Page 1 — R E L I O N ® 670 SERIES Transformer protection RET670 Version 2.1 IEC Application manual...
Page 4 Copyright This document and parts thereof must not be reproduced or copied without written permission from ABB, and the contents thereof must not be imparted to a third party, nor used for any unauthorized purpose. The software and hardware described in this document is furnished under a license and may be used or disclosed only in accordance with the terms of such license.
Page 5 This document has been carefully checked by ABB but deviations cannot be completely ruled out. In case any errors are detected, the reader is kindly requested to notify the manufacturer.
Page 6 (Low-voltage directive 2006/95/EC). This conformity is the result of tests conducted by ABB in accordance with the product standard EN 60255-26 for the EMC directive, and with the product standards EN 60255-1 and EN 60255-27 for the low voltage directive. The...
Page 7: Table Of Contents
Table of contents Table of contents Section 1 Introduction.......................21 This manual............................21 Intended audience..........................21 Product documentation........................22 1.3.1 Product documentation set...................... 22 1.3.2 Document revision history......................23 1.3.3 Related documents........................23 Document symbols and conventions...................24 1.4.1 Symbols............................24 1.4.2 Document conventions......................25 IEC61850 edition 1 / edition 2 mapping..................25 Section 2 Application......................33 General IED application........................33...
Page 8 Table of contents 4.2.2.5 Example on how to connect a star connected three-phase CT set to the IED.....73 4.2.2.6 Example how to connect delta connected three-phase CT set to the IED....76 4.2.2.7 Example how to connect single-phase CT to the IED............78 4.2.3 Relationships between setting parameter Base Current, CT rated primary current and minimum pickup of a protection IED..............
Page 9 Table of contents 6.2.1 Identification..........................116 6.2.2 Application..........................116 6.2.2.1 The basics of the high impedance principle..............117 6.2.3 Connection examples for high impedance differential protection......... 122 6.2.3.1 Connections for three-phase high impedance differential protection....... 122 6.2.3.2 Connections for 1Ph High impedance differential protection HZPDIF....... 123 6.2.4 Setting guidelines........................124 6.2.4.1...
Page 10 Table of contents 7.1.3 Setting guidelines........................180 7.1.3.1 General............................. 180 7.1.3.2 Setting of zone1........................180 7.1.3.3 Setting of overreaching zone....................180 7.1.3.4 Setting of reverse zone......................181 7.1.3.5 Series compensated and adjacent lines................181 7.1.3.6 Setting of zones for parallel line application..............185 7.1.3.7 Setting of reach in resistive direction................
Page 11 Table of contents 7.4.2 Application..........................219 7.4.2.1 Generator underimpedance protection application............219 7.4.3 Setting guidelines........................219 7.4.3.1 Configuration.......................... 219 7.4.3.2 Settings............................220 Full-scheme distance protection, quadrilateral for earth faults ZMMPDIS, ZMMAPDIS. 223 7.5.1 Identification..........................223 7.5.2 Application..........................223 7.5.2.1 Introduction..........................223 7.5.2.2 System earthing........................223 7.5.2.3 Fault infeed from remote end.....................
Page 12 Table of contents 7.9.2.3 Load encroachment....................... 251 7.9.2.4 Short line application......................252 7.9.2.5 Long transmission line application..................253 7.9.2.6 Parallel line application with mutual coupling..............253 7.9.2.7 Tapped line application......................258 7.9.3 Setting guidelines........................260 7.9.3.1 General............................. 260 7.9.3.2 Setting of zone 1........................260 7.9.3.3 Setting of overreaching zone....................
Page 13 Table of contents 7.12.3.1 General............................. 296 7.12.3.2 Setting of zone 1........................296 7.12.3.3 Setting of overreaching zone....................296 7.12.3.4 Setting of reverse zone......................297 7.12.3.5 Setting of zones for parallel line application..............298 7.12.3.6 Setting the reach with respect to load................299 7.12.3.7 Zone reach setting lower than minimum load impedance...........
Page 14 Table of contents 7.15.3 Setting guidelines........................354 7.15.3.1 Scheme communication and tripping for faults occurring during power swinging over the protected line..................354 7.15.3.2 Blocking and tripping logic for evolving power swings..........357 7.16 Pole slip protection PSPPPAM ....................359 7.16.1 Identification..........................359 7.16.2 Application..........................359 7.16.3...
Page 15 Table of contents Instantaneous residual overcurrent protection EFPIOC ............402 8.3.1 Identification..........................403 8.3.2 Application..........................403 8.3.3 Setting guidelines........................403 Four step residual overcurrent protection, (Zero sequence or negative sequence directionality) EF4PTOC ......................405 8.4.1 Identification..........................405 8.4.2 Application..........................405 8.4.3 Setting guidelines........................
Page 16 Table of contents 8.12 Directional overpower protection GOPPDOP ................. 443 8.12.1 Identification..........................443 8.12.2 Application..........................443 8.12.3 Setting guidelines........................445 8.13 Broken conductor check BRCPTOC ...................448 8.13.1 Identification..........................448 8.13.2 Application..........................448 8.13.3 Setting guidelines........................448 8.14 Capacitor bank protection CBPGAPC..................448 8.14.1 Identification..........................
Page 17 Table of contents 9.2.1 Identification..........................468 9.2.2 Application..........................468 9.2.3 Setting guidelines........................469 9.2.3.1 Equipment protection, such as for motors, generators, reactors and transformers...........................469 9.2.3.2 Equipment protection, capacitors..................469 9.2.3.3 Power supply quality......................469 9.2.3.4 High impedance earthed systems..................470 9.2.3.5 The following settings can be done for the two step overvoltage protection..470 Two step residual overvoltage protection ROV2PTOV ............471 9.3.1 Identification..........................
Page 18 Table of contents 10.3 Rate-of-change frequency protection SAPFRC ...............487 10.3.1 Identification..........................487 10.3.2 Application..........................487 10.3.3 Setting guidelines........................488 Section 11 Multipurpose protection................489 11.1 General current and voltage protection CVGAPC..............489 11.1.1 Identification..........................489 11.1.2 Application..........................489 11.1.2.1 Current and voltage selection for CVGAPC function............490 11.1.2.2 Base quantities for CVGAPC function................492 11.1.2.3...
Page 19 Table of contents 13.3.2 Application..........................511 13.3.3 Setting guidelines........................512 Section 14 Control......................515 14.1 Synchrocheck, energizing check, and synchronizing SESRSYN..........515 14.1.1 Identification..........................515 14.1.2 Application..........................515 14.1.2.1 Synchronizing..........................515 14.1.2.2 Synchrocheck.......................... 516 14.1.2.3 Energizing check........................518 14.1.2.4 Voltage selection........................518 14.1.2.5 External fuse failure....................... 519 14.1.3 Application examples.......................
Page 20 Table of contents 14.3.4.1 Application..........................549 14.3.4.2 Signals from bus-coupler..................... 550 14.3.4.3 Configuration setting......................551 14.3.5 Interlocking for bus-section breaker A1A2_BS..............551 14.3.5.1 Application..........................551 14.3.5.2 Signals from all feeders......................551 14.3.5.3 Configuration setting......................554 14.3.6 Interlocking for bus-section disconnector A1A2_DC ............554 14.3.6.1 Application..........................
Page 21 Table of contents 14.9 AutomationBits, command function for DNP3.0 AUTOBITS..........608 14.9.1 Identification..........................608 14.9.2 Application..........................608 14.9.3 Setting guidelines........................609 14.10 Single command, 16 signals SINGLECMD.................609 14.10.1 Identification..........................609 14.10.2 Application..........................609 14.10.3 Setting guidelines........................611 Section 15 Scheme communication.................613 15.1 Scheme communication logic for residual overcurrent protection ECPSCH ....613 15.1.1 Identification..........................
Page 22 Table of contents 16.5 Logic for group indication INDCALH..................624 16.5.1 Logic for group indication INDCALH..................624 16.5.1.1 Identification.......................... 624 16.5.1.2 Application..........................624 16.5.1.3 Setting guidelines........................625 16.6 Configurable logic blocks......................625 16.6.1 Application..........................625 16.6.2.1 Configuration..........................625 16.7 Fixed signal function block FXDSIGN..................626 16.7.1 Identification..........................626 16.7.2...
Page 23 Table of contents 17.2.1 Identification..........................647 17.2.2 Application..........................647 17.3 Liquid medium supervision SSIML..................... 647 17.3.1 Identification..........................647 17.3.2 Application..........................648 17.4 Breaker monitoring SSCBR......................648 17.4.1 Identification..........................648 17.4.2 Application..........................648 17.4.3 Setting guidelines........................650 17.4.3.1 Setting procedure on the IED....................650 17.5 Event function EVENT........................651 17.5.1 Identification..........................
Page 24 Table of contents 19.1 Communication protocols......................665 19.2 IEC 61850-8-1 communication protocol..................665 19.2.1 Application IEC 61850-8-1......................665 19.2.2 Horizontal communication via GOOSE for interlocking GOOSEINTLKRCV....667 19.2.3 Setting guidelines........................667 19.2.4 Generic communication function for Single Point indication SPGAPC, SP16GAPC..667 19.2.4.1 Application..........................
Page 25 Table of contents 21.3 Change lock CHNGLCK......................... 698 21.3.1 Application..........................698 21.4 Denial of service DOS........................698 21.4.1 Application..........................698 21.4.2 Setting guidelines........................699 Section 22 Basic IED functions..................701 22.1 IED identifiers..........................701 22.1.1 Application..........................701 22.2 Product information........................701 22.2.1 Application..........................701 22.2.2 Factory defined settings......................701 22.3...
Page 26 Table of contents 22.12.2 Setting guidelines........................713 22.13 Time synchronization........................713 22.13.1 Application..........................713 22.13.2 Setting guidelines........................714 22.13.2.1 System time..........................714 22.13.2.2 Synchronization........................714 22.13.2.3 Process bus IEC 61850-9-2LE synchronization..............715 Section 23 Requirements....................717 23.1 Current transformer requirements.....................717 23.1.1 Current transformer classification..................717 23.1.2 Conditions...........................
Page 27: Introduction
1MRK 504 152-UEN B Section 1 Introduction Section 1 Introduction This manual GUID-AB423A30-13C2-46AF-B7FE-A73BB425EB5F v19 The application manual contains application descriptions and setting guidelines sorted per function. The manual can be used to find out when and for what purpose a typical protection function can be used.
Page 28: Product Documentation
Section 1 1MRK 504 152-UEN B Introduction Product documentation 1.3.1 Product documentation set GUID-3AA69EA6-F1D8-47C6-A8E6-562F29C67172 v15 Engineering manual Installation manual Commissioning manual Operation manual Application manual Technical manual Communication protocol manual Cyber security deployment guideline IEC07000220-4-en.vsd IEC07000220 V4 EN-US Figure 1: The intended use of manuals throughout the product lifecycle The engineering manual contains instructions on how to engineer the IEDs using the various tools available within the PCM600 software.
Page 29: Document Revision History
1MRK 504 152-UEN B Section 1 Introduction The application manual contains application descriptions and setting guidelines sorted per function. The manual can be used to find out when and for what purpose a typical protection function can be used. The manual can also provide assistance for calculating settings. The technical manual contains operation principle descriptions, and lists function blocks, logic diagrams, input and output signals, setting parameters and technical data, sorted per function.
Page 30: Document Symbols And Conventions
Section 1 1MRK 504 152-UEN B Introduction 670 series manuals Document numbers Cyber security deployment guideline 1MRK 511 356-UEN Connection and Installation components 1MRK 513 003-BEN Test system, COMBITEST 1MRK 512 001-BEN Document symbols and conventions 1.4.1 Symbols GUID-2945B229-DAB0-4F15-8A0E-B9CF0C2C7B15 v12 The electrical warning icon indicates the presence of a hazard which could result in electrical shock.
Page 31: Document Conventions
1MRK 504 152-UEN B Section 1 Introduction 1.4.2 Document conventions GUID-96DFAB1A-98FE-4B26-8E90-F7CEB14B1AB6 v8 • Abbreviations and acronyms in this manual are spelled out in the glossary. The glossary also contains definitions of important terms. • Push button navigation in the LHMI menu structure is presented by using the push button icons.
Page 32 Section 1 1MRK 504 152-UEN B Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes BUSPTRC_B8 BUSPTRC BUSPTRC BUSPTRC_B9 BUSPTRC BUSPTRC BUSPTRC_B10 BUSPTRC BUSPTRC BUSPTRC_B11 BUSPTRC BUSPTRC BUSPTRC_B12 BUSPTRC BUSPTRC BUSPTRC_B13 BUSPTRC BUSPTRC BUSPTRC_B14 BUSPTRC BUSPTRC BUSPTRC_B15 BUSPTRC BUSPTRC BUSPTRC_B16...
Page 33 1MRK 504 152-UEN B Section 1 Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes CBPGAPC CBPLLN0 CBPMMXU CBPMMXU CBPPTRC CBPPTRC HOLPTOV HOLPTOV HPH1PTOV HPH1PTOV PH3PTOC PH3PTUC PH3PTUC PH3PTOC RP3PDOP RP3PDOP CCPDSC CCRPLD CCPDSC CCRBRF CCRBRF CCRBRF CCRWRBRF CCRWRBRF CCRWRBRF...
Page 34 Section 1 1MRK 504 152-UEN B Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes GENPDIF GENPDIF GENGAPC GENPDIF GENPHAR GENPTRC GOOSEBINRCV BINGREC GOOSEDPRCV DPGREC GOOSEINTLKRCV INTGREC GOOSEINTRCV INTSGREC GOOSEMVRCV MVGREC GOOSESPRCV BINSGREC GOOSEVCTRRCV VCTRGREC GOPPDOP GOPPDOP GOPPDOP PH1PTRC GRPTTR...
Page 35 1MRK 504 152-UEN B Section 1 Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes LPHD LPHD LPTTR LPTTR LPTTR LT3CPDIF LT3CPDIF LT3CGAPC LT3CPDIF LT3CPHAR LT3CPTRC LT6CPDIF LT6CPDIF LT6CGAPC LT6CPDIF LT6CPHAR LT6CPTRC MVGAPC MVGGIO MVGAPC NS2PTOC NS2LLN0 NS2PTOC NS2PTOC NS2PTRC...
Page 36 Section 1 1MRK 504 152-UEN B Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes SAPTOF SAPTOF SAPTOF SAPTUF SAPTUF SAPTUF SCCVPTOC SCCVPTOC SCCVPTOC SCILO SCILO SCILO SCSWI SCSWI SCSWI SDEPSDE SDEPSDE SDEPSDE SDEPTOC SDEPTOV SDEPTRC SESRSYN RSY1LLN0 AUT1RSYN AUT1RSYN...
Page 37 1MRK 504 152-UEN B Section 1 Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes U2RWPTUV GEN2LLN0 PH1PTRC PH1PTRC U2RWPTUV U2RWPTUV UV2PTUV GEN2LLN0 PH1PTRC PH1PTRC UV2PTUV UV2PTUV VDCPTOV VDCPTOV VDCPTOV VDSPVC VDRFUF VDSPVC VMMXU VMMXU VMMXU VMSQI VMSQI VMSQI VNMMXU...
Page 39: Application
1MRK 504 152-UEN B Section 2 Application Section 2 Application General IED application M16637-3 v13 The IED provides fast and selective protection, monitoring and control for two- and three- winding transformers, autotransformers, step-up transformers and generator-transformer block units, phase shifting transformers, special railway transformers and shunt reactors. The IED is designed to operate correctly over a wide frequency range in order to accommodate power system frequency variations during disturbances and generator start-up and shut- down.
Page 40: Main Protection Functions
Section 2 1MRK 504 152-UEN B Application swinging to each other can be separated with the line(s) closest to the centre of the power swing, allowing the two systems to be stable when separated. The IED can be used in applications with the IEC 61850-9-2LE process bus with up to six merging units (MU) depending on the other functionality included in the IED.
Page 41 1MRK 504 152-UEN B Section 2 Application IEC 61850 ANSI Function Transformer description RET670 (Customized) REFPDIF Restricted earth fault 1-A01 1-A01 protection, low impedance LDRGFC 11REL Additional security logic for differential protection Impedance protection ZMQPDIS, Distance 4-B12 4-B12 4-B12 4-B12 ZMQAPDIS protection zone,...
Page 42 Section 2 1MRK 504 152-UEN B Application IEC 61850 ANSI Function Transformer description RET670 (Customized) ZDARDIR Additional 1-B13 1-B13 1-B13 1-B13 distance protection directional function for earth faults ZSMGAPC 1-B13 1-B13 1-B13 1-B13 impedance supervision logic FMPSPDIS Faulty phase 2-B13 2-B13 2-B13 2-B13...
Page 43: Back-Up Protection Functions
1MRK 504 152-UEN B Section 2 Application IEC 61850 ANSI Function Transformer description RET670 (Customized) OOSPPAM Out-of-step 0–1 protection PPLPHIZ Phase preference logic ZGVPDIS Underimpedan 0–1 1-B14 1-B14 1-B14 1-B14 ce protection for generators transformers Back-up protection functions GUID-A8D0852F-807F-4442-8730-E44808E194F0 v10 IEC 61850 ANSI Function...
Page 44 Section 2 1MRK 504 152-UEN B Application IEC 61850 ANSI Function Transformer description RET670 (Customized) LCPTTR Thermal 0–2 overload protection, one time constant, Celsius LFPTTR Thermal 0–2 overload protection, one time constant, Fahrenheit TRPTTR Thermal overload 1-C05 1-C05 1-C05 1-C05 protection, two time constant...
Page 45 1MRK 504 152-UEN B Section 2 Application IEC 61850 ANSI Function Transformer description RET670 (Customized) ROV2PTOV Two step 1-D01 2-D02 residual 1-D01 1-D01 1-D02 1-D02 overvoltage protection OEXPVPH Overexcitation 1-D03 1-D03 2-D04 2-D04 protection VDCPTOV Voltage differential protection LOVPTUV Loss of voltage check Frequency protection SAPTUF...
Page 46: Control And Monitoring Functions
Section 2 1MRK 504 152-UEN B Application Control and monitoring functions GUID-E3777F16-0B76-4157-A3BF-0B6B978863DE v12 IEC 61850 ANSI Function Transformer description RET670 Control SESRSYN Synchrocheck, 1-B, 2- 1-B, 3- 1-B, 4- energizing check and synchronizing APC15 Apparatus control for single bay, max 15 apparatuses (2CBs) incl.
Page 47 1MRK 504 152-UEN B Section 2 Application IEC 61850 ANSI Function Transformer description RET670 SLGAPC Logic rotating switch for function selection and LHMI presentation VSGAPC Selector mini switch DPGAPC Generic communicatio n function for Double Point indication SPC8GAPC Single point generic control 8 signals...
Page 48 Section 2 1MRK 504 152-UEN B Application IEC 61850 ANSI Function Transformer description RET670 Secondary system supervision CCSSPVC Current circuit supervision FUFSPVC Fuse failure supervision VDSPVC Fuse failure 1-G03 1-G03 1-G03 1-G03 1-G03 1-G03 supervision based on voltage difference Logic SMPPTRC Tripping logic TMAGAPC...
Page 49 1MRK 504 152-UEN B Section 2 Application IEC 61850 ANSI Function Transformer description RET670 BTIGAPC Boolean 16 to Integer conversion with Logic Node representatio IB16 Integer to Boolean 16 conversion ITBGAPC Integer to Boolean 16 conversion with Logic Node representatio TEIGAPC Elapsed time integrator...
Page 50 Section 2 1MRK 504 152-UEN B Application IEC 61850 ANSI Function Transformer description RET670 SP16GAPC Generic communicatio n function for Single Point indication 16 inputs MVGAPC Generic communicatio n function for Measured Value BINSTATREP Logical signal status report RANGE_XP Measured value expander block...
Page 51 1MRK 504 152-UEN B Section 2 Application IEC 61850 ANSI Function Transformer description RET670 I103USRDEF Status for user defined signals for IEC 60870-5-103 L4UFCNT Event counter with limit supervision TEILGAPC Running hour- meter Metering PCFCNT Pulse-counter logic ETPMMTR Function for energy calculation and demand...
Page 52: Communication
Section 2 1MRK 504 152-UEN B Application Configurable logic blocks Q/T Total number of instances SRMEMORYQT TIMERSETQT XORQT Table 5: Total number of instances for extended logic package Extended configurable logic block Total number of instances GATE PULSETIMER SLGAPC SRMEMORY TIMERSET VSGAPC Communication...
Page 53 1MRK 504 152-UEN B Section 2 Application IEC 61850 ANSI Function Transformer description RET670 (Customized) DNPGENTCP DNP3.0 communication general TCP protocol CHSERRS485 DNP3.0 for EIA-485 communication protocol CH1TCP, CH2TCP, DNP3.0 for CH3TCP, CH4TCP TCP/IP communication protocol CHSEROPT DNP3.0 for TCP/IP and EIA-485 communication protocol...
Page 54 Section 2 1MRK 504 152-UEN B Application IEC 61850 ANSI Function Transformer description RET670 (Customized) GOOSEVCTRCONF GOOSE VCTR configuration for send and receive MULTICMDRCV, Multiple 60/10 60/10 60/10 60/10 60/10 60/10 60/10 MULTICMDSND command and transmit FRONT, LANABI, Ethernet LANAB, LANCDI, configuration of LANCD links...
Page 55: Basic Ied Functions
1MRK 504 152-UEN B Section 2 Application IEC 61850 ANSI Function Transformer description RET670 (Customized) Process bus communication IEC 61850-9-2 IEC 62439-3 1-P03 1-P03 1-P03 1-P03 1-P03 1-P03 parallel redundancy protocol Remote communication Binary signal 6/36 6/36 6/36 6/36 6/36 6/36 6/36 transfer receive/...
Page 56 Section 2 1MRK 504 152-UEN B Application IEC 61850 or function Description name DSTBEGIN, GPS time synchronization module DSTENABLE, DSTEND IRIG-B Time synchronization SETGRPS Number of setting groups ACTVGRP Parameter setting groups TESTMODE Test mode functionality CHNGLCK Change lock function SMBI Signal matrix for binary inputs SMBO...
Page 57 1MRK 504 152-UEN B Section 2 Application IEC 61850 or function ANSI Description name FNKEYTY1–FNKEYTY5 Parameter setting function for HMI in PCM600 FNKEYMD1– FNKEYMD5 LEDGEN General LED indication part for LHMI OPENCLOSE_LED LHMI LEDs for open and close keys GRP1_LED1– Basic part for CP HW LED indication module GRP1_LED15 GRP2_LED1–...
Page 59: Configuration
On request, ABB is available to support the re-configuration work, either directly or to do the design checking.
Page 60: Description Of Configuration Ret670
Section 3 1MRK 504 152-UEN B Configuration Description of configuration RET670 IP14806-1 v2 3.2.1 Introduction IP14807-1 v2 3.2.1.1 Description of configuration A30 M15203-3 v6 The configuration of the IED is shown in Figure 2. This configuration is used in applications with two winding transformers with single or double busbars but with a single breaker arrangement on both sides.
Page 61: Description Of Configuration B30
1MRK 504 152-UEN B Section 3 Configuration W1_QB1 W1_QB2 RET670 A30 – 2 Winding Transformer in single breaker arrangement 12AI (9I+3U) 1 → 0 W1_QA1 DFR/SER DR SMP PTRC DRP RDRE W1_CT 50BF 3I>BF 4(3I>) 3I>> IN>> CC RBRF OC4 PTOC PH PIOC EF PIOC ↑↓...
Page 62 Section 3 1MRK 504 152-UEN B Configuration open LV side breaker. High voltage circuit breaker synchronism check function is optional for system where synchronism check is required to close the bays/rings. The differential protection is the main protection function. It provides fast and sensitive tripping for internal faults.
Page 63: Description Of Configuration A40
1MRK 504 152-UEN B Section 3 Configuration RET670 B30 - 2 Winding Transformer in multi breaker arrangement 24AI (9I+3U, 9I+3U) 1 → 0 W1_QB1 DFR/DER DR W1_QB2 SMP PTRC DRP RDRE W1_CT2 50BF 3I> BF 52PD CC RBRF CC PDSC W1_QA1 1 →...
Page 64 Section 3 1MRK 504 152-UEN B Configuration the low voltage side breaker. The high voltage breaker is foreseen to always energize the transformer and be interlocked with an open LV side and tertiary breaker. The differential protection is the main protection function. It provides fast and sensitive tripping for internal faults.
Page 65: Description Of Configuration B40
1MRK 504 152-UEN B Section 3 Configuration W1_QB1 W1_QB2 RET670 A40 – 3 Winding Transformer in single breaker arrangement 24AI (9I+3U, 9I+3U) 1 → 0 W1_QA1 DFR/SER DR SMP PTRC DRP RDRE W1_CT 50BF 3I>BF 4(3I>) 3I>> IN>> CC RBRF OC4 PTOC PH PIOC EF PIOC...
Page 66 Section 3 1MRK 504 152-UEN B Configuration voltage breaker is foreseen to always energize the transformer and be interlocked with an open LV side breaker. High voltage circuit breaker synchronism check function is optional for system where synchronism check is required to close the bays/rings. The differential protection is the main protection function.
Page 67: Description Of Configuration A10
1MRK 504 152-UEN B Section 3 Configuration RET670 B40 - 3 Winding Transformer in multi breaker arrangement 24AI (9I+3U, 9I+3U) 1 → 0 W1_QB1 DFR/DER DR W1_QB2 SMP PTRC DRP RDRE W1_CT2 50BF 3I> BF 52PD CC RBRF CC PDSC W1_QA1 1 →...
Page 68 Section 3 1MRK 504 152-UEN B Configuration includes a 3–phase tripping scheme with a synchronism check function for manual closing of the low voltage side breaker. The high voltage breaker is foreseen to always energize the transformer and be interlocked with an open LV side breaker.
Page 69: Description Of Configuration A25
1MRK 504 152-UEN B Section 3 Configuration W1_QB1 W1_QB2 RET670 A10 – Transformer backup protection 12AI (9I+3U) 1 → 0 W1_QA1 DFR/SER DR DRP RDRE SMP PTRC W1_CT 50BF 3I>BF 4(3I>) 3I>> IN>> 4(IN>) EF4 PTOC CC RBRF OC4 PTOC PH PIOC EF PIOC Isqi...
Page 70 Section 3 1MRK 504 152-UEN B Configuration other IED670 where the local HMI interfaces to show position. Switching Auto-Manual, Raise and Lower commands, and so on can be provided. RET670 A25 – Voltage Control 12AI (6I+6U) ↑↓ ↑↓ DFR/SER DR TCM YLTC DRP RDRE TCM YLTC...
Page 71: Analog Inputs
1MRK 504 152-UEN B Section 4 Analog inputs Section 4 Analog inputs Introduction SEMOD55003-5 v10 Analog input channels must be configured and set properly in order to get correct measurement results and correct protection operations. For power measuring and all directional and differential functions the directions of the input currents must be defined in order to reflect the way the current transformers are installed/connected in the field ( primary and secondary connections ).
Page 72: Example
Section 4 1MRK 504 152-UEN B Analog inputs 4.2.1.1 Example SEMOD55055-11 v4 Usually the L1 phase-to-earth voltage connected to the first VT channel number of the transformer input module (TRM) is selected as the phase reference. The first VT channel number depends on the type of transformer input module.
Page 73: Example 2
1MRK 504 152-UEN B Section 4 Analog inputs Line Transformer Line Reverse Forward Definition of direction for directional functions Transformer protection Line protection Setting of current input: Setting of current input: Setting of current input: Set parameter Set parameter Set parameter CTStarPoint with CTStarPoint with CTStarPoint with...
Page 74: Example 3
Section 4 1MRK 504 152-UEN B Analog inputs Transformer Line Reverse Forward Definition of direction for directional functions Transformer protection Line protection Setting of current input: Setting of current input: Setting of current input: Set parameter Set parameter Set parameter CTStarPoint with CTStarPoint with CTStarPoint with...
Page 75 1MRK 504 152-UEN B Section 4 Analog inputs Transformer Line Forward Reverse Definition of direction for directional Transformer and line functions Line protection Setting of current input: Setting of current input: Set parameter Set parameter CTStarPoint with CTStarPoint with Transformer as Transformer as reference object.
Page 76 Section 4 1MRK 504 152-UEN B Analog inputs Transformer Line Reverse Forward Definition of direction for directional Transformer and line functions Line protection Setting of current input for line functions: Set parameter CTStarPoint with Line as reference object. Setting of current input Setting of current input Correct setting is for transformer functions:...
Page 77 1MRK 504 152-UEN B Section 4 Analog inputs Busbar Busbar Protection en06000196.vsd IEC06000196 V2 EN-US Figure 13: Example how to set CTStarPoint parameters in the IED CTStarPoint parameters in two ways. For busbar protection it is possible to set the The first solution will be to use busbar as a reference object.
Page 78: Examples On How To Connect, Configure And Set Ct Inputs For Most Commonly Used Ct Connections
Section 4 1MRK 504 152-UEN B Analog inputs 4.2.2.4 Examples on how to connect, configure and set CT inputs for most commonly used CT connections SEMOD55055-296 v5 Figure defines the marking of current transformer terminals commonly used around the world: In the SMAI function block, you have to set if the SMAI block is measuring AnalogInputType : Current/ current or voltage.
Page 79: Example On How To Connect A Star Connected Three-Phase Ct Set To The Ied
1MRK 504 152-UEN B Section 4 Analog inputs 4.2.2.5 Example on how to connect a star connected three-phase CT set to the SEMOD55055-352 v9 Figure gives an example about the wiring of a star connected three-phase CT set to the IED. It gives also an overview of the actions which are needed to make this measurement available to the built-in protection and control functions within the IED as well.
Page 80 Section 4 1MRK 504 152-UEN B Analog inputs These three connections are the links between the three current inputs and the three input channels of the preprocessing function block 4). Depending on the type of functions, which need this current information, more than one preprocessing block might be connected in parallel to the same three physical CT inputs.
Page 81 1MRK 504 152-UEN B Section 4 Analog inputs In the example in figure 16 case everything is done in a similar way as in the above described example (figure 15). The only difference is the setting of the parameter CTStarPoint of the used current inputs on the TRM (item 2 in the figure): CTprim =600A •...
Page 82: Example How To Connect Delta Connected Three-Phase Ct Set To The Ied
Section 4 1MRK 504 152-UEN B Analog inputs is the TRM where these current inputs are located. It shall be noted that for all these current inputs the following setting values shall be entered. • CTprim=800A • CTsec=1A • CTStarPoint=FromObject •...
Page 83 1MRK 504 152-UEN B Section 4 Analog inputs IL1-IL2 SMAI2 BLOCK AI3P IL2-IL3 REVROT ^GRP2L1 IL3-IL1 ^GRP2L2 ^GRP2L3 ^GRP2N IEC11000027-3-en.vsdx Protected Object IEC11000027 V3 EN-US Figure 18: 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 84: Example How To Connect Single-Phase Ct To The Ied
Section 4 1MRK 504 152-UEN B Analog inputs Another alternative is to have the delta connected CT set as shown in figure 19: IL1-IL3 SMAI2 BLOCK AI3P REVROT IL2-IL1 ^GRP2L1 ^GRP2L2 IL3-IL2 ^GRP2L3 ^GRP2N IEC11000028-3-en.vsdx Protected Object IEC11000028 V3 EN-US Figure 19: 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:...
Page 85: Relationships Between Setting Parameter Base Current, Ct Rated Primary Current And Minimum Pickup Of A Protection Ied
1MRK 504 152-UEN B Section 4 Analog inputs Protected Object SMAI2 BLOCK AI3P REVROT ^GRP2L1 ^GRP2L2 ^GRP2L3 ^GRP2N IEC11000029-4-en.vsdx IEC11000029 V4 EN-US Figure 20: 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 86: Setting Of Voltage Channels
Section 4 1MRK 504 152-UEN B Analog inputs CTs involved in the protection scheme. The rated CT primary current value is set as parameter CTPrim under the IED TRM settings. For all other protection applications (e.g. generator, shunt reactor, shunt capacitor and IBase parameter equal to the rated transformer protection) it is typically desirable to set current of the protected object.
Page 87: Examples On How To Connect A Three Phase-To-Earth Connected Vt To The Ied
1MRK 504 152-UEN B Section 4 Analog inputs (X1) (X1) (X1) (H1) (H1) (H1) (H2) (X2) (H2) (X2) (H2) (X2) en06000591.vsd IEC06000591 V1 EN-US Figure 21: Commonly used markings of VT terminals Where: is the symbol and terminal marking used in this document. Terminals marked with a square indicate the primary and secondary winding terminals with the same (positive) polarity is the equivalent symbol and terminal marking used by IEC (ANSI) standard for phase-to-earth connected VTs...
Page 88 Section 4 1MRK 504 152-UEN B Analog inputs SMAI2 BLOCK AI3P REVROT ^GRP2L1 ^GRP2L2 ^GRP2L3 ^GRP2N #Not used IEC06000599-4-en.vsdx IEC06000599 V4 EN-US Figure 22: A Three phase-to-earth connected VT Where: shows how to connect three secondary phase-to-earth voltages to three VT inputs on the IED is the TRM where these three voltage inputs are located.
