Page 1 — R E L I O N ® 670 SERIES Line distance protection REL670 Version 2.2 ANSI Application manual...
Page 4 Copyright This document and parts thereof must not be reproduced or copied without written permission from ABB, and the contents thereof must not be imparted to a third party, nor used for any unauthorized purpose. The software and hardware described in this document is furnished under a license and may be used or disclosed only in accordance with the terms of such license.
Page 5 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 (EMC Directive 2004/108/EC) and concerning electrical equipment for use within specified voltage limits (Low-voltage directive 2006/95/EC). This conformity is the result of tests conducted by ABB in accordance with the product standard EN 60255-26 for the EMC directive, and with the product standards EN 60255-1 and EN 60255-27 for the low voltage directive.
Page 7: Table Of Contents
Table of contents Table of contents Section 1 Introduction................29 This manual.................... 29 Intended audience.................. 29 Product documentation................30 Product documentation set..............30 Document revision history..............31 Related documents................32 Document symbols and conventions............32 Symbols.....................32 Document conventions..............33 IEC 61850 edition 1 / edition 2 mapping..........34 Section 2 Application................45 General IED application................45 Main protection functions................46...
Page 8 Table of contents Example 3..................70 Examples on how to connect, configure and set CT inputs for most commonly used CT connections..........73 Example on how to connect a wye connected three-phase CT set to the IED................74 Example how to connect delta connected three-phase CT set to the IED..................79 Example how to connect single-phase CT to the IED....
Page 9 Table of contents Identification..................113 Application..................114 Operation principle................116 Frequency reporting..............118 Reporting filters................120 Scaling Factors for ANALOGREPORT channels....... 121 PMU Report Function Blocks Connection Rules in PCM600 Application Configuration Tool (ACT)......... 123 Setting guidelines................129 Section 7 Differential protection............135 High impedance differential protection, single phase HZPDIF (87)..135 Identification..................
Page 10 Table of contents Parallel line application with mutual coupling......163 Tapped line application...............170 Series compensation in power systems........173 Challenges in protection of series compensated and adjacent power lines................. 181 Impact of series compensation on protective IED of adjacent lines.................... 193 Distance protection..............194 Setting guidelines................
Page 11 Table of contents Setting guidelines................241 General..................241 Setting of zone 1.................242 Setting of overreaching zone............242 Setting of reverse zone...............243 Setting of zones for parallel line application....... 244 Setting of reach in resistive direction..........245 Load impedance limitation, without load encroachment function246 Load impedance limitation, with Phase selection with load encroachment, quadrilateral characteristic function activated ...248 Setting of minimum operating currents........248...
Page 12 Table of contents Full-scheme distance protection, quadrilateral for earth faults ZMMPDIS (21), ZMMAPDIS (21)............278 Identification..................278 Application..................278 Introduction.................278 System grounding...............279 Fault infeed from remote end............. 282 Load encroachment..............283 Short line application..............284 Long transmission line application..........285 Parallel line application with mutual coupling......285 Tapped line application...............291 Setting guidelines................
Page 13 Table of contents Identification..................309 Application..................309 System grounding...............309 Fault infeed from remote end............. 313 Load encroachment..............314 Short line application..............315 Long transmission line application..........316 Parallel line application with mutual coupling......316 Tapped line application...............323 Setting guidelines................325 General..................325 Setting of zone 1.................326 Setting of overreaching zone............326 Setting of reverse zone...............327 Setting of zones for parallel line application.......
Page 14 Table of contents Minimum operate currents............355 High speed distance protection ZMFPDIS (21)........355 Identification..................355 Application..................355 System grounding...............356 Fault infeed from remote end............. 359 Load encroachment..............360 Short line application..............361 Long transmission line application..........362 Parallel line application with mutual coupling......363 Tapped line application...............370 Setting guidelines................
Page 15 Table of contents Underreaching and overreaching schemes........413 Setting guidelines................420 General..................420 Setting of zone 1.................421 Setting of overreaching zone............421 Setting of reverse zone...............422 Series compensated and adjacent lines........423 Setting of zones for parallel line application....... 427 Setting of reach in resistive direction..........429 Load impedance limitation, without load encroachment function430 Zone reach setting higher than minimum load impedance..431 Parameter setting guidelines............
Page 16 Table of contents Identification..................476 Application..................476 Setting guidelines................480 Phase preference logic PPL2PHIZ............481 Identification..................481 Application..................481 Setting guidelines................485 Section 9 Current protection..............487 Instantaneous phase overcurrent protection PHPIOC (50)....487 Identification..................487 Application..................487 Setting guidelines................488 Meshed network without parallel line..........489 Meshed network with parallel line..........491 Directional phase overcurrent protection, four steps...
Page 17 Table of contents Setting guidelines................524 Settings for each step ..............524 Common settings for all steps............ 527 Sensitive directional residual overcurrent and power protection SDEPSDE (67N)...................528 Identification..................529 Application..................529 Setting guidelines................531 Breaker failure protection CCRBRF(50BF)...........540 Identification..................540 Application..................540 Setting guidelines................
Page 18 Table of contents Voltage-restrained overcurrent protection for generator and step-up transformer..............565 Overcurrent protection with undervoltage seal-in....... 565 Section 10 Voltage protection............. 567 Two step undervoltage protection UV2PTUV (27)........567 Identification..................567 Application..................567 Setting guidelines................568 Equipment protection, such as for motors and generators..568 Disconnected equipment detection..........
Page 19 Table of contents Setting guidelines................582 Recommendations for input and output signals......582 Settings..................583 Service value report..............584 Setting example................584 Voltage differential protection VDCPTOV (60)........586 Identification..................586 Application..................586 Setting guidelines................588 Loss of voltage check LOVPTUV (27)..........590 Identification..................590 Application..................
Page 20 Table of contents Setting guidelines................605 Directional negative sequence overcurrent protection....605 Negative sequence overcurrent protection.........607 Generator stator overload protection in accordance with IEC or ANSI standards..............610 Open phase protection for transformer, lines or generators and circuit breaker head flashover protection for generators..612 Voltage restrained overcurrent protection for generator and step-up transformer..............
Page 21 Table of contents Identification..................633 Application..................633 Synchronizing................633 Synchronism check..............635 Energizing check................ 637 Voltage selection................ 638 External fuse failure..............639 Application examples...............640 Single circuit breaker with single busbar........641 Single circuit breaker with double busbar, external voltage selection..................642 Single circuit breaker with double busbar, internal voltage selection..................
Page 22 Table of contents Permanent fault and reclosing unsuccessful signal....663 Lock-out initiation................664 Evolving fault................665 Automatic continuation of the auto reclosing sequence..... 665 Thermal overload protection holding the auto recloser back..666 Setting guidelines................666 Configuration................666 Auto recloser settings..............675 Apparatus control APC................. 680 Application..................
