumulation protection function FTAQFVR (81A) GUID-124A1F91-44C0-4DB6-8603-CC8CA19AE2A6 v3 9.4.1 Identification GUID-87605DA0-EAA6-4A6C-BF03-7FDB187E1B29 v2 Function description IEC 61850 IEC 60617 ANSI/ identification identification IEEEidentificatio Frequency time accumulation FTAQFVR f<> protection 9.4.2 Application GUID-82CA8336-82BE-42AB-968A-D4F08941C9D0 v3 Generator prime movers are affected by abnormal frequency disturbances.
Page 228 Section 9 1MRK 511 358-UUS A Frequency protection Frequency or Resonant Frequency Ratio IEC12000611-2-en.vsd IEC12000611 V2 EN-US Figure 96: Typical stress magnification factor curve according ANSI/IEEE C37.106-2003 Standard Each turbine manufactured for different design of blades has various time restriction limits for various frequency bands.
Page 229: Setting Guidelines
1MRK 511 358-UUS A Section 9 Frequency protection Prohibited Operation Prohibited Operation Restricted Time Operation Continuous operation Continuous operation Restricted Time Operation Prohibited Operation Restricted Time Operation 0.01 1000 0.01 1000 Time (Minutes) Time (Minutes) Prohibited Operation Prohibited Operation Restricted Time Operation Continuous operation Continuous operation Restricted Time Operation...
Page 230 Section 9 1MRK 511 358-UUS A Frequency protection FTAQFVR (81A) used to protect a turbine: Frequency during start-up and shutdown is normally not calculated, consequently the protection CBCheck enabled. If the generator supply any load function is blocked by CB position, parameter when CB is in open position e.g.
Page 231: Section 10 Multipurpose Protection
1MRK 511 358-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 232: Current And Voltage Selection For Cvgapc Function
Section 10 1MRK 511 358-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 233 1MRK 511 358-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 234: Base Quantities For Cvgapc Function
Section 10 1MRK 511 358-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 235: Application Possibilities
1MRK 511 358-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 236: Setting Guidelines
Section 10 1MRK 511 358-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 237 1MRK 511 358-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 238: Negative Sequence Overcurrent Protection
Section 10 1MRK 511 358-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 239 1MRK 511 358-UUS A Section 10 Multipurpose protection × æ ö ç ÷ × è ø (Equation 102) 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 240: Generator Stator Overload Protection In Accordance With Iec Or Ansi Standards
Section 10 1MRK 511 358-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 241 1MRK 511 358-UUS A Section 10 Multipurpose protection × æ ö ç ÷ × è ø (Equation 106) 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 242: Open Phase Protection For Transformer, Lines Or Generators And Circuit Breaker Head Flashover Protection For Generators
Section 10 1MRK 511 358-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 243: Loss Of Excitation Protection For A Generator
1MRK 511 358-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 244 Section 10 1MRK 511 358-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 245: Section 11 System Protection And Control
1MRK 511 358-UUS A Section 11 System protection and control Section 11 System protection and control 11.1 Multipurpose filter SMAIHPAC GUID-6B541154-D56B-452F-B143-4C2A1B2D3A1F v1 11.1.1 Identification GUID-8224B870-3DAA-44BF-B790-6600F2AD7C5D v1 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Multipurpose filter SMAIHPAC 11.1.2 Application...
Page 246: Setting Guidelines
Section 11 1MRK 511 358-UUS A System protection and control measurement), etc. in order to report the extracted phasor values to the supervisory system (e.g. MicroSCADA). The following figure shoes typical configuration connections required to utilize this filter in conjunction with multi-purpose function as non-directional overcurrent protection. IEC13000179-1-en.vsd IEC13000179 V1 EN-US Figure 99: Required ACT configuration...
Page 247 1MRK 511 358-UUS A Section 11 System protection and control The subsynchronous current frequency is calculated as follows: 18.5 31.5 (Equation 109) EQUATION13000030 V1 EN-US In order to properly extract the weak subsynchronous signal in presence of the dominating 50Hz signal the SMAI HPAC filter shall be set as given in the following table: Table 25: Proposed settings for SMAIHPAC...
Page 248 Section 11 1MRK 511 358-UUS A System protection and control • in > = 300A • 35566 118.55 • 0.64 • • • then exact replica of the existing relay will be achieved. The following table summarizes all required settings for the multi-purpose function: Setting Group1 Operation CurrentInput...
Page 249 1MRK 511 358-UUS A Section 11 System protection and control tResetDef_OC1 0.00 P_OC1 1.000 A_OC1 118.55 B_OC1 0.640 C_OC1 0.000 Application manual...
Page 251: Section 12 Secondary System Supervision
1MRK 511 358-UUS A Section 12 Secondary system supervision Section 12 Secondary system supervision 12.1 Current circuit supervision (87) IP14555-1 v5 12.1.1 Identification M14870-1 v5 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Current circuit supervision CCSSPVC 12.1.2 Application...
Page 252: Fuse Failure Supervision Fufspvc
Section 12 1MRK 511 358-UUS A Secondary system supervision IMinOp , must be set as a minimum to twice the residual current in The minimum operate current, the supervised CT circuits under normal service conditions and rated primary current. Pickup_Block is normally set at 150% to block the function during transient The parameter conditions.
Page 253: Setting Guidelines
1MRK 511 358-UUS A Section 12 Secondary system supervision In cases where the line can have a weak-infeed of zero sequence current this function shall be avoided. A criterion based on delta current and delta voltage measurements can be added to the fuse failure supervision function in order to detect a three phase fuse failure.
Page 254: Negative Sequence Based
Section 12 1MRK 511 358-UUS A Secondary system supervision V0I0 AND V2I2 which gives that both negative and zero sequence algorithms are activated and working in an AND-condition, that is, both algorithms must give condition for block in order to activate the output signals BLKV or BLKZ.
Page 255: Delta V And Delta I
1MRK 511 358-UUS A Section 12 Secondary system supervision 3I0PU is done in percentage of IBase . The setting of pickup must The setting of the current limit be higher than the normal unbalance current that might exist in the system. The setting can be calculated according to equation 115.
Page 256: Fuse Failure Supervision Vdspvc (60)
Section 12 1MRK 511 358-UUS A Secondary system supervision VDLDPU with a sufficient margin below the minimum expected operating voltage. A safety Set the margin of at least 15% is recommended. 12.3 Fuse failure supervision VDSPVC (60) GUID-9C5BA1A7-DF2F-49D4-A13A-C6B483DDFCDC v2 12.3.1 Identification GUID-109434B0-23E5-4053-9E6E-418530A07F9C v2 Function description...
Page 257: Setting Guidelines
1MRK 511 358-UUS A Section 12 Secondary system supervision Main Vt circuit FuseFailSupvn ANSI12000143-1-en.vsd ANSI12000143 V1 EN-US Figure 100: Application of VDSPVC 12.3.3 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 258 Section 12 1MRK 511 358-UUS A 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 259: Section 13 Control
1MRK 511 358-UUS A Section 13 Control Section 13 Control 13.1 Synchronism check, energizing check, and synchronizing SESRSYN (25) IP14558-1 v4 13.1.1 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 260: Synchronism Check
Section 13 1MRK 511 358-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 261 1MRK 511 358-UUS A Section 13 Control en04000179_ansi.vsd ANSI04000179 V1 EN-US Figure 101: 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 262: Energizing Check
Section 13 1MRK 511 358-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 263: Voltage Selection
1MRK 511 358-UUS A Section 13 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 264: Application Examples
(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 104.
Page 265: Single Circuit Breaker With Single Busbar
1MRK 511 358-UUS A Section 13 Control 13.1.3.1 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 266: Single Circuit Breaker With Double Busbar, External Voltage Selection