Page 89: Example On How To Connect A Phase-To-Phase Connected Vt To The Ied
1MRK 504 152-UEN B Section 4 Analog inputs are three connections made in Signal Matrix Tool (SMT), which connect these three voltage inputs to first three input channels of the preprocessing function block 5). Depending on the type of functions which need this voltage information, more then one preprocessing block might be connected in parallel to these three VT inputs.
Page 90 Section 4 1MRK 504 152-UEN B Analog inputs 13.8 13.8 SMAI2 BLOCK AI3P REVROT ^GRP2L1 ^GRP2L2 ^GRP2L3 #Not Used ^GRP2N IEC06000600-5-en.vsdx IEC06000600 V5 EN-US Figure 23: A Two phase-to-phase connected VT Where: shows how to connect the secondary side of a phase-to-phase VT to the VT inputs on the IED is the TRM where these three voltage inputs are located.
Page 91: Example On How To Connect An Open Delta Vt To The Ied For High Impedance Earthed Or Unearthed Netwoeks
1MRK 504 152-UEN B Section 4 Analog inputs 4.2.4.5 Example on how to connect an open delta VT to the IED for high impedance earthed or unearthed netwoeks SEMOD55055-163 v8 Figure gives an example about the wiring of an open delta VT to the IED for high impedance earthed or unearthed power systems.
Page 92: Example How To Connect The Open Delta Vt To The Ied For Low Impedance Earthed Or Solidly Earthed Power Systems
Section 4 1MRK 504 152-UEN B Analog inputs Where: shows how to connect the secondary side of the open delta VT to one VT input on the IED. +3U0 shall be connected to the IED is the TRM where this voltage input is located. It shall be noted that for this voltage input the following setting values shall be entered: ×...
Page 93 1MRK 504 152-UEN B Section 4 Analog inputs Ph Ph Ph E (Equation 7) EQUATION1926 V1 EN-US The primary rated voltage of such VT is always equal to UPh-E Therefore, three series connected VT secondary windings will give the secondary voltage equal only to one individual VT secondary winding rating.
Page 94: Example On How To Connect A Neutral Point Vt To The Ied
Section 4 1MRK 504 152-UEN B Analog inputs Where: shows how to connect the secondary side of open delta VT to one VT input in the IED. +3Uo shall be connected to the IED. is TRM where this voltage input is located. It shall be noted that for this voltage input the following setting values shall be entered: ×...
Page 95 1MRK 504 152-UEN B Section 4 Analog inputs In case of a solid earth fault in high impedance earthed or unearthed systems the primary value of Uo voltage will be equal to: (Equation 11) EQUATION1931 V2 EN-US Figure gives an overview of required actions by the user in order to make this measurement available to the built-in protection and control functions within the IED as well.
Page 96 Section 4 1MRK 504 152-UEN B Analog inputs Where: shows how to connect the secondary side of neutral point VT to one VT input in the IED. shall be connected to the IED. is the TRM or AIM where this voltage input is located. For this voltage input the following setting values shall be entered: VTprim 3.81...
Page 97: Local Hmi
1MRK 504 152-UEN B Section 5 Local HMI Section 5 Local HMI AMU0600442 v14 IEC13000239-2-en.vsd IEC13000239 V2 EN-US Figure 27: Local human-machine interface The LHMI of the IED contains the following elements: • Keypad • Display (LCD) • LED indicators •...
Page 98: Display
Section 5 1MRK 504 152-UEN B Local HMI Display GUID-55739D4F-1DA5-4112-B5C7-217AAF360EA5 v10 The LHMI includes a graphical monochrome liquid crystal display (LCD) with a resolution of 320 x 240 pixels. The character size can vary. The amount of characters and rows fitting the view depends on the character size and the view that is shown.
Page 99: Leds
1MRK 504 152-UEN B Section 5 Local HMI IEC13000281-1-en.vsd GUID-C98D972D-D1D8-4734-B419-161DBC0DC97B V1 EN-US Figure 29: 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 30: Indication LED panel The function button and indication LED panels are not visible at the same time.
Page 100: Keypad
Section 5 1MRK 504 152-UEN B Local HMI three LED groups. The LEDs are lit according to priority, with red being the highest and green the lowest priority. For example, if on one panel there is an indication that requires the green LED to be lit, and on another panel there is an indication that requires the red LED to be lit, the red LED takes priority and is lit.
Page 101 1MRK 504 152-UEN B Section 5 Local HMI IEC15000157-1-en.vsd IEC15000157 V1 EN-US Figure 31: 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 102: Local Hmi Functionality
Section 5 1MRK 504 152-UEN B Local HMI IED status LEDs Local HMI functionality 5.4.1 Protection and alarm indication GUID-09CCB9F1-9B27-4C12-B253-FBE95EA537F5 v15 Protection indicators The protection indicator LEDs are Ready, Start and Trip. The start and trip LEDs are configured via the disturbance recorder. The yellow and red status LEDs are configured in the disturbance recorder function, DRPRDRE, by connecting a start or trip signal from the actual function to a BxRBDR binary input function block using the PCM600 and configure the...
Page 103: Parameter Management
1MRK 504 152-UEN B Section 5 Local HMI Alarm indicators The 15 programmable three-color LEDs are used for alarm indication. An individual alarm/ status signal, connected to any of the LED function blocks, can be assigned to one of the three LED colors when configuring the IED.
Page 104 Section 5 1MRK 504 152-UEN B Local HMI IEC13000280-1-en.vsd GUID-AACFC753-BFB9-47FE-9512-3C4180731A1B V1 EN-US Figure 32: RJ-45 communication port and green indicator LED 1 RJ-45 connector 2 Green indicator LED The default IP address for the IED front port is 10.1.150.3 and the corresponding subnetwork mask is 255.255.255.0.
Page 105: Differential Protection
1MRK 504 152-UEN B Section 6 Differential protection Section 6 Differential protection Transformer differential protection T2WPDIF and T3WPDIF IP14639-1 v3 6.1.1 Identification M15074-1 v5 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Transformer differential protection, T2WPDIF two-winding 3Id/I SYMBOL-BB V1 EN-US...
Page 106: Setting Guidelines
Section 6 1MRK 504 152-UEN B Differential protection caused by the protected transformer. Traditional transformer differential protection functions required auxiliary transformers for correction of the phase shift and ratio. The numerical microprocessor based differential algorithm as implemented in the IED compensates for both the turn-ratio and the phase shift internally in the software.
Page 107 1MRK 504 152-UEN B Section 6 Differential protection class of the current transformers, availability of information on the load tap changer position, short circuit power of the systems, and so on. The second section of the restrain characteristic has an increased slope in order to deal with increased differential current due to additional power transformer losses during heavy loading of the transformer and external fault currents.
Page 108: Elimination Of Zero Sequence Currents
Section 6 1MRK 504 152-UEN B Differential protection operate current [ times IBase ] Operate unconditionally UnrestrainedLimit Operate conditionally Section 1 Section 2 Section 3 SlopeSection3 IdMin SlopeSection2 Restrain EndSection1 restrain current [ times IBase ] EndSection2 en05000187-2.vsd IEC05000187 V2 EN-US Figure 33: Representation of the restrained, and the unrestrained operate characteristics Ioperate...
Page 109: Inrush Restraint Methods
1MRK 504 152-UEN B Section 6 Differential protection transformer, which may result in differential current as well. To make the overall differential protection insensitive to external earth-faults in these situations the zero sequence currents must be eliminated from the power transformer IED currents on the earthed windings, so that they do not appear as differential currents.
Page 110: External/Internal Fault Discriminator
Section 6 1MRK 504 152-UEN B Differential protection CrossBlockEn is set to Off , (recommended) setting value for this parameter. When parameter any cross blocking between phases will be disabled. 6.1.3.6 External/Internal fault discriminator M15266-269 v9 The external/internal fault discriminator operation is based on the relative position of the two phasors (in case of a two-winding transformer) representing the W1 and W2 negative sequence current contributions, defined by matrix expression see the technical reference manual.
Page 111: On-Line Compensation For On-Load Tap-Changer Position
1MRK 504 152-UEN B Section 6 Differential protection heavy internal faults with severely saturated current transformers this differential protection operates well below one cycle, since the harmonic distortions in the differential currents do not slow down the differential protection operation. Practically, an unrestrained operation is achieved for all internal faults.
Page 112: Open Ct Detection
Section 6 1MRK 504 152-UEN B Differential protection compensation within the differential function. The threshold for the alarm pickup level is defined by setting parameter IDiffAlarm . This threshold should be typically set in such way to obtain operation when on-load tap-changer measured value within differential function differs for more than two steps from the actual on-load tap-changer position.
Page 113: Typical Main Ct Connections For Transformer Differential Protection
1MRK 504 152-UEN B Section 6 Differential protection • power transformer phase shift (vector group compensation) • CT secondary currents magnitude difference on different sides of the protected transformer (ratio compensation) • zero sequence current elimination (zero sequence current reduction) shall be done. In the past this was performed with help of interposing CTs or special connection of main CTs (delta connected CTs).
Page 114: Application Examples
Section 6 1MRK 504 152-UEN B Differential protection For star connected main CTs, secondary currents fed to the IED: • are directly proportional to the measured primary currents • are in phase with the measured primary currents • contain all sequence components including zero sequence current component For star connected main CTs, the main CT ratio shall be set as it is in actual application.
Page 115 1MRK 504 152-UEN B Section 6 Differential protection Example 1: Star-delta connected power transformer without on-load tap-changer SEMOD167854-110 v6 Single line diagrams for two possible solutions for such type of power transformer with all relevant application data are given in figure 35. CT 300/5 CT 300/5 in Delta...
Page 116 Section 6 1MRK 504 152-UEN B Differential protection 5. Enter the following settings for all three CT input channels used for the HV side CTs, see table 13. Table 13: CT input channels used for the HV side CTs Setting parameter Selected value for solution 1 Selected value for solution 2 (delta (star connected CT)
Page 117 1MRK 504 152-UEN B Section 6 Differential protection CT 400/5 CT 400/5 Star Star 60 MVA 60 MVA 115/24.9 kV 115/24.9 kV Dyn1 Dyn1 CT 1500/5 CT 1500/5 in Delta Star (DAB) en06000555.vsd IEC06000555 V1 EN-US Figure 36: Two differential protection solutions for delta-star connected power transformer For this particular power transformer the 115 kV side phase-to-earth no-load voltages lead by 30°...
Page 118 Section 6 1MRK 504 152-UEN B Differential protection CT input channels used for the LV side CTs Setting parameter Selected value for Solution 1 Selected value for Solution 2 (delta (star connected CT) connected CT) CTprim 1500 1500 (Equation 16) EQUATION1889 V1 EN-US CTsec CTStarPoint...
Page 119 1MRK 504 152-UEN B Section 6 Differential protection CT 200/1 CT 200/1 in Delta Star (DAB) 31.5/31.5/(10.5) MVA 31.5/31.5/(10.5) MVA 110±11×1.5% /36.75/(10.5) kV 110±11×1.5% /36.75/(10.5) kV YNyn0(d5) YNyn0(d5) CT 500/5 CT 500/5 in Delta Star (DAB) en06000558.vsd IEC06000558 V1 EN-US Figure 37: Two differential protection solutions for star-star connected transformer.
Page 120 Section 6 1MRK 504 152-UEN B Differential protection To compensate for delta connected CTs, see equation 17. 6. Enter the following settings for all three CT input channels used for the LV side CTs 7. Assume GBASVAL:1 is used for winding 1 (W1, HV-side) base values: Set Ibase = 165 A (rated current), Ubase= 110 kV (rated voltage).
Page 121: Summary And Conclusions
1MRK 504 152-UEN B Section 6 Differential protection 6.1.4.4 Summary and conclusions SEMOD168160-5 v3 The IED can be used for differential protection of three-phase power transformers with main CTs either star or delta connected. However the IED has been designed with the assumption that all main CTS are star connected.
Page 122: High Impedance Differential Protection, Single Phase Hzpdif
Section 6 1MRK 504 152-UEN B Differential protection IEC vector group Positive sequence no-load Required delta CT connection type on star side of the voltage phasor diagram protected power transformer and internal vector group setting in the IED Dyn11 DAC/Yy0 IEC06000562 V1 EN-US YNd5 DAB/Yy6...
Page 123: The Basics Of The High Impedance Principle
1MRK 504 152-UEN B Section 6 Differential protection • Capacitor differential protection • Restricted earth fault protection for transformer, generator and shunt reactor windings • Restricted earth fault protection The application is dependent on the primary system arrangements and location of breakers, available CT cores and so on.
Page 124 Section 6 1MRK 504 152-UEN B Differential protection Metrosil IEC05000164-2-en.vsd IEC05000164 V3 EN-US Figure 39: Example for the high impedance restricted earth fault protection application For a through fault one current transformer might saturate when the other CTs still will feed current.
Page 125 1MRK 504 152-UEN B Section 6 Differential protection For an internal fault, all involved CTs will try to feed current through the measuring branch. Depending on the size of current transformer, relatively high voltages will be developed across the series resistor. Note that very high peak voltages can appear. To prevent the risk of flashover in the circuit, a voltage limiter must be included.
Page 126 Section 6 1MRK 504 152-UEN B Differential protection Operating Stabilizing Operating Stabilizing Operating Stabilizing Operating voltage resistor R1 current level resistor R1 current level resistor R1 current level U>Trip ohms ohms ohms 100 V 1000 0.100 A 0.200 A 0.400 A 150 V 1500 0.100 A...
Page 127 1MRK 504 152-UEN B Section 6 Differential protection Rres I> Protected Object a) Through load situation b) Through fault situation c) Internal faults IEC05000427-2-en.vsd IEC05000427 V2 EN-US Figure 40: The high impedance principle for one phase with two current transformer inputs Application manual...
Page 128: Connection Examples For High Impedance Differential Protection
Section 6 1MRK 504 152-UEN B Differential protection 6.2.3 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 129: Connections For 1Ph High Impedance Differential Protection Hzpdif
1MRK 504 152-UEN B Section 6 Differential protection Necessary connection for setting resistors. Factory-made star point on a three-phase setting resistor set. The star point connector must be removed for installations with 670 series IEDs. This star point is required for RADHA schemes only. Connections of three individual phase currents for high impedance scheme to three CT inputs in the IED.
Page 130: Setting Guidelines
Section 6 1MRK 504 152-UEN B Differential protection 6.2.4 Setting guidelines IP14945-1 v1 M13076-3 v2 The setting calculations are individual for each application. Refer to the different application descriptions below. 6.2.4.1 Configuration M13076-5 v4 The configuration is done in the Application Configuration tool. 6.2.4.2 Settings of protection function M13076-10 v6...
Page 131 1MRK 504 152-UEN B Section 6 Differential protection 3·Id IEC05000739-2-en.vsd IEC05000739 V2 EN-US Figure 43: 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 132: Autotransformer Differential Protection
Section 6 1MRK 504 152-UEN B Differential protection Calculation: (Equation 21) EQUATION1207 V2 EN-US Select a setting of U>Trip =200 V. The current transformer saturation voltage must be at least twice the set operating voltage U>Trip . > × 20 6.2 20 524 (Equation 22) EQUATION1208 V1 EN-US U>Trip...
Page 133 1MRK 504 152-UEN B Section 6 Differential protection 3·Id IEC05000173-3-en.vsd IEC05000173 V3 EN-US Figure 44: Application of the 1Ph High impedance differential protection HZPDIF function on an autotransformer Setting example It is strongly recommended to use the highest tap of the CT whenever high impedance protection is used.
Page 134 Section 6 1MRK 504 152-UEN B Differential protection Calculation: 1150 > × × 3.8 1.6 77.625 1200 (Equation 24) EQUATION1210 V1 EN-US Select a setting of U>Trip =100 V The current transformer saturation voltage must be at least, twice the set operating voltage U>Trip .
Page 135 1MRK 504 152-UEN B Section 6 Differential protection 3·Id IEC05000774-3-en.vsd IEC05000774 V3 EN-US Figure 45: Application of the high impedance differential function on tertiary busbar Setting example It is strongly recommended to use the highest tap of the CT whenever high impedance protection is used.
Page 136 Section 6 1MRK 504 152-UEN B Differential protection Basic data: Cable loop <50 m 2.5mm (one way) gives 1 ˣ 0.42 ohm at 75° C. resistance: Note! Only one way cable length is used as the power system earthing in this example is limiting the earth-fault current to a low level.
Page 137: Tertiary Reactor Protection
1MRK 504 152-UEN B Section 6 Differential protection The magnetizing current is taken from the magnetizing curve for the current transformer cores which should be available. The current value at U>Trip is taken. For the voltage dependent resistor current the peak value of voltage 100 ˣ √2 is used. Then the RMS current is calculated by dividing obtained current value from the metrosil curve with √2.
Page 138 Section 6 1MRK 504 152-UEN B 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...
Page 139: Restricted Earth Fault Protection
1MRK 504 152-UEN B Section 6 Differential protection dividing obtained current value from the metrosil curve with √2. Use the maximum value from the metrosil curve given in Figure 48. 6.2.4.6 Restricted earth fault protection M16850-156 v10 For solidly earthed systems a restricted earth fault protection REFPDIF is often provided as a complement to the normal transformer differential function.
Page 140: Alarm Level Operation
Section 6 1MRK 504 152-UEN B Differential protection Calculation: > × × 0.66 0.8 18.25 (Equation 33) EQUATION1219 V1 EN-US Select a setting of U>Trip =40 V. The current transformer saturation voltage at 5% error can roughly be calculated from the rated values.
Page 141: Low Impedance Restricted Earth Fault Protection Refpdif
1MRK 504 152-UEN B Section 6 Differential protection IEC05000749 V1 EN-US Figure 48: Current voltage characteristics for the non-linear resistors, in the range 10-200 V, the average range of current is: 0.01–10 mA Low impedance restricted earth fault protection REFPDIF IP14640-1 v6 6.3.1 Identification...
Page 142: Transformer Winding, Solidly Earthed
Section 6 1MRK 504 152-UEN B Differential protection A restricted earth-fault protection is the fastest and the most sensitive protection, a power transformer winding can have and will detect faults such as: • earth faults in the transformer winding when the network is earthed through an impedance •...
Page 143: Transformer Winding, Earthed Through Zig-Zag Earthing Transformer
1MRK 504 152-UEN B Section 6 Differential protection 6.3.2.2 Transformer winding, earthed through zig-zag earthing transformer M13048-8 v11 A common application is for low reactance earthed transformer where the earthing is through separate zig-zag earthing transformers. The fault current is then limited to typical 800 to 2000 A for each transformer.
Page 144: Reactor Winding, Solidly Earthed
Section 6 1MRK 504 152-UEN B Differential protection REFPDIF HV (W1) I3PW1CT1 I3PW2CT1 IdN/I LV (W2) Auto transformer IEC09000111-4-EN.vsd IEC09000111-4-EN V2 EN-US Figure 51: Connection of restricted earth fault, low impedance function REFPDIF for an autotransformer, solidly earthed 6.3.2.4 Reactor winding, solidly earthed M13048-18 v10 Reactors can be protected with restricted earth-fault protection, low impedance function REFPDIF.
Page 145: Multi-Breaker Applications
1MRK 504 152-UEN B Section 6 Differential protection REFPDIF I3PW1CT1 IdN/I Reactor IEC09000112-4.vsd IEC09000112-4 V2 EN-US Figure 52: Connection of restricted earth-fault, low impedance function REFPDIF for a solidly earthed reactor 6.3.2.5 Multi-breaker applications M13048-23 v9 Multi-breaker arrangements including ring, one and a half breaker, double breaker and mesh corner arrangements have two sets of current transformers on the phase side.
Page 146: Ct Earthing Direction
Section 6 1MRK 504 152-UEN B Differential protection REFPDIF I3PW1CT1 Protected winding IdN/I I3PW1CT2 IEC09000113-3.vsd IEC09000113-3 V2 EN-US Figure 53: Connection of Restricted earth fault, low impedance function REFPDIF in multi-breaker arrangements 6.3.2.6 CT earthing direction M13048-29 v12 To make the restricted earth-fault protection REFPDIF operate correctly, the main CTs are always supposed to be star -connected.
Page 147: Settings
1MRK 504 152-UEN B Section 6 Differential protection BLOCK: The input will block the operation of the function. Can be used, for example, to block for a limited time the operation during special service conditions. Recommendation for output signals M13052-21 v8 Refer to pre-configured configurations for details.
Page 148: Application
Section 6 1MRK 504 152-UEN B Differential protection 6.4.2 Application GUID-93AF4444-C7ED-4DF5-9379-176DF17AE22C v4 Additional security logic for differential protection LDRGFC can help the security of the protection especially when the communication system is in abnormal status or for example when there is unspecified asymmetry in the communication link. It reduces the probability for mal-operation of the protection.
Page 149: Setting Guidelines
1MRK 504 152-UEN B Section 6 Differential protection Release of line differential LDLPSCH protection trip CTFAIL TRIP INPUT1 OUTSERV TRL1 INPUT2 NOUT BLOCK TRL2 INPUT3 TRL3 INPUT4N TRLOCAL TRLOCL1 TRLOCL2 TRLOCL3 TRREMOTE DIFLBLKD Start signal to remote side LDRGFC I3P* START U3P* STCVL1L2...
Page 150 Section 6 1MRK 504 152-UEN B Differential protection most remote point where the differential protection shall be active. The phase-earth voltages shall be calculated for different types of faults (single phase-to-earth and phase to phase to earth) at different switching states in the network. The setting must be higher than the lowest phase-earth voltage during non-faulted operation.
Page 151: Impedance Protection
1MRK 504 152-UEN B Section 7 Impedance protection Section 7 Impedance protection Distance measuring zone, quadrilateral characteristic for series compensated lines ZMCPDIS, ZMCAPDIS, ZDSRDIR SEMOD168167-1 v3 7.1.1 Identification SEMOD168165-2 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Distance measuring zone, ZMCPDIS...
Page 152 Section 7 1MRK 504 152-UEN B Impedance protection IEC05000215 V2 EN-US Figure 55: Solidly earthed network The earth fault current is as high or even higher than the short-circuit current. The series impedances determine the magnitude of the fault current. The shunt admittance has very limited influence on the earth fault current.
Page 153: Fault Infeed From Remote End
1MRK 504 152-UEN B Section 7 Impedance protection Another definition for effectively earthed network is when the following relationships between the symmetrical components of the network impedances are valid, as shown in equation and equation 39. ≤ ⋅ (Equation 38) EQUATION1269 V4 EN-US £...
Page 154: Load Encroachment
Section 7 1MRK 504 152-UEN B Impedance protection The effect of fault current infeed from remote end is one of the most driving factors to justify complementary protection to distance protection. 7.1.2.4 Load encroachment SEMOD168232-97 v3 Sometimes the load impedance might enter the zone characteristic without any fault on the protected line.
Page 155: Parallel Line Application With Mutual Coupling
1MRK 504 152-UEN B Section 7 Impedance protection Definition of long lines with respect to the performance of distance protection can generally be described as in table 22, long lines have SIR’s less than 0.5. Table 22: Definition of long lines Line category 110 kV 500 kV...
Page 156 Section 7 1MRK 504 152-UEN B Impedance protection From an application point of view there exists three types of network configurations (classes) that must be considered when making the settings for the protection function. Those are: • Parallel line with common positive and zero sequence network •...
Page 157 1MRK 504 152-UEN B Section 7 Impedance protection Where: is phase-to-earth voltage at the IED point is phase current in the faulty phase is earth-fault current is positive sequence impedance is zero sequence impedance Z< Z< en05000221.vsd IEC05000221 V1 EN-US Figure 59: Class 1, parallel line in service The equivalent circuit of the lines can be simplified, as shown in figure 60.
Page 158 Section 7 1MRK 504 152-UEN B Impedance protection The second part in the parentheses is the error introduced to the measurement of the line impedance. If the current on the parallel line has negative sign compared to the current on the protected line that is, the current on the parallel line has an opposite direction compared to the current on the protected line, the distance function overreaches.
Page 159 1MRK 504 152-UEN B Section 7 Impedance protection Z< Z< en05000222.vsd DOCUMENT11520-IMG867 V1 EN-US Figure 61: The parallel line is out of service and earthed When the parallel line is out of service and earthed at both ends on the bus bar side of the line CT so that zero sequence current can flow on the parallel line, the equivalent zero sequence circuit of the parallel lines will be according to figure 61.
Page 160 Section 7 1MRK 504 152-UEN B Impedance protection Parallel line out of service and not earthed SEMOD168232-243 v3 Z< Z< en05000223.vsd IEC05000223 V1 EN-US Figure 63: Parallel line is out of service and not earthed When the parallel line is out of service and not earthed, the zero sequence on that line can only flow through the line admittance to the earth.
Page 161: Tapped Line Application
1MRK 504 152-UEN B Section 7 Impedance protection The real component of the KU factor is equal to equation 55. ⋅         (Equation 55) EQUATION1287 V3 EN-US The imaginary component of the same factor is equal to equation 56. ×...
Page 162 Section 7 1MRK 504 152-UEN B Impedance protection ·Z (Equation 57) DOCUMENT11524-IMG3509 V3 EN-US     ⋅  ⋅        (Equation 58) DOCUMENT11524-IMG3510 V3 EN-US Where: ZAT and ZCT is the line impedance from the B respective C station to the T point. IA and IC is fault current from A respective C station for fault between T and B.
Page 163: Series Compensation In Power Systems
1MRK 504 152-UEN B Section 7 Impedance protection RFPE ) and phase-to-phase In practice, the setting of fault resistance for both phase-to-earth ( RFPP ) must be as high as possible without interfering with the load impedance to obtain reliable fault detection. 7.1.2.8 Series compensation in power systems SEMOD168320-4 v2...
Page 164 Section 7 1MRK 504 152-UEN B Impedance protection limit 1000 1200 1400 1600 1800 P[MW] en06000586.vsd IEC06000586 V1 EN-US Figure 67: Voltage profile for a simple radial power line with 0, 30, 50 and 70% of compensation Increased power transfer capability by raising the first swing stability limit SEMOD168320-32 v2 Consider the simple one-machine and infinite bus system shown in figure 68.
Page 165 1MRK 504 152-UEN B Section 7 Impedance protection without SC with SC Mech Mech en06000588.vsd IEC06000588 V1 EN-US Figure 69: Equal area criterion and first swing stability without and with series compensation This means that the system is stable if A ≤...
Page 166 Section 7 1MRK 504 152-UEN B Impedance protection Increase in power transfer SEMOD168320-45 v2 The increase in power transfer capability as a function of the degree of compensation for a transmission line can be explained by studying the circuit shown in figure 71. The power transfer on the transmission line is given by the equation 62: ×...
Page 167 1MRK 504 152-UEN B Section 7 Impedance protection Line 1 Line 2 en06000593.vsd IEC06000593 V1 EN-US Figure 73: Two parallel lines with series capacitor for optimized load sharing and loss reduction To minimize the losses, the series capacitor must be installed in the transmission line with the lower resistance.
Page 168 Section 7 1MRK 504 152-UEN B Impedance protection en06000595.vsd IEC06000595 V1 EN-US Figure 75: Thyristor switched series capacitor en06000596.vsd IEC06000596 V1 EN-US Figure 76: Thyristor controlled series capacitor Line current Current through the thyristor Voltage over the series capacitor Rated reactance of the series capacitor A thyristor controlled series capacitor (TCSC) allows continuous control of the series capacitor reactance.
Page 169: Challenges In Protection Of Series Compensated And Adjacent Power Lines
1MRK 504 152-UEN B Section 7 Impedance protection The apparent impedance of the TCSC (the impedance seen by the power system) can typically be increased to up to 3 times the physical impedance of the capacitor, see figure 78. This high apparent reactance will mainly be used for damping of power oscillations.
Page 170 Section 7 1MRK 504 152-UEN B Impedance protection be on the bus side, so that series capacitor appears between the IED point and fault on the protected line. Figure presents the corresponding phasor diagrams for the cases with bypassed and fully inserted series capacitor. Voltage distribution on faulty lossless serial compensated line from fault point F to the bus is linearly dependent on distance from the bus, if there is no capacitor included in scheme (as shown in figure 80).
Page 171 1MRK 504 152-UEN B Section 7 Impedance protection It is obvious that voltage U will lead the fault current I as long as X > X . This situation corresponds, from the directionality point of view, to fault conditions on line without series capacitor.
Page 172 Section 7 1MRK 504 152-UEN B Impedance protection The first case corresponds also to conditions on non compensated lines and in cases, when the capacitor is bypassed either by spark gap or by the bypass switch, as shown in phasor diagram in figure 82.
Page 173 1MRK 504 152-UEN B Section 7 Impedance protection performances for the same network with and without series capacitor. Possible effects of spark gap flashing or MOV conducting are neglected. The time dependence of fault currents and the difference between them are of interest. en06000609.vsd IEC06000609 V1 EN-US Figure 83: Simplified equivalent scheme of SC network during fault conditions...
Page 174 Section 7 1MRK 504 152-UEN B Impedance protection The solution over line current is in this case presented by group of equations 73. The fault current consists also here from the steady-state part and the transient part. The difference with non-compensated conditions is that •...
Page 175 1MRK 504 152-UEN B Section 7 Impedance protection 0.02 0.04 0.06 0.08 0.12 0.14 0.16 0.18 t[ms ] en06000610.vsd IEC06000610 V1 EN-US Figure 84: Short circuit currents for the fault at the end of 500 km long 500 kV line without and with SC Location of instrument transformers SEMOD168320-261 v2...
Page 176 Section 7 1MRK 504 152-UEN B Impedance protection Distance IEDs are exposed especially to voltage inversion for close-in reverse faults, which decreases the security. The effect of negative apparent reactance must be studied seriously in case of reverse directed distance protection zones used by distance IEDs for teleprotection schemes.
Page 177 1MRK 504 152-UEN B Section 7 Impedance protection M OV MOV protected series capacitor Line current as a function of time Capacitor voltage as a function of time Capacitor current as a function of time MOV current as a function of time en06000614.vsd IEC06000614 V1 EN-US Figure 88: MOV protected capacitor with examples of capacitor voltage and...
Page 178: Impact Of Series Compensation On Protective Ied Of Adjacent Lines
Section 7 1MRK 504 152-UEN B Impedance protection (Equation 74) EQUATION1910 V1 EN-US Where is the maximum instantaneous voltage expected between the capacitor immediately before the MOV has conducted or during operation of the MOV, divaded by √2 is the rated voltage in RMS of the series capacitor £...
Page 179 1MRK 504 152-UEN B Section 7 Impedance protection en06000616.vsd IEC06000616 V1 EN-US Figure 90: Voltage inversion in series compensated network due to fault current infeed Voltage at the B bus (as shown in figure 90) is calculated for the loss-less system according to the equation below.
Page 180: Distance Protection
Section 7 1MRK 504 152-UEN B Impedance protection Application of MOVs as non-linear elements for capacitor overvoltage protection makes simple calculations often impossible. Different kinds of steady-state network simulations are in such cases unavoidable. 7.1.2.11 Distance protection SEMOD168320-338 v3 Distance protection due to its basic characteristics, is the most used protection principle on series compensated and adjacent lines worldwide.
Page 181 1MRK 504 152-UEN B Section 7 Impedance protection separately that compensation degree K in figure relates to total system reactance, inclusive line and source impedance reactance. The same setting applies regardless MOV or spark gaps are used for capacitor overvoltage protection. Equation is applicable for the case when the VTs are located on the bus side of series capacitor.
Page 182 Section 7 1MRK 504 152-UEN B Impedance protection Distance protections of adjacent power lines shown in figure are influenced by this negative impedance. If the intermediate infeed of short circuit power by other lines is taken into consideration, the negative voltage drop on X is amplified and a protection far away from the faulty line can maloperate by its instantaneous operating distance zone, if no precaution is taken.
Page 183 1MRK 504 152-UEN B Section 7 Impedance protection It usually takes a bit of a time before the spark gap flashes, and sometimes the fault current will be of such a magnitude that there will not be any flashover and the negative impedance will be sustained.
Page 184 Section 7 1MRK 504 152-UEN B Impedance protection in figure and a fault occurs behind the capacitor, the resultant reactance becomes negative and the fault current will have an opposite direction compared with fault current in a power line without a capacitor (current inversion). The negative direction of the fault current will persist until the spark gap has flashed.
Page 185 1MRK 504 152-UEN B Section 7 Impedance protection en06000628.vsd IEC06000628 V1 EN-US Figure 98: Zero sequence equivalent circuit of a series compensated double circuit line with one circuit disconnected and earthed at both IEDs Zero sequence mutual impedance may disturb also correct operation of distance protection for external evolving faults, when one circuit has already been disconnected in one phase and runs non-symmetrical during dead time of single pole autoreclosing cycle.
Page 186: Setting Guidelines
Section 7 1MRK 504 152-UEN B Impedance protection 7.1.3 Setting guidelines SEMOD168241-1 v2 7.1.3.1 General SEMOD168247-4 v2 The settings for the distance protection function are done in primary values. The instrument transformer ratio that has been set for the analog input card is used to automatically convert the measured secondary input signals to primary values used in the distance protection function.