Page 23 Table of contents Signals from bus-coupler............713 Configuration setting..............714 Interlocking for bus-section breaker A1A2_BS (3)......715 Application.................. 715 Signals from all feeders.............. 715 Configuration setting..............718 Interlocking for bus-section disconnector A1A2_DC (3)....719 Application.................. 719 Signals in single breaker arrangement........719 Signals in double-breaker arrangement........723 Signals in breaker and a half arrangement.........725 Interlocking for busbar grounding switch BB_ES (3).......
Page 24 Table of contents Identification..................742 Application..................742 Setting guidelines................742 Single command, 16 signals SINGLECMD.......... 742 Identification..................743 Application..................743 Setting guidelines................745 Section 16 Scheme communication............ 747 Scheme communication logic for distance or overcurrent protection ZCPSCH(85)..................747 Identification..................747 Application..................747 Blocking schemes...............748 Delta blocking scheme...............
Page 25 Table of contents Weak-end infeed logic..............763 Setting guidelines................764 Current reversal logic..............764 Weak-end infeed logic..............764 Current reversal and weak-end infeed logic for phase segregated communication ZC1WPSCH (85)............765 Identification..................765 Application..................765 Setting guidelines................767 Local acceleration logic ZCLCPSCH............ 768 Identification..................
Page 26 Table of contents Identification................782 Application.................. 782 Setting guidelines............... 782 Carrier receive logic LCCRPTRC (94)..........783 Identification................783 Application.................. 783 Setting guidelines............... 783 Negative sequence overvoltage protection LCNSPTOV (47)..783 Identification................783 Application.................. 784 Setting guidelines............... 784 Zero sequence overvoltage protection LCZSPTOV (59N)....784 Identification................
Page 27 Table of contents Example of directional data............795 Blocking of the function block............. 797 Setting guidelines................797 Trip matrix logic TMAGAPC..............798 Identification..................798 Application..................798 Setting guidelines................798 Logic for group alarm ALMCALH............799 Identification..................799 Application..................799 Setting guidelines................799 Logic for group alarm WRNCALH............799 Identification..................
Page 28 Table of contents Elapsed time integrator with limit transgression and overflow supervision TEIGAPC................809 Identification..................809 Application..................809 Setting guidelines................810 Comparator for integer inputs - INTCOMP........... 810 Identification..................810 Application..................810 Setting guidelines................810 Setting example................811 Comparator for real inputs - REALCOMP..........812 Identification..................
Page 29 Table of contents Disturbance report DRPRDRE............. 836 Identification..................837 Application..................837 Setting guidelines................838 Recording times................841 Binary input signals..............841 Analog input signals..............842 Sub-function parameters............843 Consideration................843 Logical signal status report BINSTATREP........... 844 Identification..................844 Application..................844 Setting guidelines................845 Fault locator LMBRFLO................
Page 30 Table of contents Redundant communication..............856 Identification..................856 Application..................857 Setting guidelines................858 Merging unit..................859 Application..................859 Setting guidelines................860 Routes....................860 Application..................860 Setting guidelines................860 Section 21 Station communication............863 Communication protocols..............863 IEC 61850-8-1 communication protocol..........863 Application IEC 61850-8-1...............863 Setting guidelines................
Page 31 Table of contents Identification..................883 Application..................883 Communication hardware solutions........... 884 Setting guidelines................885 Section 23 Security................891 Authority status ATHSTAT..............891 Application..................891 Self supervision with internal event list INTERRSIG......891 Application..................891 Change lock CHNGLCK............... 892 Application..................892 Denial of service SCHLCCH/RCHLCCH ..........893 Application..................
Page 32 Table of contents Application..................900 Setting guidelines................900 Signal matrix for binary outputs SMBO ..........900 Application..................901 Setting guidelines................901 Signal matrix for mA inputs SMMI............901 Application..................901 Setting guidelines................901 Signal matrix for analog inputs SMAI............901 Application..................901 Frequency values................
Page 33 Table of contents PTP requirements.................924 Sample specification of communication requirements for the protection and control terminals in digital telecommunication networks925 Section 26 Glossary................927 Line distance protection REL670 2.2 ANSI Application manual...
Page 35: Section 1 Introduction
Section 1 1MRK 506 369-UUS - Introduction Section 1 Introduction This manual 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.
Page 36: Product Documentation
Section 1 1MRK 506 369-UUS - Introduction Product documentation 1.3.1 Product documentation set 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 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 37: Document Revision History
Section 1 1MRK 506 369-UUS - Introduction The commissioning manual contains instructions on how to commission the IED. The manual can also be used by system engineers and maintenance personnel for assistance during the testing phase. The manual provides procedures for the checking of external circuitry and energizing the IED, parameter setting and configuration as well as verifying settings by secondary injection.
Page 38: Related Documents
Section 1 1MRK 506 369-UUS - Introduction 1.3.3 Related documents Documents related to REL670 Document numbers Application manual 1MRK 506 369-UUS Commissioning manual 1MRK 506 371-UUS Product guide 1MRK 506 372-BEN Technical manual 1MRK 506 370-UUS Type test certificate 1MRK 506 372-TUS 670 series manuals Document numbers Operation manual...
Page 39: Document Conventions
Section 1 1MRK 506 369-UUS - Introduction Class 1 Laser product. Take adequate measures to protect the eyes and do not view directly with optical instruments. The caution icon indicates important information or warning related to the concept discussed in the text. It might indicate the presence of a hazard which could result in corruption of software or damage to equipment or property.
Page 40: Iec 61850 Edition 1 / Edition 2 Mapping
Section 1 1MRK 506 369-UUS - Introduction • the character ^ in front of an input/output signal name indicates that the signal name may be customized using the PCM600 software. • the character * after an input signal name indicates that the signal must be connected to another function block in the application configuration to achieve a valid application configuration.
Page 41 Section 1 1MRK 506 369-UUS - Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes BDCGAPC SWSGGIO BBCSWI BDCGAPC BDZSGAPC BBS6LLN0 LLN0 BDZSGAPC BDZSGAPC BFPTRC_F01 BFPTRC BFPTRC BFPTRC_F02 BFPTRC BFPTRC BFPTRC_F03 BFPTRC BFPTRC BFPTRC_F04 BFPTRC BFPTRC BFPTRC_F05 BFPTRC BFPTRC BFPTRC_F06...