Section 13 1MRK 511 358-UUS A Control 13.1.3.2 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 267: Single Circuit Breaker With Double Busbar, Internal Voltage Selection
1MRK 511 358-UUS A Section 13 Control 13.1.3.3 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 268: Double Circuit Breaker
Section 13 1MRK 511 358-UUS A Control 13.1.3.4 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 269: Breaker-And-A-Half
1MRK 511 358-UUS A Section 13 Control 13.1.3.5 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 270 Section 13 1MRK 511 358-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 271: Setting Guidelines
1MRK 511 358-UUS A Section 13 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 272 Section 13 1MRK 511 358-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 273 1MRK 511 358-UUS A Section 13 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 274 Section 13 1MRK 511 358-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 275 1MRK 511 358-UUS A Section 13 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 276: Autorecloser For 1 Phase, 2 Phase And/Or 3 Phase Operation Smbrrec (79)
Section 13 1MRK 511 358-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. 13.2 Autorecloser for 1 phase, 2 phase and/or 3 phase operation SMBRREC (79) IP14559-1 v6 13.2.1...
Page 277 1MRK 511 358-UUS A Section 13 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 110: Single-shot automatic reclosing at a permanent fault...
Page 278 Section 13 1MRK 511 358-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 279: Auto-Reclosing Operation Off And On
1MRK 511 358-UUS A Section 13 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 280: Initiate Auto-Reclosing From Cb Open Information
Section 13 1MRK 511 358-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 281: Long Trip Signal
1MRK 511 358-UUS A Section 13 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 282: Armode = 1/2Ph , 1-Phase Or 2-Phase Reclosing In The First Shot
Section 13 1MRK 511 358-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 283: External Selection Of Auto-Reclose Mode
1MRK 511 358-UUS A Section 13 Control Table 27: 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 284: Reclosing Reset Timer
Section 13 1MRK 511 358-UUS A Control 13.2.2.15 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 285: Evolving Fault
1MRK 511 358-UUS A Section 13 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 286: Automatic Continuation Of The Reclosing Sequence
Section 13 1MRK 511 358-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 287 1MRK 511 358-UUS A Section 13 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 288 Section 13 1MRK 511 358-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 289 1MRK 511 358-UUS A Section 13 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 290 Section 13 1MRK 511 358-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 291 1MRK 511 358-UUS A Section 13 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 292: Auto-Recloser Parameter Settings
Section 13 1MRK 511 358-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 293 1MRK 511 358-UUS A Section 13 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 294 Section 13 1MRK 511 358-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 295: Apparatus Control Apc
1MRK 511 358-UUS A Section 13 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 296 Section 13 1MRK 511 358-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 117: Overview of the apparatus control functions Features in the apparatus control function: •...
Page 297 1MRK 511 358-UUS A Section 13 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 298: Bay Control (Qcbay)
Section 13 1MRK 511 358-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 29 Table 29: orCat attribute according to IEC61850...
Page 299: Switch Controller (Scswi)
1MRK 511 358-UUS A Section 13 Control IEC13000016-2-en.vsd IEC13000016 V2 EN-US Figure 119: APC - Local remote function block 13.3.1.2 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 300: Switches (Sxcbr/Sxswi)
Section 13 1MRK 511 358-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 301 1MRK 511 358-UUS A Section 13 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 302: Interaction Between Modules
Section 13 1MRK 511 358-UUS A Control SCSWI RES_ EXT SELECTED Other SCSWI in the bay en 05000118_ ansi. vsd ANSI05000118 V2 EN-US Figure 121: 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 122.
Page 303 1MRK 511 358-UUS A Section 13 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 304: Setting Guidelines
Section 13 1MRK 511 358-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 305: Switch Controller (Scswi)
1MRK 511 358-UUS A Section 13 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 306: Switch (Sxcbr/Sxswi)
Section 13 1MRK 511 358-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 307 1MRK 511 358-UUS A Section 13 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 308: Configuration Guidelines
Section 13 1MRK 511 358-UUS A Control 13.4.1 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 309: Signals From Bus-Coupler
1MRK 511 358-UUS A Section 13 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 310 Section 13 1MRK 511 358-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 126: 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 311 1MRK 511 358-UUS A Section 13 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 312: Configuration Setting
Section 13 1MRK 511 358-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 313: Interlocking For Bus-Coupler Bay Abc_Bc (3)
1MRK 511 358-UUS A Section 13 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 314: Configuration
Section 13 1MRK 511 358-UUS A Control WA1 (A) WA2 (B) WA7 (C) 2089 189G 289G en04000514_ansi.vsd ANSI04000514 V1 EN-US Figure 128: Switchyard layout ABC_BC (3) 13.4.3.2 Configuration M13553-138 v4 The signals from the other bays connected to the bus-coupler module ABC_BC are described below.
Page 315 1MRK 511 358-UUS A Section 13 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 316: Signals From Bus-Coupler
Section 13 1MRK 511 358-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 317 1MRK 511 358-UUS A Section 13 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 318: Configuration Setting
Section 13 1MRK 511 358-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 133: 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 319: Interlocking For Transformer Bay Ab_Trafo (3)
1MRK 511 358-UUS A Section 13 Control • BBTR_OP = 1 • VP_BBTR = 1 13.4.4 Interlocking for transformer bay AB_TRAFO (3) IP14149-1 v2 13.4.4.1 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 134.
Page 320: Configuration Setting
Section 13 1MRK 511 358-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 135: 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 321: Interlocking For Bus-Section Breaker A1A2_Bs (3)
1MRK 511 358-UUS A Section 13 Control 13.4.5 Interlocking for bus-section breaker A1A2_BS (3) IP14154-1 v2 13.4.5.1 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 136. The function can be used for different busbars, which includes a bus-section circuit breaker.
Page 322 Section 13 1MRK 511 358-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 323 1MRK 511 358-UUS A Section 13 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 324: Configuration Setting
Section 13 1MRK 511 358-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 325: Application
1MRK 511 358-UUS A Section 13 Control 13.4.6.1 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 140. A1A2_DC (3) function can be used for different busbars, which includes a bus-section disconnector.
Page 326 Section 13 1MRK 511 358-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 327 1MRK 511 358-UUS A Section 13 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 328: Signals In Double-Breaker Arrangement
Section 13 1MRK 511 358-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 329 1MRK 511 358-UUS A Section 13 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 330: Signals In Breaker And A Half Arrangement
Section 13 1MRK 511 358-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 331: Interlocking For Busbar Grounding Switch Bb_Es (3)
1MRK 511 358-UUS A Section 13 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 332 Section 13 1MRK 511 358-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 333 1MRK 511 358-UUS A Section 13 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 334 Section 13 1MRK 511 358-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 335: Signals In Double-Breaker Arrangement