Page 187: Setting Of Reverse Zone
1MRK 504 152-UEN B Section 7 Impedance protection down during faults. The zone2 must not be reduced below 120% of the protected line section. The whole line must be covered under all conditions. The requirement that the zone 2 shall not reach more than 80% of the shortest adjacent line at remote end is highlighted with a simple example below.
Page 188 Section 7 1MRK 504 152-UEN B Impedance protection Directional control SEMOD168247-145 v2 The directional function (ZDSRDIR) which is able to cope with the condition at voltage reversal, shall be used in all IEDs with conventional distance protection (ZMCPDIS,ZMCAPDIS). This function is necessary in the protection on compensated lines as well as all non-compensated lines connected to this busbar (adjacent lines).
Page 189 1MRK 504 152-UEN B Section 7 Impedance protection æ ö c degree of compensation ç ÷ ç ÷ è ø (Equation 90) EQUATION1894 V1 EN-US is the reactance of the series capacitor p is the maximum allowable reach for an under-reaching zone with respect to the sub- harmonic swinging related to the resulting fundamental frequency reactance the zone is not allowed to over-reach.
Page 190 Section 7 1MRK 504 152-UEN B Impedance protection line LLOC en06000584-2.vsd IEC06000584 V2 EN-US Figure 103: Measured impedance at voltage inversion Forward direction: Where equals line reactance up to the series capacitor(in the picture LLoc approximate 33% of XLine) is set to (XLindex-XC) · p/100. is defined according to figure is safety factor for fast operation of Zone 1 Compensated line with the series...
Page 191: Setting Of Zones For Parallel Line Application
1MRK 504 152-UEN B Section 7 Impedance protection When the calculation of XFw gives a negative value the zone 1 must be permanently blocked. Fault resistance SEMOD168247-201 v2 The resistive reach is, for all affected applications, restricted by the set reactive reach and the load impedance and same conditions apply as for a non-compensated network.
Page 192 Section 7 1MRK 504 152-UEN B Impedance protection Parallel line in service – Setting of zone1 SEMOD168247-50 v2 With reference to section "Parallel line application with mutual coupling", the zone reach can be set to 85% of protected line. Parallel line in service – setting of zone2 SEMOD168247-53 v2 Overreaching zones (in general, zones 2 and 3) must overreach the protected circuit in all cases.
Page 193: Setting Of Reach In Resistive Direction
1MRK 504 152-UEN B Section 7 Impedance protection æ ö × ------------------------- - ç – ÷ è ø (Equation 97) EQUATION562 V1 EN-US 7.1.3.7 Setting of reach in resistive direction SEMOD168247-76 v2 Set the resistive reach independently for each zone, and separately for phase-to-phase ( R1PP ), R1PE ) measurement.
Page 194 Section 7 1MRK 504 152-UEN B Impedance protection ------ - loadmin (Equation 102) EQUATION571 V1 EN-US Where: is the minimum phase-to-phase voltage in kV is the maximum apparent power in MVA. The load impedance [Ω/phase] is a function of the minimum operation voltage and the maximum load current: --------------------- - load...
Page 195: Load Impedance Limitation, With Load Encroachment Function Activated
1MRK 504 152-UEN B Section 7 Impedance protection £ × RFPP 1.6 Z load (Equation 106) EQUATION579 V2 EN-US Equation is applicable only when the loop characteristic angle for the phase-to-phase faults is more than three times as large as the maximum expected load-impedance angle. More accurate calculations are necessary according to equation 107.
Page 196: Phase Selection, Quadrilateral Characteristic With Fixed Angle Fdpspdis
Section 7 1MRK 504 152-UEN B Impedance protection tPE ) and for the ph-ph ( tPP ) measuring loops in each distance protection zone separately, to further increase the total flexibility of a distance protection. Phase selection, quadrilateral characteristic with fixed angle FDPSPDIS IP12400-1 v3 7.2.1...
Page 197 1MRK 504 152-UEN B Section 7 Impedance protection arctan (Equation 108) EQUATION2115 V1 EN-US In some applications, for instance cable lines, the angle of the loop might be less than 60°. In these applications, the settings of fault resistance coverage in forward and reverse direction, RFFwPE and RFRvPE for phase-to-earth faults and RFFwPP and RFRvPP for phase-to-phase faults have to be increased to avoid that FDPSPDIS characteristic shall cut off some part of the zone characteristic.
Page 198 Section 7 1MRK 504 152-UEN B Impedance protection ( / loop) 60° 60° ( / loop) IEC09000043_1_en.vsd IEC09000043 V1 EN-US Figure 104: Relation between distance protection phase selection (FDPSPDIS) and impedance zone (ZMQPDIS) for phase-to-earth fault φloop>60° (setting parameters in italic) FDPSPDIS (phase selection)(red line) 2 ZMQPDIS (Impedance protection zone) RFltRevPG...
Page 199 1MRK 504 152-UEN B Section 7 Impedance protection ³ × 1.44 X0 (Equation 110) EQUATION1310 V1 EN-US where: is the reactive reach for the zone to be covered by FDPSPDIS, and the constant 1.44 is a safety margin is the zero-sequence reactive reach for the zone to be covered by FDPSPDIS The reactive reach in reverse direction is automatically set to the same reach as for forward direction.
Page 200 Section 7 1MRK 504 152-UEN B Impedance protection Fault resistance reach M13142-176 v7 The fault resistance reaches in forward direction RFFwPP , must cover RFPP with at least 25% margin. RFPP is the setting of fault resistance for phase-to-phase fault for the longest overreaching zone to be covered by FDPSPDIS, see Figure 105.
Page 201 1MRK 504 152-UEN B Section 7 Impedance protection ( / phase) 60° 60° ( / phase) IEC09000257_1_en.vsd IEC09000257 V1 EN-US Figure 105: Relation between distance protection (ZMQPDIS) and FDPSPDIS characteristic for phase-to-phase fault for φline>60° (setting parameters in italic) FDPSPDIS (phase selection) (red line) 2 ZMQPDIS (Impedance protection zone) RFRvPP 3 0.5 ·...
Page 202: Resistive Reach With Load Encroachment Characteristic
Section 7 1MRK 504 152-UEN B Impedance protection 7.2.3.2 Resistive reach with load encroachment characteristic M13142-312 v4 The procedure for calculating the settings for the load encroachment consist basically to ArgLd , the blinder RLdFw in forward direction and blinder RLdRv in define the load angle reverse direction, as shown in figure 106.
Page 203: Distance Measuring Zones, Quadrilateral Characteristic Zmqpdis, Zmqapdis, Zdrdir
1MRK 504 152-UEN B Section 7 Impedance protection Distance measuring zones, quadrilateral characteristic ZMQPDIS, ZMQAPDIS, ZDRDIR IP14498-1 v4 7.3.1 Identification M14852-1 v6 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Distance protection zone, ZMQPDIS quadrilateral characteristic (zone 1) S00346 V1 EN-US Distance protection zone, ZMQAPDIS...
Page 204 Section 7 1MRK 504 152-UEN B Impedance protection IEC05000215 V2 EN-US Figure 107: Solidly earthed network The earth-fault current is as high or even higher than the short-circuit current. The series impedances determine the magnitude of the fault current. The shunt admittance has very limited influence on the earth-fault current.
Page 205 1MRK 504 152-UEN B Section 7 Impedance protection Where: is the highest fundamental frequency voltage on one of the healthy phases at single phase-to-earth fault. is the phase-to-earth fundamental frequency voltage before fault. Another definition for effectively earthed network is when the following relationships between the symmetrical components of the network impedances are valid, see equation equation 119.
Page 206: Fault Infeed From Remote End
Section 7 1MRK 504 152-UEN B Impedance protection Where: is the earth-fault current (A) is the current through the neutral point resistor (A) is the current through the neutral point reactor (A) is the total capacitive earth-fault current (A) The neutral point reactor is normally designed so that it can be tuned to a position where the reactive current balances the capacitive current from the network that is: ×...
Page 207: Load Encroachment
1MRK 504 152-UEN B Section 7 Impedance protection If we divide U by I we get Z present to the IED at A side. = p ·Z ·R (Equation 123) EQUATION1274-IEC-650 V1 EN-US The infeed factor (I can be very high, 10-20 depending on the differences in source impedances at local and remote end.
Page 208: Short Line Application
Section 7 1MRK 504 152-UEN B Impedance protection could preferably be switched off. See section "Load impedance limitation, without load encroachment function". The settings of the parameters for load encroachment are done in FDPSPDIS function. Load impedance ArgLd area in forward direction RLdRv RLdFw...
Page 209: Parallel Line Application With Mutual Coupling
1MRK 504 152-UEN B Section 7 Impedance protection What can be recognized as long lines with respect to the performance of distance protection can generally be described as in table 24, long lines have Source impedance ratio (SIR’s) less than 0.5. Table 24: Definition of long and very long lines Line category 110 kV...
Page 210 Section 7 1MRK 504 152-UEN B Impedance protection From an application point of view there exists three types of network configurations (classes) that must be considered when making the settings for the protection function. The different network configuration classes are: Parallel line with common positive and zero sequence network Parallel circuits with common positive but isolated zero sequence network Parallel circuits with positive and zero sequence sources isolated.
Page 211 1MRK 504 152-UEN B Section 7 Impedance protection Where: is phase to earth voltage at the relay point is phase current in the faulty phase is earth fault current is positive sequence impedance is zero sequence impedance Z< Z< IEC09000250_1_en.vsd IEC09000250 V1 EN-US Figure 112: Class 1, parallel line in service The equivalent circuit of the lines can be simplified, see figure 113.
Page 212 Section 7 1MRK 504 152-UEN B Impedance protection If the current on the parallel line has negative sign compared to the current on the protected line, that is, the current on the parallel line has an opposite direction compared to the current on the protected line, the distance function will overreach.
Page 213 1MRK 504 152-UEN B Section 7 Impedance protection Z< Z< IEC09000251_1_en.vsd IEC09000251 V1 EN-US Figure 114: The parallel line is out of service and earthed When the parallel line is out of service and earthed at both line ends on the bus bar side of the line CTs so that zero sequence current can flow on the parallel line, the equivalent zero sequence circuit of the parallel lines will be according to figure 115.
Page 214 Section 7 1MRK 504 152-UEN B Impedance protection Parallel line out of service and not earthed M17048-537 v5 Z< Z< IEC09000254_1_en.vsd IEC09000254 V1 EN-US Figure 116: Parallel line is out of service and not earthed When the parallel line is out of service and not earthed, the zero sequence on that line can only flow through the line admittance to the earth.
Page 215: Tapped Line Application
1MRK 504 152-UEN B Section 7 Impedance protection ⋅         (Equation 137) EQUATION1287 V3 EN-US The imaginary component of the same factor is equal to equation 138. × é ù é ù ë û...
Page 216 Section 7 1MRK 504 152-UEN B Impedance protection     ⋅  ⋅        (Equation 140) DOCUMENT11524-IMG3510 V3 EN-US Where: and Z is the line impedance from the A respective C station to the T point. and I is fault current from A respective C station for fault between T and B.
Page 217: Setting Guidelines
1MRK 504 152-UEN B Section 7 Impedance protection RFPE and phase-to-phase In practice, the setting of fault resistance for both phase-to-earth RFPP should be as high as possible without interfering with the load impedance in order to obtain reliable fault detection. However for zone1 it is necessary to limit the reach according to setting instructions in order to avoid overreach.
Page 218: Setting Of Reverse Zone
Section 7 1MRK 504 152-UEN B Impedance protection • The impedance corresponding to the protected line, plus the first zone reach of the shortest adjacent line. • The impedance corresponding to the protected line, plus the impedance of the maximum number of transformers operating in parallel on the bus at the remote end of the protected line.
Page 219: Setting Of Zones For Parallel Line Application
1MRK 504 152-UEN B Section 7 Impedance protection In many applications it might be necessary to consider the enlarging factor due to fault current infeed from adjacent lines in the reverse direction in order to obtain certain sensitivity. 7.3.3.5 Setting of zones for parallel line application SEMOD55087-50 v2 Parallel line in service –...
Page 220: Setting Of Reach In Resistive Direction
Section 7 1MRK 504 152-UEN B Impedance protection æ ö × ç ------------------------- - ÷ è ø (Equation 149) EQUATION561 V1 EN-US æ ö × ------------------------- - ç – ÷ è ø (Equation 150) EQUATION562 V1 EN-US 7.3.3.6 Setting of reach in resistive direction SEMOD55087-84 v7 R1 independently for each zone.
Page 221 1MRK 504 152-UEN B Section 7 Impedance protection ensure that there is a sufficient setting margin between the boundary and the minimum load impedance. The minimum load impedance (Ω/phase) is calculated as: ------ - loadmin (Equation 155) EQUATION571 V1 EN-US Where: is the minimum phase-to-phase voltage in kV is the maximum apparent power in MVA.
Page 222: Load Impedance Limitation, With Phase Selection With Load Encroachment, Quadrilateral Characteristic Function Activated
Section 7 1MRK 504 152-UEN B Impedance protection ≤ 1 6 . ⋅ RFFwPE load (Equation 159) IEC13000275 V1 EN-US Equation is applicable only when the loop characteristic angle for the phase-to-phase faults is more than three times as large as the maximum expected load-impedance angle. More accurate calculations are necessary according to equation 160.
Page 223 1MRK 504 152-UEN B Section 7 Impedance protection × × < < ArgDir L L M ArgNeg (Equation 162) EQUATION726 V2 EN-US where: ArgDir is the setting for the lower boundary of the forward directional characteristic, by default set to 15 (= -15 degrees) and ArgNegRes is the setting for the upper boundary of the forward directional characteristic, by default set to...
Page 224: Setting Of Timers For Distance Protection Zones
Section 7 1MRK 504 152-UEN B Impedance protection ArgNegRes ArgDir en05000722.vsd IEC05000722 V1 EN-US Figure 120: Setting angles for discrimination of forward and reverse fault in Directional impedance quadrilateral function ZDRDIR The reverse directional characteristic is equal to the forward characteristic rotated by 180 degrees.
Page 225: Full-Scheme Distance Measuring, Mho Characteristic Zmhpdis
1MRK 504 152-UEN B Section 7 Impedance protection Full-scheme distance measuring, Mho characteristic ZMHPDIS SEMOD154227-1 v4 7.4.1 Identification SEMOD154447-2 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE identification identification C37.2 device number Full-scheme distance protection, ZMHPDIS mho characteristic S00346 V1 EN-US 7.4.2 Application SEMOD154444-1 v1...
Page 226: Settings
Section 7 1MRK 504 152-UEN B Impedance protection IEC10000101 V3 EN-US Figure 121: Mho function example configuration for generator protection application 7.4.3.2 Settings GUID-53D13CBF-02DD-40EE-B579-5DFA16144C20 v3 Full-scheme distance measuring, Mho characteristic ZMHPDIS used as an under-impedance function shall be set for the application example shown in figure Application manual...
Page 227 1MRK 504 152-UEN B Section 7 Impedance protection HV Substation HV CB 65MVA Step-up 123/13kV Transformer =10% Auxiliary Transformer Generator CB REG670 Excitation Transformer VT: 13,5kV/110V 70MVA 13,2kV 3062A CT: 4000/5 Z< ZMH PDIS IEC10000102 V1 EN-US Figure 122: Application example for generator under-impedance function The first under-impedance protection zone shall cover 100% of the step-up transformer impedance with a time delay of 1.0s.
Page 228 Section 7 1MRK 504 152-UEN B Impedance protection Set the first zone of Full-scheme distance measuring, Mho characteristic ZMHPDIS to disable phase-to-earth loops and enable phase-to-phase loops: • Generator rated phase current and phase-phase voltage quantities shall be set for base UBase =13,2kV) and base current ( IBase =3062A) settings.
Page 229: Full-Scheme Distance Protection, Quadrilateral For Earth Faults Zmmpdis, Zmmapdis
1MRK 504 152-UEN B Section 7 Impedance protection Full-scheme distance protection, quadrilateral for earth faults ZMMPDIS, ZMMAPDIS SEMOD154561-1 v2 7.5.1 Identification SEMOD154542-2 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Fullscheme distance protection, ZMMPDIS quadrilateral for earth faults (zone 1) S00346 V1 EN-US Fullscheme distance protection, ZMMAPDIS...
Page 230 Section 7 1MRK 504 152-UEN B Impedance protection very limited influence on the earth fault current. The shunt admittance may, however, have some marginal influence on the earth fault current in networks with long transmission lines. The earth fault current at single phase-to-earth in phase L1 can be calculated as equation163: ×...
Page 231 1MRK 504 152-UEN B Section 7 Impedance protection £ (Equation 166) EQUATION1270 V4 EN-US The magnitude of the earth fault current in effectively earthed networks is high enough for impedance measuring element to detect fault. However, in the same way as for solid earthed networks, distance protection has limited possibilities to detect high resistance faults and should therefore always be complemented with other protection function(s) that can carry out the fault clearance in this case.
Page 232: Fault Infeed From Remote End
Section 7 1MRK 504 152-UEN B Impedance protection IEC05000216 V2 EN-US Figure 125: High impedance earthing network The operation of high impedance earthed networks is different compare to solid earthed networks where all major faults have to be cleared very fast. In high impedance earthed networks, some system operators do not clear single phase-to-earth faults immediately;...
Page 233: Load Encroachment
1MRK 504 152-UEN B Section 7 Impedance protection p*ZL (1-p)*ZL Z < Z < en05000217.vsd IEC05000217 V1 EN-US Figure 126: Influence of fault infeed from remote end. The effect of fault current infeed from remote end is one of the most driving factors for justify complementary protection to distance protection.
Page 234: Short Line Application
Section 7 1MRK 504 152-UEN B Impedance protection Load impedance ARGLd ARGLd area in forward direction ARGLd ARGLd RLdRv RLdFw en05000495.vsd IEC05000495 V1 EN-US Figure 127: Load encroachment phenomena and shaped load encroachment characteristic 7.5.2.5 Short line application SEMOD154680-105 v2 In short line applications, the major concern is to get sufficient fault resistance coverage.
Page 235: Parallel Line Application With Mutual Coupling
1MRK 504 152-UEN B Section 7 Impedance protection Table 26: Definition of long lines Line category 110 kV 500 kV Long lines 77 km - 99 km 350 km - 450 km Very long lines > 99 km > 450 km As mentioned in the previous chapter, the possibility in IED to set resistive and reactive reach independent for positive and zero sequence fault loops and individual fault resistance settings for phase-to-phase and phase-to-earth fault together with load encroachment algorithm...
Page 236 Section 7 1MRK 504 152-UEN B Impedance protection Most multi circuit lines have two parallel operating circuits. The application guide mentioned below recommends in more detail the setting practice for this particular type of line. The basic principles also apply to other multi circuit lines. Parallel line applications SEMOD154680-168 v2 This type of networks are defined as those networks where the parallel transmission lines...
Page 237 1MRK 504 152-UEN B Section 7 Impedance protection Z0 m 99000038.vsd IEC99000038 V1 EN-US Figure 129: Equivalent zero sequence impedance circuit of the double-circuit, parallel, operating line with a single phase-to-earth fault at the remote busbar When mutual coupling is introduced, the voltage at the IED point A will be changed. If the current on the parallel line have negative sign compare to the current on the protected line that is, the current on the parallel line has an opposite direction compare to the current on the protected line, the distance function will overreach.
Page 238 Section 7 1MRK 504 152-UEN B Impedance protection Z m0 99000039.vsd DOCUMENT11520-IMG7100 V1 EN-US Figure 131: Equivalent zero-sequence impedance circuit for the double-circuit line that operates with one circuit disconnected and earthed at both ends. Here the equivalent zero sequence impedance is equal to Z0-Z0m in parallel with (Z0- Z0m)/Z0-Z0m+Z0m which is equal to equation 172.
Page 239 1MRK 504 152-UEN B Section 7 Impedance protection When the parallel line is out of service and not earthed, the zero sequence on that line can only flow through the line admittance to the earth. The line admittance is high which limits the zero sequence current on the parallel line to very low values.
Page 240: Tapped Line Application
Section 7 1MRK 504 152-UEN B Impedance protection × é ù é ù ë û ë û (Equation 179) EQUATION1288 V2 EN-US Ensure that the underreaching zones from both line ends will overlap a sufficient amount (at least 10%) in the middle of the protected circuit. 7.5.2.8 Tapped line application SEMOD154680-265 v1...
Page 241 1MRK 504 152-UEN B Section 7 Impedance protection Where: ZAT and ZCT is the line impedance from the B respective C station to the T point. IA and IC is fault current from A respective C station for fault between T and B. U2/U1 Transformation ratio for transformation of impedance at U1 side of the transformer to the measuring side U2 (it is assumed that current and voltage...
Page 242: Setting Guidelines
Section 7 1MRK 504 152-UEN B Impedance protection 7.5.3 Setting guidelines SEMOD154701-1 v1 7.5.3.1 General SEMOD154704-4 v2 The settings for the Full-scheme distance protection, quadrilateral for earth faults (ZMMPDIS) function are done in primary values. The instrument transformer ratio that has been set for the analogue input card is used to automatically convert the measured secondary input signals to primary values used in ZMMPDIS function.
Page 243: Setting Of Reverse Zone
1MRK 504 152-UEN B Section 7 Impedance protection faults. The zone2 must not be reduced below 120% of the protected line section. The whole line must be covered under all conditions. The requirement that the zone 2 shall not reach more than 80% of the shortest adjacent line at remote end is highlighted wit a simple example below.
Page 244 Section 7 1MRK 504 152-UEN B Impedance protection Parallel line in service – Setting of zone1 SEMOD154704-50 v1 With reference to section "Parallel line applications", the zone reach can be set to 85% of protected line. Parallel line in service – setting of zone2 SEMOD154704-53 v2 Overreaching zones (in general, zones 2 and 3) must overreach the protected circuit in all cases.
Page 245: Setting Of Reach In Resistive Direction
1MRK 504 152-UEN B Section 7 Impedance protection æ ö × ------------------------- - ç – ÷ è ø (Equation 191) EQUATION562 V1 EN-US 7.5.3.6 Setting of reach in resistive direction SEMOD154704-76 v1 RIPE ) Set the resistive reach independently for each zone, for phase-to-earth loop ( measurement.
Page 246: Load Impedance Limitation, With Load Encroachment Function Activated
Section 7 1MRK 504 152-UEN B Impedance protection --------------------- - load × (Equation 196) EQUATION574 V1 EN-US Minimum voltage U and maximum current Imax are related to the same operating conditions. Minimum load impedance occurs normally under emergency conditions. Because a safety margin is required to avoid load encroachment under three- phase conditions and to guarantee correct healthy phase IED operation under combined heavy three-phase load and earth faults, consider both: phase-to- phase and phase-to-earth fault operating characteristics.
Page 247: Setting Of Timers For Distance Protection Zones
1MRK 504 152-UEN B Section 7 Impedance protection sensitivity by reducing the minimum operating current down to 10% of the IED base current. This happens especially in cases, when the IED serves as a remote back-up protection on series of very long transmission lines. IMinOpIN that will If the load current compensation is activated, there is an additional criteria IMinOpIN .
Page 248 Section 7 1MRK 504 152-UEN B Impedance protection • Zero-sequence voltage polarized (-U • Negative-sequence voltage polarized (-U2) • Zero-sequence current (I • Dual polarization (-U • Zero-sequence voltage with zero-sequence current compensation (-U0Comp) • Negative-sequence voltage with negative-sequence current compensation (-U2Comp) The zero-sequence voltage polarized earth directional unit compares the phase angles of zero sequence current I with zero sequence voltage -U...
Page 249: Mho Impedance Supervision Logic Zsmgapc
1MRK 504 152-UEN B Section 7 Impedance protection difference must exist in the magnitudes of the zero sequence currents for close-up forward and reverse faults, that is, it is a requirement that |U0| >> |k · I0| for reverse faults, otherwise there is a risk that reverse faults can be seen as forward.
Page 250: Setting Guidelines
Section 7 1MRK 504 152-UEN B Impedance protection 7.7.3 Setting guidelines SEMOD174968-1 v1 SEMOD154558-7 v4 GlobalBaseSel : Selects the global base value group used by the function to define ( IBase ), UBase ) and ( SBase ). PilotMode : Set PilotMode to On when pilot scheme is to be used. In this mode fault inception function will send a block signal to remote end to block the overreaching zones, when operated.
Page 251: Setting Guidelines
1MRK 504 152-UEN B Section 7 Impedance protection The heavy load transfer that is common in many transmission networks may in some cases be in opposite to the wanted fault resistance coverage. Therefore, FMPSPDIS has an built-in algorithm for load encroachment, which gives the possibility to enlarge the resistive setting of both the Phase selection with load encroachment and the measuring zones without interfering with the load.
Page 252: Load Encroachment
Section 7 1MRK 504 152-UEN B Impedance protection ILoad × ULmn (Equation 202) EQUATION1615 V1 EN-US where: Smax is the maximal apparent power transfer during emergency conditions and ULmn is the phase-to-phase voltage during the emergency conditions at the IED location. 7.8.3.1 Load encroachment SEMOD154782-39 v4...
Page 253: Distance Protection Zone, Quadrilateral Characteristic, Separate Settings Zmrpdis, Zmrapdis And Zdrdir
1MRK 504 152-UEN B Section 7 Impedance protection æ ö ArgLd ç ÷ è ø (Equation 205) EQUATION1623 V1 EN-US where: Pmax is the maximal active power transfer during emergency conditions and Smax is the maximal apparent power transfer during emergency conditions. RLd can be calculated according to equation 206: ×...
Page 254: System Earthing
Section 7 1MRK 504 152-UEN B Impedance protection The distance protection function in the IED is designed to meet basic requirements for application on transmission and sub-transmission lines although it also can be used on distribution levels. 7.9.2.1 System earthing GUID-AA9E698B-D0B5-45FC-ABA5-6A2CD988E16D v1 The type of system earthing plays an important role when designing the protection system.
Page 255 1MRK 504 152-UEN B Section 7 Impedance protection Effectively earthed networks GUID-5F4CCC18-2BAC-4140-B56C-B9002CD36318 v1 A network is defined as effectively earthed if the earth-fault factor f is less than 1.4. The earth- fault factor is defined according to equation 208. (Equation 208) EQUATION1268 V4 EN-US Where: is the highest fundamental frequency voltage on one of the healthy phases at single...
Page 256: Fault Infeed From Remote End
Section 7 1MRK 504 152-UEN B Impedance protection (Equation 211) EQUATION1271 V3 EN-US Where: is the earth-fault current (A) is the current through the neutral point resistor (A) is the current through the neutral point reactor (A) is the total capacitive earth-fault current (A) The neutral point reactor is normally designed so that it can be tuned to a position where the reactive current balances the capacitive current from the network that is: ×...
Page 257: Load Encroachment
1MRK 504 152-UEN B Section 7 Impedance protection × × × I p Z (Equation 213) EQUATION1273 V1 EN-US If we divide U by I we get Z present to the IED at A side. × × (Equation 214) EQUATION1274 V2 EN-US The infeed factor (I can be very high, 10-20 depending on the differences in source impedances at local and remote end.
Page 258: Short Line Application
Section 7 1MRK 504 152-UEN B Impedance protection The use of the load encroachment feature is essential for long heavy loaded lines, where there might be a conflict between the necessary emergency load transfer and necessary sensitivity of the distance protection. The function can also preferably be used on heavy loaded medium long lines.
Page 259: Long Transmission Line Application
1MRK 504 152-UEN B Section 7 Impedance protection 7.9.2.5 Long transmission line application GUID-40F06841-F192-4159-87BA-7BC7E4B014AA v1 For long transmission lines, the margin to the load impedance, that is, to avoid load encroachment, will normally be a major concern. It is well known that it is difficult to achieve high sensitivity for phase-to-earth fault at remote line end of a long line when the line is heavy loaded.
Page 260 Section 7 1MRK 504 152-UEN B Impedance protection The reach of the distance protection zone 1 will be different depending on the operation condition of the parallel line. This can be handled by the use of different setting groups for handling the cases when the parallel line is in operation and out of service and earthed at both ends.
Page 261 1MRK 504 152-UEN B Section 7 Impedance protection Z< Z< IEC09000250_1_en.vsd IEC09000250 V1 EN-US Figure 141: Class 1, parallel line in service. The equivalent zero sequence circuit of the lines can be simplified, see figure 142. IEC09000253_1_en.vsd IEC09000253 V1 EN-US Figure 142: Equivalent zero sequence impedance circuit of the double-circuit, parallel, operating line with a single phase-to-earth fault at the remote busbar.
Page 262 Section 7 1MRK 504 152-UEN B Impedance protection × × × p Z1 I K 3I (Equation 218) EQUATION2313 V1 EN-US One can also notice that the following relationship exists between the zero sequence currents: ⋅ ⋅ − (Equation 219) EQUATION1279 V3 EN-US Simplification of equation 219, solving it for 3I0p and substitution of the result into equation gives that the voltage can be drawn as:...
Page 263 1MRK 504 152-UEN B Section 7 Impedance protection IEC09000252_1_en.vsd IEC09000252 V1 EN-US Figure 144: Equivalent zero sequence impedance circuit for the double-circuit line that operates with one circuit disconnected and earthed at both ends. Here the equivalent zero sequence impedance is equal to Z m in parallel with (Z which is equal to equation 222.
Page 264: Tapped Line Application
Section 7 1MRK 504 152-UEN B Impedance protection sequence impedance circuit for faults at the remote bus bar can be simplified to the circuit shown in figure The line zero sequence mutual impedance does not influence the measurement of the distance protection in a faulty circuit.
Page 265 1MRK 504 152-UEN B Section 7 Impedance protection     ⋅  ⋅        (Equation 226) DOCUMENT11524-IMG3510 V3 EN-US Where: and Z is the line impedance from the A respective C station to the T point. and I is fault current from A respective C station for fault between T and B.
Page 266: Setting Guidelines
Section 7 1MRK 504 152-UEN B Impedance protection RFPE and phase-to-phase In practice, the setting of fault resistance for both phase-to-earth RFPP should be as high as possible without interfering with the load impedance in order to obtain reliable fault detection. 7.9.3 Setting guidelines IP14962-1 v1...
Page 267: Setting Of Reverse Zone
1MRK 504 152-UEN B Section 7 Impedance protection Larger overreach than the mentioned 80% can often be acceptable due to fault current infeed from other lines. This requires however analysis by means of fault calculations. If any of the above indicates a zone 2 reach less than 120%, the time delay of zone 2 must be increased by approximately 200ms to avoid unwanted operation in cases when the telecommunication for the short adjacent line at remote end is down during faults.
Page 268: Setting Of Zones For Parallel Line Application
Section 7 1MRK 504 152-UEN B Impedance protection 7.9.3.5 Setting of zones for parallel line application SEMOD55087-50 v2 Parallel line in service – Setting of zone 1 GUID-F10BF2FF-7B0F-40B0-877B-081E1D5B067B v1 With reference to section "Parallel line applications", the zone reach can be set to 85% of protected line.
Page 269: Setting Of Reach In Resistive Direction
1MRK 504 152-UEN B Section 7 Impedance protection æ ö × ç ------------------------- - ÷ è ø (Equation 235) EQUATION561 V1 EN-US æ ö × ------------------------- - ç – ÷ è ø (Equation 236) EQUATION562 V1 EN-US 7.9.3.6 Setting of reach in resistive direction GUID-3BFE80FD-8A51-4B71-8762-73DFA73AB28B v2 Set the resistive independently for each zone.
Page 270 Section 7 1MRK 504 152-UEN B Impedance protection reach for any zone to ensure that there is a sufficient setting margin between the boundary and the minimum load impedance. The minimum load impedance (Ω/phase) is calculated as: ------ - loadmin (Equation 241) EQUATION571 V1 EN-US Where:...
Page 271: Load Impedance Limitation, With Phase Selection With Load Encroachment, Quadrilateral Characteristic Function Activated
1MRK 504 152-UEN B Section 7 Impedance protection £ × RFPP 1.6 Z load (Equation 245) EQUATION579 V2 EN-US Equation is applicable only when the loop characteristic angle for the phase-to-phase faults is more than three times as large as the maximum expected load-impedance angle. More accurate calculations are necessary according to equation 246.
Page 272: Phase Selection, Quadrilateral Characteristic With Settable Angle Frpspdis
Section 7 1MRK 504 152-UEN B Impedance protection tPP measuring loops in each distance protection zone separately, to further phase-to-phase increase the total flexibility of a distance protection. 7.10 Phase selection, quadrilateral characteristic with settable angle FRPSPDIS GUID-29E9C424-5AF7-40EE-89D9-F6BB4F0A0836 v2 7.10.1 Identification GUID-07DB9506-656C-4E5F-A043-3DAA624313C7 v2 Function description...
Page 273 1MRK 504 152-UEN B Section 7 Impedance protection RLdFw ARGLd ARGLd ARGLd ARGLd RLdRv en05000196.vsd IEC05000196 V1 EN-US Figure 149: Characteristic of load encroachment function The influence of load encroachment function on the operation characteristic is dependent on the chosen operation mode of the FRPSPDIS function. When output signal STCNDZis selected, the characteristic for the FRPSPDIS (and also zone measurement depending on settings) can be reduced by the load encroachment characteristic (as shown in figure 150).