Page 42 Section 1 1MRK 506 369-UUS - Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes BUSPTRC_B1 BUSPTRC BUSPTRC BBSPLLN0 BUSPTRC_B2 BUSPTRC BUSPTRC BUSPTRC_B3 BUSPTRC BUSPTRC BUSPTRC_B4 BUSPTRC BUSPTRC BUSPTRC_B5 BUSPTRC BUSPTRC BUSPTRC_B6 BUSPTRC BUSPTRC BUSPTRC_B7 BUSPTRC BUSPTRC BUSPTRC_B8 BUSPTRC BUSPTRC...
Page 43 Section 1 1MRK 506 369-UUS - Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes BZNPDIF_Z2 BZNPDIF BZNPDIF BZNPDIF_Z3 BZNPDIF BZNPDIF BZNPDIF_Z4 BZNPDIF BZNPDIF BZNPDIF_Z5 BZNPDIF BZNPDIF BZNPDIF_Z6 BZNPDIF BZNPDIF BZNSPDIF_A BZNSPDIF BZASGAPC BZASPDIF BZNSGAPC BZNSPDIF BZNSPDIF_B BZNSPDIF BZBSGAPC BZBSPDIF...
Page 44 Section 1 1MRK 506 369-UUS - Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes CVMMXN CVMMXN CVMMXN D2PTOC D2LLN0 D2PTOC D2PTOC PH1PTRC PH1PTRC DPGAPC DPGGIO DPGAPC DRPRDRE DRPRDRE DRPRDRE ECPSCH ECPSCH ECPSCH ECRWPSCH ECRWPSCH ECRWPSCH EF2PTOC EF2LLN0 EF2PTRC EF2PTRC...
Page 45 Section 1 1MRK 506 369-UUS - Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes L4CPDIF L4CLLN0 LLN0 L4CPDIF L4CGAPC L4CPTRC L4CPDIF L4CPSCH L4CPTRC L4UFCNT L4UFCNT L4UFCNT L6CPDIF L6CPDIF L6CGAPC L6CPDIF L6CPHAR L6CPTRC LAPPGAPC LAPPLLN0 LAPPPDUP LAPPPDUP LAPPPUPF LAPPPUPF LCCRPTRC...
Page 46 Section 1 1MRK 506 369-UUS - Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes NS2PTOC NS2LLN0 NS2PTOC NS2PTOC NS2PTRC NS2PTRC NS4PTOC EF4LLN0 EF4PTRC EF4PTRC EF4RDIR EF4RDIR PH1PTOC GEN4PHAR PH1PTOC O2RWPTOV GEN2LLN0 O2RWPTOV O2RWPTOV PH1PTRC PH1PTRC OC4PTOC OC4LLN0 GEN4PHAR GEN4PHAR...
Page 47 Section 1 1MRK 506 369-UUS - Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes SCHLCCH SCHLCCH SCHLCCH SCILO SCILO SCILO SCSWI SCSWI SCSWI SDEPSDE SDEPSDE SDEPSDE SDEPTOC SDEPTOV SDEPTRC SESRSYN RSY1LLN0 AUT1RSYN AUT1RSYN MAN1RSYN MAN1RSYN SYNRSYN SYNRSYN SLGAPC SLGGIO...
Page 48 Section 1 1MRK 506 369-UUS - Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes TR1ATCC TR1ATCC TR1ATCC TR8ATCC TR8ATCC TR8ATCC TRPTTR TRPTTR TRPTTR U2RWPTUV GEN2LLN0 PH1PTRC PH1PTRC U2RWPTUV U2RWPTUV UV2PTUV GEN2LLN0 PH1PTRC PH1PTRC UV2PTUV UV2PTUV VDCPTOV VDCPTOV VDCPTOV VDSPVC...
Page 49 Section 1 1MRK 506 369-UUS - Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes ZMMAPDIS ZMMAPDIS ZMMAPDIS ZMMPDIS ZMMPDIS ZMMPDIS ZMQAPDIS ZMQAPDIS ZMQAPDIS ZMQPDIS ZMQPDIS ZMQPDIS ZMRAPDIS ZMRAPDIS ZMRAPDIS ZMRPDIS ZMRPDIS ZMRPDIS ZMRPSB ZMRPSB ZMRPSB ZSMGAPC ZSMGAPC ZSMGAPC Line distance protection REL670 2.2 ANSI...
Page 51: Section 2 Application
Section 2 1MRK 506 369-UUS - Application Section 2 Application General IED application The Intelligent Electronic Device (IED) is used for the protection, control and monitoring of overhead lines and cables in solidly, impedance earthed or isolated networks. The IED can be used up to the high voltage levels.
Page 52: Main Protection Functions
Section 2 1MRK 506 369-UUS - Application The IED can be used in applications with IEC/UCA 61850-9-2LE process bus with up to eight merging units (MU) depending on other functionality included in the IED. Each MU has eight analogue channels, normally four currents and four voltages. Conventional and Merging Unit channels can be mixed freely in the application.
Page 53 Section 2 1MRK 506 369-UUS - Application IEC 61850 or ANSI Function description Line Distance function name REL670 (Customized) Differential protection HZPDIF High impedance differential protection, single phase LDRGFC 11RE Additional security logic for differential protection Impedance protection ZMQPDIS, Distance protection zone, quadrilateral characteristic ZMQAPDIS ZDRDIR Directional impedance quadrilateral...
Page 54: Back-Up Protection Functions
Section 2 1MRK 506 369-UUS - Application Back-up protection functions IEC 61850 or ANSI Function description function name REL670 (Customized) Current protection PHPIOC Instantaneous phase overcurrent protection OC4PTOC Directional phase overcurrent protection, four steps 51_67 EFPIOC Instantaneous residual overcurrent protection EF4PTOC Directional residual overcurrent protection, four steps NS4PTOC...
Page 55: Control And Monitoring Functions
Section 2 1MRK 506 369-UUS - Application IEC 61850 or ANSI Function description function name REL670 (Customized) Multipurpose protection CVGAPC General current and voltage protection General calculation SMAIHPAC Multipurpose filter 1) 67 requires voltage 2) 67N requires voltage Control and monitoring functions IEC 61850 or ANSI Function description...
Page 56 Section 2 1MRK 506 369-UUS - Application IEC 61850 or ANSI Function description Line Distance function name REL670 (Customized) I103POSCMD IED commands with position and select for IEC 60870-5-103 I103POSCMDV IED direct commands with position for IEC 60870-5-103 I103IEDCMD IED commands for IEC 60870-5-103 I103USRCMD Function commands user defined for IEC 60870-5-103 Secondary system...
Page 57 Section 2 1MRK 506 369-UUS - Application IEC 61850 or ANSI Function description Line Distance function name REL670 (Customized) BTIGAPC Boolean to integer conversion with logical node representation, 16 bit IB16 Integer to Boolean 16 conversion ITBGAPC Integer to Boolean 16 conversion with Logic Node representation TEIGAPC Elapsed time integrator with limit transgression and overflow...