1MRK 511 358-UUS A Section 13 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 336: Signals In Breaker And A Half Arrangement
Section 13 1MRK 511 358-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 337: Configuration Setting
1MRK 511 358-UUS A Section 13 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 161: 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 338: Interlocking For Breaker-And-A-Half Diameter Bh (3)
Section 13 1MRK 511 358-UUS A Control 13.4.9 Interlocking for breaker-and-a-half diameter BH (3) IP14173-1 v3 13.4.9.1 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 162. WA1 (A) WA2 (B) 189G...
Page 339: Voltage Control
1MRK 511 358-UUS A Section 13 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 340 Section 13 1MRK 511 358-UUS A Control different types of tap changer mechanisms. The pulse is generated whenever the measured voltage, for a given time, deviates from the set reference value by more than the preset deadband (degree of insensitivity). The voltage can be controlled at the point of voltage measurement, as well as at a load point located out in the network.
Page 341 1MRK 511 358-UUS A Section 13 Control functionality the Apparatus control function blocks Bay control (QCBAY), Local remote (LOCREM) and Local remote control (LOCREMCTRL) are used. Information about the control location is given to TR1ATCC (90) or TR8ATCC (90) function through connection of the Permitted Source to Operate (PSTO) output of the QCBAY function block to the input PSTO of the TR1ATCC (90) or TR8ATCC (90) function block.
Page 342 Section 13 1MRK 511 358-UUS A Control High Voltage Side raise,lower signals/alarms position (Load Current) I 3ph or ph-ph or 1ph Currents 3ph or ph-ph or 1ph Voltages Low Voltage Side VB (Busbar Voltage) Line Impedance R+jX Load Center VL (Load Point Voltage) ANSI10000044-1-en.vsd ANSI10000044 V1 EN-US Figure 163: Signal flow for a single transformer with voltage control...
Page 343 1MRK 511 358-UUS A Section 13 Control VSet and decides which action TR1ATCC (90) then compares this voltage with the set voltage, should be taken. To avoid unnecessary switching around the setpoint, a deadband (degree of VSet , see figure 164, and it is insensitivity) is introduced.
Page 344 Section 13 1MRK 511 358-UUS A Control The purpose of the time delay is to prevent unnecessary load tap changer operations caused by temporary voltage fluctuations and to coordinate load tap changer operations in radial networks in order to limit the number of load tap changer operations. This can be done by setting a longer time delay closer to the consumer and shorter time delays higher up in the system.
Page 345 1MRK 511 358-UUS A Section 13 Control t1=180 t1=150 t1=120 t1=90 t1=60 t1=30 IEC06000488_2_en.vsd IEC06000488 V2 EN-US Figure 165: Inverse time characteristic for TR1ATCC (90) and TR8ATCC (90) t2 , will be used for consecutive commands (commands in the same The second time delay, direction as the first command).
Page 346 Section 13 1MRK 511 358-UUS A Control is to allow for a situation like that, the limitation can be removed by setting the parameter OperCapaLDC to Enabled . ANSI06000487-2-en.vsd ANSI06000487 V2 EN-US Figure 166: Vector diagram for line voltage drop compensation The calculated load voltage V is shown on the local HMI as value ULOAD under Main menu/Test/ Function status/Control/TransformerVoltageControl(ATCC,90)/TR1ATCC:x/TR8ATCC:x.
Page 347 1MRK 511 358-UUS A Section 13 Control Adjusted set voltage in per unit set, adjust VSet Original set voltage: Base quality is V VRAuto Automatic load voltage adjustment factor, setting Load current I2Base Rated current, LV winding i (corresponding to Constant load voltage adjust.
Page 348 Section 13 1MRK 511 358-UUS A Control Parallel control with the master-follower method SEMOD159053-140 v5 In the master-follower method, one of the transformers is selected to be master, and will regulate the voltage in accordance with the principles for Automatic voltage control. Selection of the master is made by activating the binary input FORCMAST in TR8ATCC (90) function block for one of the transformers in the group.
Page 349 1MRK 511 358-UUS A Section 13 Control Load en06000486_ansi.vsd ANSI06000486 V1 EN-US Figure 168: Parallel transformers with equal rated data. In the reverse reactance method, the line voltage drop compensation is used. The original of the line voltage drop compensation function purpose is to control the voltage at a load point further out in the network.
Page 350 Section 13 1MRK 511 358-UUS A Control will be approximately equal to the length of V ) from V up towards the transformer itself. Thus in principal the difference between the vector diagrams in figure and figure is the sign of the setting parameter X If now the tap position between the transformers will differ, a circulating current will appear, and the transformer with the highest tap (highest no load voltage) will be the source of this circulating...
Page 351 1MRK 511 358-UUS A Section 13 Control that the busbar or load voltage is regulated to a preset target value that the load is shared between parallel transformers in proportion to their ohmic short circuit reactance If the transformers have equal percentage impedance given in the respective transformer MVA base, the load will be divided in direct proportion to the rated power of the transformers when the circulating current is minimized.
Page 352 Section 13 1MRK 511 358-UUS A Control Bmean (Equation 124) EQUATION1980-ANSI V1 EN-US This value for the no-load voltage is then simply put into the voltage control function for single transformer. There it is treated as the measured busbar voltage, and further control actions are taken as described previously in section "Automatic voltage control for a single transformer".
Page 353 1MRK 511 358-UUS A Section 13 Control transformers have equal magnitude of V then there is a predetermined order governing which one is going to tap first. Avoidance of simultaneous tapping (operation with the master follower method) SEMOD159053-197 v2 A time delay for the follower in relation to the command given from the master can be set when the setting MFMode is Follow Tap that is, when the follower follows the tap position (with or tAutoMSF then introduces a time delay on...
Page 354 Section 13 1MRK 511 358-UUS A Control TR8ATCC (90) in adapt mode will continue the calculation of V , but instead of adding V to the measured busbar voltage, it will compare it with the deadband DV. The following control rules are used: If V is positive and its modulus is greater than DV, then initiate an VLOWER command.
Page 355 1MRK 511 358-UUS A Section 13 Control I cc..T2 I cc..T2 I cc..T1 cc..T1 Load Load en06000512_ansi.vsd ANSI06000512 V1 EN-US Figure 171: Capacitor bank on the LV-side From figure it is obvious that the two different connections of the capacitor banks are completely the same regarding the currents in the primary network.
Page 356 Section 13 1MRK 511 358-UUS A Control × (Equation 126) EQUATION1982-ANSI V1 EN-US In this way the measured LV currents can be adjusted so that the capacitor bank current will not influence the calculation of the circulating current. Three independent capacitor bank values Q1, Q2 and Q3 can be set for each transformer in order to make possible switching of three steps in a capacitor bank in one bay.
Page 357 1MRK 511 358-UUS A Section 13 Control In a simple case, when only the switchgear in the transformer bays needs to be considered, there is a built-in function in TR8ATCC (90) block that can provide information on whether a transformer is connected to the parallel group or not.
Page 358 Section 13 1MRK 511 358-UUS A Control group, and the other is the data set that is transferred to the TCMYLTC or TCLYLTC (84) function block for the same transformer as TR8ATCC (90) block belongs to. There are 10 binary signals and 6 analog signals in the data set that is transmitted from one TR8ATCC (90) block to the other TR8ATCC (90) blocks in the same parallel group: Table 30: Binary signals Signal...
Page 359 1MRK 511 358-UUS A Section 13 Control TR8ATCC (90), and they are predefined as T1, T2, T3,..., T8 (transformers 1 to 8). In figure there TrfId set to T1, T2 and T3 , respectively. are three transformers with the parameter For parallel control with the circulating current method or the master-follower method alternatively, the same type of data set as described above, must be exchanged between two TR8ATCC (90).