Page 274 Section 7 1MRK 504 152-UEN B Impedance protection "Phase selection" "quadrilateral" zone Distance measuring zone Load encroachment characteristic Directional line en05000673.vsd IEC05000673 V1 EN-US Figure 151: Operation characteristic in forward direction when load encroachment is enabled Figure is valid for phase-to-earth. During a three-phase fault, or load, when the "quadrilateral"...
Page 275 1MRK 504 152-UEN B Section 7 Impedance protection (ohm/phase) Phase selection ”Quadrilateral” zone Distance measuring zone (ohm/phase) en05000674.vsd IEC05000674 V1 EN-US Figure 152: Operation characteristic for FRPSPDIS in forward direction for three-phase fault, ohm/phase domain The result from rotation of the load characteristic at a fault between two phases is presented in fig 153.
Page 276: Load Encroachment Characteristics
Section 7 1MRK 504 152-UEN B Impedance protection IEC08000437.vsd IEC08000437 V1 EN-US Figure 153: Rotation of load characteristic for a fault between two phases This rotation may seem a bit awkward, but there is a gain in selectivity by using the same measurement as for the quadrilateral characteristic since not all phase-to-phase loops will be fully affected by a fault between two phases.
Page 277: Phase-To-Earth Fault In Forward Direction
1MRK 504 152-UEN B Section 7 Impedance protection resistance coverage can be derived from trigonometric evaluation of the basic characteristic for respectively fault type. The following setting guideline considers normal overhead lines applications and provides two different setting alternatives: A recommended characteristic angle of 60 degrees for the phase selection A characteristic angle of 90 and 70 degrees for phase-to-earth and phase-to-phase respectively, like...
Page 278: Phase-To-Earth Fault In Reverse Direction
Section 7 1MRK 504 152-UEN B Impedance protection Reactive reach GUID-8C693495-10FA-47D5-BEFC-E72C8577E88B v1 The reactive reach in forward direction must as minimum be set to cover the measuring zone used in the Teleprotection schemes, mostly zone 2. Equation and equation gives the minimum recommended reactive reach.
Page 279: Phase-To-Phase Fault In Forward Direction
1MRK 504 152-UEN B Section 7 Impedance protection Resistive reach M13142-156 v4 The resistive reach in reverse direction must be set longer than the longest reverse zones. In blocking schemes it must be set longer than the overreaching zone at remote end that is used in the communication scheme.
Page 280: Setting Guidelines
Section 7 1MRK 504 152-UEN B Impedance protection phase R1PP= tan 70° 0 × RFRvPP 0 × RFFwPP 0.5*RFPP 0.5*RFPP phase 0.5*RFPP 0.5*RFPP 0.5*RFPP 0.5*RFPP 0 × RFRvPP R1PP= tan 70° en08000249.vsd IEC08000249 V1 EN-US Figure 155: Relation between measuring zone and FRPSPDIS characteristic for phase-to- phase fault for φline>70°...
Page 281: Minimum Operate Currents
1MRK 504 152-UEN B Section 7 Impedance protection RLdFw ArgLd ArgLd ArgLd ArgLd RLdRv IEC09000050-1-en.vsd IEC09000050 V1 EN-US Figure 156: Load encroachment characteristic ArgLd is the same in forward and reverse direction, so it could be suitable to The load angle begin to calculate the setting for that parameter.
Page 282: Phase Selection, Quadrilateral Characteristic With Fixed Angle Fdpspdis
Section 7 1MRK 504 152-UEN B Impedance protection 7.11 Phase selection, quadrilateral characteristic with fixed angle FDPSPDIS IP12400-1 v3 7.11.1 Identification 7.11.1.1 Identification M14850-1 v5 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Phase selection with load FDPSPDIS encroachment, quadrilateral characteristic...
Page 283 1MRK 504 152-UEN B Section 7 Impedance protection In some applications, for instance cable lines, the angle of the loop might be less than 60°. In these applications, the settings of fault resistance coverage in forward and reverse direction, RFFwPE and RFRvPE for phase-to-earth faults and RFFwPP and RFRvPP for phase-to-phase faults have to be increased to avoid that FDPSPDIS characteristic shall cut off some part of the zone characteristic.
Page 284 Section 7 1MRK 504 152-UEN B Impedance protection ( / loop) 60° 60° ( / loop) IEC09000043_1_en.vsd IEC09000043 V1 EN-US Figure 157: Relation between distance protection phase selection (FDPSPDIS) and impedance zone (ZMQPDIS) for phase-to-earth fault φloop>60° (setting parameters in italic) FDPSPDIS (phase selection)(red line) 2 ZMQPDIS (Impedance protection zone) RFltRevPG...
Page 285 1MRK 504 152-UEN B Section 7 Impedance protection ³ × 1.44 X0 (Equation 259) EQUATION1310 V1 EN-US where: is the reactive reach for the zone to be covered by FDPSPDIS, and the constant 1.44 is a safety margin is the zero-sequence reactive reach for the zone to be covered by FDPSPDIS The reactive reach in reverse direction is automatically set to the same reach as for forward direction.
Page 286 Section 7 1MRK 504 152-UEN B Impedance protection Fault resistance reach M13142-176 v7 The fault resistance reaches in forward direction RFFwPP , must cover RFPP with at least 25% margin. RFPP is the setting of fault resistance for phase-to-phase fault for the longest overreaching zone to be covered by FDPSPDIS, see Figure 158.
Page 287 1MRK 504 152-UEN B Section 7 Impedance protection ( / phase) 60° 60° ( / phase) IEC09000257_1_en.vsd IEC09000257 V1 EN-US Figure 158: Relation between distance protection (ZMQPDIS) and FDPSPDIS characteristic for phase-to-phase fault for φline>60° (setting parameters in italic) FDPSPDIS (phase selection) (red line) 2 ZMQPDIS (Impedance protection zone) RFRvPP 3 0.5 ·...
Page 288: Resistive Reach With Load Encroachment Characteristic
Section 7 1MRK 504 152-UEN B Impedance protection 7.11.3.2 Resistive reach with load encroachment characteristic M13142-312 v4 The procedure for calculating the settings for the load encroachment consist basically to ArgLd , the blinder RLdFw in forward direction and blinder RLdRv in define the load angle reverse direction, as shown in figure 159.
Page 289: High Speed Distance Protection Zmfpdis
1MRK 504 152-UEN B Section 7 Impedance protection 7.12 High speed distance protection ZMFPDIS GUID-CC4F7338-2281-411D-B55A-67BF03F31681 v3 7.12.1 Identification GUID-8ACD3565-C607-4399-89D2-A05657840E6D v3 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number High speed distance protection zone ZMFPDIS S00346 V1 EN-US 7.12.2 Application IP14961-1 v2...
Page 290 Section 7 1MRK 504 152-UEN B Impedance protection Where: is the phase-to-earth voltage (kV) in the faulty phase before fault is the positive sequence impedance (Ω/phase) is the negative sequence impedance (Ω/phase) is the zero sequence impedance (Ω/phase) is the fault impedance (Ω), often resistive is the earth-return impedance defined as (Z The high zero-sequence current in solidly earthed networks makes it possible to use impedance measuring techniques to detect earth faults.
Page 291 1MRK 504 152-UEN B Section 7 Impedance protection earthed networks, distance protection has limited possibilities to detect high resistance faults and should therefore always be complemented with other protection function(s) that can carry out the fault clearance in this case. High impedance earthed networks GUID-02F306F5-1038-42AC-AFAE-3F8423C4C066 v4 In high impedance networks, the neutral of the system transformers are connected to the...
Page 292: Fault Infeed From Remote End
Section 7 1MRK 504 152-UEN B Impedance protection In this type of network, it is mostly not possible to use distance protection for detection and clearance of earth faults. The low magnitude of the earth-fault current might not give start of the zero-sequence measurement elements or the sensitivity will be too low for acceptance.
Page 293: Load Encroachment
1MRK 504 152-UEN B Section 7 Impedance protection 7.12.2.3 Load encroachment GUID-6785BF05-2775-4422-8077-A663D01C6C07 v4 In some cases the measured load impedance might enter the set zone characteristic without any fault on the protected line. This phenomenon is called load encroachment and it might occur when an external fault is cleared and high emergency load is transferred onto the protected line.
Page 294: Long Transmission Line Application
Section 7 1MRK 504 152-UEN B Impedance protection Table 29: Definition of short and very short line Line category 110 kV 500 kV Very short line 1.1-5.5 km 5-25 km Short line 5.5-11 km 25-50 km The IED's ability to set resistive and reactive reach independent for positive and zero sequence fault loops and individual fault resistance settings for phase-to-phase and phase-to-earth fault together with load encroachment algorithm improves the possibility to detect high resistive faults without conflict with the load impedance.
Page 295 1MRK 504 152-UEN B Section 7 Impedance protection From an application point of view there exists three types of network configurations (classes) that must be considered when making the settings for the protection function. The different network configuration classes are: Parallel line with common positive and zero sequence network Parallel circuits with common positive but isolated zero sequence network Parallel circuits with positive and zero sequence sources isolated.
Page 296 Section 7 1MRK 504 152-UEN B Impedance protection Where: is phase to earth voltage at the relay point is phase current in the faulty phase is earth fault current is positive sequence impedance is zero sequence impedance Z< Z< IEC09000250_1_en.vsd IEC09000250 V1 EN-US Figure 164: Class 1, parallel line in service The equivalent circuit of the lines can be simplified, see figure 165.
Page 297 1MRK 504 152-UEN B Section 7 Impedance protection If the current on the parallel line has negative sign compared to the current on the protected line, that is, the current on the parallel line has an opposite direction compared to the current on the protected line, the distance function will overreach.
Page 298 Section 7 1MRK 504 152-UEN B Impedance protection Z< Z< IEC09000251_1_en.vsd IEC09000251 V1 EN-US Figure 166: The parallel line is out of service and earthed When the parallel line is out of service and earthed at both line ends on the bus bar side of the line CTs so that zero sequence current can flow on the parallel line, the equivalent zero sequence circuit of the parallel lines will be according to figure 167.
Page 299 1MRK 504 152-UEN B Section 7 Impedance protection Parallel line out of service and not earthed GUID-949669D3-8B9F-4ECA-8F09-52A783A494E1 v2 Z< Z< IEC09000254_1_en.vsd IEC09000254 V1 EN-US Figure 168: Parallel line is out of service and not earthed When the parallel line is out of service and not earthed, the zero sequence on that line can only flow through the line admittance to the earth.
Page 300: Tapped Line Application
Section 7 1MRK 504 152-UEN B Impedance protection ⋅         (Equation 286) EQUATION1287 V3 EN-US The imaginary component of the same factor is equal to equation 287. × é ù é ù ë û...
Page 301 1MRK 504 152-UEN B Section 7 Impedance protection     ⋅  ⋅        (Equation 289) DOCUMENT11524-IMG3510 V3 EN-US Where: and Z is the line impedance from the A respective C station to the T point. and I is fault current from A respective C station for fault between T and B.
Page 302: Setting Guidelines
Section 7 1MRK 504 152-UEN B Impedance protection RFPE and phase-to-phase In practice, the setting of fault resistance for both phase-to-earth RFPP should be as high as possible without interfering with the load impedance in order to obtain reliable fault detection. 7.12.3 Setting guidelines IP14962-1 v1...
Page 303: Setting Of Reverse Zone
1MRK 504 152-UEN B Section 7 Impedance protection Larger overreach than the mentioned 80% can often be acceptable due to fault current infeed from other lines. This requires however analysis by means of fault calculations. If any of the above gives a zone 2 reach less than 120%, the time delay of zone 2 must be increased by approximately 200ms to avoid unwanted operation in cases when the telecommunication for the short adjacent line at remote end is down during faults.
Page 304: Setting Of Zones For Parallel Line Application
Section 7 1MRK 504 152-UEN B Impedance protection 7.12.3.5 Setting of zones for parallel line application GUID-4E0C3824-41B6-410F-A10E-AB9C3BFE9B12 v1 Parallel line in service – Setting of zone 1 GUID-8A62367C-2636-4EC1-90FF-397A51F586F7 v1 With reference to section "Parallel line applications", the zone reach can be set to 85% of the protected line.
Page 305: Setting The Reach With Respect To Load
1MRK 504 152-UEN B Section 7 Impedance protection æ ö × ç ------------------------- - ÷ è ø (Equation 298) EQUATION561 V1 EN-US æ ö × ------------------------- - ç – ÷ è ø (Equation 299) EQUATION562 V1 EN-US 7.12.3.6 Setting the reach with respect to load GUID-ED84BDE6-16CD-45ED-A45D-5CFB828A9040 v4 RFPP and for the phase- Set separately the expected fault resistance for phase-to-phase faults...
Page 306: Zone Reach Setting Lower Than Minimum Load Impedance
Section 7 1MRK 504 152-UEN B Impedance protection phase faults, this means per-phase, or positive-sequence, impedance. During a phase-to-earth fault, it means the per-loop impedance, including the earth return impedance. 7.12.3.7 Zone reach setting lower than minimum load impedance GUID-68C336F4-5285-4167-B3F8-B0963BD85439 v4 Even if the resistive reach of all protection zones is set lower than the lowest expected load RLdFw , RLdRv impedance and there is no risk for load encroachment, it is still necessary to set...
Page 307: Zone Reach Setting Higher Than Minimum Load Impedance
1MRK 504 152-UEN B Section 7 Impedance protection é × ù £ × × × RFPE ê ú ë û load × (Equation 307) EQUATION578 V4 EN-US Where: ∂ is a maximum load-impedance angle, related to the maximum load power. To avoid load encroachment for the phase-to-phase measuring elements, the set resistive reach of any distance protection zone must be less than 160% of the minimum load impedance.
Page 308: Other Settings
Section 7 1MRK 504 152-UEN B Impedance protection this corresponds to the per-phase, or positive-sequence, impedance. For a phase-to-earth fault, it corresponds to the per-loop impedance, including the earth return impedance. RLdFw RLdFw ARGLd ARGLd ARGLd ARGLd ArgLd Possible ARGLd load ARGLd RLdRv...
Page 309 1MRK 504 152-UEN B Section 7 Impedance protection This setting defines the operating direction for zones Z3, Z4 and Z5 (the directionality of zones Z1, Z2 and ZRV is fixed). The options are Non-directional , Forward or Reverse . The result from respective set value is illustrated in Figure 173, where the positive impedance corresponds to...
Page 310 Section 7 1MRK 504 152-UEN B Impedance protection TimerModeZx = Enable Ph-Ph, Ph-E PPZx tPPZx PEZx tPEZx BLOCK VTSZ BLKZx BLKTRZx TimerLinksZx LoopLink (tPP-tPE) ZoneLinkStart LoopLink & ZoneLink No Links STPHS Phase Selection 1st starting zone LNKZ1 FALSE (0) LNKZ2 LNKZx LNKZRV LNKZ3...
Page 311: High Speed Distance Protection For Series Compensated Lines Zmfcpdis
1MRK 504 152-UEN B Section 7 Impedance protection leasePE × ³ × (Equation 312) EQUATION2548 V1 EN-US Where: INReleasePE the setting for the minimum residual current needed to enable operation in the phase-to- earth fault loops in % the maximum phase current in any of the three phases phmax By default, this setting is set excessively high to always enable phase-to-phase measurement for phase-to-phase-earth faults.
Page 312 Section 7 1MRK 504 152-UEN B Impedance protection Solidly earthed networks GUID-6870F6A8-EB28-47CF-AF26-7CE758BF934E v1 In solidly earthed systems, the transformer neutrals are connected directly to earth without any impedance between the transformer neutral and earth. IEC05000215 V2 EN-US Figure 175: Solidly earthed network The earth-fault current is as high or even higher than the short-circuit current.
Page 313: Fault Infeed From Remote End
1MRK 504 152-UEN B Section 7 Impedance protection Where: is the highest fundamental frequency voltage on one of the healthy phases at single phase-to-earth fault. is the phase-to-earth fundamental frequency voltage before fault. Another definition for effectively earthed network is when the following relationships between the symmetrical components of the network impedances are valid, see equations and 316: <...
Page 314: Load Encroachment
Section 7 1MRK 504 152-UEN B Impedance protection If we divide U by I we get Z present to the IED at A side: = p ·Z ·R (Equation 318) EQUATION1274-IEC-650 V1 EN-US The infeed factor (I can be very high, 10-20 depending on the differences in source impedances at local and remote end.
Page 315: Short Line Application
1MRK 504 152-UEN B Section 7 Impedance protection according to the expected maximum load since these settings are used internally in the function as reference points to improve the performance of the phase selection. Load impedance ArgLd area in forward direction RLdRv RLdFw...
Page 316: Parallel Line Application With Mutual Coupling
Section 7 1MRK 504 152-UEN B Impedance protection Table 32: Definition of long and very long lines Line category 110 kV 500 kV Long lines 77 km - 99 km 350 km - 450 km Very long lines > 99 km >...
Page 317 1MRK 504 152-UEN B Section 7 Impedance protection The different network configuration classes are: Parallel line with common positive and zero sequence network Parallel circuits with common positive but separated zero sequence network Parallel circuits with positive and zero sequence sources separated. One example of class 3 networks could be the mutual coupling between a 400 kV line and rail road overhead lines.
Page 318 Section 7 1MRK 504 152-UEN B Impedance protection Where: is phase to earth voltage at the relay point. is phase current in the faulty phase. is earth fault current. is positive sequence impedance. is zero sequence impedance. Z< Z< IEC09000250_1_en.vsd IEC09000250 V1 EN-US Figure 179: Class 1, parallel line in service The equivalent circuit of the lines can be simplified, see figure 180.
Page 319 1MRK 504 152-UEN B Section 7 Impedance protection If the current on the parallel line has negative sign compared to the current on the protected line, that is, the current on the parallel line has an opposite direction compared to the current on the protected line, the distance function will overreach.
Page 320 Section 7 1MRK 504 152-UEN B Impedance protection Z< Z< IEC09000251_1_en.vsd IEC09000251 V1 EN-US Figure 181: The parallel line is out of service and earthed When the parallel line is out of service and earthed at both line ends on the bus bar side of the line CTs so that zero sequence current can flow on the parallel line, the equivalent zero sequence circuit of the parallel lines will be according to figure 182.
Page 321 1MRK 504 152-UEN B Section 7 Impedance protection Parallel line out of service and not earthed GUID-DF8B0C63-E6D1-4E11-A8CB-D0C8EAE10FF0 v1 Z< Z< IEC09000254_1_en.vsd IEC09000254 V1 EN-US Figure 183: Parallel line is out of service and not earthed When the parallel line is out of service and not earthed, the zero sequence on that line can only flow through the line admittance to the earth.
Page 322: Tapped Line Application
Section 7 1MRK 504 152-UEN B Impedance protection ⋅         (Equation 332) EQUATION1287 V3 EN-US The imaginary component of the same factor is equal to equation 333. × é ù é ù ë û...
Page 323 1MRK 504 152-UEN B Section 7 Impedance protection     ⋅  ⋅        (Equation 335) DOCUMENT11524-IMG3510 V3 EN-US Where: and Z is the line impedance from the A respective C station to the T point. and I is fault current from A respective C station for fault between T and B.
Page 324: Series Compensation In Power Systems
Section 7 1MRK 504 152-UEN B Impedance protection RFPE and phase-to-phase In practice, the setting of fault resistance for both phase-to-earth RFPP should be as high as possible without interfering with the load impedance in order to obtain reliable fault detection. 7.13.3 Series compensation in power systems GUID-7F3BBF91-4A17-4B31-9828-F2757672C440 v2...
Page 325: Increase In Power Transfer
1MRK 504 152-UEN B Section 7 Impedance protection limit 1000 1200 1400 1600 1800 P[MW] en06000586.vsd IEC06000586 V1 EN-US Figure 187: Voltage profile for a simple radial power line with 0, 30, 50 and 70% of compensation 7.13.3.2 Increase in power transfer GUID-C9163D4E-CC2B-4645-B2AC-2C8A3FE3D337 v3 The increase in power transfer capability as a function of the degree of compensation for a transmission line can be explained by studying the circuit shown in figure 188.
Page 326: Voltage And Current Inversion
Section 7 1MRK 504 152-UEN B Impedance protection Multiple of power over a non-compensated line Power transfer with constant angle difference Degree of Degree of series compensation [%] compensation IEC06000592-2-en.vsd IEC06000592 V2 EN-US Figure 189: Increase in power transfer over a transmission line depending on degree of series compensation 7.13.3.3 Voltage and current inversion...
Page 327 1MRK 504 152-UEN B Section 7 Impedance protection With bypassed With inserted capacitor capacitor Source voltage Pre -fault voltage U’ Fault voltage Source Z< en06000605.vsd IEC06000605 V1 EN-US Figure 190: Voltage inversion on series compensated line With bypassed With inserted capacitor capacitor en06000606.vsd...
Page 328 Section 7 1MRK 504 152-UEN B Impedance protection Current inversion GUID-9F7FDF59-D0B4-4972-9CB0-B3D56DACA09E v1 Figure presents part of a series compensated line with corresponding equivalent voltage source. It is generally anticipated that fault current I flows on non-compensated lines from power source towards the fault F on the protected line. Series capacitor may change the situation.
Page 329 1MRK 504 152-UEN B Section 7 Impedance protection With bypassed With inserted capacitor capacitor en06000608.vsd IEC06000608 V1 EN-US Figure 193: Phasor diagrams of currents and voltages for the bypassed and inserted series capacitor during current inversion It is a common practice to call this phenomenon current inversion. Its consequences on operation of different protections in series compensated networks depend on their operating principle.
Page 330 Section 7 1MRK 504 152-UEN B Impedance protection Bus side instrument transformers GUID-B7D1F10A-5467-4F91-9BC1-AB8906357428 v1 CT1 and VT1 on figure represent the case with bus side instrument transformers. The protection devices are in this case exposed to possible voltage and current inversion for line faults, which decreases the required dependability.
Page 331 1MRK 504 152-UEN B Section 7 Impedance protection KC = 80% KC = 50% KC = 2 x 33% KC = 80% KC = 0% LOC = 0% LOC = 50% LOC = 33%, 66% LOC = 100% en06000613.vsd IEC06000613 V1 EN-US Figure 196: Apparent impedances seen by distance IED for different SC locations and spark gaps used for overvoltage protection M OV...
Page 332: Impact Of Series Compensation On Protective Ied Of Adjacent Lines
Section 7 1MRK 504 152-UEN B Impedance protection instantaneous voltage drop over the capacitor becomes higher than the protective voltage level in each half-cycle separately, see figure 197. ref. Goldsworthy, D,L “A Extensive studies at Bonneville Power Administration in USA ( Linearized Model for MOV-Protected series capacitors”...
Page 333 1MRK 504 152-UEN B Section 7 Impedance protection selection of protection devices (mostly distance IEDs) on remote ends of lines adjacent to the series compensated circuit, and sometimes even deeper in the network. en06000616.vsd IEC06000616 V1 EN-US Figure 199: Voltage inversion in series compensated network due to fault current infeed Voltage at the B bus (as shown in figure 199) is calculated for the loss-less system according to the equation below.
Page 334: Distance Protection
Section 7 1MRK 504 152-UEN B Impedance protection kind of investigation must consider also the maximum sensitivity and possible resistive reach of distance protection devices, which on the other hand simplifies the problem. Application of MOVs as non-linear elements for capacitor overvoltage protection makes simple calculations often impossible.
Page 335 1MRK 504 152-UEN B Section 7 Impedance protection × (Equation 348) EQUATION1914 V1 EN-US Here K is a safety factor, presented graphically in figure 201, which covers for possible overreaching due to low frequency (sub-harmonic) oscillations. Here it should be noted separately that compensation degree K in figure relates to total system reactance,...
Page 336 Section 7 1MRK 504 152-UEN B Impedance protection and in figure a three phase fault occurs beyond the capacitor. The resultant IED impedance seen from the IED location to the fault may become negative (voltage inversion) until the spark gap has flashed.
Page 337 1MRK 504 152-UEN B Section 7 Impedance protection adjacent line may be lower than the capacitor reactance and voltage inversion phenomenon may occur also on remote end of adjacent lines. Distance protection of such line must have built-in functionality which applies normally to protection of series compensated lines. It usually takes a bit of a time before the spark gap flashes, and sometimes the fault current will be of such a magnitude that there will not be any flashover and the negative impedance will be sustained.
Page 338 Section 7 1MRK 504 152-UEN B Impedance protection with fault current in a power line without a capacitor (current inversion). The negative direction of the fault current will persist until the spark gap has flashed. Sometimes there will be no flashover at all, because the fault current is less than the setting value of the spark gap. The negative fault current will cause a high voltage on the network.
Page 339 1MRK 504 152-UEN B Section 7 Impedance protection en06000628.vsd IEC06000628 V1 EN-US Figure 207: Zero sequence equivalent circuit of a series compensated double circuit line with one circuit disconnected and earthed at both IEDs Zero sequence mutual impedance may disturb also correct operation of distance protection for external evolving faults, when one circuit has already been disconnected in one phase and runs non-symmetrical during dead time of single pole autoreclosing cycle.
Page 340: Setting Guidelines
Section 7 1MRK 504 152-UEN B Impedance protection 7.13.4 Setting guidelines IP14962-1 v1 7.13.4.1 General GUID-B9958CEF-90ED-4644-B169-C6B4A018193B v1 The settings for Distance measuring zones, quadrilateral characteristic (ZMFCPDIS) are done in primary values. The instrument transformer ratio that has been set for the analog input card is used to automatically convert the measured secondary input signals to primary values used in ZMFCPDIS.
Page 341: Setting Of Reverse Zone
1MRK 504 152-UEN B Section 7 Impedance protection If the chosen zone 2 reach gives such a value that it will interfere with zone 2 on adjacent lines, the time delay of zone 2 must be increased by approximately 200 ms to avoid unwanted operation in cases when the telecommunication for the short adjacent line at the remote end is down during faults.
Page 342 Section 7 1MRK 504 152-UEN B Impedance protection Setting of zone 1 GUID-69E8535D-F3E2-483D-8463-089063712C67 v2 A voltage reversal can cause an artificial internal fault (voltage zero) on faulty line as well as on the adjacent lines. This artificial fault always have a resistive component, this is however small and can mostly not be used to prevent tripping of a healthy adjacent line.
Page 343 1MRK 504 152-UEN B Section 7 Impedance protection at three phase fault and therefore the calculation need only to be performed for three phase faults. The compensation degree in earth return path is different than in phases. It is for this reason possible to calculate a compensation degree separately for the phase-to-phase and three- phase faults on one side and for the single phase-to-earth fault loops on the other side.
Page 344 Section 7 1MRK 504 152-UEN B Impedance protection X1Fw is set to (XLine-XC · K) · p/100. • X1Rv can be set to the same value as X1Fw • K equals side infeed factor at next busbar. • X1Fw gives a negative value the zone 1 must be When the calculation of permanently blocked.
Page 345: Setting Of Zones For Parallel Line Application
1MRK 504 152-UEN B Section 7 Impedance protection Optional higher distance protection zones GUID-506F93E2-1E1C-4EEC-B260-F362F3897C4F v1 When some additional distance protection zones (zone 4, for example) are used they must be set according to the influence of the series capacitor. 7.13.4.6 Setting of zones for parallel line application GUID-E1228762-EBF7-4E58-9A52-96C5D22A0F0D v1 Parallel line in service –...
Page 346: Setting Of Reach In Resistive Direction
Section 7 1MRK 504 152-UEN B Impedance protection Set the values of the corresponding zone (zero-sequence resistance and reactance) equal to: æ ö × ç ------------------------- - ÷ è ø (Equation 366) EQUATION561 V1 EN-US æ ö × ------------------------- - ç...
Page 347: Load Impedance Limitation, Without Load Encroachment Function
1MRK 504 152-UEN B Section 7 Impedance protection functionality is not needed (that is, when the load is not encroaching on the distance zones). Always define the load encroachment boundary according to the actual load or in consideration of how far the phase selection must actually reach. 7.13.4.8 Load impedance limitation, without load encroachment function GUID-16C2EB30-7FEA-42E4-98C8-52CCC36644C6 v4...
Page 348: Zone Reach Setting Higher Than Minimum Load Impedance
Section 7 1MRK 504 152-UEN B Impedance protection é × ù £ × × × RFPE ê ú ë û load × (Equation 375) EQUATION578 V4 EN-US Where: is a maximum load-impedance angle, related to the maximum load power. ϑ To avoid load encroachment for the phase-to-phase measuring elements, the set resistive reach of any distance protection zone must be less than 160% of the minimum load impedance.
Page 349: Parameter Setting Guidelines
1MRK 504 152-UEN B Section 7 Impedance protection this corresponds to the per-phase, or positive-sequence, impedance. For a phase-to-earth fault, it corresponds to the per-loop impedance, including the earth return impedance. RLdFw RLdFw ARGLd ARGLd ARGLd ARGLd ArgLd Possible ARGLd load ARGLd RLdRv...
Page 350 Section 7 1MRK 504 152-UEN B Impedance protection These settings define the operating direction for Zones Z3, Z4 and Z5 (the directionality of zones Z1, Z2 and ZRV is fixed). The options are Non-directional , Forward or Reverse . The result from respective set value is illustrated in figure below, where positive impedance corresponds to the direction out on the protected line.
Page 351: Power Swing Detection Zmrpsb
1MRK 504 152-UEN B Section 7 Impedance protection measurement is activated (and phase-to-phase measurement is blocked). The relations are defined by the following equation. leasePE × ³ × (Equation 380) EQUATION2548 V1 EN-US Where: INReleasePE is the setting for the minimum residual current needed to enable operation in the phase-to- earth fault loops in % Iphmax is the maximum phase current in any of three phases...
Page 352: Basic Characteristics
Section 7 1MRK 504 152-UEN B Impedance protection locus in an impedance plane, see figure 214. This locus can enter the operating characteristic of a distance protection and cause, if no preventive measures have been considered, its unwanted operation. Operating characteristic Impedance locus at power swing IEC09000224_1_en.vsd...
Page 353 1MRK 504 152-UEN B Section 7 Impedance protection Reduce the power system with protected power line into equivalent two-machine system with positive sequence source impedances Z behind the IED and Z behind the remote end bus B. Observe a fact that these impedances can not be directly calculated from the maximum three-phase short circuit currents for faults on the corresponding busbar.
Page 354 Section 7 1MRK 504 152-UEN B Impedance protection all settings are performed in primary values. The impedance transformation factor is presented for orientation and testing purposes only. 1200 0.11 × × KIMP 0.33 (Equation 381) EQUATION1336 V1 EN-US The minimum load impedance at minimum expected system voltage is equal to equation 382. 144.4 1000 (Equation 382)
Page 355 1MRK 504 152-UEN B Section 7 Impedance protection ArgLd ArgLd (ZMRPSB) (FDPSPDIS) IEC09000225-1-en.vsd IEC09000225 V1 EN-US Figure 216: Impedance diagrams with corresponding impedances under consideration RLdOutFw The outer boundary of oscillation detection characteristic in forward direction should be set with certain safety margin K compared to the minimum expected load resistance R .
Page 356 Section 7 1MRK 504 152-UEN B Impedance protection RLdOutFw obtains in this particular case its value according to 400kV. The outer boundary equation 388. × × RLdOutFw 0.9 137.2 123.5 (Equation 388) EQUATION1343 V1 EN-US RLdInFw of the oscillation detection It is a general recommendation to set the inner boundary characteristic to 80% or less of its outer boundary.
Page 357 1MRK 504 152-UEN B Section 7 Impedance protection 155.75 RLdInFw 75.8 max1 æ ö æ ö 91.5 × × 2 tan 2 tan ç ÷ ç ÷ è ø è ø (Equation 395) EQUATION1350 V1 EN-US RLdInFw 75.8 kLdRFw max1 0.61 RLdOutFw 123.5...
Page 358: Power Swing Logic Pslpsch
Section 7 1MRK 504 152-UEN B Impedance protection then it is necessary to set the load argument in FDPSPDIS or FRPSPDIS function to not less than equation 400. é ù é ° ù ArgLd tan 25 ³ ° ArgLd arc tan arc tan 37.5 ê...
Page 359 1MRK 504 152-UEN B Section 7 Impedance protection • A fault occurs on a so far healthy power line, over which the power swing has been detected and the fast distance protection zone has been blocked by ZMRPSB element. • The power swing occurs over two phases of a protected line during the dead time of a singlepole auto-reclosing after the Ph-E fault has been correctly cleared by the distance protection.
Page 360: Setting Guidelines
Section 7 1MRK 504 152-UEN B Impedance protection Measured impedance at initital fault position Zone 2 Zone 1 Impedance locus at initial power swing after the fault clearance ZMRPSB operating characteristic IEC99000181_2_en.vsd IEC99000181 V2 EN-US Figure 218: Impedance trajectory within the distance protection zones 1 and 2 during and after the fault on line B –...
Page 361 1MRK 504 152-UEN B Section 7 Impedance protection LDCM” and the “Binary signal transfer to remote end” function. It is also possible to include, in an easy way (by means of configuration possibilities), the complete functionality into regular scheme communication logic for the distance protection function. The communication scheme for the regular distance protection does not operate during the power-swing conditions, because the distance protection zones included in the scheme are normally blocked.