Page 58 Section 2 1MRK 506 369-UUS - Application Table 4: Number of function instances in APC10 Function name Function description Total number of instances SCILO Interlocking BB_ES A1A2_BS A1A2_DC ABC_BC BH_CONN BH_LINE_A BH_LINE_B DB_BUS_A DB_BUS_B DB_LINE ABC_LINE AB_TRAFO SCSWI Switch controller SXSWI Circuit switch QCRSV...
Page 59 Section 2 1MRK 506 369-UUS - Application Table 5: Number of function instances in APC15 Function name Function description Total number of instances SCILO Interlocking BB_ES A1A2_BS A1A2_DC ABC_BC BH_CONN BH_LINE_A BH_LINE_B DB_BUS_A DB_BUS_B DB_LINE ABC_LINE AB_TRAFO SCSWI Switch controller SXSWI Circuit switch QCRSV...
Page 60 Section 2 1MRK 506 369-UUS - Application Configurable logic blocks Q/T Total number of instances SRMEMORYQT TIMERSETQT XORQT Table 7: Total number of instances for extended logic package Extended configurable logic block Total number of instances GATE PULSETIMER RSMEMORY SLGAPC SRMEMORY TIMERSET VSGAPC...
Page 61: Communication
Section 2 1MRK 506 369-UUS - Application IEC 61850 or ANSI Function description Line Distance function name REL670 (Customized) SP16GAPC Generic communication function for Single Point indication 16 inputs MVGAPC Generic communication function for measured values BINSTATREP Logical signal status report RANGE_XP Measured value expander block SSIMG...
Page 62 Section 2 1MRK 506 369-UUS - Application IEC 61850 or function ANSI Function description Line Distance name REL670 (Customized) DNPGEN DNP3.0 communication general protocol CHSERRS485 DNP3.0 for EIA-485 communication protocol CH1TCP, CH2TCP, DNP3.0 for TCP/IP communication protocol CH3TCP, CH4TCP CHSEROPT DNP3.0 for TCP/IP and EIA-485 communication protocol MSTSER DNP3.0 serial master...
Page 63 Section 2 1MRK 506 369-UUS - Application IEC 61850 or function ANSI Function description Line Distance name REL670 (Customized) PMUCONF, Synchrophasor report, 8 phasors (see Table 8) PMUREPORT, PHASORREPORT1, ANALOGREPORT1 BINARYREPORT1, SMAI1 - SMAI12 3PHSUM PMUSTATUS Precision time protocol FRONTSTATUS Access point diagnostic for front Ethernet port SCHLCCH Access point diagnostic for non-redundant Ethernet port...
Page 64: Basic Ied Functions
Section 2 1MRK 506 369-UUS - Application IEC 61850 or function ANSI Function description Line Distance name REL670 (Customized) ECPSCH Scheme communication logic for residual overcurrent protection ECRWPSCH Current reversal and weak-end infeed logic for residual overcurrent protection Direct transfer trip Table 8: Number of function instances in Synchrophasor report, 8 phasors Function name...
Page 65 Section 2 1MRK 506 369-UUS - Application IEC 61850 or function Description name ACTVGRP Parameter setting groups TESTMODE Test mode functionality CHNGLCK Change lock function SMBI Signal matrix for binary inputs SMBO Signal matrix for binary outputs SMMI Signal matrix for mA inputs SMAI1 - SMAI12 Signal matrix for analog inputs 3PHSUM...
Page 67: Section 3 Configuration
Section 3 1MRK 506 369-UUS - Configuration Section 3 Configuration Introduction The IED is available to be ordered in four different alternatives with the configuration suitable for the application. Normally these configurations should be acceptable to use with only few changes of binary input and outputs, which can be done from the signal matrix tool in the PCM600 engineering platform.
Page 68: Description Of Configuration Rel670
Section 3 1MRK 506 369-UUS - Configuration Description of configuration REL670 3.2.1 Introduction 3.2.1.1 Description of configuration A41 Line distance protection REL670 2.2 ANSI Application manual...
Page 69 Section 3 1MRK 506 369-UUS - Configuration REL670 A41 – Single breaker with three phase tripping for high ohmic and resonance earthed systems 12AI (6I+6U) WA2_VT Control S XCBR S SIMG S SIML VN MMXU WA1_VT 1->0 1→0 SC/VC 5(0→1) VN MMXU SMP PTRC SMP PTRC...
Page 70: Description Of Configuration A42
Section 3 1MRK 506 369-UUS - Configuration 3.2.1.2 Description of configuration A42 REL670 A42 – Single breaker with single or three phase tripping 12AI (6I+6U) WA2_VT Control Control Control S SCBR S SCBR S XCBR S SIMG S SIML VN MMXU WA1_VT 1->0 1→0...
Page 71: Description Of Configuration B42
Section 3 1MRK 506 369-UUS - Configuration 3.2.1.3 Description of configuration B42 REL670 B42 – Multi breaker with single or three phase tripping 12AI (6I+6U) WA1_VT WA1_CT Control Control 50BF 3I>BF 52PD Control S SCBR S SCBR CC PDSC VN MMXU S SCBR CC RBRF Σ...
Page 72: Description Of Configuration D42
Section 3 1MRK 506 369-UUS - Configuration 3.2.1.4 Description of configuration D42 REL670 D42 – Single breaker with single or three phase tripping with PMU functionality 12AI (6I+6U) Pha sor data df/dt<> f> f> IEEE Std 1344 SA PFRC SA PTOF SA PTUF PMU REP IEEE Std C37.118...
Page 73: Section 4 Analog Inputs
Section 4 1MRK 506 369-UUS - Analog inputs Section 4 Analog inputs Introduction Analog input channels must be configured and set properly in order to get correct measurement results and correct protection operations. For power measuring, all directional and differential functions, the directions of the input currents must be defined in order to reflect the way the current transformers are installed/connected in the field ( primary and secondary connections ).
Page 74: Example
Section 4 1MRK 506 369-UUS - Analog inputs 4.2.1.1 Example Usually the A phase-to-ground voltage connected to the first VT channel number of the transformer input module (TRM) is selected as the phase reference. The first VT channel number depends on the type of transformer input module. For a TRM with 6 current and 6 voltage inputs the first VT channel is 7.
Page 75: Example 1
Section 4 1MRK 506 369-UUS - Analog inputs 4.2.2.1 Example 1 Two IEDs used for protection of two objects. 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...
Page 76 Section 4 1MRK 506 369-UUS - Analog inputs 4.2.2.3 Example 3 One IED used to protect two objects. Transformer Line Forward Reverse Definition of direction for directional Transformer and line functions Line protection Setting of current input: Setting of current input: Set parameter Set parameter CT_WyePoint with...