Page 360 Section 13 1MRK 511 358-UUS A Control Table 33: Blocking settings Setting Values (Range) Description OCBk Alarm When any one of the three HV currents exceeds the IBlock , TR1ATCC (90) or TR8ATCC (90) will (automatically Auto Block preset value reset) Auto&Man Block be temporarily totally blocked.
Page 361 1MRK 511 358-UUS A Section 13 Control Setting Values (Range) Description RevActPartBk(aut Alarm The risk of voltage instability increases as omatically reset) Auto Block transmission lines become more heavily loaded in an attempt to maximize the efficient use of existing generation and transmission facilities.
Page 362 Section 13 1MRK 511 358-UUS A Control Setting Values (Range) Description TapChgBk Alarm If the input TCINPROG of TCMYLTC or TCLYLTC (84) (manually reset Auto Block function block is connected to the tap changer Auto&Man Block mechanism, then this blocking condition will be active if the TCINPROG input has not reset when the tTCTimeout timer has timed out.
Page 363 1MRK 511 358-UUS A Section 13 Control Setting Values (Range) Description TapPosBk Alarm This blocking/alarm is activated by either: (automatically Auto Block The tap changer reaching an end position i.e. one reset/manually Auto&Man Block of the extreme positions according to the reset) LowVoltTap and setting parameters...
Page 364 Section 13 1MRK 511 358-UUS A Control Setting Values (Range) Description MFPosDiffBk Alarm In the master-follower mode, if the tap difference (manually reset) Auto Block between a follower and the master is greater than the set value (setting parameter MFPosDiffLim ) then this blocking condition is fulfilled and the outputs OUTOFPOS and AUTOBLK (alternatively an alarm) will be set.
Page 365 1MRK 511 358-UUS A Section 13 Control Table 36: Blockings without setting possibilities Activation Type of blocking Description Disconnected Auto Block Automatic control is blocked for a transformer transformer when parallel control with the circulating current (automatically reset) method is used, and that transformer is disconnected from the LV-busbar.
Page 366 Section 13 1MRK 511 358-UUS A Control • Over-Current • Total block via settings • Total block via configuration • Analog input error • Automatic block via settings • Automatic block via configuration • Under-Voltage • Command error • Position indication error •...
Page 367 1MRK 511 358-UUS A Section 13 Control older transformers the sensors can be worn and the contacts maybe bouncing etc. Before the right timing data is set it may then happen that TR1ATCC (90) or TR8ATCC (90) becomes totally blocked or blocked in auto mode because of incorrect settings. In this situation, it is recommended to temporarily set these types of blockings to alarm instead until the commissioning of all main items are working as expected.
Page 368 Section 13 1MRK 511 358-UUS A Control VRAISE/VLOWER tTCTimeout TCINPROG en06000482_ansi.vsd ANSI06000482 V1 EN-US Figure 174: Timing of pulses for tap changer operation monitoring pos Description Safety margin to avoid that TCINPROG is not set high without the simultaneous presence of an VRAISE or VLOWER command.
Page 369 1MRK 511 358-UUS A Section 13 Control lead to the output signal TCERRAL being set high and TR1ATCC (90) or TR8ATCC (90) function being blocked. Effectively this is then also a supervision of a run-away tap situation. Hunting detection SEMOD159053-361 v4 Hunting detection is provided in order to generate an alarm when the voltage control gives an abnormal number of commands or abnormal sequence of commands within a pre-defined period of time.
Page 370: Setting Guidelines
Section 13 1MRK 511 358-UUS A Control 13.5.3 Setting guidelines SEMOD171503-1 v1 13.5.3.1 TR1ATCC or TR8ATCC general settings SEMOD171501-4 v5 GlobalBaseSel1 : Used to select a GBASVAL function for reference of base values for winding 1 (HV). GlobalBaseSel2 : Used to select a GBASVAL function for reference of base values for winding 2 (LV). TrfId : The transformer identity is used to identify transformer individuals in a parallel group.
Page 371: Tr1Atcc (90) Or Tr8Atcc (90) Setting Group
1MRK 511 358-UUS A Section 13 Control 13.5.3.2 TR1ATCC (90) or TR8ATCC (90) Setting group SEMOD171501-22 v9 General Operation : Switching automatic voltage control for tap changer, TR1ATCC (90) for single control Enabled / Disabled . and TR8ATCC (90) for parallel control function (IB1) : Base current in primary Ampere for the HV-side of the transformer.
Page 372 Section 13 1MRK 511 358-UUS A Control Vmax : This setting gives the upper limit of permitted busbar voltage (see section "Automatic VBase . If OVPartBk is voltage control for a single transformer", figure 164). It is set in percent of Auto&ManBlock , then busbar voltages above Vmax will result in a partial blocking such that set to only lower commands are permitted.
Page 373 1MRK 511 358-UUS A Section 13 Control Rline Xline Zline *Rline *Xline en06000626_ansi.vsd ANSI06000626 V1 EN-US Figure 175: Transformer with reverse reactance regulation and no circulating current Rline +j I Xline has the argument j2 and it is realised that if j2 is slightly The voltage DV=V less than -90°, then V will have approximately the same length as V...
Page 374 Section 13 1MRK 511 358-UUS A Control Rline and Xline for j = 11° from Figure shows an example of this where the settings of figure has been applied with a different value of j (j = 30°). =-79 Rline Xline Zline *Rline...
Page 375 1MRK 511 358-UUS A Section 13 Control Load voltage adjustment (LVA) LVAConst1 : Setting of the first load voltage adjustment value. This adjustment of the target value VSet is given in percent of VBase . LVAConst2 : Setting of the second load voltage adjustment value. This adjustment of the target value VSet is given in percent of VBase .
Page 376 Section 13 1MRK 511 358-UUS A Control P> en06000634_2_en.vsd IEC06000634 V2 EN-US Figure 177: Setting of a negative value for P> P< : When the active power falls below the value given by this setting, the output PLTREV will be tPower .
Page 377 1MRK 511 358-UUS A Section 13 Control Comp can be If the transformers are connected to the same bus on the HV- as well as the LV-side, calculated with the following formula which is valid for any number of two-winding transformers in parallel, irrespective if the transformers are of different size and short circuit impedance.
Page 378: Tcmyltc And Tclyltc (84) General Settings
Section 13 1MRK 511 358-UUS A Control the Automatic voltage control for tap changer, parallel control TR8ATCC (90) function block of the tMFPosDiff . follower will be activated after the time delay tMFPosDiff : Time delay for activation of the output OUTOFPOS. 13.5.3.3 TCMYLTC and TCLYLTC (84) general settings SEMOD171501-150 v7...
Page 379: Logic Rotating Switch For Function Selection And Lhmi Presentation Slgapc
1MRK 511 358-UUS A Section 13 Control 13.6 Logic rotating switch for function selection and LHMI presentation SLGAPC SEMOD114936-1 v4 13.6.1 Identification SEMOD167845-2 v3 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Logic rotating switch for function SLGAPC selection and LHMI presentation 13.6.2...
Page 380 Section 13 1MRK 511 358-UUS A Control StopAtExtremes : Sets the behavior of the switch at the end positions – if set to Disabled , when pressing UP while on first position, the switch will jump to the last position; when pressing DOWN Enabled , no jump will be at the last position, the switch will jump to the first position;...
Page 381 1MRK 511 358-UUS A Section 13 Control 13.7.3 Setting guidelines SEMOD158807-4 v4 Selector mini switch (VSGAPC) function can generate pulsed or steady commands (by setting the Mode parameter). When pulsed commands are generated, the length of the pulse can be set using tPulse parameter.
Page 382 Section 13 1MRK 511 358-UUS A Control Table 37: Description of the input-output relationship POSITION VALID OPEN CLOSE Value Description Intermediate Intermediate Open Closed Bad State 13.8.3 Setting guidelines SEMOD55398-5 v4 The function does not have any parameters available in the local HMI or PCM600. 13.9 Single point generic control 8 signals SPC8GAPC SEMOD176448-1 v3...
Page 383 1MRK 511 358-UUS A Section 13 Control Latchedx : decides if the command signal for output x is Latched (steady) or Pulsed . tPulsex : if Latchedx is set to Pulsed , then tPulsex will set the length of the pulse (in seconds). 13.10 AutomationBits, command function for DNP3.0 AUTOBITS...