Page 362 Section 7 1MRK 504 152-UEN B Impedance protection Connect the CACC functional input to start output signal of the local overreaching power swing distance protection zone, which serves as a local criteria at receiving of carrier signal during the power swing cycle. The CR signal should be configured to the functional input which provides the logic with information on received carrier signal sent by the remote end power swing distance protection zone.
Page 363: Blocking And Tripping Logic For Evolving Power Swings
1MRK 504 152-UEN B Section 7 Impedance protection × v tnPE × RFPE (Equation 403) EQUATION1539 V1 EN-US Here is factor 0.8 considered for safety reasons and: RFPE phase-to-earth resistive reach setting for a power swing distance protection zone n in Ω...
Page 364 Section 7 1MRK 504 152-UEN B Impedance protection Configure for this reason the STZMPSD to the functional output signal of ZMRPSB function, which indicates the measured impedance within its external boundaries. & BLKZMH & STZML STZMLL & >1 BLOCK & STMZH &...
Page 365: Pole Slip Protection Pspppam
1MRK 504 152-UEN B Section 7 Impedance protection 7.16 Pole slip protection PSPPPAM SEMOD156709-1 v2 7.16.1 Identification SEMOD158949-2 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Pole slip protection PSPPPAM 7.16.2 Application SEMOD143248-4 v3 Normally, the generator operates synchronously with the power system, that is, all the generators in the system have the same angular velocity and approximately the same phase angle difference.
Page 366 Section 7 1MRK 504 152-UEN B Impedance protection en06000313.vsd IEC06000313 V1 EN-US Figure 221: Relative generator phase angle at a fault and pole slip relative to the external power system The relative angle of the generator is shown for different fault duration at a three-phase short circuit close to the generator.
Page 367 1MRK 504 152-UEN B Section 7 Impedance protection en06000314.vsd IEC06000314 V1 EN-US Figure 222: Undamped oscillations causing pole slip The relative angle of the generator is shown a contingency in the power system, causing un- damped oscillations. After a few periods of the oscillation the swing amplitude gets to large and the stability cannot be maintained.
Page 368: Setting Guidelines
Section 7 1MRK 504 152-UEN B Impedance protection 7.16.3 Setting guidelines SEMOD167596-1 v1 SEMOD167582-4 v4 GlobalBaseSel : Selects the global base value group used by the function to define ( IBase ), UBase ) and ( SBase ). Operation : With the parameter Operation the function can be set On or Off . MeasureMode : The voltage and current used for the impedance measurement is set by the MeasureMode .
Page 369: Setting Example For Line Application
1MRK 504 152-UEN B Section 7 Impedance protection UBase Base IBase (Equation 405) EQUATION1883 V1 EN-US ImpedanceZB is the reverse impedance as show in figure 223. ZB should be equal to the generator transient reactance X'd. The impedance is given in % of the base impedance, see equation 405.
Page 370 Section 7 1MRK 504 152-UEN B Impedance protection Apparent anglePhi impedance at normal load IEC07000015_2_en.vsd IEC07000015 V2 EN-US Figure 225: Impedances to be set for pole slip protection The setting parameters of the protection is: Line + source impedance in the forward direction The source impedance in the reverse direction The line impedance in the forward direction AnglePhi :...
Page 371 1MRK 504 152-UEN B Section 7 Impedance protection UBase ZBase SBase 1000 (Equation 406) EQUATION1960 V1 EN-US Z line Zsc station 5000 (Equation 407) EQUATION1961 V1 EN-US This corresponds to: Ð ° 0.0125 0.325 0.325 88 (Equation 408) EQUATION1962 V1 EN-US Set ZA to 0.32.
Page 372: Setting Example For Generator Application
Section 7 1MRK 504 152-UEN B Impedance protection Zload en07000016.vsd IEC07000016 V1 EN-US Figure 226: Simplified figure to derive StartAngle ³ » angleStart arctan arctan arctan + arctan = 21.8 + 33.0 Zload Zload (Equation 413) EQUATION1968 V2 EN-US In case of minor damped oscillations at normal operation we do not want the protection to start.
Page 373 1MRK 504 152-UEN B Section 7 Impedance protection en07000017.vsd IEC07000017 V1 EN-US Figure 227: Generator application of pole slip protection If the apparent impedance crosses the impedance line ZB – ZA this is the detected criterion of out of step conditions, see figure 228. Apparent anglePhi impedance at...
Page 374 Section 7 1MRK 504 152-UEN B Impedance protection Use the following block transformer data: UBase : 20 kV (low voltage side) SBase set to 200 MVA : 15% Short circuit power from the external network without infeed from the protected line: 5000 MVA (assumed to a pure reactance).
Page 375 1MRK 504 152-UEN B Section 7 Impedance protection Ð 0.15 0.15 90 (Equation 420) EQUATION1975 V2 EN-US AnglePhi to 90°. Set ZC to 0.15 and StartAngle ) should be chosen not to cross into normal operating area. The The warning angle ( maximum line power is assumed to be 200 MVA.
Page 376: Out-Of-Step Protection Oosppam
Section 7 1MRK 504 152-UEN B Impedance protection N1Limit to 1 to get trip at first pole If the centre of pole slip is within the generator block set slip. N2Limit to 3 to get enable split of the system If the centre of pole slip is within the network set before generator trip.
Page 377 1MRK 504 152-UEN B Section 7 Impedance protection The center of the electromechanical oscillation can be in the generator unit (or generator- transformer unit) or outside, somewhere in the power system. When the center of the electromechanical oscillation occurs within the generator it is essential to trip the generator immediately.
Page 378: Setting Guidelines
Section 7 1MRK 504 152-UEN B Impedance protection unstable stable 3-ph ← 3-rd pole-slip fault 260 ms ← 2-nd pole-slip 1.05 ← For 260 ms long 3-phase fault generator loses synchronism. Generator operates in 1-st asynchronous mode at speeds > nominal pole-slip ←...
Page 379 1MRK 504 152-UEN B Section 7 Impedance protection Table 33: An example how to calculate values for the settings ForwardR, ForwardX, ReverseR, and ReverseX Turbine Generator Transformer Double power line Equivalent (hydro) 200 MVA 300 MVA 230 kV, 300 km power system 13.8 kV...
Page 380 Section 7 1MRK 504 152-UEN B Impedance protection • For the synchronous machines as the generator in Table 33, the transient reactance Xd' shall be used. This due to the relatively slow electromechanical oscillations under out-of- step conditions. • Sometimes the equivalent resistance of the generator is difficult to get. A good estimate is 1 percent of transient reactance Xd'.
Page 381: Phase Preference Logic Pplphiz
(LV-side) then inversion is not necessary ( Off ), provided that the CT’s star point earthing complies with ABB recommendations, as it is shown in Table 33. If the currents fed to the Out-of-step protection are measured on the...
Page 382 Section 7 1MRK 504 152-UEN B Impedance protection Different practices for tripping is used by different utilities. The main use of this logic is in systems where single phase-to-earth faults are not automatically cleared, only alarm is given and the fault is left on until a suitable time to send people to track down and repair the fault. When cross-country faults occur, the practice is to trip only one of the faulty lines.
Page 383 1MRK 504 152-UEN B Section 7 Impedance protection the phase selection and if the fault type indicates a two or three phase fault the integer releasing the zone is not changed. If the fault indicates and earth-fault checks are done which mode of tripping to be used, for example 1231c, which means that fault in the phases are tripped in the cyclic order L1 before L2 before L3 before L1.
Page 384: Setting Guidelines
Section 7 1MRK 504 152-UEN B Impedance protection IL3=IN IL1=IN en06000553.vsd IEC06000553 V1 EN-US Figure 235: The currents in the phases at a double earth fault The function has a block input (BLOCK) to block start from the function if required in certain conditions.
Page 385: Under Impedance Protection For Generators And Transformers Zgvpdis
1MRK 504 152-UEN B Section 7 Impedance protection IN> : The setting of the residual current level (neutral current) which is used by the evaluation logic to verify that a cross-country fault exists. The setting can typically be 20% of base IBase ) but the setting shall be above the maximum current generated by the system current ( earthing.
Page 386 Section 7 1MRK 504 152-UEN B Impedance protection Protection designed to operate for below types of faults Faults in the generator, generator terminal connections to the step-up transformer and in the low voltage (LV) side of the generator step-up transformer are: Phase-to-phase faults in generator Three-phase faults in generator Phase-to-phase faults in the LV winding of the generator transformer or inter-connecting...
Page 387: Operating Zones
1MRK 504 152-UEN B Section 7 Impedance protection 7.19.2.1 Operating zones GUID-FE7ADB29-3A48-41BF-AE43-94884D305A29 v2 Zone3 Zone2 Zone1 REG670 A) Power system model Z3Fwd Z2Fwd ImpedanceAn ImpedanceAn Z3Rev Z2Rev Z1Fwd ImpedanceAn R(ohm) Z1Rev B) Typical setting of zones for under impedance relay IEC11000308-3-en.vsd IEC11000308 V3 EN-US Figure 236: Zone characteristics and typical power system model...
Page 388: Zone 1 Operation
Section 7 1MRK 504 152-UEN B Impedance protection 7.19.2.2 Zone 1 operation GUID-D5A94DC8-64AB-4623-88B6-64AD0AF5D53C v4 Zone 1 is used as fast selective tripping for phase-to-phase faults and three–phase faults in the generator, on the terminal leads and LV side of generator transformer. Since generator is high impedance earthed, the fault current for phase-to-earth faults will be too low and impedance protection is not intended to operate for these faults.
Page 389: Zone 3 Operation
1MRK 504 152-UEN B Section 7 Impedance protection If the currents are equal, L1-E loop has higher priority than L2-E and L2-E loop has higher priority than L3-E. UL1E, UL2E, UL3E are three phase–to–earth voltages and IL1, IL2, IL3 are three phase currents and U0 is zero sequence voltage.
Page 390: External Block Signals
Section 7 1MRK 504 152-UEN B Impedance protection Figure shows the implemented load encroachment characteristic. Load encroachment characteristic ArgLd ArgLd -RLd ArgLd ArgLd IEC11000304_1_en IEC11000304 V1 EN-US Figure 237: Load Encroachment characteristic in under Impedance function ZBase . The resistive settings of this function is also provided in percentage of It is calculated according to equation 423.
Page 391: Load Encroachment
1MRK 504 152-UEN B Section 7 Impedance protection ImpedanceAng : The common characteristic angle for all the three zone distance elements IMinOp : The minimum operating current in %IBase. Zone 1 ZGVPDIS function has an offset mho characteristic and it can evaluate three phase-to-phase impedance measuring loops.
Page 392 Section 7 1MRK 504 152-UEN B Impedance protection ArgLd : Angle in degrees of load encroachment characteristics RLd : Positive sequence resistance in per unit The procedure of calculating the settings for load encroachment consists basically of defining ArgLd and resistive blinder RLd . The load encroachment logic can be enabled for load angle zone 2 and zone 3 elements.
Page 393: Under Voltage Seal-In
1MRK 504 152-UEN B Section 7 Impedance protection 7.19.3.3 Under voltage seal-in GUID-946B8F59-8609-4F93-B346-AE053F1C2F9C v2 Settings involved in under voltage seal-in are: OpModeU< : Under voltage seal-in feature is enabled using this setting and can be selected as Off or Z2Start or Z3Start . If the under voltage seal-in has to be triggered with zone 2 start, Z2Start enumeration has to be selected .
Page 395: Current Protection
1MRK 504 152-UEN B Section 8 Current protection Section 8 Current protection Instantaneous phase overcurrent protection PHPIOC IP14506-1 v6 8.1.1 Identification M14880-1 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Instantaneous phase overcurrent PHPIOC protection 3-phase output 3I>>...
Page 396: Meshed Network Without Parallel Line
Section 8 1MRK 504 152-UEN B Current protection Only detailed network studies can determine the operating conditions under which the highest possible fault current is expected on the line. In most cases, this current appears during three-phase fault conditions. But also examine single-phase-to-earth and two-phase- to-earth conditions.
Page 397 1MRK 504 152-UEN B Section 8 Current protection Fault IEC09000023-1-en.vsd IEC09000023 V1 EN-US Figure 240: Through fault current from B to A: I The IED must not trip for any of the two through-fault currents. Hence the minimum theoretical current setting (Imin) will be: ³...
Page 398: Meshed Network With Parallel Line
Section 8 1MRK 504 152-UEN B Current protection 8.1.3.2 Meshed network with parallel line M12915-34 v6 In case of parallel lines, the influence of the induced current from the parallel line to the protected line has to be considered. One example is given in figure where the two lines are connected to the same busbars.
Page 399: Four Step Phase Overcurrent Protection Oc4Ptoc
1MRK 504 152-UEN B Section 8 Current protection Four step phase overcurrent protection OC4PTOC SEMOD129998-1 v7 8.2.1 Identification M14885-1 v5 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Four step phase overcurrent OC4PTOC 51_67 protection 3-phase output TOC-REVA V2 EN-US 8.2.2 Application...
Page 400: Setting Guidelines
Section 8 1MRK 504 152-UEN B Current protection to the current pick-up level. This multiplication factor is activated from a binary input signal to the function. Power transformers can have a large inrush current, when being energized. This phenomenon is due to saturation of the transformer magnetic core during parts of the period. There is a risk that inrush current will reach levels above the pick-up current of the phase overcurrent protection.
Page 401: Settings For Each Step
1MRK 504 152-UEN B Section 8 Current protection IEC09000636_1_vsd IEC09000636 V1 EN-US Figure 243: Directional function characteristic RCA = Relay characteristic angle ROA = Relay operating angle Reverse Forward 8.2.3.1 Settings for each step M12982-19 v10.1.1 x means step 1, 2, 3 and 4. DirModex : The directional mode of step x .
Page 402 Section 8 1MRK 504 152-UEN B Current protection Curve name ANSI Moderately Inverse ANSI/IEEE Definite time ANSI Long Time Extremely Inverse ANSI Long Time Very Inverse ANSI Long Time Inverse IEC Normal Inverse IEC Very Inverse IEC Inverse IEC Extremely Inverse IEC Short Time Inverse IEC Long Time Inverse IEC Definite Time...
Page 403 1MRK 504 152-UEN B Section 8 Current protection Operate time txMin IMinx Current IEC10000058 IEC10000058 V2 EN-US Figure 244: Minimum operate current and operate time for inverse time characteristics txMin shall be In order to fully comply with the definition of the curve, the setting parameter set to a value equal to the operating time of the selected inverse curve for twenty times the set current pickup value.
Page 404: 2Nd Harmonic Restrain
Section 8 1MRK 504 152-UEN B Current protection æ ö ç ÷ ç ÷ × IxMult ç ÷ æ ö ç ç ÷ ÷ è è ø ø > (Equation 432) EQUATION1261 V2 EN-US tPRCrvx , tTRCrvx , tCRCrvx : These parameters are used by the customer to create the inverse Technical manual .
Page 405 1MRK 504 152-UEN B Section 8 Current protection Current I Line phase current Operate current Reset current The IED does not reset Time t IEC05000203-en-2.vsd IEC05000203 V3 EN-US Figure 245: Operate and reset current for an overcurrent protection The lowest setting value can be written according to equation 433. Im ax ³...
Page 406 Section 8 1MRK 504 152-UEN B Current protection £ × 0.7 Isc min (Equation 434) EQUATION1263 V2 EN-US where: is a safety factor Iscmin is the smallest fault current to be detected by the overcurrent protection. As a summary the operating current shall be chosen within the interval stated in equation 435. Im ax ×...
Page 407 1MRK 504 152-UEN B Section 8 Current protection en05000204.wmf IEC05000204 V1 EN-US Figure 246: 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 408: Instantaneous Residual Overcurrent Protection Efpioc
Section 8 1MRK 504 152-UEN B Current protection Feeder I> I> Time axis The fault Protection Breaker at Protection occurs B1 trips B1 opens A1 resets en05000205.vsd IEC05000205 V1 EN-US Figure 247: 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 409: Identification
1MRK 504 152-UEN B Section 8 Current protection 8.3.1 Identification M14887-1 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Instantaneous residual overcurrent EFPIOC protection IN>> IEF V1 EN-US 8.3.2 Application M12699-3 v5 In many applications, when fault current is limited to a defined value by the object impedance, an instantaneous earth-fault protection can provide fast and selective tripping.
Page 410 Section 8 1MRK 504 152-UEN B Current protection Fault IEC09000023-1-en.vsd IEC09000023 V1 EN-US Figure 249: 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 411: Four Step Residual Overcurrent Protection
1MRK 504 152-UEN B Section 8 Current protection ³ I m in M A X I (Equation 440) EQUATION287 V1 EN-US Where: and I have been described for the single line case. Considering the safety margins mentioned previously, the minimum setting (Is) is: = 1.3 ×...
Page 412 Section 8 1MRK 504 152-UEN B Current protection In many applications several steps with different current operating levels and time delays are needed. EF4PTOC can have up to four, individual settable steps. The flexibility of each step of EF4PTOC is great. The following options are possible: Non-directional/Directional function: In some applications the non-directional functionality is used.
Page 413: Setting Guidelines
1MRK 504 152-UEN B Section 8 Current protection to the residual current pick-up level. This multiplication factor is activated from a binary input signal ENMULTx to the function. Power transformers can have a large inrush current, when being energized. This inrush current can have residual current components.
Page 414 Section 8 1MRK 504 152-UEN B Current protection Protection operate time: 15-60 ms Protection resetting time: 15-60 ms Breaker opening time: 20-120 ms The different characteristics are described in the technical reference manual. tx : Definite time delay for step x . The definite time tx is added to the inverse time when inverse time characteristic is selected.
Page 415: Common Settings For All Steps
1MRK 504 152-UEN B Section 8 Current protection tResetx : Constant reset time delay in s for step x. HarmBlockx : This is used to enable block of step x from 2 harmonic restrain function. tPCrvx, tACrvx, tBCrvx, tCCrvx : Parameters for user programmable of inverse time characteristic curve.
Page 416: 2Nd Harmonic Restrain
Section 8 1MRK 504 152-UEN B Current protection Voltage (3U • or U Current (3I • · ZNpol or 3I ·ZNpol where ZNpol is RNpol + jXNpol), or Dual (dual polarizing, (3U • both currents and voltage, + 3I · ZNpol) or (U ·...
Page 417: Switch Onto Fault Logic
1MRK 504 152-UEN B Section 8 Current protection of the two transformers will be in phase opposition. The summation of the two currents will thus give a small 2 harmonic current. The residual fundamental current will however be significant. The inrush current of the transformer in service before the parallel transformer energizing, will be a little delayed compared to the first transformer.
Page 418: Transformer Application Example
Section 8 1MRK 504 152-UEN B Current protection ActivationSOTF : This setting will select the signal to activate SOTF function; CB position open/CB position closed/CB close command . tSOTF : Time delay for operation of the SOTF function. The setting range is 0.000 - 60.000 s in step of 0.001 s.
Page 419 1MRK 504 152-UEN B Section 8 Current protection It can be suitable to use a residual overcurrent protection with at least two steps. Step 1 shall have a short definite time delay and a relatively high current setting, in order to detect and clear high current earth faults in the transformer winding or in the power system close to the transformer.
Page 420 Section 8 1MRK 504 152-UEN B Current protection YN/D or YN/Y transformer Three phase CT summated Single CT > Single phase-to- earth fault IEC05000492-en-2.vsd IEC05000492 V2 EN-US Figure 256: Step 1 fault calculation 1 This calculation gives the current fed to the protection: 3I 0fault1 To assure that step 1, selectivity to other earth-fault protections in the network a short delay is selected.
Page 421: Four Step Directional Negative Phase Sequence Overcurrent Protection Ns4Ptoc
1MRK 504 152-UEN B Section 8 Current protection × < < × lowmar highmar 0fault 2 step1 0fault1 (Equation 443) EQUATION1455 V2 EN-US Where: lowmar is a margin to assure selectivity (typical 1.2) and highmar is a margin to assure fast fault clearance of busbar fault (typical 1.2). Setting of step 2 SEMOD55591-57 v4 The setting of the sensitive step 2 is dependent of the chosen time delay.
Page 422 Section 8 1MRK 504 152-UEN B Current protection Non-directional/Directional function: In some applications the non-directional functionality is used. This is mostly the case when no fault current can be fed from the protected object itself. In order to achieve both selectivity and fast fault clearance, the directional function can be necessary.
Page 423: Setting Guidelines
1MRK 504 152-UEN B Section 8 Current protection 8.5.3 Setting guidelines GUID-460D6C58-598C-421E-AA9E-FD240210A6CC v3 The parameters for Four step negative sequence overcurrent protection NS4PTOC are set via the local HMI or Protection and Control Manager (PCM600). The following settings can be done for the four step negative sequence overcurrent protection: Operation : Sets the protection to On or Off .
Page 424 Section 8 1MRK 504 152-UEN B Current protection The different characteristics are described in the Technical Reference Manual (TRM). Ix> : Operation negative sequence current level for step x given in % of IBase . tx : Definite time delay for step x . The definite time tx is added to the inverse time when inverse time characteristic is selected.
Page 425: Common Settings For All Steps
1MRK 504 152-UEN B Section 8 Current protection For IEC inverse time delay characteristics the possible delay time settings are instantaneous (1) and IEC (2 = set constant time reset). For the programmable inverse time delay characteristics all three types of reset time characteristics are available;...
Page 426: Sensitive Directional Residual Overcurrent And Power Protection Sdepsde
Section 8 1MRK 504 152-UEN B Current protection Reverse Area Upol=-U2 AngleRCA Forward Area Iop = I2 IEC10000031-1-en.vsd IEC10000031 V1 EN-US Figure 259: Relay characteristic angle given in degree In a transmission network a normal value of RCA is about 80°. UPolMin : Minimum polarization (reference) voltage % of UBase .
Page 427: Application
1MRK 504 152-UEN B Section 8 Current protection 8.6.2 Application SEMOD171959-4 v11 In networks with high impedance earthing, the phase-to-earth fault current is significantly smaller than the short circuit currents. Another difficulty for earth fault protection is that the magnitude of the phase-to-earth fault current is almost independent of the fault location in the network.
Page 428: Setting Guidelines
Section 8 1MRK 504 152-UEN B Current protection Phase currents Phase- ground voltages IEC13000013-1-en.vsd IEC13000013 V1 EN-US Figure 260: Connection of SDEPSDE to analog preprocessing function block Overcurrent functionality uses true 3I0, i.e. sum of GRPxL1, GRPxL2 and GRPxL3. For 3I0 to be calculated, connection is needed to all three phase inputs.
Page 429 1MRK 504 152-UEN B Section 8 Current protection The fault current, in the fault point, can be calculated as: × phase + × (Equation 446) EQUATION1944 V1 EN-US The impedance Z is dependent on the system earthing. In an isolated system (without neutral point apparatus) the impedance is equal to the capacitive coupling between the phase conductors and earth: ×...
Page 430 Section 8 1MRK 504 152-UEN B Current protection Source impedance (pos. seq) (pos. seq) (zero seq) Substation A (pos. seq) lineAB,1 (zero seq) lineAB,0 Substation B (pos. seq) lineBC,1 (zero seq) lineBC,0 Phase to earth fault en06000654.vsd IEC06000654 V1 EN-US Figure 261: Equivalent of power system for calculation of setting The residual fault current can be written: phase...
Page 431 1MRK 504 152-UEN B Section 8 Current protection × (Equation 453) EQUATION1951 V1 EN-US × (Equation 454) EQUATION1952 V1 EN-US The residual power is a complex quantity. The protection will have a maximum sensitivity in the characteristic angle RCA. The apparent residual power component in the characteristic angle, measured by the protection, can be written: ×...
Page 432 Section 8 1MRK 504 152-UEN B Current protection RCADir ROADir ang(3I ) ang(3U × 3I cos IEC06000648-4-en.vsd IEC06000648 V4 EN-US Figure 262: Characteristic for RCADir equal to 0° RCADir equal to -90° is shown in Figure 263. The characteristic is for ...
Page 433 1MRK 504 152-UEN B Section 8 Current protection RCADir = 0º ROADir = 80º Operate area IEC06000652-3-en.vsd IEC06000652 V3 EN-US Figure 264: Characteristic for RCADir = 0° and ROADir = 80° DirMode is set Forward or Reverse to set the direction of the operation for the directional OpMode .
Page 434 Section 8 1MRK 504 152-UEN B Current protection SN> is the operate power level for the directional function when OpMode is set 3I03U0Cosfi . The setting is given in % of SBase . The setting should be based on calculation of the active or capacitive earth fault residual power at required sensitivity of the protection.
Page 435: Thermal Overload Protection, One Time Constant, Celsius/Fahrenheit Lcpttr/Lfpttr
1MRK 504 152-UEN B Section 8 Current protection See chapter “Inverse time characteristics” in Technical Manual for the description of different characteristics tPCrv, tACrv, tBCrv, tCCrv : Parameters for customer creation of inverse time characteristic curve (Curve type = 17). The time characteristic equation is: æ...
Page 436: Setting Guideline
Section 8 1MRK 504 152-UEN B Current protection In stressed situations in the power system it can be required to overload lines and cables for a limited time. This should be done while managing the risks safely. The thermal overload protection provides information that makes a temporary overloading of cables and lines possible.
Page 437: Thermal Overload Protection, Two Time Constants Trpttr
1MRK 504 152-UEN B Section 8 Current protection Thermal overload protection, two time constants TRPTTR IP14513-1 v4 8.8.1 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 8.8.2 Application...
Page 438: Setting Guideline
Section 8 1MRK 504 152-UEN B Current protection After tripping by the thermal overload protection, the transformer will cool down over time. There will be a time gap before the heat content (temperature) reaches such a level so that the transformer can be taken into service again.
Page 439 1MRK 504 152-UEN B Section 8 Current protection DQ - (Equation 460) EQUATION1180 V1 EN-US If the transformer has forced cooling (FOA) the measurement should be made both with and Tau2 and Tau1 . without the forced cooling in operation, giving The time constants can be changed if the current is higher than a set value or lower than a set value.
Page 440: Breaker Failure Protection Ccrbrf
Section 8 1MRK 504 152-UEN B Current protection Breaker failure protection CCRBRF IP14514-1 v6 8.9.1 Identification M14878-1 v5 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Breaker failure protection, 3-phase CCRBRF 50BF activation and output 3I>BF SYMBOL-U V1 EN-US 8.9.2 Application...
Page 441 1MRK 504 152-UEN B Section 8 Current protection CB Pos Check means that a phase current must be larger than the operate level to allow re-trip. (circuit breaker position check) and Contact means re-trip is done when circuit breaker is No CBPos Check means re-trip is done without check of closed (breaker position is used).
Page 442 Section 8 1MRK 504 152-UEN B Current protection t2 : Time delay of the back-up trip. The choice of this setting is made as short as possible at the same time as unwanted operation must be avoided. Typical setting is 90 – 200ms (also dependent of re-trip timer).
Page 443: Pole Discordance Protection Ccpdsc
1MRK 504 152-UEN B Section 8 Current protection when gas pressure is low in a SF6 circuit breaker, of others. After the set time an alarm is given, so that actions can be done to repair the circuit breaker. The time delay for back-up trip is bypassed when the CBFLT is active.
Page 444: Directional Underpower Protection Guppdup
Section 8 1MRK 504 152-UEN B Current protection GlobalBaseSel : Selects the global base value group used by the function to define ( IBase ), UBase ) and ( SBase ). Operation : Off or On tTrip : Time delay of the operation. ContSel : Operation of the contact based pole discordance protection.
Page 445 1MRK 504 152-UEN B Section 8 Current protection Often, the motoring condition may imply that the turbine is in a very dangerous state. The task of the reverse power protection is to protect the turbine and not to protect the generator itself.
Page 446: Setting Guidelines
Section 8 1MRK 504 152-UEN B Current protection synchronization may be higher. One should set the underpower protection (reference angle set to 0) to trip if the active power from the generator is less than about 2%. One should set the overpower protection (reference angle set to 180) to trip if the power flow from the network to the generator is higher than 1%.
Page 447 1MRK 504 152-UEN B Section 8 Current protection Mode Set value Formula used for complex power calculation = × × (Equation 469) EQUATION1703 V1 EN-US = × × (Equation 470) EQUATION1704 V1 EN-US = × × (Equation 471) EQUATION1705 V1 EN-US The function has two stages that can be set independently.
Page 448 Section 8 1MRK 504 152-UEN B Current protection 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°. 0° should be used for generator low forward active power protection. Operate °...
Page 449: Directional Overpower Protection Goppdop
1MRK 504 152-UEN B Section 8 Current protection The calibration factors for current and voltage measurement errors are set % of rated current/ voltage: IAmpComp5, IAmpComp30, IAmpComp100 UAmpComp5, UAmpComp30, UAmpComp100 IAngComp5, IAngComp30, IAngComp100 The angle compensation is given as difference between current and voltage angle errors. The values are given for operating points 5, 30 and 100% of rated current/voltage.
Page 450 Section 8 1MRK 504 152-UEN B Current protection When the steam ceases to flow through a turbine, the cooling of the turbine blades will disappear. Now, it is not possible to remove all heat generated by the windage losses. Instead, the heat will increase the temperature in the steam turbine and especially of the blades.
Page 451: Setting Guidelines
1MRK 504 152-UEN B Section 8 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 269: Reverse power protection with underpower IED and overpower IED 8.12.3 Setting guidelines SEMOD172150-4 v7...
Page 452 Section 8 1MRK 504 152-UEN B Current protection The function has two stages that can be set independently. OpMode1(2) the function can be set On / Off . With the parameter The function gives trip if the power component in the direction defined by the setting Angle1(2) is larger than the set pick up power value Power1(2) Operate Power1(2)
Page 453 1MRK 504 152-UEN B Section 8 Current protection Angle1(2 ) = 180 Operate Power 1(2) IEC06000557-2-en.vsd IEC06000557 V2 EN-US Figure 271: For reverse power the set angle should be 180° in the overpower function TripDelay1(2) is set in seconds to give the time delay for trip of the stage after pick up. Hysteresis1(2) is given in p.u.
Page 454: Broken Conductor Check Brcptoc
Section 8 1MRK 504 152-UEN B Current protection IAmpComp5, IAmpComp30, IAmpComp100 UAmpComp5, UAmpComp30, UAmpComp100 IAngComp5, IAngComp30, IAngComp100 The angle compensation is given as difference between current and voltage angle errors. The values are given for operating points 5, 30 and 100% of rated current/voltage. The values should be available from instrument transformer test protocols.
Page 455: Identification
1MRK 504 152-UEN B Section 8 Current protection 8.14.1 Identification GUID-67FC8DBF-4391-4562-A630-3F244CBB4A33 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Capacitor bank protection CBPGAPC 8.14.2 Application GUID-5EC8BAEC-9118-49EC-970C-43D6C416640A v1 GUID-BACAE67B-E64B-4963-B323-ECB0B69031B9 v2 Shunt capacitor banks (SCBs) are somewhat specific and different from other power system elements.
Page 456 Section 8 1MRK 504 152-UEN B Current protection Rack Capacitor Unit (Can) IEC09000753_1_en.vsd IEC09000753 V1 EN-US Figure 272: 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 457: Scb Protection
1MRK 504 152-UEN B Section 8 Current protection Additionally, the SCB star point, when available, can be either directly earthed , earthed via impedance or isolated from earth. Which type of SCB earthing is used depends on voltage level, used circuit breaker, utility preference and previous experience. Many utilities have standard system earthing principle to earth neutrals of SCB above 100 kV.
Page 458: Setting Guidelines
Section 8 1MRK 504 152-UEN B Current protection Thus, as a general rule, the minimum number of capacitor units connected in parallel within a SCB is such that isolation of one capacitor unit in a group should not cause a voltage unbalance sufficient to place more than 110% of rated voltage on the remaining capacitors of that parallel group.
Page 459 1MRK 504 152-UEN B Section 8 Current protection × 1000 200[ MVAr × 3 400[ (Equation 488) IEC09000755 V1 EN-US or on the secondary CT side: 0.578 _ ec 500 1 (Equation 489) IEC09000756 V1 EN-US Note that the SCB rated current on the secondary CT side is important for secondary injection of the function.
Page 460: Restrike Detection
Section 8 1MRK 504 152-UEN B Current protection QOL> = 130% (of SCB MVAr rating); Reactive power level required for pickup. Selected value gives pickup recommended by international standards. tQOL = 60s ; Time delay for reactive power overload trip Harmonic voltage overload feature: OperationHOL = On ;...
Page 461: Application
1MRK 504 152-UEN B Section 8 Current protection 8.15.2 Application GUID-66CBDF76-B548-478F-8D59-CBAC4F6C1F85 v1 GUID-ED2E176E-BE14-45C2-875F-369E1F27BC29 v1 Negative sequence overcurrent protection for machines NS2PTOC is intended primarily for the protection of generators against possible overheating of the rotor caused by negative sequence component in the stator current. The negative sequence currents in a generator may, among others, be caused by: •...