Page 77 Section 4 1MRK 506 369-UUS - Analog inputs for the current channels to the line protection is set with the line as reference object and the directional functions of the line protection shall be set to Forward to protect the line. Transformer Line Reverse...
Page 78 Section 4 1MRK 506 369-UUS - Analog inputs Busbar Busbar Protection en06000196_ansi.vsd ANSI06000196 V1 EN Figure 11: Example how to set CT_WyePoint parameters in the IED For busbar protection, it is possible to set the CT_WyePoint parameters in two ways. The first solution will be to use busbar as a reference object.
Page 79: Examples On How To Connect, Configure And Set Ct Inputs For Most Commonly Used Ct Connections
Section 4 1MRK 506 369-UUS - Analog inputs Regardless which one of the above two options is selected, busbar differential protection will behave correctly. The main CT ratios must also be set. This is done by setting the two parameters CTsec and CTprim for each current channel.
Page 80: Example On How To Connect A Wye Connected Three-Phase Ct Set To The Ied
Section 4 1MRK 506 369-UUS - Analog inputs It shall be noted that depending on national standard and utility practices, the rated secondary current of a CT has typically one of the following values: • • However, in some cases, the following rated secondary currents are used as well: •...
Page 81 Section 4 1MRK 506 369-UUS - Analog inputs SMAI_20 CT 600/5 Wye Connected Protected Object ANSI13000002-3-en.vsd ANSI13000002 V3 EN Figure 13: Wye connected three-phase CT set with wye point towards the protected object Where: The drawing shows how to connect three individual phase currents from a wye connected three- phase CT set to the three CT inputs of the IED.
Page 82 Section 4 1MRK 506 369-UUS - 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 83 Section 4 1MRK 506 369-UUS - Analog inputs SMAI_20_2 BLOCK AI3P REVROT ^GRP2_A ^GRP2_B ^GRP2_C CT 800/1 ^GRP2N Wye Connected Protected Object ANSI11000026-5-en-.vsd ANSI11000026 V5 EN Figure 14: Wye connected three-phase CT set with its wye point away from the protected object In the example, everything is done in a similar way as in the above described example (Figure 13).
Page 84 Section 4 1MRK 506 369-UUS - Analog inputs SMAI2 BLOCK AI3P AI 01 (I) ^GRP2_A ^GRP2_B ^GRP2_C AI 02 (I) ^GRP2N TYPE AI 03 (I) CT 800/1 Wye Connected AI 04 (I) AI 05 (I) AI 06 (I) Protected Object ANSI06000644-2-en.vsd ANSI06000644 V2 EN Figure 15:...
Page 85: Example How To Connect Delta Connected Three-Phase Ct Set To The Ied
Section 4 1MRK 506 369-UUS - Analog inputs Is a connection made in the Signal Matrix tool (SMT) and Application configuration tool (ACT), which connects the residual/neutral current input to the fourth input channel of the preprocessing function block 6). Note that this connection in SMT shall not be done if the residual/neutral current is not connected to the IED.
Page 86 Section 4 1MRK 506 369-UUS - Analog inputs SMAI_20 IA-IB IB-IC IC-IA ANSI11000027-2-en.vsd Protected Object ANSI11000027 V2 EN Figure 16: Delta DAB connected three-phase CT set Line distance protection REL670 2.2 ANSI Application manual...
Page 87 Section 4 1MRK 506 369-UUS - Analog inputs Where: shows how to connect three individual phase currents from a delta connected three-phase CT set to three CT inputs of the IED. 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.
Page 88: Example How To Connect Single-Phase Ct To The Ied
Section 4 1MRK 506 369-UUS - Analog inputs SMAI_20 IA-IC IB-IA IC-IB ANSI11000028-2-en.vsd Protected Object ANSI11000028 V2 EN Figure 17: Delta DAC connected three-phase CT set In this case, everything is done in a similar way as in the above described example, except that for all used current inputs on the TRM the following setting parameters shall be entered: =800A...
Page 89 Section 4 1MRK 506 369-UUS - Analog inputs For correct terminal designations, see the connection diagrams valid for the delivered IED. Protected Object SMAI_20_2 BLOCK AI3P REVROT ^GRP2_A ^GRP2_B ^GRP2_C ^GRP2_N ANSI11000029-3-en.vsd ANSI11000029 V3 EN Figure 18: Connections for single-phase CT input Where: shows how to connect single-phase CT input in the IED.
Page 90: Relationships Between Setting Parameter Base Current, Ct Rated Primary Current And Minimum Pickup Of A Protection Ied
Section 4 1MRK 506 369-UUS - Analog inputs 4.2.3 Relationships between setting parameter Base Current, CT rated primary current and minimum pickup of a protection IED Note that for all line protection applications (e.g. distance protection or line differential protection) the parameter Base Current (i.e. IBase setting in the IED) used by the relevant protection function, shall always be set equal to the largest rated CT primary current among all CTs involved in the protection scheme.
Page 91: Examples How To Connect, Configure And Set Vt Inputs For Most Commonly Used Vt Connections
Section 4 1MRK 506 369-UUS - Analog inputs 132kV 120V (Equation 1) EQUATION1937 V1 EN The following setting should be used: VTprim=132 (value in kV) VTsec=120 (value in V) 4.2.4.2 Examples how to connect, configure and set VT inputs for most commonly used VT connections Figure defines the marking of voltage transformer terminals commonly used around...
Page 92: Examples On How To Connect A Three Phase-To-Ground Connected Vt To The Ied
Section 4 1MRK 506 369-UUS - Analog inputs The IED fully supports all of these values and most of them will be shown in the following examples. 4.2.4.3 Examples on how to connect a three phase-to-ground connected VT to the Figure gives an example on how to connect the three phase-to-ground connected VT to the IED.
Page 93 Section 4 1MRK 506 369-UUS - Analog inputs SMAI2 BLOCK AI2P ^GRP2L1 ^GRP2L2 ^GRP2L1L2 ^GRP2N IEC16000140-1-en.vsdx IEC16000140 V1 EN Figure 21: A two phase-to-earth connected VT Where: shows how to connect three secondary phase-to-ground voltages to three VT inputs on the IED is the TRM where these three voltage inputs are located.
Page 94: Example On How To Connect A Phase-To-Phase Connected Vt To The Ied
Section 4 1MRK 506 369-UUS - 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 95 Section 4 1MRK 506 369-UUS - Analog inputs 13.8 13.8 AI 07(I) SMAI2 BLOCK AI3P AI 08 (V) ^GRP2_A (A-B) ^GRP2_B (B-C) AI 09 (V) ^GRP2_C (C-A) ^GRP2N #Not Used TYPE AI 10(V) AI 11(V) AI 12(V) ANSI06000600-3-en.vsd ANSI06000600 V3 EN Figure 22: A Two phase-to-phase connected VT Where:...