Page 384 Section 13 1MRK 511 358-UUS A Control 13.11.2 Application M12445-3 v3 Single command, 16 signals (SINGLECMD) is a common function and always included in the IED. The IEDs may be provided with a function to receive commands either from a substation automation system or from the local HMI.
Page 385 1MRK 511 358-UUS A Section 13 Control Single command function Function n SINGLECMD Function n CMDOUTy OUTy en04000207.vsd IEC04000207 V2 EN-US Figure 181: Application example showing a logic diagram for control of built-in functions Single command function Configuration logic circuits SINGLESMD Device 1 CMDOUTy...
Page 386 Section 13 1MRK 511 358-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 387 1MRK 511 358-UUS A Section 14 Scheme communication Section 14 Scheme communication 14.1 Scheme communication logic for distance or overcurrent protection ZCPSCH(85) IP15749-1 v3 14.1.1 Identification M14854-1 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Scheme communication logic for ZCPSCH distance or overcurrent protection...
Page 388 Section 14 1MRK 511 358-UUS A Scheme communication 14.1.2.1 Blocking schemes M16866-24 v4 In blocking scheme a reverse looking zone is used to send a block signal to remote end to block an overreaching zone. Since the scheme is sending the blocking signal during conditions where the protected line is healthy, it is common to use the line itself as communication media (PLC).
Page 389 1MRK 511 358-UUS A Section 14 Scheme communication is inhibited by a forward directed distance (or directional current or directional ground fault) element. Since the scheme is sending the blocking signal during conditions where the protected line is healthy, it is common to use the line itself as communication media (PLC). The scheme can be used on all line lengths.
Page 390 Section 14 1MRK 511 358-UUS A Scheme communication Depending on if the sending signal(s) is issued by underreaching or overreaching zone, it is divided into Permissive underreach or Permissive overreach scheme. Permissive underreaching scheme M16866-53 v3 Permissive underreaching scheme is not suitable to use on short line length due to difficulties for distance protection measurement in general to distinguish between internal and external faults in those applications.
Page 391 1MRK 511 358-UUS A Section 14 Scheme communication scheme must be activated at the same time as the received signal is present. The scheme can be used for all line lengths. In permissive overreaching schemes, the communication channel plays an essential roll to obtain fast tripping at both ends.
Page 392 Section 14 1MRK 511 358-UUS A Scheme communication To overcome the lower dependability in permissive schemes, an unblocking function can be used. Use this function at older, less reliable, power-line carrier (PLC) communication, where the signal has to be sent through the primary fault. The unblocking function uses a guard signal CR_GUARD, which must always be present, even when no CR signal is received.
Page 393 1MRK 511 358-UUS A Section 14 Scheme communication 14.1.3.2 Delta blocking scheme GUID-F4359690-F433-46CB-A173-8C14559E3FCF v1 Operation Enabled SchemeType DeltaBlocking tCoord = 0 s tSendMin = 0 s Unblock Disabled NoRestart if Unblocking scheme with no alarm for loss of guard is (Set to to be used.
Page 394 Section 14 1MRK 511 358-UUS A Scheme communication 14.1.3.6 Intertrip scheme M13869-62 v4 Operation Enabled SchemeType Intertrip tCoord 50 ms (10 ms + maximal transmission time) tSendMin = 0.1 s (0 s in parallel line applications) Unblock Disabled tSecurity = 0.015 s 14.2 Current reversal and Weak-end infeed logic for distance protection 3-phase ZCRWPSCH (85)
Page 395 1MRK 511 358-UUS A Section 14 Scheme communication CLOSED CLOSED FAULT LINE 1 Weak Strong source source CLOSED CLOSED LINE 2 en99000043_ansi.vsd ANSI99000043 V1 EN-US Figure 187: Current distribution for a fault close to B side when all breakers are closed When the breaker B1 opens for clearing the fault, the fault current through B2 bay will invert.
Page 396 Section 14 1MRK 511 358-UUS A Scheme communication In case of single-pole tripping, the phase voltages are used as phase selectors together with the received signal CRLn. Together with the blocking teleprotection scheme some limitations apply: • Only the trip part of the function can be used together with the blocking scheme. It is not possible to use the echo function to send the echo signal to the remote line IED.
Page 397 1MRK 511 358-UUS A Section 14 Scheme communication When single pole tripping is required a detailed study of the voltages at phase-to- phase respectively phase-to-ground faults, at different fault locations, is normally required. 14.3 Local acceleration logic ZCLCPSCH SEMOD52894-1 v4 14.3.1 Identification M14860-1 v4...
Page 398 Section 14 1MRK 511 358-UUS A Scheme communication tLoadOn is used to increase the security of the loss-of-load function for example to The timer avoid unwanted release due to transient inrush current when energizing the line power tLoadOn has elapsed at the transformer.
Page 399 1MRK 511 358-UUS A Section 14 Scheme communication The communication logic module enables blocking as well as permissive under/overreaching schemes. The logic can also be supported by additional logic for weak-end infeed and current reversal, included in the Current reversal and weak-end infeed logic for residual overcurrent protection (ECRWPSCH, 85) function.
Page 400 Section 14 1MRK 511 358-UUS A Scheme communication 14.5.2 Application IP15041-1 v1 14.5.2.1 Fault current reversal logic M15285-3 v6 Figure and Figure show a typical system condition, which can result in a fault current reversal. Assume that fault is near the B1 breaker. B1 Relay sees the fault in Zone1 and A1 relay identifies the fault in Zone2.
Page 401 1MRK 511 358-UUS A Section 14 Scheme communication breaker in B. To cope with this situation, a selectable weak-end infeed logic is provided for the permissive overreaching scheme. Strong Weak CLOSED CLOSED source source FAULT LINE 1 en99000054_ansi.vsd ANSI99000054 V1 EN-US Figure 191: Initial condition for weak-end infeed 14.5.3 Setting guidelines...
Page 402 Section 14 1MRK 511 358-UUS A Scheme communication Tele- Tele- Tele- Protection Protection Protection communication Protection Function Function Equipment System Equipment CS initiation to CS from the CR to the CR selection and protection CS propagation, protection communication decision, operate function, operate propagation function, operate...
Page 403 1MRK 511 358-UUS A Section 15 Logic Section 15 Logic 15.1 Tripping logic SMPPTRC (94) IP14576-1 v4 15.1.1 Identification SEMOD56226-2 v6 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Tripping logic SMPPTRC I->O SYMBOL-K V1 EN-US 15.1.2 Application M12252-3 v8...
Page 404 Section 15 1MRK 511 358-UUS A Logic The same philosophy can be used for two-pole tripping and autoreclosing. To prevent closing of a circuit breaker after a trip the function can block the closing. The two instances of the SMPPTRC (94) function are identical except, for the name of the function block (SMPPTRC1 and SMPPTRC2).
Page 405 1MRK 511 358-UUS A Section 15 Logic The single-pole tripping can include different options and the use of the different inputs in the function block. The inputs 1PTRZ and 1PTREF are used for single-pole tripping for distance protection and directional ground fault protection as required. The inputs are combined with the phase selection logic and the pickup signals from the phase selector must be connected to the inputs PS_A, PS_B and PS_C to achieve the tripping on the respective single-pole trip outputs TR_A, TR_B and TR_C.
Page 406 Section 15 1MRK 511 358-UUS A Logic Distance protection zone 2 TRIP Distance protection zone 3 TRIP SMPPTRC (94) Overcurrent protection TRIP BLOCK TRIP BLKLKOUT TR_A TRIN_3P TR_B Distance protection zone 1 TRIP TRINP_A TR_C TRIN_B TR1P Phase Selection TRINL3 TR2P TR3P PS_A...
Page 407 1MRK 511 358-UUS A Section 15 Logic 15.1.2.5 Blocking of the function block M14828-21 v3 The function block can be blocked in two different ways. Its use is dependent on the application. Blocking can be initiated internally by logic, or by the operator using a communication channel. Total blockage of the trip function is done by activating the input BLOCK and can be used to block the output of the trip logic in the event of internal failures.