Page 462: Generator Continuous Unbalance Current Capability
Section 8 1MRK 504 152-UEN B Current protection • Minimum operate time delay for inverse time characteristic, freely settable. This setting assures appropriate coordination with, for example, line protections. • Maximum operate time delay for inverse time characteristic, freely settable. •...
Page 463 1MRK 504 152-UEN B Section 8 Current protection en08000358.vsd IEC08000358 V1 EN-US Figure 274: Short-time unbalanced current capability of direct cooled generators Continuous I - capability of generators is also covered by the standard. Table below (from IEEE standard C50.13: 2014) contains the suggested capability: Table 44: Continous I capability Type of generator...
Page 464: Setting Guidelines
Section 8 1MRK 504 152-UEN B Current protection 8.15.3 Setting guidelines GUID-2E6EBD7C-108F-49F1-A577-2730089B638D v2 GlobalBaseSel : Selects the global base value group used by the function to define ( IBase ), UBase ) and ( SBase ). GUID-F7AA2194-4D1C-4475-8853-C7D064912614 v4 When inverse time overcurrent characteristic is selected, the operate time of the stage will be the sum of the inverse time delay and the set definite time delay.
Page 465: Start Sensitivity
1MRK 504 152-UEN B Section 8 Current protection Negative sequence inverse time characteristic 10000 tMax 1000 tMin 0.01 Negative sequence current IEC08000355-2-en.vsd IEC08000355 V2 EN-US Figure 275: Inverse Time Delay characteristic, step 1 The example in figure indicates that the protection function has a set minimum operating t1Min of 5 sec.
Page 466: Voltage-Restrained Time Overcurrent Protection Vrpvoc
Section 8 1MRK 504 152-UEN B Current protection 8.16 Voltage-restrained time overcurrent protection VRPVOC GUID-613620B1-4092-4FB6-901D-6810CDD5C615 v4 8.16.1 Identification GUID-7835D582-3FF4-4587-81CE-3B40D543E287 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Voltage-restrained time overcurrent VRPVOC I>/U< protection 8.16.2 Application GUID-622CDDDD-6D03-430E-A82D-861A4CBE067C v7 A breakdown of the insulation between phase conductors or a phase conductor and earth results in a short-circuit or an earth fault.
Page 467: Application Possibilities
1MRK 504 152-UEN B Section 8 Current protection UBase shall be entered as rated phase-to-phase voltage of the protected object in primary kV. 8.16.2.2 Application possibilities GUID-5053F964-C2D6-4611-B5EF-AC3DB0889F51 v5 VRPVOC function can be used in one of the following applications: • voltage controlled over-current •...
Page 468: Explanation Of The Setting Parameters
Section 8 1MRK 504 152-UEN B Current protection 8.16.3.1 Explanation of the setting parameters GUID-9B777E6D-602B-4214-9170-A44ED2D725BF v3 Operation : Set to On in order to activate the function; set to Off to switch off the complete function. StartCurr : Operation phase current level given in % of IBase . Characterist : Selection of time characteristic: Definite time delay and different types of inverse time characteristics are available;...
Page 469: Overcurrent Protection With Undervoltage Seal-In
1MRK 504 152-UEN B Section 8 Current protection • Inverse Time Over Current IDMT curve: IEC very inverse, with multiplier k=1 • Start current of 185% of generator rated current at rated generator voltage • Start current 25% of the original start current value for generator voltages below 25% of rated voltage To ensure proper operation of the function: Operation to On...
Page 470 Section 8 1MRK 504 152-UEN B Current protection The other parameters may be left at their default value. Application manual...
Page 471: Voltage Protection
1MRK 504 152-UEN B Section 9 Voltage protection Section 9 Voltage protection Two step undervoltage protection UV2PTUV IP14544-1 v3 9.1.1 Identification M16876-1 v6 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Two step undervoltage protection UV2PTUV 3U<...
Page 472: Equipment Protection, Such As For Motors And Generators
Section 9 1MRK 504 152-UEN B Voltage protection There is a very wide application area where general undervoltage functions are used. All voltage related settings are made as a percentage of the global settings base voltage UBase , which normally is set to the primary rated voltage level (phase-to-phase) of the power system or the high voltage equipment under consideration.
Page 473 1MRK 504 152-UEN B Section 9 Voltage protection < × UBase kV (Equation 490) EQUATION1447 V1 EN-US and operation for phase-to-phase voltage under: < × (%) UBase(kV) (Equation 491) EQUATION1990 V1 EN-US n = 1 or 2). Therefore, The below described setting parameters are identical for the two steps ( the setting parameters are described only once.
Page 474: Two Step Overvoltage Protection Ov2Ptov
Section 9 1MRK 504 152-UEN B Voltage protection CrvSatn × > (Equation 492) EQUATION1448 V1 EN-US IntBlkSeln : This parameter can be set to Off , Block of trip , Block all . In case of a low voltage the undervoltage function can be blocked.
Page 475: Setting Guidelines
1MRK 504 152-UEN B Section 9 Voltage protection overhead line, transformer flash over fault from the high voltage winding to the low voltage winding and so on). Malfunctioning of a voltage regulator or wrong settings under manual control (symmetrical voltage decrease). Low load compared to the reactive power generation (symmetrical voltage decrease).
Page 476: High Impedance Earthed Systems
Section 9 1MRK 504 152-UEN B Voltage protection 9.2.3.4 High impedance earthed systems M13852-19 v5 In high impedance earthed systems, earth-faults cause a voltage increase in the non-faulty phases. Two step overvoltage protection (OV2PTOV) is used to detect such faults. The setting must be above the highest occurring "normal"...
Page 477: Two Step Residual Overvoltage Protection Rov2Ptov
1MRK 504 152-UEN B Section 9 Voltage protection tResetn : Reset time for step n if definite time delay is used, given in s. The default value is 25 tnMin : Minimum operation time for inverse time characteristic for step n , given in s. For very high voltages the overvoltage function, using inverse time characteristic, can give very short t1Min longer than the operation operation time.
Page 478: Setting Guidelines
Section 9 1MRK 504 152-UEN B Voltage protection connection. The residual voltage can also be calculated internally, based on measurement of the three-phase voltages. In high impedance earthed systems the residual voltage will increase in case of any fault connected to earth. Depending on the type of fault and fault resistance the residual voltage will reach different values.
Page 479: Direct Earthed System
1MRK 504 152-UEN B Section 9 Voltage protection occurring "normal" residual voltage, and below the lowest occurring residual voltage during the faults under consideration. A metallic single-phase earth fault causes a transformer neutral to reach a voltage equal to the nominal phase-to-earth voltage. The voltage transformers measuring the phase-to-earth voltages measure zero voltage in the faulty phase.
Page 480: Settings For Two Step Residual Overvoltage Protection
Section 9 1MRK 504 152-UEN B Voltage protection IEC07000189 V1 EN-US Figure 278: Earth fault in Direct earthed system 9.3.3.6 Settings for Two step residual overvoltage protection M13853-21 v12 Operation : Off or On UBase (given in GlobalBaseSel ) is used as voltage reference for the voltage. The voltage can be fed to the IED in different ways: The IED is fed from a normal voltage transformer group where the residual voltage is calculated internally from the phase-to-earth voltages within the protection.
Page 481 1MRK 504 152-UEN B Section 9 Voltage protection > × UBase kV (Equation 496) IECEQUATION2290 V1 EN-US The setting is dependent of the required sensitivity of the protection and the system earthing. In non-effectively earthed systems the residual voltage can be maximum the rated phase-to- earth voltage, which should correspond to 100%.
Page 482: Overexcitation Protection Oexpvph
Section 9 1MRK 504 152-UEN B Voltage protection Overexcitation protection OEXPVPH IP14547-1 v3 9.4.1 Identification M14867-1 v3 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Overexcitation protection OEXPVPH U/f > SYMBOL-Q V1 EN-US 9.4.2 Application M13785-3 v6 When the laminated core of a power transformer is subjected to a magnetic flux density beyond its design limits, stray flux will flow into non-laminated components not designed to carry flux and cause eddy currents to flow.
Page 483: Setting Guidelines
1MRK 504 152-UEN B Section 9 Voltage protection Heat accumulated in critical parts during a period of overexcitation will be reduced gradually when the excitation returns to the normal value. If a new period of overexcitation occurs after a short time interval, the heating will start from a higher level, therefore, OEXPVPH must have thermal memory.
Page 484: Settings
Section 9 1MRK 504 152-UEN B Voltage protection RESET: OEXPVPH has a thermal memory, which can take a long time to reset. Activation of the RESET input will reset the function instantaneously. Recommendations for Output signals M6496-84 v7 Please see the default factory configuration for examples of configuration. ERROR: The output indicates a measuring error.
Page 485: Service Value Report
1MRK 504 152-UEN B Section 9 Voltage protection CurveType : Selection of the curve type for the inverse delay. The IEEE curves or tailor made curve can be selected depending of which one matches the capability curve best. kForIEEE : The time constant for the inverse characteristic. Select the one giving the best match to the transformer capability.
Page 486: Voltage Differential Protection Vdcptov
Section 9 1MRK 504 152-UEN B Voltage protection Table 45: Settings U/f op (%) Timer Time set (s) 7200 (max) Information on the cooling time constant T should be retrieved from the power cool transformer manufacturer. V/Hz transformer capability curve relay operate characteristic Continous 0.05...
Page 487: Application
1MRK 504 152-UEN B Section 9 Voltage protection 9.5.2 Application SEMOD153893-5 v3 The Voltage differential protection VDCPTOV functions can be used in some different applications. • Voltage unbalance protection for capacitor banks. The voltage on the bus is supervised with the voltage in the capacitor bank, phase- by phase. Difference indicates a fault, either short-circuited or open element in the capacitor bank.
Page 488: Setting Guidelines
Section 9 1MRK 504 152-UEN B Voltage protection The application to supervise the voltage on two voltage transformers in the generator circuit is shown in figure 282. To Protection Ud> To Excitation en06000389.vsd IEC06000389 V1 EN-US Figure 282: Supervision of fuses on generator circuit voltage transformers 9.5.3 Setting guidelines SEMOD153915-5 v3...
Page 489: Loss Of Voltage Check Lovptuv
1MRK 504 152-UEN B Section 9 Voltage protection tTrip : The time delay for tripping is set by this parameter. Normally, the delay does not need to be so short in capacitor bank applications as there is no fault requiring urgent tripping. tReset : The time delay for reset of tripping level element is set by this parameter.
Page 490: Advanced Users Settings
Section 9 1MRK 504 152-UEN B Voltage protection All settings are in primary values or per unit. Set operate level per phase to typically 70% of the global parameter UBase level. Set the time delay tTrip =5-20 seconds. 9.6.3.1 Advanced users settings SEMOD171929-8 v4 For advanced users the following parameters need also to be set.
Page 491: Section 10 Frequency Protection
1MRK 504 152-UEN B Section 10 Frequency protection Section 10 Frequency protection 10.1 Underfrequency protection SAPTUF IP15746-1 v3 10.1.1 Identification M14865-1 v5 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Underfrequency protection SAPTUF f < SYMBOL-P V1 EN-US 10.1.2 Application M13350-3 v4...
Page 492: Overfrequency Protection Saptof
Section 10 1MRK 504 152-UEN B Frequency protection The under frequency START value is set in Hz. All voltage magnitude related settings are made as a percentage of a global base voltage parameter. The UBase value should be set as a primary phase-to-phase value.
Page 493: Setting Guidelines
1MRK 504 152-UEN B Section 10 Frequency protection 10.2.3 Setting guidelines M14959-3 v7 All the frequency and voltage magnitude conditions in the system where SAPTOF performs its functions must be considered. The same also applies to the associated equipment, its frequency and time characteristic.
Page 494: Setting Guidelines
Section 10 1MRK 504 152-UEN B Frequency protection with a low frequency signal, especially in smaller power systems, where loss of a fairly large generator will require quick remedial actions to secure the power system integrity. In such situations load shedding actions are required at a rather high frequency level, but in combination with a large negative rate-of-change of frequency the underfrequency protection can be used at a rather high setting.
Page 495: Section 11 Multipurpose Protection
1MRK 504 152-UEN B Section 11 Multipurpose protection Section 11 Multipurpose protection 11.1 General current and voltage protection CVGAPC IP14552-1 v2 11.1.1 Identification M14886-2 v3 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number General current and voltage CVGAPC 2(I>/U<) protection...
Page 496: Current And Voltage Selection For Cvgapc Function
Section 11 1MRK 504 152-UEN B Multipurpose protection • Definite time delay for both steps Two overvoltage steps with the following built-in features • Definite time delay or Inverse Time Overcurrent TOC/IDMT delay for both steps Two undervoltage steps with the following built-in features •...
Page 497 1MRK 504 152-UEN B Section 11 Multipurpose protection Set value for parameter Comment "CurrentInput” phase3 - phase1 CVGAPC function will measure the current phasor internally calculated as the vector difference between the phase L3 current phasor and phase L1 current phasor ( IL3-IL1) MaxPh-Ph CVGAPC function will measure ph-ph current phasor with the maximum magnitude...
Page 498: Base Quantities For Cvgapc Function
Section 11 1MRK 504 152-UEN B Multipurpose protection Set value for parameter Comment "VoltageInput" MaxPh-Ph CVGAPC function will measure ph-ph voltage phasor with the maximum magnitude MinPh-Ph CVGAPC function will measure ph-ph voltage phasor with the minimum magnitude UnbalancePh-Ph CVGAPC function will measure magnitude of unbalance voltage, which is internally calculated as the algebraic magnitude difference between the ph-ph voltage phasor with maximum magnitude and ph-ph voltage phasor with minimum magnitude.
Page 499: Inadvertent Generator Energization
1MRK 504 152-UEN B Section 11 Multipurpose protection • Special thermal overload protection • Open Phase protection • Unbalance protection Generator protection • 80-95% Stator earth fault protection (measured or calculated 3Uo) • Rotor earth fault protection (with external COMBIFLEX RXTTE4 injection unit) •...
Page 500: Setting Guidelines
Section 11 1MRK 504 152-UEN B Multipurpose protection will, with a delay for example 10 s, detect the situation when the generator is not connected to the grid (standstill) and activate the overcurrent function. The overvoltage function will detect the situation when the generator is taken into operation and will disable the overcurrent function.
Page 501: Negative Sequence Overcurrent Protection
1MRK 504 152-UEN B Section 11 Multipurpose protection Enable one overcurrent stage (for example, OC1) 10. By parameter CurveType_OC1 select appropriate TOC/IDMT or definite time delayed curve in accordance with your network protection philosophy StartCurr_OC1 to value between 3-10% (typical values) 11.
Page 502 Section 11 1MRK 504 152-UEN B Multipurpose protection æ ö ç ÷ è ø (Equation 498) EQUATION1372 V1 EN-US where: is the operating time in seconds of the negative sequence overcurrent IED is the generator capability constant in seconds is the measured negative sequence current is the generator rated current By defining parameter x equal to maximum continuous negative sequence rating of the generator in accordance with the following formula...
Page 503: Generator Stator Overload Protection In Accordance With Iec Or Ansi Standards
1MRK 504 152-UEN B Section 11 Multipurpose protection When the equation is compared with the equation for the inverse time characteristic of the OC1 it is obvious that if the following rules are followed: set k equal to the generator negative sequence capability value A_OC1 equal to the value 1/x2 B_OC1 = 0.0, C_OC1 =0.0 and P_OC1 =2.0 StartCurr_OC1 equal to the value x...
Page 504 Section 11 1MRK 504 152-UEN B Multipurpose protection This formula is applicable only when measured current (for example, positive sequence current) exceeds a pre-set value (typically in the range from 105 to 125% of the generator rated current). By defining parameter x equal to the per unit value for the desired pickup for the overload IED in accordance with the following formula: x = 116% = 1.16 pu (Equation 503)
Page 505: Open Phase Protection For Transformer, Lines Or Generators And Circuit Breaker Head Flashover Protection For Generators
1MRK 504 152-UEN B Section 11 Multipurpose protection select positive sequence current as measuring quantity for this CVGAPC function make sure that the base current value for CVGAPC function is equal to the generator rated current set k = 37.5 for the IEC standard or k = 41.4 for the ANSI standard A_OC1 = 1/1.162 = 0.7432 C_OC1 = 1/1.162 = 0.7432 B_OC1 = 0.0 and P_OC1 = 2.0...
Page 506: Voltage Restrained Overcurrent Protection For Generator And Step-Up Transformer
Section 11 1MRK 504 152-UEN B Multipurpose protection 11.1.3.5 Voltage restrained overcurrent protection for generator and step-up transformer M13088-158 v3 Example will be given how to use one CVGAPC function to provide voltage restrained overcurrent protection for a generator. Let us assume that the time coordination study gives the following required settings: •...
Page 507 1MRK 504 152-UEN B Section 11 Multipurpose protection ROADir to value 90 degree Set parameter Set parameter LowVolt_VM to value 5% Enable one overcurrent step (for example, OC1) CurveType_OC1 to value IEC Def. Time 10. Select parameter StartCurr_OC1 to value 38% 11.
Page 509: Section 12 System Protection And Control
1MRK 504 152-UEN B Section 12 System protection and control Section 12 System protection and control 12.1 Multipurpose filter SMAIHPAC GUID-6B541154-D56B-452F-B143-4C2A1B2D3A1F v1 12.1.1 Identification GUID-8224B870-3DAA-44BF-B790-6600F2AD7C5D v1 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Multipurpose filter SMAIHPAC 12.1.2 Application...
Page 510: Setting Guidelines
Section 12 1MRK 504 152-UEN B System protection and control The following figure shoes typical configuration connections required to utilize this filter in conjunction with multi-purpose function as non-directional overcurrent protection. IEC13000179-1-en.vsd IEC13000179 V1 EN-US Figure 284: Required ACT configuration Such overcurrent arrangement can be for example used to achieve the subsynchronous resonance protection for turbo generators.
Page 511 1MRK 504 152-UEN B Section 12 System protection and control In order to properly extract the weak subsynchronous signal in presence of the dominating 50Hz signal the SMAI HPAC filter shall be set as given in the following table: Table 48: Proposed settings for SMAIHPAC I_HPAC_31_5Hz: SMAIHPAC:1 ConnectionType Ph —...
Page 512 Section 12 1MRK 504 152-UEN B System protection and control Setting Group1 Operation CurrentInput MaxPh IBase 1000 VoltageInput MaxPh UBase 20.50 OPerHarmRestr I_2ndI_fund 20.0 BlkLevel2nd 5000 EnRestrainCurr RestrCurrInput PosSeq RestrCurrCoeff 0.00 RCADir ROADir LowVolt_VM Setting Group1 Operation_OC1 StartCurr_OC1 30.0 CurrMult_OC1 CurveType_OC1 Programmable tDef_OC1...
Page 513: Section 13 Secondary System Supervision
1MRK 504 152-UEN B Section 13 Secondary system supervision Section 13 Secondary system supervision 13.1 Current circuit supervision CCSSPVC IP14555-1 v5 13.1.1 Identification M14870-1 v5 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Current circuit supervision CCSSPVC 13.1.2 Application...
Page 514: Fuse Failure Supervision Fufspvc
Section 13 1MRK 504 152-UEN B Secondary system supervision Ip>Block is normally set at 150% to block the function during transient The parameter conditions. The FAIL output is connected to the blocking input of the protection function to be blocked at faulty CT secondary circuits.
Page 515: Setting Guidelines
1MRK 504 152-UEN B Section 13 Secondary system supervision 13.2.3 Setting guidelines IP15000-1 v1 13.2.3.1 General M13683-3 v5 The negative and zero sequence voltages and currents always exist due to different non- symmetries in the primary system and differences in the current and voltage instrument transformers.
Page 516: Zero Sequence Based
Section 13 1MRK 504 152-UEN B Secondary system supervision   UBase (Equation 510) EQUATION1519 V5 EN-US where: is the maximal negative sequence voltage during normal operation conditions, plus a margin of 10...20% UBase GlobalBaseSel is the base voltage for the function according to the setting 3I2<...
Page 517: Delta U And Delta I
1MRK 504 152-UEN B Section 13 Secondary system supervision 13.2.3.5 Delta U and delta I GUID-02336F26-98C0-419D-8759-45F5F12580DE v7 OpDUDI to On if the delta function shall be in operation. Set the operation mode selector The setting of DU> should be set high (approximately 60% of UBase ) and the current threshold DI<...
Page 518: Setting Guidelines
Section 13 1MRK 504 152-UEN B Secondary system supervision and energisation-check function. These functions might mal-operate if there is an incorrect measured voltage due to fuse failure or other kind of faults in voltage measurement circuit. VDSPVC is designed to detect fuse failures or faults in voltage measurement circuit based on comparison of the voltages of the main and pilot fused circuits phase wise.
Page 519 1MRK 504 152-UEN B Section 13 Secondary system supervision UBase is available in the Global Base Value groups; the particular Global Base transformer. Value group, that is used by VDSPVC, is set by the setting parameter GlobalBaseSel . Ud>MainBlock and Ud>PilotAlarm should be set low (approximately 30% of The settings UBase ) so that they are sensitive to the fault on the voltage measurement circuit, since the voltage on both sides are equal in the healthy condition.
Page 521: Section 14 Control
1MRK 504 152-UEN B Section 14 Control Section 14 Control 14.1 Synchrocheck, energizing check, and synchronizing SESRSYN IP14558-1 v4 14.1.1 Identification M14889-1 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Synchrocheck, energizing check, and SESRSYN synchronizing sc/vc SYMBOL-M V1 EN-US...
Page 522: Synchrocheck
Section 14 1MRK 504 152-UEN B Control The synchronizing function compensates for the measured slip frequency as well as the circuit breaker closing delay. The phase angle advance is calculated continuously. The calculation of SlipFrequency and the set tBreaker the operation pulse sent in advance is using the measured time.
Page 523 1MRK 504 152-UEN B Section 14 Control need for a check of synchronization increases if the meshed system decreases since the risk of the two networks being out of synchronization at manual or automatic closing is greater. The synchrocheck function measures the conditions across the circuit breaker and compares them to set limits.
Page 524: Energizing Check
Section 14 1MRK 504 152-UEN B Control 14.1.2.3 Energizing check M12310-3 v11 The main purpose of the energizing check function is to facilitate the controlled re-connection of disconnected lines and buses to energized lines and buses. The energizing check function measures the bus and line voltages and compares them to both high and low threshold values.
Page 525: External Fuse Failure
(B16I). If the PSTO input is used, connected to the Local-Remote switch on the local HMI, the choice can also be from the station HMI system, typically ABB Microscada through IEC 61850–8–1 communication.
Page 526: Application Examples
Section 14 1MRK 504 152-UEN B Control 14.1.3 Application examples M12323-3 v6 The synchronizing function block can also be used in some switchyard arrangements, but with different parameter settings. Below are some examples of how different arrangements are connected to the IED analogue inputs and to the function block SESRSYN. One function block is used per circuit breaker.
Page 527: Single Circuit Breaker With Double Busbar, External Voltage Selection
1MRK 504 152-UEN B Section 14 Control 14.1.3.2 Single circuit breaker with double busbar, external voltage selection M12325-3 v8 WA1_VT/ SESRSYN WA2_VT U3PBB1* GRP_OFF U3PBB2* LINE_VT U3PLN1* WA2_MCB WA1_MCB U3PLN2* WA1_MCB/ WA1_MCB / WA2_MCB WA2_MCB UB1OK UB1FF LINE_MCB ULN1OK WA1_VT / WA2_VT ULN1FF LINE_MCB LINE_VT...
Page 528: Double Circuit Breaker
Section 14 1MRK 504 152-UEN B Control 14.1.3.4 Double circuit breaker M12329-3 v7 WA1_QA1 SESRSYN WA1_VT U3PBB1* U3PBB2* GRP_OFF LINE_VT U3PLN1* U3PLN2* WA2_ WA1_MCB UB1OK WA1_MCB WA2_MCB UB1FF WA1_MCB LINE_MCB ULN1OK WA1_VT ULN1FF WA2_VT WA1_QA1 WA2_QA1 WA2_QA1 SESRSYN WA2_VT U3PBB1* U3PBB2* GRP_OFF LINE_VT...
Page 529 1MRK 504 152-UEN B Section 14 Control Setting parameter CBConfig = 1 ½ bus CB WA1_QA1 WA1_VT SESRSYN U3 PBB1* WA2_VT U3 PBB2* LINE1_VT U3 PLN1* LINE2_VT U3 PLN2* TIE_QA1 B1 QOPEN B1 QCLD WA2_QA1 B2 QOPEN B2 QCLD LINE1_QB9 LN1 QOPEN LN1 QCLD LINE2_QB9...
Page 530: Setting Guidelines
Section 14 1MRK 504 152-UEN B Control WA1_QA1: • B1QOPEN/CLD = Position of TIE_QA1 breaker and belonging disconnectors • B2QOPEN/CLD = Position of WA2_QA1 breaker and belonging disconnectors • LN1QOPEN/CLD = Position of LINE1_QB9 disconnector • LN2QOPEN/CLD = Position of LINE2_QB9 disconnector •...
Page 531 1MRK 504 152-UEN B Section 14 Control General settings Operation : The operation mode can be set On or Off . The setting Off disables the whole function. GblBaseSelBus and GblBaseSelLine These configuration settings are used for selecting one of twelve GBASVAL functions, which then is used as base value reference voltage, for bus and line respectively.
Page 532 Section 14 1MRK 504 152-UEN B Control Setting of the voltage difference between the line voltage and the bus voltage. The difference is set depending on the network configuration and expected voltages in the two networks running asynchronously. A normal setting is 0.10-0.15 p.u. FreqDiffMin The setting FreqDiffMin is the minimum frequency difference where the systems are defined...
Page 533 1MRK 504 152-UEN B Section 14 Control Synchrocheck settings OperationSC OperationSC setting Off disables the synchrocheck function and sets the outputs On , the function is AUTOSYOK, MANSYOK, TSTAUTSY and TSTMANSY to low. With the setting in the service mode and the output signal depends on the input conditions. UHighBusSC and UHighLineSC The voltage level settings must be chosen in relation to the bus or line network voltage.
Page 534: Apparatus Control Apc
Section 14 1MRK 504 152-UEN B Control ManEnergDBDL On , manual closing is also enabled when both line voltage and bus If the parameter is set to ULowLineEnerg and ULowBusEnerg respectively, and ManEnerg is set to voltage are below DLLB , DBLL or Both . UHighBusEnerg and UHighLineEnerg The voltage level settings must be chosen in relation to the bus or line network voltage.
Page 535 1MRK 504 152-UEN B Section 14 Control Station HMI Station bus Local Local Local Apparatus Apparatus Apparatus Control Control Control breakers disconnectors earthing switches IEC08000227.vsd IEC08000227 V1 EN-US Figure 295: Overview of the apparatus control functions Features in the apparatus control function: •...
Page 536 Section 14 1MRK 504 152-UEN B Control The signal flow between the function blocks is shown in Figure 296. To realize the reservation function, the function blocks Reservation input (RESIN) and Bay reserve (QCRSV) also are included in the apparatus control function. The application description for all these functions can be found below.
Page 537: Bay Control (Qcbay)
1MRK 504 152-UEN B Section 14 Control 2 = Remote 2,3,4,5,6 3 = Faulty 4,5,6 4 = Not in use 4,5,6 5 = All 1,2,3,4,5,6 6 = Station 2,4,5,6 7 = Remote 3,4,5,6 PSTO = All, then it is no priority between operator places. All operator places are allowed to operate.
Page 538: Switch Controller (Scswi)
Section 14 1MRK 504 152-UEN B Control IEC13000016-2-en.vsd IEC13000016 V2 EN-US Figure 297: APC - Local remote function block 14.2.1.2 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 539: Switches (Sxcbr/Sxswi)
1MRK 504 152-UEN B Section 14 Control In the case when there are three one-phase switches (SXCBR) connected to the switch controller function, the switch controller will "merge" the position of the three switches to the resulting three-phase position. In case of a pole discordance situation, that is, the positions of the one-phase switches are not equal for a time longer than a settable time;...
Page 540 Section 14 1MRK 504 152-UEN B Control transferred over the station bus for evaluation in the IED. After the evaluation the operation can be executed with high security. This functionality is realized over the station bus by means of the function blocks QCRSV and RESIN.
Page 541: Interaction Between Modules
1MRK 504 152-UEN B Section 14 Control The solution in Figure can also be realized over the station bus according to the application example in Figure 300. The solutions in Figure and Figure do not have the same high security compared to the solution in Figure 298, but instead have a higher availability, since no acknowledgment is required.
Page 542: Setting Guidelines
Section 14 1MRK 504 152-UEN B Control SMPPTRC SESRSYN Synchronizing (Trip logic) (Synchrocheck & Synchronizer) in progress Trip Synchrocheck QCBAY Operator place (Bay control) selection Open cmd Close cmd Res. req. SCSWI SXCBR (Switching control) Res. granted (Circuit breaker) QCRSV (Reservation) Res.
Page 543: Switch Controller (Scswi)
1MRK 504 152-UEN B Section 14 Control LocSta is true, only commands from station level are accepted, otherwise only commands from remote level are accepted. RemoteIncStation has only effect on the IEC61850-8-1 The parameter communication. Further, when using IEC61850 edition 1 communication, the Yes , since the command LocSta is not defined in parameter should be set to IEC61850-8-1 edition 1.
Page 544: Switch (Sxcbr/Sxswi)
Section 14 1MRK 504 152-UEN B Control 14.2.3.3 Switch (SXCBR/SXSWI) M16675-3 v7 tStartMove is the supervision time for the apparatus to start moving after a command execution. When the time has expired, the switch function is reset, and a cause-code is given. tIntermediate time the position indication is allowed to be in an intermediate (00) During the state.
Page 545: Configuration Guidelines
1MRK 504 152-UEN B Section 14 Control • With basically zero current. The circuit is open on one side and has a small extension. The capacitive current is small (for example, < 5A) and power transformers with inrush current are not allowed. •...
Page 546: Application
Section 14 1MRK 504 152-UEN B Control 14.3.2.1 Application M13561-3 v8 The interlocking for line bay (ABC_LINE) function is used for a line connected to a double busbar arrangement with a transfer busbar according to figure 302. The function can also be used for a double busbar arrangement without transfer busbar or a single busbar arrangement with/without transfer busbar.
Page 547: Signals From Bus-Coupler
1MRK 504 152-UEN B Section 14 Control QB7OPTR (bay 1) BB7_D_OP QB7OPTR (bay 2) & ..QB7OPTR (bay n-1) VPQB7TR (bay 1) VP_BB7_D VPQB7TR (bay 2) & ..VPQB7TR (bay n-1) EXDU_BPB (bay 1) EXDU_BPB EXDU_BPB (bay 2)
Page 548 Section 14 1MRK 504 152-UEN B Control Signal BC12CLTR A bus-coupler connection through the own bus-coupler exists between busbar WA1 and WA2. BC17OPTR No bus-coupler connection through the own bus-coupler between busbar WA1 and WA7. BC17CLTR A bus-coupler connection through the own bus-coupler exists between busbar WA1 and WA7.
Page 549: Configuration Setting
1MRK 504 152-UEN B Section 14 Control BC12CLTR (sect.1) BC_12_CL DCCLTR (A1A2) >1 & DCCLTR (B1B2) BC12CLTR (sect.2) VPBC12TR (sect.1) VP_BC_12 & VPDCTR (A1A2) VPDCTR (B1B2) VPBC12TR (sect.2) BC17OPTR (sect.1) BC_17_OP & DCOPTR (A1A2) >1 BC17OPTR (sect.2) BC17CLTR (sect.1) BC_17_CL >1 DCCLTR (A1A2) &...
Page 550: Interlocking For Bus-Coupler Bay Abc_Bc
Section 14 1MRK 504 152-UEN B Control • QC71_OP = 1 • QC71_CL = 0 • BB7_D_OP = 1 • BC_17_OP = 1 • BC_17_CL = 0 • BC_27_OP = 1 • BC_27_CL = 0 • EXDU_BPB = 1 • VP_BB7_D = 1 •...
Page 551: Configuration
1MRK 504 152-UEN B Section 14 Control WA1 (A) WA2 (B) WA7 (C) QB20 en04000514.vsd IEC04000514 V1 EN-US Figure 306: Switchyard layout ABC_BC 14.3.3.2 Configuration M13553-138 v4 The signals from the other bays connected to the bus-coupler module ABC_BC are described below.
Page 552 Section 14 1MRK 504 152-UEN B Control QB12OPTR (bay 1) BBTR_OP QB12OPTR (bay 2) & ..QB12OPTR (bay n-1) VPQB12TR (bay 1) VP_BBTR VPQB12TR (bay 2) & ..VPQB12TR (bay n-1) EXDU_12 (bay 1) EXDU_12 EXDU_12 (bay 2)
Page 553: Signals From Bus-Coupler
1MRK 504 152-UEN B Section 14 Control For a bus-coupler bay in section 1, these conditions are valid: BBTR_OP (sect.1) BBTR_OP DCOPTR (A1A2) & >1 DCOPTR (B1B2) BBTR_OP (sect.2) VP_BBTR (sect.1) VP_BBTR & VPDCTR (A1A2) VPDCTR (B1B2) VP_BBTR (sect.2) EXDU_12 (sect.1) EXDU_12 &...