Page 96: Example On How To Connect An Open Delta Vt To The Ied For High Impedance Grounded Or Ungrounded Networks
Section 4 1MRK 506 369-UUS - Analog inputs are three connections made in the Signal Matrix tool (SMT), Application configuration tool (ACT), which connects these three voltage inputs to first three input channels of the preprocessing function block 5). Depending on the type of functions, which need this voltage information, more than one preprocessing block might be connected in parallel to these three VT inputs shows that in this example the fourth (that is, residual) input channel of the preprocessing block is not connected in SMT.
Page 97 Section 4 1MRK 506 369-UUS - Analog inputs AI 07 (I) AI 08 (V) SMAI2 AI 09 (V) BLOCK AI3P ^GRP2_A # Not Used AI 10 (V) ^GRP2_B # Not Used ^GRP2_C # Not Used AI 11 (V) +3Vo ^GRP2N TYPE AI 12 (V) ANSI06000601-2-en.vsd...
Page 98 Section 4 1MRK 506 369-UUS - Analog inputs Where: shows how to connect the secondary side of the open delta VT to one VT input on the IED. +3Vo shall be connected to the IED is the TRM where this voltage input is located. It shall be noted that for this voltage input the following setting values shall be entered: ×...
Page 99: Example How To Connect The Open Delta Vt To The Ied For Low Impedance Grounded Or Solidly Grounded Power Systems
Section 4 1MRK 506 369-UUS - Analog inputs 4.2.4.6 Example how to connect the open delta VT to the IED for low impedance grounded or solidly grounded power systems Figure gives an example about the connection of an open delta VT to the IED for low impedance grounded or solidly grounded power systems.
Page 100 Section 4 1MRK 506 369-UUS - Analog inputs AI07 (I) AI08 (V) SMAI2 AI09 (V) BLOCK AI3P ^GRP2_A # Not Used AI10 (V) # Not Used ^GRP2_B # Not Used ^GRP2_C +3Vo AI11 (V) ^GRP2N TYPE AI12 (V) ANSI06000602-2-en.vsd ANSI06000602 V2 EN Figure 24: Open delta connected VT in low impedance or solidly grounded power system Line distance protection REL670 2.2 ANSI...
Page 101 Section 4 1MRK 506 369-UUS - Analog inputs Where: shows how to connect the secondary side of open delta VT to one VT input in the IED. +3Vo shall be connected to the IED. is TRM where this voltage input is located. It shall be noted that for this voltage input the following setting values shall be entered: ×...
Page 102: Example On How To Connect A Neutral Point Vt To The Ied
Section 4 1MRK 506 369-UUS - Analog inputs 4.2.4.7 Example on how to connect a neutral point VT to the IED Figure gives an example on how to connect a neutral point VT to the IED. This type of VT connection presents secondary voltage proportional to V to the IED.
Page 103 Section 4 1MRK 506 369-UUS - Analog inputs Protected Object SMAI2 BLOCK AI3P REVROT # Not Used ^GRP2L1 # Not Used ^GRP2L2 # Not Used ^GRP2L3 ^GRP2N IEC06000603-4-en.vsdx IEC06000603 V4 EN Protected Object AI07 (I) AI08 (I) SMAI2 BLOCK AI3P AI09 (I) ^GRP2_A # Not Used...
Page 104 Section 4 1MRK 506 369-UUS - 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 105: Section 5 Local Hmi
Section 5 1MRK 506 369-UUS - Local HMI Section 5 Local HMI ANSI13000239-2-en.vsd ANSI13000239 V2 EN Figure 26: Local human-machine interface The LHMI of the IED contains the following elements: Line distance protection REL670 2.2 ANSI Application manual...
Page 106: Display
Section 5 1MRK 506 369-UUS - Local HMI • Keypad • Display (LCD) • LED indicators • Communication port for PCM600 The LHMI is used for setting, monitoring and controlling. Display The LHMI includes a graphical monochrome liquid crystal display (LCD) with a resolution of 320 x 240 pixels.
Page 107 Section 5 1MRK 506 369-UUS - Local HMI IEC15000270-1-en.vsdx IEC15000270 V1 EN Figure 27: Display layout 1 Path 2 Content 3 Status 4 Scroll bar (appears when needed) The function key button panel shows on request what actions are possible with the function buttons.
Page 108 Section 5 1MRK 506 369-UUS - Local HMI IEC13000281-1-en.vsd GUID-C98D972D-D1D8-4734-B419-161DBC0DC97B V1 EN Figure 28: 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 Figure 29: Indication LED panel The function button and indication LED panels are not visible at the same time.
Page 109: Leds
Section 5 1MRK 506 369-UUS - Local HMI LEDs The LHMI includes three protection status LEDs above the display: Normal, Pickup and Trip. There are 15 programmable indication LEDs on the front of the LHMI. Each LED can indicate three states with the colors: green, yellow and red. The texts related to each three- color LED are divided into three panels.
Page 110: Keypad
Section 5 1MRK 506 369-UUS - Local HMI IEC16000076-1-en.vsd IEC16000076 V1 EN Figure 30: OPENCLOSE_LED connected to SXCBR Keypad The LHMI keypad contains push-buttons which are used to navigate in different views or menus. The push-buttons are also used to acknowledge alarms, reset indications, provide help and switch between local and remote control mode.
Page 111 Section 5 1MRK 506 369-UUS - Local HMI ANSI15000157-1-en.vsdx ANSI15000157 V1 EN 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 Line distance protection REL670 2.2 ANSI...
Page 112: Local Hmi Functionality
Section 5 1MRK 506 369-UUS - Local HMI Menu Clear Help Communication port Programmable indication LEDs IED status LEDs Local HMI functionality 5.4.1 Protection and alarm indication Protection indicators The protection indicator LEDs are Normal, Pickup and Trip. Table 11: Normal LED (green) LED state Description...
Page 113: Parameter Management
Section 5 1MRK 506 369-UUS - Local HMI Table 13: Trip LED (red) LED state Description Normal operation. A protection function has tripped. An indication message is displayed if the auto-indication feature is enabled in the local HMI. The trip indication is latching and must be reset via communication, LHMI or binary input on the LEDGEN component.
Page 114: Front Communication
Section 5 1MRK 506 369-UUS - Local HMI Numerical values are presented either in integer or in decimal format with minimum and maximum values. Character strings can be edited character by character. Enumerated values have a predefined set of selectable values. 5.4.3 Front communication The RJ-45 port in the LHMI enables front communication.