Page 408 Section 15 1MRK 511 358-UUS A Logic 15.2.3 Setting guidelines M15291-3 v5 Operation : Operation of function Enabled / Disabled . PulseTime : Defines the pulse time when in Pulsed mode. When used for direct tripping of circuit breaker(s) the pulse time delay shall be set to approximately 0.150 seconds in order to obtain satisfactory minimum duration of the trip pulse to the circuit breaker trip coils.
Page 409 1MRK 511 358-UUS A Section 15 Logic 15.4.1.2 Application GUID-FC0DBB7B-FF86-44BF-83D6-DDF120A176DE v1 Group warning logic function WRNCALH is used to route warning signals to LEDs and/or output contacts on the IED. WRNCALH output signal WARNING and the physical outputs allows the user to adapt the warning signal to physical tripping outputs according to the specific application needs.
Page 410 Section 15 1MRK 511 358-UUS A Logic 15.6.1 Application GUID-F5D6F065-441B-4296-AC56-F4DC1F5487E3 v3 A set of standard logic blocks, like AND, OR etc, and timers are available for adapting the IED configuration to the specific application needs. Additional logic blocks that, beside the normal logical function, have the capability to propagate timestamp and quality are also available.
Page 411 1MRK 511 358-UUS A Section 15 Logic IEC09000310-1-en.vsd IEC09000310 V1 EN-US Figure 196: Example designation, serial execution number and cycle time for logic function that also propagates timestamp and quality of input signals The execution of different function blocks within the same cycle is determined by the order of their serial execution numbers.
Page 412 Section 15 1MRK 511 358-UUS A Logic Example for use of GRP_OFF signal in FXDSIGN The Restricted earth fault function REFPDIF (87N) can be used both for auto-transformers and normal transformers. When used for auto-transformers, information from both windings parts, together with the neutral point current, needs to be available to the function.
Page 413 1MRK 511 358-UUS A Section 15 Logic 15.8 Boolean 16 to Integer conversion B16I SEMOD175715-1 v1 15.8.1 Identification SEMOD175721-2 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Boolean 16 to integer conversion B16I 15.8.2 Application SEMOD175832-4 v4 Boolean 16 to integer conversion function B16I is used to transform a set of 16 binary (logical) signals into an integer.
Page 414 Section 15 1MRK 511 358-UUS A Logic Name of input Type Default Description Value when Value when activated deactivated IN14 BOOLEAN Input 14 8192 IN15 BOOLEAN Input 15 16384 IN16 BOOLEAN Input 16 32768 The sum of the numbers in column “Value when activated” when all INx (where 1≤x≤16) are active that is=1;...
Page 415 1MRK 511 358-UUS A Section 15 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 416 Section 15 1MRK 511 358-UUS A Logic on the activated INx will be available on the output OUT as a sum of the values of all the inputs INx that are activated. OUT is an integer. When all INx where 1≤x≤16 are activated that is = Boolean 1 it corresponds to that integer 65535 is available on the output OUT.
Page 417 1MRK 511 358-UUS A Section 15 Logic 15.11.2 Application SEMOD158512-5 v6 Integer to boolean 16 conversion with logic node representation function (ITBGAPC) is used to transform an integer into a set of 16 boolean signals. ITBGAPC function can receive an integer from a station computer –...
Page 418 Section 15 1MRK 511 358-UUS A Logic 15.12 Elapsed time integrator with limit transgression and overflow supervision TEIGAPC 15.12.1 Identification GUID-1913E066-37D1-4689-9178-5B3C8B029815 v2 Function Description IEC 61850 IEC 60617 ANSI/IEEE C37.2 device identification identification number Elapsed time integrator TEIGAPC 15.12.2 Application GUID-B4B47167-C8DE-4496-AEF1-5F0FD1768A87 v2 The function TEIGAPC is used for user-defined logics and it can also be used for different purposes internally in the IED.
Page 419 1MRK 511 358-UUS A Section 15 Logic 15.13.2 Application GUID-4C6D730D-BB1C-45F1-A719-1267234BF1B9 v1 The function gives the possibility to monitor the level of integer values in the system relative to each other or to a fixed value. It is a basic arithmetic function that can be used for monitoring, supervision, interlocking and other logics.
Page 420 Section 15 1MRK 511 358-UUS A Logic RefSource = 0 Set the SetValue shall be set between -2000000000 to 2000000000. 15.14 Comparator for real inputs - REALCOMP 15.14.1 Identification GUID-0D68E846-5A15-4C2C-91A2-F81A74034E81 v1 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Comparator for real inputs...
Page 421 1MRK 511 358-UUS A Section 15 Logic 15.14.4 Setting example GUID-E7070CF6-B44B-4799-BE18-5C75B9FE2A87 v1 Let us consider a comparison is to be done between current magnitudes in the range of 90 to 110 with nominal rating is 100 and the order is kA. For the above condition the comparator can be designed with settings as follows, EnaAbs = Absolute RefSource = SetValue...
Page 423 1MRK 511 358-UUS A Section 16 Monitoring Section 16 Monitoring 16.1 Measurement GUID-9D2D47A0-FE62-4FE3-82EE-034BED82682A v1 16.1.1 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 424 Section 16 1MRK 511 358-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 425 1MRK 511 358-UUS A Section 16 Monitoring 16.1.3 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 426 Section 16 1MRK 511 358-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 427 1MRK 511 358-UUS A Section 16 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 428 Section 16 1MRK 511 358-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 199: Calibration curves 16.1.4.1 Setting examples...
Page 429 1MRK 511 358-UUS A Section 16 Monitoring 380kV Busbar 800/5 A 380kV 120V 380kV OHL ANSI09000039-1-en.vsd ANSI09000039 V1 EN-US Figure 200: 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 (see section Set correctly CT and VT data and phase angle reference channel...
Page 430 Section 16 1MRK 511 358-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 431 1MRK 511 358-UUS A Section 16 Monitoring Measurement function application for a power transformer SEMOD54481-61 v7 Single line diagram for this application is given in figure 201. 132kV Busbar 200/5 31.5 MVA 500/5 33kV 120V 33kV Busbar ANSI09000040-1-en.vsd ANSI09000040 V1 EN-US Figure 201: Single line diagram for transformer application In order to measure the active and reactive power as indicated in figure 201, it is necessary to do the following:...
Page 432 Section 16 1MRK 511 358-UUS A Monitoring Table 42: 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 433 1MRK 511 358-UUS A Section 16 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 202: Single line diagram for generator application In order to measure the active and reactive power as indicated in figure 202, it is necessary to do the following: Set correctly all CT and VT data and phase angle reference channel PhaseAngleRef (see section...
Page 434 Section 16 1MRK 511 358-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 435 1MRK 511 358-UUS A Section 16 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 436 Section 16 1MRK 511 358-UUS A Monitoring 100000 50000 20000 10000 5000 2000 1000 Interrupted current (kA) IEC12000623_1_en.vsd IEC12000623 V1 EN-US Figure 203: 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 437 1MRK 511 358-UUS A Section 16 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 438 Section 16 1MRK 511 358-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 439 1MRK 511 358-UUS A Section 16 Monitoring 16.5.1 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 16.5.2 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 440 Section 16 1MRK 511 358-UUS A Monitoring 16.6 Disturbance report DRPRDRE IP14584-1 v2 16.6.1 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 16.6.2 Application M12152-3 v7...
Page 441 1MRK 511 358-UUS A Section 16 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 442 Section 16 1MRK 511 358-UUS A Monitoring For Disturbance report function there are a number of settings which also influences the sub- functions. Three LED indications placed above the LCD screen makes it possible to get quick status information about the IED. Green LED: Steady light In Service...
Page 443 1MRK 511 358-UUS A Section 16 Monitoring The maximum number of recordings depend on each recordings total recording time. Long recording time will reduce the number of recordings to less than 100. The IED flash disk should NOT be used to store any user files. This might cause disturbance recordings to be deleted due to lack of disk space.