Page 554: Configuration Setting
Section 14 1MRK 504 152-UEN B Control These signals from each bus-section disconnector bay (A1A2_DC) are also needed. For B1B2_DC, corresponding signals from busbar B are used. The same type of module (A1A2_DC) is used for different busbars, that is, for both bus-section disconnector A1A2_DC and B1B2_DC. Signal DCCLTR The bus-section disconnector is closed.
Page 555: Interlocking For Transformer Bay Ab_Trafo
1MRK 504 152-UEN B Section 14 Control • QC71_OP = 1 • QC71_CL = 0 If there is no second busbar B and therefore no QB2 and QB20 disconnectors, then the interlocking for QB2 and QB20 are not used. The states for QB2, QB20, QC21, BC_12, BBTR are set to open by setting the appropriate module inputs as follows.
Page 556: Signals From Bus-Coupler
Section 14 1MRK 504 152-UEN B Control WA1 (A) WA2 (B) AB_TRAFO QA2 and QC4 are not used in this interlocking en04000515.vsd IEC04000515 V1 EN-US Figure 312: Switchyard layout AB_TRAFO M13566-4 v4 The signals from other bays connected to the module AB_TRAFO are described below. 14.3.4.2 Signals from bus-coupler M13566-6 v4...
Page 557: Configuration Setting
1MRK 504 152-UEN B Section 14 Control 14.3.4.3 Configuration setting M13566-22 v5 If there are no second busbar B and therefore no QB2 disconnector, then the interlocking for QB2 is not used. The state for QB2, QC21, BC_12 are set to open by setting the appropriate module inputs as follows.
Page 558 Section 14 1MRK 504 152-UEN B Control connection exists between busbars on one bus-section side and if on the other bus-section side a busbar transfer is in progress: Section 1 Section 2 (WA1)A1 (WA2)B1 (WA7)C A1A2_BS ABC_BC ABC_BC B1B2_BS ABC_LINE AB_TRAFO ABC_LINE AB_TRAFO...
Page 559 1MRK 504 152-UEN B Section 14 Control S1S2OPTR (B1B2) BC12OPTR (sect.1) >1 QB12OPTR (bay 1/sect.2) . . . & & BBTR_OP . . . QB12OPTR (bay n/sect.2) S1S2OPTR (B1B2) BC12OPTR (sect.2) >1 QB12OPTR (bay 1/sect.1) . . . & . . . QB12OPTR (bay n /sect.1) VPS1S2TR (B1B2) VPBC12TR (sect.1)
Page 560: Configuration Setting
Section 14 1MRK 504 152-UEN B Control S1S2OPTR (A1A2) BC12OPTR (sect.1) >1 QB12OPTR (bay 1/sect.2) . . . & & BBTR_OP . . . QB12OPTR (bay n/sect.2) S1S2OPTR (A1A2) BC12OPTR (sect.2) >1 QB12OPTR (bay 1/sect.1) . . . & . . . QB12OPTR (bay n /sect.1) VPS1S2TR (A1A2) VPBC12TR (sect.1)
Page 561: Application
1MRK 504 152-UEN B Section 14 Control 14.3.6.1 Application M13544-3 v7 The interlocking for bus-section disconnector (A1A2_DC) function is used for one bus-section disconnector between section 1 and 2 according to figure 318. A1A2_DC function can be used for different busbars, which includes a bus-section disconnector. WA1 (A1) WA2 (A2) A1A2_DC...
Page 562 Section 14 1MRK 504 152-UEN B Control Signal QB1OPTR QB1 is open. QB2OPTR QB2 is open (AB_TRAFO, ABC_LINE). QB220OTR QB2 and QB20 are open (ABC_BC). VPQB1TR The switch status of QB1 is valid. VPQB2TR The switch status of QB2 is valid. VQB220TR The switch status of QB2 and QB20 are valid.
Page 563 1MRK 504 152-UEN B Section 14 Control QB1OPTR (bay 1/sect.A2) S2DC_OP . . . & ..QB1OPTR (bay n/sect.A2) DCOPTR (A2/A3) VPQB1TR (bay 1/sect.A2) VPS2_DC . . . & ..VPQB1TR (bay n/sect.A2) VPDCTR (A2/A3) EXDU_BB (bay 1/sect.A2)
Page 564: Signals In Double-Breaker Arrangement
Section 14 1MRK 504 152-UEN B Control QB2OPTR (QB220OTR)(bay 1/sect.B2) S2DC_OP . . . & ..QB2OPTR (QB220OTR)(bay n/sect.B2) DCOPTR (B2/B3) VPQB2TR(VQB220TR) (bay 1/sect.B2) VPS2_DC . . . & ..VPQB2TR(VQB220TR) (bay n/sect.B2) VPDCTR (B2/B3) EXDU_BB (bay 1/sect.B2)
Page 565 1MRK 504 152-UEN B Section 14 Control Signal QB1OPTR QB1 is open. QB2OPTR QB2 is open. VPQB1TR The switch status of QB1 is valid. VPQB2TR The switch status of QB2 is valid. EXDU_DB No transmission error from the bay that contains the above information. The logic is identical to the double busbar configuration “Signals in single breaker arrangement”.
Page 566: Signals In 1 1/2 Breaker Arrangement
Section 14 1MRK 504 152-UEN B Control QB2OPTR (bay 1/sect.B1) S1DC_OP . . . & ..QB2OPTR (bay n/sect.B1) VPQB2TR (bay 1/sect.B1) VPS1_DC . . . & ..VPQB2TR (bay n/sect.B1) EXDU_DB (bay 1/sect.B1) EXDU_BB .
Page 567: Interlocking For Busbar Earthing Switch Bb_Es
1MRK 504 152-UEN B Section 14 Control The project-specific logic is the same as for the logic for the double-breaker configuration. Signal S1DC_OP All disconnectors on bus-section 1 are open. S2DC_OP All disconnectors on bus-section 2 are open. VPS1_DC The switch status of disconnectors on bus-section 1 is valid. VPS2_DC The switch status of disconnectors on bus-section 2 is valid.
Page 568 Section 14 1MRK 504 152-UEN B Control These signals from each line bay (ABC_LINE), each transformer bay (AB_TRAFO), and each bus- coupler bay (ABC_BC) are needed: Signal QB1OPTR QB1 is open. QB2OPTR QB2 is open (AB_TRAFO, ABC_LINE) QB220OTR QB2 and QB20 are open (ABC_BC) QB7OPTR QB7 is open.
Page 569 1MRK 504 152-UEN B Section 14 Control QB1OPTR (bay 1/sect.A1) BB_DC_OP . . . & ..QB1OPTR (bay n/sect.A1) DCOPTR (A1/A2) VPQB1TR (bay 1/sect.A1) VP_BB_DC . . . & ..VPQB1TR (bay n/sect.A1) VPDCTR (A1/A2) EXDU_BB (bay 1/sect.A1)
Page 570 Section 14 1MRK 504 152-UEN B Control QB2OPTR(QB220OTR)(bay 1/sect.B1) BB_DC_OP . . . & ..QB2OPTR (QB220OTR)(bay n/sect.B1) DCOPTR (B1/B2) VPQB2TR(VQB220TR) (bay 1/sect.B1) VP_BB_DC . . . & ..VPQB2TR(VQB220TR) (bay n/sect.B1) VPDCTR (B1/B2) EXDU_BB (bay 1/sect.B1) .
Page 571: Signals In Double-Breaker Arrangement
1MRK 504 152-UEN B Section 14 Control QB7OPTR (bay 1) BB_DC_OP . . . & ..QB7OPTR (bay n) VPQB7TR (bay 1) VP_BB_DC . . . & ..VPQB7TR (bay n) EXDU_BB (bay 1) EXDU_BB .
Page 572: Signals In 1 1/2 Breaker Arrangement
Section 14 1MRK 504 152-UEN B Control is used for different busbars, that is, for both bus-section disconnectors A1A2_DC and B1B2_DC. Signal DCOPTR The bus-section disconnector is open. VPDCTR The switch status of bus-section disconnector DC is valid. EXDU_DC No transmission error from the bay that contains the above information. The logic is identical to the double busbar configuration described in section “Signals in single breaker arrangement”.
Page 573: Configuration Setting
1MRK 504 152-UEN B Section 14 Control WA1 (A) WA2 (B) DB_BUS_B DB_BUS_A QB61 QB62 DB_LINE en04000518.vsd IEC04000518 V1 EN-US Figure 339: Switchyard layout double circuit breaker M13584-4 v4 For a double circuit-breaker bay, the modules DB_BUS_A, DB_LINE and DB_BUS_B must be used.
Page 574: Application
Section 14 1MRK 504 152-UEN B Control 14.3.9.1 Application M13570-3 v6 The interlocking for 1 1/2 breaker diameter (BH_CONN, BH_LINE_A, BH_LINE_B) functions are used for lines connected to a 1 1/2 breaker diameter according to figure 340. WA1 (A) WA2 (B) BH_LINE_B BH_LINE_A QB61...
Page 575: Voltage Control
1MRK 504 152-UEN B Section 14 Control If there is no voltage supervision, then set the corresponding inputs as follows: • VOLT_OFF = 1 • VOLT_ON = 0 14.4 Voltage control SEMOD158732-1 v2 14.4.1 Identification SEMOD173054-2 v5 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification...
Page 576 Section 14 1MRK 504 152-UEN B Control Of these alternatives, the first and the last require communication between the function control blocks of the different transformers, whereas the middle alternative does not require any communication. The voltage control includes many extra features such as possibility to avoid simultaneous tapping of parallel transformers, hot stand by regulation of a transformer within a parallel group, with a LV CB open, compensation for a possible capacitor bank on the LV side bay of a transformer, extensive tap changer monitoring including contact wear and hunting detection,...
Page 577 1MRK 504 152-UEN B Section 14 Control Measured Quantities SEMOD159053-61 v4 In normal applications, the LV side of the transformer is used as the voltage measuring point. If necessary, the LV side current is used as load current to calculate the line-voltage drop to the regulation point.
Page 578 Section 14 1MRK 504 152-UEN B Control earth voltage can increase with as much as a factor √3 in case of earth faults in a non-solidly earthed system. The analog input signals are normally common with other functions in the IED for example, protection functions.
Page 579 1MRK 504 152-UEN B Section 14 Control Umax , TR1ATCC can initiate one or more fast step down If the busbar voltage rises above commands (ULOWER commands) in order to bring the voltage back into the security range Umin , and Umax ). The fast step down function operation can be set in one of the (settings FSDMode .
Page 580 Section 14 1MRK 504 152-UEN B Control t1=180 t1=150 t1=120 t1=90 t1=60 t1=30 IEC06000488_2_en.vsd IEC06000488 V2 EN-US Figure 343: Inverse time characteristic for TR1ATCC and TR8ATCC t2 , will be used for consecutive commands (commands in the same The second time delay, direction as the first command).
Page 581 1MRK 504 152-UEN B Section 14 Control IEC06000487-2-en.vsd IEC06000487 V2 EN-US Figure 344: Vector diagram for line voltage drop compensation The calculated load voltage U is shown on the local HMI as value ULOAD under Main menu/ Test/Function status/Control/TransformerVoltageControl(ATCC,90)/TR1ATCC:x/ TR8ATCC:x. Load voltage adjustment SEMOD159053-118 v6 Due to the fact that most loads are proportional to the square of the voltage, it is possible to...
Page 582 Section 14 1MRK 504 152-UEN B Control Load current I2Base Rated current, LV winding i (corresponding to Constant load voltage adjust. factor for active input LVAConst1, LVAConst2, LVAConst3 and LVAConst4 ) It shall be noted that the adjustment factor is negative in order to decrease the load voltage and positive in order to increase the load voltage.
Page 583 1MRK 504 152-UEN B Section 14 Control simultaneously, and consequently they will blindly follow the master irrespective of their individual tap positions. Effectively this means that if the tap positions of the followers were harmonized with the master from the beginning, they would stay like that as long as all transformers in the parallel group continue to participate in the parallel control.
Page 584 Section 14 1MRK 504 152-UEN B Control Load en06000486.vsd IEC06000486 V1 EN-US Figure 346: 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 585 1MRK 504 152-UEN B Section 14 Control 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 current. Figure below shows this situation with T1 being on a higher tap than ...T2 ...T1...
Page 586 Section 14 1MRK 504 152-UEN B Control different IEDs. If the functions are located in different IEDs they must communicate via GOOSE interbay communication on the IEC 61850 communication protocol. Complete exchange of TR8ATCC data, analog as well as binary, via GOOSE is made cyclically every 300 ms. The busbar voltage U is measured individually for each transformer in the parallel group by its associated TR8ATCC function.
Page 587 1MRK 504 152-UEN B Section 14 Control USet values for individual In parallel operation with the circulating current method, different transformers can cause the voltage regulation to be unstable. For this reason, the mean value USet for parallel operating transformers can be automatically calculated and used for the On / Off by setting parameter OperUsetPar .
Page 588 Section 14 1MRK 504 152-UEN B Control OperHoming DISC on TR8ATCC block is activated by open LV CB. If now the setting parameter On for that transformer, TR8ATCC will act in the following way: • The algorithm calculates the “true” busbar voltage, by averaging the voltage measurements of the other transformers included in the parallel group (voltage measurement of the “disconnected transformer”...
Page 589 1MRK 504 152-UEN B Section 14 Control If one follower in a master follower parallel group is put in manual mode, still with the setting OperationAdaptOn , the rest of the group will continue in automatic master follower control. The follower in manual mode will of course disregard any possible tapping of the master. However, as one transformer in the parallel group is now exempted from the parallel control, the binary output signal ADAPT on TR8ATCC function block will be activated for the rest of the parallel group.
Page 590 Section 14 1MRK 504 152-UEN B Control to the load on the LV side, or it may be divided between the LV and the HV side. In the latter case, the part of I that goes to the HV side will divide between the two transformers and it will be measured with opposite direction for T2 and T1.
Page 591 1MRK 504 152-UEN B Section 14 Control With the four outputs in the function block available, it is possible to do more than just supervise a level of power flow in one direction. By combining the outputs with logical elements in application configuration, it is also possible to cover for example, intervals as well as areas in the P-Q plane.
Page 592 Section 14 1MRK 504 152-UEN B Control Communication between these TR8ATCCs is made either on the GOOSE interbay communication on the IEC 61850 protocol if TR8ATCC functions reside in different IEDs, or alternatively configured internally in one IED if multiple instances of TR8ATCC reside in the same IED.
Page 593 1MRK 504 152-UEN B Section 14 Control Manual configuration of VCTR GOOSE data set is required. Note that both data value attributes and quality attributes have to be mapped. The following data objects must be configured: • BusV • LodAIm •...
Page 594 Section 14 1MRK 504 152-UEN B Control Total Block: Prevents any tap changer operation independently of the control mode (automatic as well as manual). Setting parameters for blocking that can be set in TR1ATCC or TR8ATCC under general settings in PST/local HMI are listed in table 55. Table 55: Blocking settings Setting Values (Range)
Page 595 1MRK 504 152-UEN B Section 14 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 596 Section 14 1MRK 504 152-UEN B 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 597 1MRK 504 152-UEN B Section 14 Control Table 56: Blocking settings Setting Value (Range) Description On / Off TotalBlock (manually reset) TR1ATCC or TR8ATCC function can be totally blocked via the TotalBlock , setting parameter On / Off from which can be set the local HMI or PST.
Page 598 Section 14 1MRK 504 152-UEN B Control Table 58: 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 599 1MRK 504 152-UEN B Section 14 Control • Under-Voltage • Command error • Position indication error • Tap changer error • Reversed Action • Circulating current • Communication error Master-follower method When the master is blocked, the followers will not tap by themselves and there is consequently no need for further mutual blocking.
Page 600 Section 14 1MRK 504 152-UEN B Control Tap changer extreme positions SEMOD159053-339 v2 This feature supervises the extreme positions of the tap changer according to the settings LowVoltTap and HighVoltTap . When the tap changer reaches its lowest/highest position, the corresponding ULOWER/URAISE command is prevented in both automatic and manual mode.
Page 601 1MRK 504 152-UEN B Section 14 Control signal in this case is thus that resetting of TR1ATCC or TR8ATCC can sometimes be made faster, which in turn makes the system ready for consecutive commands in a shorter time. tTCTimeout times out before The second use is to detect a jammed tap changer.
Page 602: Setting Guidelines
Section 14 1MRK 504 152-UEN B Control The NoOfOperations counter simply counts the total number of operations (incremental counter). Both counters are stored in a non-volatile memory as well as, the times and dates of their last reset. These dates are stored automatically when the command to reset the counter is issued. It is therefore necessary to check that the IED internal time is correct before these counters are reset.
Page 603: Tr1Atcc Or Tr8Atcc Setting Group
1MRK 504 152-UEN B Section 14 Control OVPartBk : Selection of action to be taken in case the busbar voltage U Umax . exceeds RevActPartBk : Selection of action to be taken in case Reverse Action has been activated. TapChgBk : Selection of action to be taken in case a Tap Changer Error has been identified. TapPosBk : Selection of action to be taken in case of Tap Position Error, or if the tap changer has reached an end position.
Page 604 Section 14 1MRK 504 152-UEN B Control selected to a value near the power transformer’s tap changer voltage step (typically 75 - 125% of the tap changer step). UDeadbandInner : Setting value for one half of the inner deadband, to be set in percent of UBase .
Page 605 1MRK 504 152-UEN B Section 14 Control method and with no circulation (for example, assume two equal transformers on the same tap position). The load current lags the busbar voltage U with the power factor j and the Rline and Xline is designated j1. argument of the impedance Rline Xline...
Page 606 Section 14 1MRK 504 152-UEN B Control The effect of changing power factor of the load will be that j2 will no longer be close to -90° resulting in U being smaller or greater than U if the ratio Rline/Xline is not adjusted. Rline and Xline for j = 11°...
Page 607 1MRK 504 152-UEN B Section 14 Control Load voltage adjustment (LVA) LVAConst1 : Setting of the first load voltage adjustment value. This adjustment of the target USet is given in percent of UBase . value LVAConst2 : Setting of the second load voltage adjustment value. This adjustment of the target USet is given in percent of UBase .
Page 608 Section 14 1MRK 504 152-UEN B Control P> en06000634_2_en.vsd IEC06000634 V2 EN-US Figure 355: 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 609 1MRK 504 152-UEN B Section 14 Control ´ D = ´ ´ Comp a 100% ´ (Equation 528) EQUATION1941 V1 EN-US where: • DU is the deadband setting in percent. • n denotes the desired number of difference in tap position between the transformers, that shall give a voltage deviation U which corresponds to the dead-band setting.
Page 610: Tcmyltc And Tclyltc General Settings
Section 14 1MRK 504 152-UEN B Control 14.4.3.3 TCMYLTC and TCLYLTC general settings SEMOD171501-150 v7 GlobalBaseSel : Selects the global base value group used by the function to define ( IBase ), UBase ) and ( SBase ). LowVoltTap : This gives the tap position for the lowest LV-voltage. HighVoltTap : This gives the tap position for the highest LV-voltage.
Page 611: Identification
1MRK 504 152-UEN B Section 14 Control 14.5.1 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 14.5.2 Application SEMOD114927-4 v6 The logic rotating switch for function selection and LHMI presentation function (SLGAPC) (or the selector switch function block, as it is also known) is used to get a selector switch functionality similar with the one provided by a hardware multi-position selector switch.
Page 612: Identification
Section 14 1MRK 504 152-UEN B Control 14.6.1 Identification SEMOD167850-2 v3 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Selector mini switch VSGAPC 14.6.2 Application SEMOD158803-5 v6 Selector mini switch (VSGAPC) function is a multipurpose function used in the configuration tool in PCM600 for a variety of applications, as a general purpose switch.
Page 613: Identification
1MRK 504 152-UEN B Section 14 Control 14.7.1 Identification GUID-E16EA78F-6DF9-4B37-A92D-5C09827E2297 v3 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Generic communication function for DPGAPC Double Point indication 14.7.2 Application SEMOD55391-5 v8 Generic communication function for Double Point indication (DPGAPC) function block is used to send double point position indication to other systems, equipment or functions in the substation through IEC 61850-8-1 or other communication protocols.
Page 614: Identification
Section 14 1MRK 504 152-UEN B Control 14.8.1 Identification SEMOD176456-2 v3 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Single point generic control 8 signals SPC8GAPC 14.8.2 Application SEMOD176511-4 v4 The Single point generic control 8 signals (SPC8GAPC) function block is a collection of 8 single point commands, designed to bring in commands from REMOTE (SCADA) to those parts of the logic configuration that do not need complicated function blocks that have the capability to receive commands (for example SCSWI).
Page 615: Setting Guidelines
1MRK 504 152-UEN B Section 14 Control (for LON).AUTOBITS function block have 32 individual outputs which each can be mapped as a Binary Output point in DNP3. The output is operated by a "Object 12" in DNP3. This object contains parameters for control-code, count, on-time and off-time. To operate an AUTOBITS output point, send a control-code of latch-On, latch-Off, pulse-On, pulse-Off, Trip or Close.
Page 616 Section 14 1MRK 504 152-UEN B Control Single command function Configuration logic circuits SINGLECMD Close CB1 CMDOUTy OUTy User- & defined conditions Synchro- check en04000206.vsd IEC04000206 V2 EN-US Figure 358: Application example showing a logic diagram for control of a circuit breaker via configuration logic circuits Figure and figure...
Page 617: Setting Guidelines
1MRK 504 152-UEN B Section 14 Control Single command function Configuration logic circuits SINGLESMD Device 1 CMDOUTy OUTy & User- defined conditions en04000208.vsd IEC04000208 V2 EN-US Figure 360: Application example showing a logic diagram for control of external devices via configuration logic circuits 14.10.3 Setting guidelines M12448-3 v2...
Page 619: Section 15 Scheme Communication
1MRK 504 152-UEN B Section 15 Scheme communication Section 15 Scheme communication 15.1 Scheme communication logic for residual overcurrent protection ECPSCH IP14711-1 v2 15.1.1 Identification M14882-1 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Scheme communication logic for ECPSCH residual overcurrent protection 15.1.2...
Page 620: Setting Guidelines
Section 15 1MRK 504 152-UEN B Scheme communication 15.1.3 Setting guidelines M13920-4 v6 The parameters for the scheme communication logic for residual overcurrent protection function are set via the local HMI or PCM600. The following settings can be done for the scheme communication logic for residual overcurrent protection function: Operation : Off or On .
Page 621: Weak-End Infeed Logic
1MRK 504 152-UEN B Section 15 Scheme communication IEC9900043-2.vsd IEC99000043 V3 EN-US Figure 361: Current distribution for a fault close to B side when all breakers are closed IEC99000044-2.vsd IEC99000044 V3 EN-US Figure 362: Current distribution for a fault close to B side when breaker at B1 is opened When the breaker on the parallel line operates, the fault current on the healthy line is reversed.
Page 622: Current Reversal
Section 15 1MRK 504 152-UEN B Scheme communication 15.2.3.1 Current reversal M13933-6 v5 CurrRev to On or Off . The current reversal function is set on or off by setting the parameter tPickUpRev and tDelayRev . Time delays shall be set for the timers tPickUpRev is chosen shorter (<80%) than the breaker opening time, but minimum 20 ms.
Page 623 1MRK 504 152-UEN B Section 15 Scheme communication The zero sequence voltage for a fault at the remote line end and appropriate fault resistance is calculated. To avoid unwanted trip from the weak-end infeed logic (if spurious signals should occur), set the operate value of the broken delta voltage level detector (3U0) higher than the maximum false network frequency residual voltage that can occur during normal service conditions.
Page 625: Section 16 Logic
1MRK 504 152-UEN B Section 16 Logic Section 16 Logic 16.1 Tripping logic SMPPTRC IP14576-1 v4 16.1.1 Identification SEMOD56226-2 v6 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Tripping logic SMPPTRC I->O SYMBOL-K V1 EN-US 16.1.2 Application M12252-3 v8 All trip signals from the different protection functions shall be routed through the trip logic.
Page 626: Three-Phase Tripping
Section 16 1MRK 504 152-UEN B Logic To prevent closing of a circuit breaker after a trip the function can block the closing. The two instances of the SMPPTRC function are identical except, for the name of the function block (SMPPTRC1 and SMPPTRC2). References will therefore only be made to SMPPTRC1 in the following description, but they also apply to SMPPTRC2.
Page 627 1MRK 504 152-UEN B Section 16 Logic The inputs are combined with the phase selection logic and the start signals from the phase selector must be connected to the inputs PSL1, PSL2 and PSL3 to achieve the tripping on the respective single-phase trip outputs TRL1, TRL2 and TRL3.
Page 628: Single-, Two- Or Three-Phase Tripping
Section 16 1MRK 504 152-UEN B Logic 16.1.2.3 Single-, two- or three-phase tripping M14828-15 v3 The single-/two-/three-phase tripping mode provides single-phase tripping for single-phase faults, two-phase tripping for two-phase faults and three-phase tripping for multi-phase faults. The operating mode is always used together with an autoreclosing scheme with setting Program = 1/2/3Ph or Program = 1/3Ph attempt.
Page 629: Trip Matrix Logic Tmagapc
1MRK 504 152-UEN B Section 16 Logic tWaitForPHS : Sets a duration after any of the inputs 1PTRZ or 1PTREF has been activated during which a phase selection must occur to get a single phase trip. If no phase selection has been achieved a three-phase trip will be issued after the time has elapsed.
Page 630: Application
Section 16 1MRK 504 152-UEN B Logic 16.3.2 Application GUID-70B268A9-B248-422D-9896-89FECFF80B75 v1 Group alarm logic function ALMCALH is used to route alarm signals to different LEDs and/or output contacts on the IED. ALMCALH output signal and the physical outputs allows the user to adapt the alarm signal to physical tripping outputs according to the specific application needs.
Page 631: Setting Guidelines
1MRK 504 152-UEN B Section 16 Logic INDCALH output signal IND and the physical outputs allows the user to adapt the indication signal to physical outputs according to the specific application needs. 16.5.1.3 Setting guidelines GUID-7E776D39-1A42-4F90-BF50-9B38F494A01E v2 Operation : On or Off 16.6 Configurable logic blocks IP11009-1 v3...
Page 632: Fixed Signal Function Block Fxdsign
Section 16 1MRK 504 152-UEN B Logic IEC09000695_2_en.vsd IEC09000695 V2 EN-US Figure 367: Example designation, serial execution number and cycle time for logic function IEC09000310-1-en.vsd IEC09000310 V1 EN-US Figure 368: 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 633: Application
1MRK 504 152-UEN B Section 16 Logic 16.7.2 Application M15322-3 v11 The Fixed signals function FXDSIGN generates nine pre-set (fixed) signals that can be used in the configuration of an IED, either for forcing the unused inputs in other function blocks to a certain level/value, or for creating certain logic.
Page 634: Boolean 16 To Integer Conversion B16I
Section 16 1MRK 504 152-UEN B Logic 16.8 Boolean 16 to Integer conversion B16I SEMOD175715-1 v1 16.8.1 Identification SEMOD175721-2 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Boolean 16 to integer conversion B16I 16.8.2 Application SEMOD175832-4 v4 Boolean 16 to integer conversion function B16I is used to transform a set of 16 binary (logical) signals into an integer.
Page 635: Boolean To Integer Conversion With Logical Node Representation, 16 Bit Btigapc
1MRK 504 152-UEN B Section 16 Logic The sum of the numbers in column “Value when activated” when all INx (where 1≤x≤16) are active that is=1; is 65535. 65535 is the highest boolean value that can be converted to an integer by the B16I function block.
Page 636: Integer To Boolean 16 Conversion Ib16
Section 16 1MRK 504 152-UEN B Logic Name of input Type Default Description Value when Value when activated deactivated IN12 BOOLEAN Input 12 2048 IN13 BOOLEAN Input 13 4096 IN14 BOOLEAN Input 14 8192 IN15 BOOLEAN Input 15 16384 IN16 BOOLEAN Input 16 32768...
Page 637: Integer To Boolean 16 Conversion With Logic Node Representation Itbgapc
1MRK 504 152-UEN B Section 16 Logic Name of input Type Default Description Value when Value when activated deactivated BOOLEAN Input 6 BOOLEAN Input 7 BOOLEAN Input 8 BOOLEAN Input 9 IN10 BOOLEAN Input 10 IN11 BOOLEAN Input 11 1024 IN12 BOOLEAN Input 12...
Page 638: Elapsed Time Integrator With Limit Transgression And Overflow Supervision Teigapc
Section 16 1MRK 504 152-UEN B Logic Table 60: Output signals Name of OUTx Type Description Value when Value when activated deactivated OUT1 BOOLEAN Output 1 OUT2 BOOLEAN Output 2 OUT3 BOOLEAN Output 3 OUT4 BOOLEAN Output 4 OUT5 BOOLEAN Output 5 OUT6 BOOLEAN...
Page 639: Comparator For Integer Inputs - Intcomp
1MRK 504 152-UEN B Section 16 Logic A resolution of 10 ms can be achieved when the settings are defined within the range 1.00 second ≤ tAlarm ≤ 99 999.99 seconds 1.00 second ≤ tWarning ≤ 99 999.99 seconds. If the values are above this range the resolution becomes lower 99 999.99 seconds ≤...
Page 640: Setting Example
Section 16 1MRK 504 152-UEN B Logic 16.13.4 Setting example GUID-13302FD6-1585-42FE-BD6D-44F231982C59 v1 For absolute comparison between inputs: EnaAbs = 1 Set the RefSource = 1 Set the Similarly for Signed comparison between inputs EnaAbs = 0 Set the Set the RefSource = 1 For absolute comparison between input and setting EnaAbs = 1...
Page 641: Setting Example
1MRK 504 152-UEN B Section 16 Logic RefSource : This setting is used to select the reference source between input and setting for comparison. REF : The function will take reference value from input REF • SetValue : The function will take reference value from setting SetValue •...
Page 642 Section 16 1MRK 504 152-UEN B Logic EqualBandHigh = 5.0 % of reference value EqualBandLow = 5.0 % of reference value . Application manual...
Page 643: Section 17 Monitoring
1MRK 504 152-UEN B Section 17 Monitoring Section 17 Monitoring 17.1 Measurement GUID-9D2D47A0-FE62-4FE3-82EE-034BED82682A v1 17.1.1 Identification SEMOD56123-2 v7 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Measurements CVMMXN P, Q, S, I, U, f SYMBOL-RR V1 EN-US Phase current measurement CMMXU SYMBOL-SS V1 EN-US...
Page 644: Zero Clamping
Section 17 1MRK 504 152-UEN B Monitoring The available measured values of an IED are depending on the actual hardware (TRM) and the logic configuration made in PCM600. All measured values can be supervised with four settable limits that is, low-low limit, low limit, high limit and high-high limit.
Page 645: Setting Guidelines
1MRK 504 152-UEN B Section 17 Monitoring Example how CVMMXN is operating: The following outputs can be observed on the local HMI under Monitoring/Servicevalues/ SRV1 Apparent three-phase power Active three-phase power Reactive three-phase power Power factor ILAG I lagging U ILEAD I leading U System mean voltage, calculated according to selected mode...
Page 646 Section 17 1MRK 504 152-UEN B Monitoring UGenZeroDb : Minimum level of voltage in % of UBase used as indication of zero voltage (zero point clamping). If measured value is below UGenZeroDb calculated S, P, Q and PF will be zero. IGenZeroDb : Minimum level of current in % of IBase used as indication of zero current (zero IGenZeroDb calculated S, P, Q and PF will be zero.
Page 647: Setting Examples
1MRK 504 152-UEN B Section 17 Monitoring XLimHyst : Hysteresis value in % of range and is common for all limits. All phase angles are presented in relation to defined reference channel. The parameter PhaseAngleRef defines the reference, see section "". Calibration curves It is possible to calibrate the functions (CVMMXN, CMMXU, VMMXU and VNMMXU) to get class 0.5 presentations of currents, voltages and powers.
Page 648 Section 17 1MRK 504 152-UEN B Monitoring Measurement function application for a 110kV OHL SEMOD54481-12 v9 Single line diagram for this application is given in figure 372: 110kV Busbar 600/1 A 110 0,1 110kV OHL IEC09000039-2-en.vsd IEC09000039-1-EN V2 EN-US Figure 372: Single line diagram for 110kV OHL application In order to monitor, supervise and calibrate the active and reactive power as indicated in figure it is necessary to do the following:...
Page 649 1MRK 504 152-UEN B Section 17 Monitoring Table 62: Settings parameters for level supervision Setting Short Description Selected Comments value PMin Minimum value -100 Minimum expected load PMax Minimum value Maximum expected load PZeroDb Zero point clamping in 0.001% 3000 Set zero point clamping to 45 MW that is, 3% of range of 200 MW...
Page 650 Section 17 1MRK 504 152-UEN B Monitoring 110kV Busbar 200/1 31,5 MVA 110/36,75/(10,5) kV Yy0(d5) 500/5 L1L2 35 / 0,1kV 35kV Busbar IEC09000040-1-en.vsd IEC09000040-1-EN V1 EN-US Figure 373: Single line diagram for transformer application In order to measure the active and reactive power as indicated in figure 373, it is necessary to do the following: PhaseAngleRef (see section Set correctly all CT and VT and phase angle reference channel...