Page 115: Section 6 Wide Area Measurement System
Section 6 1MRK 506 369-UUS - Wide area measurement system Section 6 Wide area measurement system C37.118 Phasor Measurement Data Streaming Protocol Configuration PMUCONF 6.1.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Configuration parameters for IEEE 1344 PMUCONF and C37.118 protocol 6.1.2...
Page 116: Short Guidance For Use Of Tcp
Section 6 1MRK 506 369-UUS - Wide area measurement system that PMUREPORT instance. Whereas, for UDP clients, the PMUREPORT instance for each UDP channel is defined by the user in the PMU and the client has to know the PMU ID corresponding to that instance in order to be able to communicate.
Page 117: Short Guidance For Use Of Udp
Section 6 1MRK 506 369-UUS - Wide area measurement system As can be seen, there are two separate parameters in the IED for selecting port numbers for TCP connections; one for IEEE1344 protocol (1344TCPport) and another one for C37.118 protocol (C37.118 TCPport). Client can communicate with the IED over IEEE1344 protocol using the selected TCP port defined in 1344TCPport, and can communicate with the IED over IEEE C37.118 protocol using the selected TCP port number in C37.118TCPport.
Page 118 Section 6 1MRK 506 369-UUS - Wide area measurement system SendDataUDP[x] – Enable / disable UDP data stream ProtocolOnUDP[x] – Send IEEE1344 or C37.118 on UDP PMUReportUDP[x] – Instance number of PMUREPORT function block that must send data on this UDP stream (UDP client group[x]) UDPDestAddres[x] –...
Page 119: Protocol Reporting Via Ieee 1344 And C37.118 Pmureport
Section 6 1MRK 506 369-UUS - Wide area measurement system The data streams in the IED can be sent as unicast or as multicast. The user-defined IP address set in the parameter UDPDestAddress[x] for each UDP stream defines if it is a Unicast or Multicast.
Page 120: Application
Section 6 1MRK 506 369-UUS - Wide area measurement system 6.2.2 Application The phasor measurement reporting block moves the phasor calculations into an IEEE C37.118 and/or IEEE 1344 synchrophasor frame format. The PMUREPORT block contains parameters for PMU performance class and reporting rate, the IDCODE and Global PMU ID, format of the data streamed through the protocol, the type of reported synchrophasors, as well as settings for reporting analog and digital signals.
Page 121 Section 6 1MRK 506 369-UUS - Wide area measurement system IEC140000118-2-en.vsd IEC140000118 V2 EN Figure 34: Multiple instances of PMUREPORT function block Figure shows both instances of the PHASORREPORT function blocks. The instance number is visible in the bottom of each function block. For each instance, there are four separate PHASORREPORT blocks including 32 configurable phasor channels (8 phasor channels in each PHASORREPORT block).
Page 122: Operation Principle
Section 6 1MRK 506 369-UUS - Wide area measurement system IEC140000120-2-en.vsd IEC140000120 V2 EN Figure 36: Multiple instances of ANALOGREPORT blocks Figure shows both instances of BINARYREPORT function blocks. The instance number is visible in the bottom of each function block. For each instance, there are three separate BINARYREPORT blocks capable of reporting up to 24 Binary signals (8 Binary signals in each BINARYREPORT block).
Page 123 Section 6 1MRK 506 369-UUS - Wide area measurement system • To measure the power system related AC quantities (voltage, current) and to calculate the phasor representation of these quantities. • To synchronize the calculated phasors with the UTC by time-tagging, in order to make synchrophasors (time is reference).
Page 124: Frequency Reporting
Section 6 1MRK 506 369-UUS - Wide area measurement system U/I samples PMUREPORT1 PHASOR1 PHASOR2 8 TCP IEEEC37.118 / 1344 SMAI messages 6 UDC PHASOR32 ANALOG1 ANALOG2 SMMI ANALOG24 MEAS. BINARY1 BINARY2 BINARY24 PROTECTION GPS / FREQTRIG IRIG-B DFDTTRIG PPS time data MAGHIGHTRIG MAGLOWTRIG IEC140000146-1-en.vsd...
Page 125 Section 6 1MRK 506 369-UUS - Wide area measurement system This adaptive filtering is ensured by proper configuration and settings of all relevant pre- processing blocks, see Signal matrix for analog inputs in the Application manual. Note that in all preconfigured IEDs such configuration and settings are already made and the three-phase voltage are used as master for frequency tracking.
Page 126: Reporting Filters
Section 6 1MRK 506 369-UUS - Wide area measurement system Name Type Values (Range) Unit Description FREQREFCHSEL INTEGER Frequency reference channel number selected FREQREFCHERR BOOLEAN 0=Freq ref not Frequency reference channel available error 1=Freq ref error 2=Freq ref available FREQTRIG BOOLEAN Frequency trigger DFDTTRIG...
Page 127: Scaling Factors For Analogreport Channels
Section 6 1MRK 506 369-UUS - Wide area measurement system 6.2.3.3 Scaling Factors for ANALOGREPORT channels The internal calculation of analog values in the IED is based on 32 bit floating point. Therefore, if the user selects to report the analog data (AnalogDataType) as Integer, there will be a down-conversion of a 32 bit floating value to a new 16 bit integer value.
Page 128 Section 6 1MRK 506 369-UUS - Wide area measurement system AnalogXRange = 3277.0 IECEQUATION2446 V1 EN The scale factor is calculated as follows: ´ (3277.0 2.0 ) sc alefactor 0.1 a nd offse t 65535.0 IECEQUATION2447 V1 EN The scale factor will be sent as 1 on configuration frame 2, and 0.1 on configuration frame 3.
Page 129: Pmu Report Function Blocks Connection Rules In Pcm600 Application Configuration Tool (Act)
Section 6 1MRK 506 369-UUS - Wide area measurement system 6.2.3.4 PMU Report Function Blocks Connection Rules in PCM600 Application Configuration Tool (ACT) There are 3 important general rules which have to be considered in PCM600 ACT for the connection of preprocessor blocks (SMAI) and 3PHSUM blocks to PHASORREPORT blocks: Rule 1: Only SMAI or 3PHSUM blocks shall be connected to PMU PHASORREPORT blocks...
Page 130 Section 6 1MRK 506 369-UUS - Wide area measurement system every 3 ms while the PHASORREPORT block is expecting input every 0.9 ms. The PHASORREPORT filtering window is designed to receive updated input every 0.9 ms and therefore the application will fail. Rule 2: The same SMAI or 3PHSUM block can be connected to more than one PHASORREPORT block only if all the connected PHASORREPORT blocks have...