Page 444 Section 16 1MRK 511 358-UUS A Monitoring TrigDRN : Disturbance report may trig for binary input N ( Enabled ) or not ( Disabled ). TrigLevelN : Trig on positive ( Trig on 1 ) or negative ( Trig on 0 ) slope for binary input N. Func103N : Function type number (0-255) for binary input N according to IEC-60870-5-103, that is, 128: Distance protection, 160: overcurrent protection, 176: transformer differential protection and 192: line differential protection.
Page 445 1MRK 511 358-UUS A Section 16 Monitoring OperationM = Disabled , no waveform (samples) will be recorded and reported in graph. However, Trip value, pre-fault and fault value will be recorded and reported. The input channel can still be used to trig the disturbance recorder. OperationM = Enabled , waveform (samples) will also be recorded and reported in graph.
Page 446 Section 16 1MRK 511 358-UUS A Monitoring 16.7.1 Identification GUID-E0247779-27A2-4E6C-A6DD-D4C31516CA5C v3 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Logical signal status report BINSTATREP 16.7.2 Application GUID-F9D225B1-68F7-4D15-AA89-C9211B450D19 v2 The Logical signal status report (BINSTATREP) function makes it possible for a SPA master to poll signals from various other function blocks.
Page 447 1MRK 511 358-UUS A Section 16 Monitoring important for those involved in operation and maintenance. Reliable information on the fault location greatly decreases the downtime of the protected lines and increases the total availability of a power system. The fault locator is started with the input CALCDIST to which trip signals indicating in-line faults are connected, typically distance protection zone 1 and accelerating zone or the line differential protection.
Page 448 Section 16 1MRK 511 358-UUS A Monitoring DRPRDRE LMBRFLO ANSI05000045_2_en.vsd ANSI05000045 V2 EN-US Figure 206: Simplified network configuration with network data, required for settings of the fault location-measuring function For a single-circuit line (no parallel line), the figures for mutual zero-sequence impedance (X ) and analog input are set at zero.
Page 449 1MRK 511 358-UUS A Section 16 Monitoring en07000113_1_ansi.v ANSI07000113 V2 EN-US Figure 207: Example of connection of parallel line IN for Fault locator LMBRFLO 16.9 Limit counter L4UFCNT GUID-22E141DB-38B3-462C-B031-73F7466DD135 v1 16.9.1 Identification GUID-F3FB7B33-B189-4819-A1F0-8AC7762E9B7E v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification...
Page 450 Section 16 1MRK 511 358-UUS A Monitoring It is also possible to initiate the counter from a non-zero value by resetting the function to the wanted initial value provided as a setting. If applicable, the counter can be set to stop or rollover to zero and continue counting after reaching the maximum count value.
Page 451 1MRK 511 358-UUS A Section 17 Metering Section 17 Metering 17.1 Pulse-counter logic PCFCNT IP14600-1 v3 17.1.1 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 17.1.2 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 452 Section 17 1MRK 511 358-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 453 1MRK 511 358-UUS A Section 17 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 455 1MRK 511 358-UUS A Section 18 Station communication Section 18 Station communication 18.1 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 456 Section 18 1MRK 511 358-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 209: SA system with IEC 61850–8–1 M16925-3 v3 Figure 210 shows the GOOSE peer-to-peer communication. Station HSI MicroSCADA Gateway...
Page 457 1MRK 511 358-UUS A Section 18 Station communication 18.2.2 Horizontal communication via GOOSE for interlocking GOOSEINTLKRCV SEMOD173197-1 v2 PID-415-SETTINGS v5 Table 44: GOOSEINTLKRCV Non group settings (basic) Name Values (Range) Unit Step Default Description Operation Disabled Disabled Operation Disabled/Enabled Enabled 18.2.3 Setting guidelines SEMOD55317-5 v6...
Page 458 Section 18 1MRK 511 358-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 459 1MRK 511 358-UUS A Section 18 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 211: Redundant station bus 18.2.6.3 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 460 Section 18 1MRK 511 358-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 212: 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 461 1MRK 511 358-UUS A Section 18 Station communication 18.3 IEC 61850-9-2LE communication protocol SEMOD172279 v2 18.3.1 Introduction SEMOD166571-1 v2 SEMOD166590-5 v7 Every IED can be provided with communication interfaces enabling it to connect to the process buses in order to get data from analog data acquisition units close to the process (primary apparatus), commonly known as Merging Units (MU).
Page 462 Section 18 1MRK 511 358-UUS A Station communication The merging units (MU) are called so because they can gather analog values from one or more measuring transformers, sample the data and send the data over process bus to other clients (or subscribers) in the system.
Page 463 1MRK 511 358-UUS A Section 18 Station communication 18.3.2 Setting guidelines GUID-29B296B3-6185-459F-B06F-8E7F0C6C9460 v4 Merging Units (MUs) have several settings on local HMI under: • Main menu/Configuration/Analog modules/MUx:92xx. The corresponding settings are also available in PST (PCM600). • Main menu/Configuration/Communication/Merging units configuration/MUx:92xx. The corresponding settings are also available in ECT (PCM600).
Page 464 Section 18 1MRK 511 358-UUS A Station communication ANSI13000298-1-en.vsd ANSI13000298 V1 EN-US Figure 215: Normal operation Case 2: Failure of the MU (sample lost) blocks the sending of binary signals through LDCM. The received binary signals are not blocked and processd normally. →DTT from the remote end is still processed.
Page 465 1MRK 511 358-UUS A Section 18 Station communication ANSI13000300-1-en.vsd ANSI13000300 V1 EN-US Figure 217: MU failed, 9-2 system Table 45: Blocked protection functions if IEC 61850-9-2LE communication is interrupted. Function description IEC 61850 identification Function description IEC 61850 identification Accidental energizing AEGPVOC Two step overvoltage OV2PTOV...
Page 466 Section 18 1MRK 511 358-UUS A Station communication Function description IEC 61850 identification Function description IEC 61850 identification Faulty phase FMPSPDIS Circuit breaker condition SSCBR identification with load monitoring enchroachment Phase selection, FRPSPDIS Insulation gas monitoring SSIMG quadrilateral characteristic with settable angle Frequency time FTAQFVR...
Page 467 1MRK 511 358-UUS A Section 18 Station communication Function description IEC 61850 identification Function description IEC 61850 identification Line differential LDLPSCH Distance measuring zone, ZMCAPDIS coordination quadrilateral characteristic for series compensated lines Additional security logic LDRGFC Distance measuring zone, ZMCPDIS for differential protection quadrilateral characteristic for series...
Page 468 Figure 218: Setting example when MU is the synchronizing source Settings in local HMI under Settings/Time/Synchronization/TIMESYNCHGEN/IEC 61850-9-2: HwSyncSrc : set to PPS since this is what is generated by the MU (ABB MU) • AppSynch : set to Synch , since protection functions should be blocked in case of loss of •...
Page 469 1MRK 511 358-UUS A Section 18 Station communication protection functions.. This will happen max 4 seconds after an interruption of the PPS fiber fineSyncSource is lost). from the MU (or if the • SYNCH signal on the MU1_4I_4U function block indicates when protection functions are blocked due to loss of internal time synchronization to the IED (that is loss of the hardware synchSrc ) •...
Page 470 Section 18 1MRK 511 358-UUS A Station communication timeQuality • TSYNCERR signal on the TIMEERR function block will go high whenever internal SyncAccLevel ( 4us in this case). This will block the protection functions goes above the setting after maximum 4 seconds after an interruption in the PPS fiber communication from the MU. •...
Page 471 1MRK 511 358-UUS A Section 18 Station communication To get higher availability in the protection functions, it is possible to avoid blocking if time synchronization is lost when there is a single source of analog data. This means that if there is only AppSynch can be set to NoSynch but parameter one physical MU and no TRM, parameter HwSyncSrc can still be set to PPS .