Page 651 1MRK 504 152-UEN B Section 17 Monitoring Table 64: General settings parameters for the Measurement function Setting Short description Selected Comment value Operation Operation Off / On Function must be PowAmpFact Amplitude factor to scale 1.000 Typically no scaling is required power calculations PowAngComp Angle compensation for phase...
Page 652 Section 17 1MRK 504 152-UEN B Monitoring 220kV Busbar 300/1 100 MVA 242/15,65 kV 15 / 0,1kV L1L2 L2L3 100MVA 15,65kV 4000/5 IEC09000041-1-en.vsd IEC09000041-1-EN V1 EN-US Figure 374: Single line diagram for generator application In order to measure the active and reactive power as indicated in figure 374, it is necessary to do the following: PhaseAngleRef (see Set correctly all CT and VT data and phase angle reference channel...
Page 653: Gas Medium Supervision Ssimg
1MRK 504 152-UEN B Section 17 Monitoring Table 65: General settings parameters for the Measurement function Setting Short description Selected Comment value Operation Operation Off/On Function must be PowAmpFact Amplitude factor to scale 1.000 Typically no scaling is required power calculations PowAngComp Angle compensation for phase Typically no angle compensation is required.
Page 654: Application
Section 17 1MRK 504 152-UEN B Monitoring 17.3.2 Application GUID-140AA10C-4E93-4C23-AD57-895FADB0DB29 v5 Liquid medium supervision (SSIML) is used for monitoring the circuit breaker condition. Proper arc extinction by the compressed oil in the circuit breaker is very important. When the level becomes too low, compared to the required value, the circuit breaker operation is blocked to minimize the risk of internal failures.
Page 655 1MRK 504 152-UEN B Section 17 Monitoring 100000 50000 20000 10000 5000 2000 1000 Interrupted current (kA) IEC12000623_1_en.vsd IEC12000623 V1 EN-US Figure 375: 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 656: Setting Guidelines
Section 17 1MRK 504 152-UEN B Monitoring depends on the type of circuit breaker. The energy values were accumulated using the current value and exponent factor for CB contact opening duration. When the next CB opening operation is started, the energy is accumulated from the previous value. The accumulated energy value can be reset to initial accumulation energy value by using the Reset accumulating energy input, RSTIPOW.
Page 657: Event Function Event
1MRK 504 152-UEN B Section 17 Monitoring tTrCloseAlm : Setting of alarm level for closing travel time. OperAlmLevel : Alarm limit for number of mechanical operations. OperLOLevel : Lockout limit for number of mechanical operations. CurrExponent : Current exponent setting for energy calculation. It varies for different types of 0.5 to 3.0 .
Page 658: Setting Guidelines
Section 17 1MRK 504 152-UEN B Monitoring created from any available signal in the IED that is connected to the Event function (EVENT). The event function block is used for LON and SPA communication. Analog and double indication values are also transferred through EVENT function. 17.5.3 Setting guidelines IP14841-1 v1...
Page 659: Application
1MRK 504 152-UEN B Section 17 Monitoring 17.6.2 Application M12152-3 v7 To get fast, complete and reliable information about disturbances in the primary and/or in the secondary system it is very important to gather information on fault currents, voltages and events.
Page 660 Section 17 1MRK 504 152-UEN B Monitoring the analog input function blocks (AxRADR),. Disturbance report function acquires information from both AxRADR and BxRBDR. AxRADR Disturbance Report DRPRDRE Analog signals Trip value rec BxRBDR Disturbance recorder Binary signals Event list Event recorder Indications IEC09000337-3-en.vsdx IEC09000337 V3 EN-US...
Page 661: Recording Times
1MRK 504 152-UEN B Section 17 Monitoring Operation M12179-82 v5 The operation of Disturbance report function DRPRDRE has to be set On or Off . If Off is selected, note that no disturbance report is registered, and none sub-function will operate (the only general parameter that influences Event list (EL)).
Page 662: Binary Input Signals
Section 17 1MRK 504 152-UEN B Monitoring PostRetrig = Off The function is insensitive for new trig signals during post fault time. PostRetrig = On The function completes current report and starts a new complete report that is, the latter will include: •...
Page 663: Sub-Function Parameters
1MRK 504 152-UEN B Section 17 Monitoring OperationM = On , waveform (samples) will also be recorded and reported in graph. NomValueM : Nominal value for input M. OverTrigOpM , UnderTrigOpM : Over or Under trig operation, Disturbance report may trig for On ) or not ( Off ).
Page 664: Logical Signal Status Report Binstatrep
Section 17 1MRK 504 152-UEN B Monitoring Minimize the number of recordings: • Binary signals: Use only relevant signals to start the recording that is, protection trip, carrier receive and/or start signals. • Analog signals: The level triggering should be used with great care, since unfortunate settings will cause enormously number of recordings.
Page 665: Identification
1MRK 504 152-UEN B Section 17 Monitoring 17.8.1 Identification GUID-F3FB7B33-B189-4819-A1F0-8AC7762E9B7E v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Limit counter L4UFCNT 17.8.2 Application GUID-41B13135-5069-4A5A-86CE-B7DBE9CFEF38 v2 Limit counter (L4UFCNT) is intended for applications where positive and/or negative flanks on a binary signal need to be counted.
Page 666 Section 17 1MRK 504 152-UEN B Monitoring tAlarm and tWarning are independent settings, that is, there is no check if tAlarm > tWarning . The limit for the overflow supervision is fixed at 99999.9 hours. tAddToTime is a user settable time parameter in hours. The setting Application manual...
Page 667: Section 18 Metering
1MRK 504 152-UEN B Section 18 Metering Section 18 Metering 18.1 Pulse-counter logic PCFCNT IP14600-1 v3 18.1.1 Identification M14879-1 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Pulse-counter logic PCFCNT S00947 V1 EN-US 18.1.2 Application M13395-3 v6 Pulse-counter logic (PCFCNT) function counts externally generated binary pulses, for instance pulses coming from an external energy meter, for calculation of energy consumption values.
Page 668: Function For Energy Calculation And Demand Handling Etpmmtr
Section 18 1MRK 504 152-UEN B Metering The setting is common for all input channels on BIM, that is, if limit changes are made for inputs not connected to the pulse counter, the setting also influences the inputs on the same board used for pulse counting. 18.2 Function for energy calculation and demand handling ETPMMTR...
Page 669: Setting Guidelines
1MRK 504 152-UEN B Section 18 Metering EAFAccPlsQty , EARAccPlsQty , ERFAccPlsQty and ERVAccPlsQty of the energy metering function and then the pulse counter can be set-up to present the correct values by scaling in this function. Pulse counter values can then be presented on the local HMI in the same way and/or sent to the SA (Substation Automation) system through communication where the total energy then is calculated by summation of the energy pulses.
Page 671: Section 19 Station Communication
1MRK 504 152-UEN B Section 19 Station communication Section 19 Station communication 19.1 Communication protocols M14815-3 v12 Each IED is provided with a communication interface, enabling it to connect to one or many substation level systems or equipment, either on the Substation Automation (SA) bus or Substation Monitoring (SM) bus.
Page 672 Section 19 1MRK 504 152-UEN B Station communication Engineering Station HSI Workstation Gateway Base System Printer KIOSK 3 KIOSK 1 KIOSK 2 IEC09000135_en.v IEC09000135 V1 EN-US Figure 379: SA system with IEC 61850–8–1 M16925-3 v3 Figure 380 shows the GOOSE peer-to-peer communication. Station HSI MicroSCADA Gateway...
Page 673: Horizontal Communication Via Goose For Interlocking Gooseintlkrcv
1MRK 504 152-UEN B Section 19 Station communication 19.2.2 Horizontal communication via GOOSE for interlocking GOOSEINTLKRCV SEMOD173197-1 v2 PID-415-SETTINGS v5 Table 66: GOOSEINTLKRCV Non group settings (basic) Name Values (Range) Unit Step Default Description Operation Operation Off/On 19.2.3 Setting guidelines SEMOD55317-5 v6 There are two settings related to the IEC 61850–8–1 protocol: Operation User can set IEC 61850 communication to On or Off .
Page 674: Iec 61850-8-1 Redundant Station Bus Communication
Section 19 1MRK 504 152-UEN B Station communication is connected to the range output, the logical outputs of the RANGE_XP are changed accordingly. 19.2.6 IEC 61850-8-1 redundant station bus communication GUID-FF43A130-7D2D-4BA3-B51C-80398D73228F v2 19.2.6.1 Identification GUID-00C469E6-00D4-4780-BD0D-426647AB8E0F v3.1.1 Function description LHMI and ACT IEC 61850 IEC 60617 ANSI/IEEE C37.2...
Page 675: Setting Guidelines
1MRK 504 152-UEN B Section 19 Station communication Station Control System Redundancy Supervision Data Data Switch A Switch B Data Data Configuration PRPSTATUS =IEC09000758=3=en=Original.vsd IEC09000758 V3 EN-US Figure 381: Redundant station bus 19.2.6.3 Setting guidelines GUID-6AD04F29-9B52-40E7-AA07-6D248EF99FC6 v2 Redundant communication (PRP) is configured in the local HMI under Main menu/ Configuration/Communication/Ethernet configuration/PRP The settings are found in the Parameter Setting tool in PCM600 under IED Configuration/ Communication/Ethernet configuration/PRP.
Page 676: Iec 61850-9-2Le Communication Protocol
Section 19 1MRK 504 152-UEN B Station communication IEC10000057-2-en.vsd IEC10000057 V2 EN-US Figure 382: PST screen: PRP Operation is set to On, which affect Rear OEM - Port AB and CD which are both set to PRP 19.3 IEC 61850-9-2LE communication protocol SEMOD172279 v2 19.3.1 Introduction...
Page 677 1MRK 504 152-UEN B Section 19 Station communication Set the CD-port to 9–2LE communication using only LHMI. All other settings are also available from PCM600. Factors influencing the accuracy of the sampled values from the merging unit are, for example, anti aliasing filters, frequency range, step response, truncating, A/D conversion inaccuracy, time tagging accuracy etc.
Page 678: Setting Guidelines
Section 19 1MRK 504 152-UEN B Station communication Station Wide Station Wide SCADA System GPS Clock IEC61850-8-1 Splitter Electrical-to- Optical Converter IEC61850-8-1 110 V Other 1PPS Relays IEC61850-9-2LE Ethernet Switch IEC61850-9-2LE 1PPS Merging Unit Combi Sensor Conventional VT en08000069-3.vsd IEC08000069 V2 EN-US Figure 384: Example of a station configuration with the IED receiving analog values from both classical measuring transformers and merging units.
Page 679: Specific Settings Related To The Iec 61850-9-2Le Communication
1MRK 504 152-UEN B Section 19 Station communication 19.3.2.1 Specific settings related to the IEC 61850-9-2LE communication SEMOD166590-24 v5 The process bus communication IEC 61850-9-2LE have specific settings, similar to the analog inputs modules. Besides the names of the merging unit channels (that can be edited only from PCM600, not from the local HMI) there are important settings related to the merging units and time synchronization of the signals: When changing the sending (MU unit) MAC address, a reboot of the IED is...
Page 680 Section 19 1MRK 504 152-UEN B Station communication Failure of the MU (sample lost) blocks the sending of binary signals through LDCM. The received binary signals are not blocked and processd normally. →DTT from the remote end is still processed. IEC13000299-1-en.vsd IEC13000299 V1 EN-US Figure 386: MU failed, mixed system...
Page 681 1MRK 504 152-UEN B Section 19 Station communication Function description IEC 61850 identification Function description IEC 61850 identification Breaker failure CCSRBRF Restricted earth fault REFPDIF protection, single phase protection, low version impedance Current circuit CCSSPVC Two step residual ROV2PTOV supervison overvoltage protection Compensated over- and COUVGAPC...
Page 682 Section 19 1MRK 504 152-UEN B Station communication Function description IEC 61850 identification Function description IEC 61850 identification Negative sequence LCNSPTOC Local acceleration logic ZCLCPSCH overcurrent protection Negative sequence LCNSPTOV Scheme communication ZCPSCH overvoltage protection logic for distance or overcurrent protection Three phase overcurrent LCP3PTOC Current reversal and...
Page 683: Setting Examples For Iec 61850-9-2Le And Time Synchronization
1MRK 504 152-UEN B Section 19 Station communication Function description IEC 61850 identification Function description IEC 61850 identification Out-of-step protection OOSPPAM Busbar differential BCZPDIF protection, check zone Busbar differential BDZSGAPC Busbar differential BFPTRC_Fx, (1≤x≤24) protection, dynamic zone protection, single phase selection feeder xx Busbar differential...
Page 684 Section 19 1MRK 504 152-UEN B Station communication HwSyncSrc : set to PPS since this is what is generated by the MU (ABB MU) • • AppSynch : set to Synch , since protection functions should be blocked in case of loss of...
Page 685 1MRK 504 152-UEN B Section 19 Station communication HwSyncSrc : set to PPS/IRIG-B depending on available outputs on the clock • • AppSynch : set to Synch , for blocking protection functions in case of loss of time synchronization SyncAccLevel : could be set to 4us since this correspond to a maximum phase-angle error •...
Page 686: Lon Communication Protocol
Section 19 1MRK 504 152-UEN B Station communication HwSyncSrc : set to Off • • AppSynch : set to NoSynch . This means that protection functions will not be blocked SyncAccLevel : set to unspecified • Settings in PST in PCM600 under: Hardware/Analog modules/Merging units/MU01 SyncMode : set to NoSynch .
Page 687: Multicmdrcv And Multicmdsnd
1MRK 504 152-UEN B Section 19 Station communication Table 68: Specification of the fiber optic connectors Glass fiber Plastic fiber Cable connector ST-connector snap-in connector Cable diameter 62.5/125 m 1 mm Max. cable length 1000 m 10 m Wavelength 820-900 nm 660 nm Transmitted power -13 dBm (HFBR-1414)
Page 688: Identification
Section 19 1MRK 504 152-UEN B Station communication 19.4.2.1 Identification GUID-1A6E066C-6399-4D37-8CA5-3074537E48B2 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Multiple command and receive MULTICMDRCV Multiple command and send MULTICMDSND 19.4.2.2 Application M14790-3 v5 The IED provides two function blocks enabling several IEDs to send and receive signals via the interbay bus.
Page 689: Setting Guidelines
1MRK 504 152-UEN B Section 19 Station communication The SPA communication is mainly used for the Station Monitoring System. It can include different IEDs with remote communication possibilities. Connection to a computer (PC) can be made directly (if the PC is located in the substation) or by telephone modem through a telephone network with ITU (former CCITT) characteristics or via a LAN/WAN connection.
Page 690: Iec 60870-5-103 Communication Protocol
Section 19 1MRK 504 152-UEN B Station communication 19.6 IEC 60870-5-103 communication protocol IP14615-1 v2 19.6.1 Application IP14864-1 v1 M17109-3 v6 TCP/IP Control Center Station HSI Gateway Star coupler IEC05000660-4-en.vsd IEC05000660 V4 EN-US Figure 393: 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 691 1MRK 504 152-UEN B Section 19 Station communication • Autorecloser ON/OFF • Teleprotection ON/OFF • Protection ON/OFF • LED reset • Characteristics 1 - 4 (Setting groups) • File transfer (disturbance files) • Time synchronization Hardware M17109-59 v1 When communicating locally with a Personal Computer (PC) or a Remote Terminal Unit (RTU) in the station, using the SPA/IEC port, the only hardware needed is:·...
Page 692 Section 19 1MRK 504 152-UEN B Station communication • Earth fault indications in monitor direction Function block with defined functions for earth fault indications in monitor direction, I103EF. This block includes the FUNCTION TYPE parameter, and the INFORMATION NUMBER parameter is defined for each output signal. •...
Page 693 1MRK 504 152-UEN B Section 19 Station communication Settings for RS485 and optical serial communication M17109-118 v10 General settings SPA, DNP and IEC 60870-5-103 can be configured to operate on the SLM optical serial port while DNP and IEC 60870-5-103 only can utilize the RS485 port. A single protocol can be active on a given physical port at any time.
Page 694 Section 19 1MRK 504 152-UEN B Station communication The slave number can be set to any value between 1 and 254. The communication speed, can be set either to 9600 bits/s or 19200 bits/s. RevPolarity : Setting for inverting the light (or not). Standard IEC 60870-5-103 setting is •...
Page 695 1MRK 504 152-UEN B Section 19 Station communication DRA#-Input IEC103 meaning Private range Private range Private range Private range Private range Private range Private range Private range Private range Private range Private range Private range Private range Private range Private range Private range Private range Private range...
Page 696: Dnp3 Communication Protocol
Section 19 1MRK 504 152-UEN B Station communication REB 207 Private range REG 150 Private range REQ 245 Private range RES 118 Private range Refer to the tables in the Technical reference manual /Station communication, specifying the information types supported by the communication protocol IEC 60870-5-103. To support the information, corresponding functions must be included in the protection IED.
Page 697: Section 20 Remote Communication
1MRK 504 152-UEN B Section 20 Remote communication Section 20 Remote communication 20.1 Binary signal transfer IP12423-1 v2 20.1.1 Identification M14849-1 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Binary signal transfer BinSignReceive Binary signal transfer BinSignTransm 20.1.2 Application...
Page 698: Setting Guidelines
Section 20 1MRK 504 152-UEN B Remote communication solutions are aimed for connections to a multiplexer, which in turn is connected to a telecommunications transmission network (for example, SDH or PDH). Multiplexer Multiplexer Telecom. Network *) Converting optical to galvanic G.703 en05000527-2.vsd IEC05000527 V2 EN-US Figure 396: LDCM with an external optical to galvanic converter and a multiplexer...
Page 699 1MRK 504 152-UEN B Section 20 Remote communication TerminalNo , but equal to the TerminalNo of the remote end LDCM. In the remote IED the TerminalNo and RemoteTermNo settings are reversed as follows: TerminalNo to 2 and RemoteTermNo to 1 •...
Page 700 Section 20 1MRK 504 152-UEN B Remote communication Type of LDCM Short range (SR) Short range (SR) Medium range (MR) Long range (LR) Minimum output –21 dBm –13.7 dBm –3.2 dBm –1.3 dBm power Minimum receiver –32.5 dBm –32.5 dBm –30 dBm –30 dBm sensitivity...
Page 701 1MRK 504 152-UEN B Section 20 Remote communication TransmCurr : This setting decides which of 2 possible local currents that shall be transmitted, or if and how the sum of 2 local currents shall be transmitted, or finally if the channel shall be used as a redundant channel.
Page 703: Section 21 Security
1MRK 504 152-UEN B Section 21 Security Section 21 Security 21.1 Authority status ATHSTAT SEMOD158575-1 v2 21.1.1 Application SEMOD158527-5 v3 Authority status (ATHSTAT) function is an indication function block, which informs about two events related to the IED and the user authorization: •...
Page 704: Change Lock Chnglck
CHNGLCK input. If such a situation would occur in spite of these precautions, then please contact the local ABB representative for remedial action. 21.4 Denial of service DOS 21.4.1...
Page 705: Setting Guidelines
1MRK 504 152-UEN B Section 21 Security controlled. Heavy network load might for instance be the result of malfunctioning equipment connected to the network. DOSFRNT, DOSLANAB and DOSLANCD measure the IED load from communication and, if necessary, limit it for not jeopardizing the IEDs control and protection functionality due to high CPU load.
Page 707: Section 22 Basic Ied Functions
• IEDProdType The settings are visible on the local HMI , under Main menu/Diagnostics/IED status/Product identifiersand underMain menu/Diagnostics/IED Status/IED identifiers This information is very helpful when interacting with ABB product support (e.g. during repair and maintenance). 22.2.2 Factory defined settings...
Page 708: Measured Value Expander Block Range_Xp
Section 22 1MRK 504 152-UEN B Basic IED functions • Describes the firmware version. • The firmware version can be checked from Main menu/Diagnostics/IED status/ Product identifiers • Firmware version numbers run independently from the release production numbers. For every release number there can be one or more firmware versions depending on the small issues corrected in between releases.
Page 709: Parameter Setting Groups
1MRK 504 152-UEN B Section 22 Basic IED functions 22.4 Parameter setting groups IP1745-1 v1 22.4.1 Application M12007-6 v9 Six sets of settings are available to optimize IED operation for different power system conditions. By creating and switching between fine tuned setting sets, either from the local HMI or configurable binary inputs, results in a highly adaptable IED that can cope with a variety of power system scenarios.
Page 710: Setting Guidelines
Section 22 1MRK 504 152-UEN B Basic IED functions 22.5.3 Setting guidelines M15292-3 v2 Set the system rated frequency. Refer to section "Signal matrix for analog inputs SMAI" description on frequency tracking. 22.6 Summation block 3 phase 3PHSUM SEMOD55968-1 v2 22.6.1 Application SEMOD56004-4 v3...
Page 711: Application
1MRK 504 152-UEN B Section 22 Basic IED functions 22.7.2 Application GUID-D58ECA9A-9771-443D-BF84-8EF582A346BF v4 Global base values function (GBASVAL) is used to provide global values, common for all applicable functions within the IED. One set of global values consists of values for current, voltage and apparent power and it is possible to have twelve different sets.
Page 712: Setting Guidelines
Section 22 1MRK 504 152-UEN B Basic IED functions 22.9.2 Setting guidelines SEMOD55228-5 v2 There are no setting parameters for the Signal matrix for binary outputs SMBO available to the user in Parameter Setting tool. However, the user must give a name to SMBO instance and SMBO outputs, directly in the Application Configuration tool.
Page 713: Setting Guidelines
1MRK 504 152-UEN B Section 22 Basic IED functions SMAI1 SPFCOUT SAPTOF BLOCK G1AI3P U3P* TRIP SAPTOF(1)_TRIP DFTSPFC UL1L2 START BLOCK REVROT G1AI1 BLKDMAGN BLKTRIP PHASEL1 G1AI2 FREQ ^GRP1L1 G1AI4 TRM_40.CH7(U) PHASEL2 ^GRP1L2 PHASEL3 ^GRP1L3 NEUTRAL ^GRP1N IEC10000060-2-en.vsdx IEC10000060 V2 EN-US Figure 397: Connection example ConnectionType is The above described scenario does not work if SMAI setting...
Page 714 Section 22 1MRK 504 152-UEN B Basic IED functions ConnectionType : Connection type for that specific instance (n) of the SMAI (if it is The setting Ph-N or Ph-Ph ). Depending on connection type setting the not connected Ph-N or Ph-Ph Ph-Ph connection L1, outputs will be calculated as long as they are possible to calculate.
Page 715 1MRK 504 152-UEN B Section 22 Basic IED functions Task time group 1 SMAI instance 3 phase group SMAI1:1 SMAI2:2 SMAI3:3 AdDFTRefCh7 SMAI4:4 SMAI5:5 SMAI6:6 SMAI7:7 SMAI8:8 SMAI9:9 SMAI10:10 SMAI11:11 SMAI12:12 Task time group 2 SMAI instance 3 phase group SMAI1:13 AdDFTRefCh4 SMAI2:14...
Page 716 Section 22 1MRK 504 152-UEN B Basic IED functions SMAI1:13 BLOCK SPFCOUT DFTSPFC AI3P ^GRP1L1 ^GRP1L2 ^GRP1L3 SMAI1:1 ^GRP1N BLOCK SPFCOUT DFTSPFC AI3P ^GRP1L1 ^GRP1L2 ^GRP1L3 ^GRP1N SMAI1:25 BLOCK SPFCOUT DFTSPFC AI3P ^GRP1L1 ^GRP1L2 ^GRP1L3 ^GRP1N IEC07000198-2-en.vsd IEC07000198 V3 EN-US Figure 399: Configuration for using an instance in task time group 1 as DFT reference Assume instance SMAI7:7 in task time group 1 has been selected in the configuration to control the frequency tracking .
Page 717: Test Mode Functionality Test
1MRK 504 152-UEN B Section 22 Basic IED functions SMAI1:1 BLOCK SPFCOUT DFTSPFC AI3P ^GRP1L1 ^GRP1L2 ^GRP1L3 SMAI1:13 ^GRP1N BLOCK SPFCOUT DFTSPFC AI3P ^GRP1L1 ^GRP1L2 ^GRP1L3 ^GRP1N SMAI1:25 BLOCK SPFCOUT DFTSPFC AI3P ^GRP1L1 ^GRP1L2 ^GRP1L3 ^GRP1N IEC07000199-2-en.vsd IEC07000199 V3 EN-US Figure 400: Configuration for using an instance in task time group 2 as DFT reference.
Page 718: Iec 61850 Protocol Test Mode
Section 22 1MRK 504 152-UEN B Basic IED functions 22.12.1.1 IEC 61850 protocol test mode GUID-82998715-6F23-4CAF-92E4-05E1A863CF33 v5 The function block TESTMODE has implemented the extended testing mode capabilities for IEC 61850 Ed2 systems. Operator commands sent to the function block TESTMODE determine the behavior of the functions.
Page 719: Setting Guidelines
1MRK 504 152-UEN B Section 22 Basic IED functions the Main menu/Test/Function status/Function group/Function block descriptive name/LN name/Outputs. Beh of a function block is set to Test , the function block is not blocked and all • When the control commands with a test bit are accepted. Beh of a function block is set to Test/blocked , all control commands with a test •...
Page 720: Setting Guidelines
Section 22 1MRK 504 152-UEN B Basic IED functions 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. For IED's using IEC 61850-9-2LE from one single MU as analog data source, the MU and IED still needs to be synchronized to each other.
Page 721: Process Bus Iec 61850-9-2Le Synchronization
1MRK 504 152-UEN B Section 22 Basic IED functions • • • • IEC 60870-5-103 • The function input to be used for minute-pulse synchronization is called BININPUT. For a Technical Manual . description of the BININPUT settings, see the The system time can be set manually, either via the local HMI or via any of the communication ports.
Page 723: Section 23 Requirements
1MRK 504 152-UEN B Section 23 Requirements Section 23 Requirements 23.1 Current transformer requirements IP15171-1 v2 M11609-3 v2 The performance of a protection function will depend on the quality of the measured current signal. Saturation of the current transformers (CTs) will cause distortion of the current signals and can result in a failure to operate or cause unwanted operations of some functions.
Page 724: Fault Current
Section 23 1MRK 504 152-UEN B Requirements and low remanence type. The results may not always be valid for non remanence type CTs (TPZ). The performances of the protection functions have been checked in the range from symmetrical to fully asymmetrical fault currents. Primary time constants of at least 120 ms have been considered at the tests.
Page 725: General Current Transformer Requirements
CT (TPZ) is not well defined as far as the phase angle error is concerned. If no explicit recommendation is given for a specific function we therefore recommend contacting ABB to confirm that the non remanence type can be used.
Page 726: Distance Protection
Section 23 1MRK 504 152-UEN B Requirements where: The rated primary current of the power transformer (A) Maximum primary fundamental frequency current that passes two main CTs and the power transformer (A) The rated primary CT current (A) The rated secondary CT current (A) The rated current of the protection IED (A) The secondary resistance of the CT (W) The resistance of the secondary wire and additional load (W).
Page 727: Breaker Failure Protection
1MRK 504 152-UEN B Section 23 Requirements where: Maximum primary fundamental frequency current for close-in forward and kmax reverse faults (A) Maximum primary fundamental frequency current for faults at the end of kzone1 zone 1 reach (A) The rated primary CT current (A) The rated secondary CT current (A) The rated current of the protection IED (A) The secondary resistance of the CT (W)
Page 728: Restricted Earth Fault Protection (Low Impedance Differential)
Section 23 1MRK 504 152-UEN B Requirements æ ö ³ = × × × ç ÷ alreq è ø (Equation 534) EQUATION1380 V2 EN-US where: The primary operate value (A) The rated primary CT current (A) The rated secondary CT current (A) The rated current of the protection IED (A) The secondary resistance of the CT (W) The resistance of the secondary cable and additional load (W).
Page 729 1MRK 504 152-UEN B Section 23 Requirements In substations with breaker-and-a-half or double-busbar double-breaker arrangement, the fault current may pass two main phase CTs for the restricted earth fault protection without passing the power transformer. In such cases and if both main CTs have equal ratios and magnetization characteristics the CTs must satisfy Requirement (12) and the Requirement (14) below: æ...
Page 730: Current Transformer Requirements For Cts According To Other Standards
Section 23 1MRK 504 152-UEN B Requirements Where: Maximum primary fundamental frequency three-phase fault current that passes the CTs and the power transformer (A). The resistance of the single secondary wire and additional load (Ω). In impedance earthed systems the phase-to-earth fault currents often are relatively small and the requirements might result in small CTs.
Page 731: Current Transformers According To Iec 61869-2, Class Px, Pxr (And Old Iec 60044-6, Class Tps And Old British Standard, Class X)
1MRK 504 152-UEN B Section 23 Requirements 23.1.7.2 Current transformers according to IEC 61869-2, class PX, PXR (and old IEC 60044-6, class TPS and old British Standard, class X) M11623-14 v5 CTs according to these classes are specified approximately in the same way by a rated knee point e.m.f.
Page 732: Voltage Transformer Requirements
Section 23 1MRK 504 152-UEN B Requirements 23.2 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 voltage transformers (CVTs) can affect some protection functions. Magnetic or capacitive voltage transformers can be used.
Page 733: Iec 61850-9-2Le Merging Unit Requirements
1MRK 504 152-UEN B Section 23 Requirements • One master clock for the actual network • The actual port Synchronized to the SDH system clock at 2048 kbit • Synchronization; bit synchronized, synchronized mapping • Maximum clock deviation <±50 ppm nominal, <±100 ppm operational •...
Page 734 Section 23 1MRK 504 152-UEN B Requirements Factors influencing the accuracy of the sampled values from the merging unit are for example anti aliasing filters, frequency range, step response, truncating, A/D conversion inaccuracy, time tagging accuracy etc. In principle the accuracy of the current and voltage transformers, together with the merging unit, shall have the same quality as direct input of currents and voltages.
Page 735: Section 24 Glossary
1MRK 504 152-UEN B Section 24 Glossary Section 24 Glossary M14893-1 v18 Alternating current Actual channel Application configuration tool within PCM600 A/D converter Analog-to-digital converter ADBS Amplitude deadband supervision Analog digital conversion module, with time synchronization Analog input ANSI American National Standards Institute Autoreclosing ASCT Auxiliary summation current transformer...
Page 736 Section 24 1MRK 504 152-UEN B Glossary CO cycle Close-open cycle Codirectional Way of transmitting G.703 over a balanced line. Involves two twisted pairs making it possible to transmit information in both directions Command COMTRADE Standard Common Format for Transient Data Exchange format for Disturbance recorder according to IEEE/ANSI C37.111, 1999 / IEC 60255-24 Contra-directional...
Page 737 1MRK 504 152-UEN B Section 24 Glossary Electromagnetic interference EnFP End fault protection Enhanced performance architecture Electrostatic discharge F-SMA Type of optical fiber connector Fault number Flow control bit; Frame count bit FOX 20 Modular 20 channel telecommunication system for speech, data and protection signals FOX 512/515 Access multiplexer...
Page 738 Section 24 1MRK 504 152-UEN B Glossary IEEE Institute of Electrical and Electronics Engineers IEEE 802.12 A network technology standard that provides 100 Mbits/s on twisted- pair or optical fiber cable IEEE P1386.1 PCI Mezzanine Card (PMC) standard for local bus modules. References the CMC (IEEE P1386, also known as Common Mezzanine Card) standard for the mechanics and the PCI specifications from the PCI SIG (Special Interest Group) for the electrical EMF (Electromotive force).
Page 739 1MRK 504 152-UEN B Section 24 Glossary National Control Centre Number of grid faults Numerical module OCO cycle Open-close-open cycle Overcurrent protection Optical Ethernet module OLTC On-load tap changer OTEV Disturbance data recording initiated by other event than start/pick-up Overvoltage Overreach A term used to describe how the relay behaves during a fault condition.
Page 740 Section 24 1MRK 504 152-UEN B Glossary Short circuit location Station control system SCADA Supervision, control and data acquisition System configuration tool according to standard IEC 61850 Service data unit SELV circuit Safety Extra-Low Voltage circuit type according to IEC60255-27 Small form-factor pluggable (abbreviation) Optical Ethernet port (explanation) Serial communication module.
Page 741 1MRK 504 152-UEN B Section 24 Glossary Transformer Module. This module transforms currents and voltages taken from the process into levels suitable for further signal processing. Type identification User management tool Underreach A term used to describe how the relay behaves during a fault condition. For example, a distance relay is underreaching when the impedance presented to it is greater than the apparent impedance to the fault applied to the balance point, that is, the set reach.
Page 744 ABB AB Substation Automation Products SE-721 59 Västerås, Sweden Phone +46 (0) 21 32 50 00 Scan this QR code to visit our website www.abb.com/substationautomation © Copyright 2016 ABB. All rights reserved.

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ABB RELION 670 Series Applications Manual

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Analog Inputs

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Differential Protection

Impedance Protection

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