Page 472 Section 18 1MRK 511 358-UUS A Station communication The LON Protocol M14804-32 v2 The LON protocol is specified in the LonTalkProtocol Specification Version 3 from Echelon Corporation. This protocol is designed for communication in control networks and is a peer-to- peer protocol where all the devices connected to the network can communicate with each other directly.
Page 473 1MRK 511 358-UUS A Section 18 Station communication 18.4.2.2 Application M14790-3 v5 The IED provides two function blocks enabling several IEDs to send and receive signals via the interbay bus. The sending function block, MULTICMDSND, takes 16 binary inputs. LON enables these to be transmitted to the equivalent receiving function block, MULTICMDRCV, which has 16 binary outputs.
Page 474 Section 18 1MRK 511 358-UUS A Station communication glass <1000 m according to optical budget plastic <20 m (inside cubicle) according to optical budget Functionality SEMOD115767-25 v2 The SPA protocol V2.5 is an ASCII-based protocol for serial communication. The communication is based on a master-slave principle, where the IED is a slave and the PC is the master.
Page 475 1MRK 511 358-UUS A Section 18 Station communication 18.6 IEC 60870-5-103 communication protocol IP14615-1 v2 18.6.1 Application IP14864-1 v1 M17109-3 v6 TCP/IP Control Station Center Gateway Star coupler ANSI05000660-4-en.vsd ANSI05000660 V4 EN-US Figure 223: 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 476 Section 18 1MRK 511 358-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 477 1MRK 511 358-UUS A Section 18 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 478 Section 18 1MRK 511 358-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 479 1MRK 511 358-UUS A Section 18 Station communication GUID-CD4EB23C-65E7-4ED5-AFB1-A9D5E9EE7CA8 V3 EN GUID-CD4EB23C-65E7-4ED5-AFB1-A9D5E9EE7CA8 V3 EN-US Figure 224: 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 480 Section 18 1MRK 511 358-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 481 1MRK 511 358-UUS A Section 18 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 483 1MRK 511 358-UUS A Section 19 Remote communication Section 19 Remote communication 19.1 Binary signal transfer IP12423-1 v2 19.1.1 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 19.1.2 Application...
Page 484 Section 19 1MRK 511 358-UUS A Remote communication en06000519-2.vsd IEC06000519 V2 EN-US Figure 225: 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 226.
Page 485 1MRK 511 358-UUS A Section 19 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 486 Section 19 1MRK 511 358-UUS A 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 487 1MRK 511 358-UUS A Section 19 Remote communication Table 49: 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 488 Section 19 1MRK 511 358-UUS A 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 489 1MRK 511 358-UUS A Section 20 Security Section 20 Security 20.1 Authority status ATHSTAT SEMOD158575-1 v2 20.1.1 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 490 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 491 1MRK 511 358-UUS A Section 20 Security 20.4 Denial of service DOS 20.4.1 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 493 • 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). 21.2.2 Factory defined settings...
Page 494 Section 21 1MRK 511 358-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 495 1MRK 511 358-UUS A Section 21 Basic IED functions 21.3.3 Setting guidelines SEMOD113223-4 v1 There are no settable parameters for the measured value expander block function. 21.4 Parameter setting groups IP1745-1 v1 21.4.1 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 496 Section 21 1MRK 511 358-UUS A Basic IED functions 21.5.2 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. 21.5.3 Setting guidelines M15292-3 v2...
Page 497 1MRK 511 358-UUS A Section 21 Basic IED functions 21.7.1 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 21.7.2 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 498 Section 21 1MRK 511 358-UUS A Basic IED functions 21.9 Signal matrix for binary outputs SMBO SEMOD55215-1 v2 21.9.1 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 499 1MRK 511 358-UUS A Section 21 Basic IED functions 21.11.2 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 500 Section 21 1MRK 511 358-UUS A Basic IED functions 21.11.3 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 501 1MRK 511 358-UUS A Section 21 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 502 Section 21 1MRK 511 358-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 503 1MRK 511 358-UUS A Section 21 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 229: 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 504 Section 21 1MRK 511 358-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 230: Configuration for using an instance in task time group 2 as DFT reference.
Page 505 1MRK 511 358-UUS A Section 21 Basic IED functions 21.12.1.1 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 506 Section 21 1MRK 511 358-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 507 1MRK 511 358-UUS A Section 21 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 508 Section 21 1MRK 511 358-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 509 1MRK 511 358-UUS A Section 22 Requirements Section 22 Requirements 22.1 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 510 Section 22 1MRK 511 358-UUS A Requirements 22.1.2 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 511 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 512 Section 22 1MRK 511 358-UUS A Requirements æ ö × ³ = × × ç ÷ a lre q è ø (Equation 132) 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 513 1MRK 511 358-UUS A Section 22 Requirements 22.1.6.3 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 514 Section 22 1MRK 511 358-UUS A Requirements æ ö × ³ × ç ÷ k ma x a lre q è ø (Equation 136) EQUATION1681 V1 EN-US where: Maximum primary fundamental frequency current for close-in forward and reverse faults (A) kmax The rated primary CT current (A) The rated secondary CT current (A)
Page 515 1MRK 511 358-UUS A Section 22 Requirements possible to give a general relation between the E and the E but normally the E knee knee approximately 80 % of the E . Therefore, the CTs according to class PX, PXR, X and TPS must have a rated knee point e.m.f.
Page 516 Section 22 1MRK 511 358-UUS A Requirements 22.2 Voltage transformer requirements M11608-3 v5 The performance of a protection function will depend on the quality of the measured input signal. Transients caused by capacitive Coupled voltage transformers (CCVTs) can affect some protection functions.
Page 517 1MRK 511 358-UUS A Section 22 Requirements The G.703 E1, 2 Mbit shall be set according to ITU-T G.803, G.810-13 • One master clock for the actual network • The actual port Synchronized to the SDH system clock at 2048 kbit •...
Page 518 Section 22 1MRK 511 358-UUS A Requirements There are two sample rates defined: 80 samples/cycle (4000 samples/sec. at 50Hz or 4800 samples/sec. at 60 Hz) for a merging unit “type1” and 256 samples/cycle for a merging unit “type2”. The IED can receive data rates of 80 samples/cycle. Note that the IEC 61850-9-2 LE standard does not specify the quality of the sampled values, only the transportation.
Page 519 1MRK 511 358-UUS A Section 23 Glossary Section 23 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 520 Section 23 1MRK 511 358-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 521 1MRK 511 358-UUS A Section 23 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 522 Section 23 1MRK 511 358-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 523 1MRK 511 358-UUS A Section 23 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 524 Section 23 1MRK 511 358-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 525 1MRK 511 358-UUS A Section 23 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 526 Section 23 1MRK 511 358-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 528 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.

This manual is also suitable for:

Relion rec670

ABB Relion 670 Series Applications Manual

Introduction

Application

Configuration

Analog Inputs

Local HMI

Differential Protection

Current Protection

Voltage Protection

Frequency Protection

Section 10 Multipurpose Protection

Section 11 System Protection and Control

Section 12 Secondary System Supervision

Section 13 Control

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Summary of Contents for ABB Relion 670 Series