Page 131 Section 6 1MRK 506 369-UUS - Wide area measurement system IEC140000127-2-en.vsd IEC140000127 V2 EN Figure 42: An example of correct connection of SMAI and PHASORREPORT blocks in ACT Figure shows an example of wrong connection of SMAI and PHASORREPORT blocks in ACT where the same SMAI block is connected to different PHASORREPORT blocks with different instance numbers.
Page 132 Section 6 1MRK 506 369-UUS - Wide area measurement system IEC140000128-2-en.vsd IEC140000128 V2 EN Figure 43: An example of wrong connection of SMAI and PHASORREPORT blocks in ACT Rule 3: This rule is only related to the connection of 3PHSUM block to the PHASORREPORT block.
Page 133 Section 6 1MRK 506 369-UUS - Wide area measurement system IEC140000129-2-en.vsd IEC140000129 V2 EN Figure 44: An example of correct connection of 3PHSUM and PHASORREPORT blocks in ACT IEC140000130-1-en.vsd IEC140000130 V1 EN Figure 45: SMAI1 setting parameters example-showing that SMAI3 is selected as the DFT reference (DFTRefGrp3) Line distance protection REL670 2.2 ANSI Application manual...
Page 134 Section 6 1MRK 506 369-UUS - Wide area measurement system IEC140000131-1-en IEC140000131 V1 EN Figure 46: 3PHSUM setting parameters example-showing that 3PHSUM is using the External DFT reference coming indirectly from SMAI3 Figure shows an example of wrong connection of 3PHSUM and PHASORREPORT blocks in ACT where SMAI3 is configured as the reference block for DFT reference external out (DFTRefExtOut) and 3PHSUM uses external DFT reference (from SMAI3).
Page 135: Setting Guidelines
Section 6 1MRK 506 369-UUS - Wide area measurement system adapted according to the performance class (SvcClass) and reporting rate of the connected instance of PHASORREPORT function block. On the other hand, when 3PHSUM uses external DFT reference, it also adapts its filtering according to the SMAI reference block. Therefore, in order to avoid two different filtering applied to the 3PHSUM block, both SMAI reference block and 3PHSUM shall be connected to the same PHASORREPORT instance.
Page 136 Section 6 1MRK 506 369-UUS - Wide area measurement system PMUREPORT PHASORREPORT ANALOGREPORT BINARYREPORT Each category has its corresponding parameter settings except for BINARYREPORT function block which does not have any specific parameters and settings. PMUREPORT is the main function block which controls the operation of other PMU reporting function blocks.
Page 137 Section 6 1MRK 506 369-UUS - Wide area measurement system options are Rectangular or Polar format. Rectangular format represents the synchrophasor as real and imaginary values, real value first (a + bj) while the Polar format represents the synchrophasor as magnitude and angle, magnitude jα...
Page 138 Section 6 1MRK 506 369-UUS - Wide area measurement system message format. Depends on the selected data type, the size of each field can be 2 (Integer) or 4 (Float) bytes per IEEE C37.118.2 message. The data sent via the FREQ field is frequency deviation from nominal frequency (50 Hz or 60 Hz), in mHz.
Page 139 Section 6 1MRK 506 369-UUS - Wide area measurement system compensated for all input delays, the time tag of the sample in the middle of the estimation window can be used for the phasor estimation (output) time tag as long as the filtering coefficients are symmetrical across the filtering window. Note: It is recommended to set this parameter on MiddleSample.
Page 140 Section 6 1MRK 506 369-UUS - Wide area measurement system C37.118.2 message format. The options are Single point-on-wave, RMS of analog input and Peak of analog input. Line distance protection REL670 2.2 ANSI Application manual...
Page 141: Section 7 Differential Protection
Section 7 1MRK 506 369-UUS - Differential protection Section 7 Differential protection High impedance differential protection, single phase HZPDIF (87) 7.1.1 Identification IEC 61850 IEC 60617 ANSI/IEEE C37.2 Function description identification identification device number High impedance differential protection, HZPDIF single phase SYMBOL-CC V2 EN 7.1.2 Application...
Page 142: The Basics Of The High Impedance Principle
Section 7 1MRK 506 369-UUS - Differential protection 3·87 3·87B 3·87 3·87B 3·87T 3·87 3·87T 3·87G ANSI05000163-1-en.vsd ANSI05000163 V2 EN Figure 48: Different applications of a 1Ph High impedance differential protection HZPDIF (87) function 7.1.2.1 The basics of the high impedance principle The high impedance differential protection principle has been used for many years and is well documented in literature publicly available.
Page 143 Section 7 1MRK 506 369-UUS - Differential protection sometimes above one kilo Ohm. When an internal fault occurs the current cannot circulate and is forced through the measuring branch causing relay operation. It should be remembered that the whole scheme, its built-in components and wiring must be adequately maintained throughout the lifetime of the equipment in order to be able to withstand the high voltage peaks (that is, pulses) which may appear during an internal fault.
Page 144 Section 7 1MRK 506 369-UUS - Differential protection > × (Equation 16) EQUATION1531-ANSI V1 EN where: IF max is the maximum through fault current at the secondary side of the CT is the current transformer secondary winding resistance and is the maximum loop resistance of the circuit at any CT. The minimum operating voltage has to be calculated (all loops) and the IED function is set higher than the highest achieved value (setting TripPickup).
Page 145 Section 7 1MRK 506 369-UUS - Differential protection Minimum ohms can be difficult to adjust due to the small value compared to the total value. Normally the voltage can be increased to higher values than the calculated minimum TripPickup with a minor change of total operating values as long as this is done by adjusting the resistor to a higher value.
Page 146 Section 7 1MRK 506 369-UUS - Differential protection å = × n IR Ires lmag (Equation 17) EQUATION1747 V1 EN where: is the CT ratio primary current at IED pickup, IED pickup current (U>Trip/SeriesResistor) Ires is the current through the voltage limiter and ΣImag is the sum of the magnetizing currents from all CTs in the circuit (for example, 4 for restricted earth fault protection, 2 for reactor differential protection, 3-5 for autotransformer differential...
Page 147 Section 7 1MRK 506 369-UUS - Differential protection Rres I> Protected Object a) Through load situation b) Through fault situation c) Internal faults ANSI05000427-2-en.vsd ANSI05000427 V2 EN Figure 50: The high impedance principle for one phase with two current transformer inputs Line distance protection REL670 2.2 ANSI Application manual...
Page 148: Connection Examples For High Impedance Differential Protection
Section 7 1MRK 506 369-UUS - Differential protection 7.1.3 Connection examples for high impedance differential protection 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 149: Connections For 1Ph High Impedance Differential Protection Hzpdif (87)
Section 7 1MRK 506 369-UUS - Differential protection Description Scheme grounding point It is important to insure that only one grounding point exist in this scheme. Three-phase plate with setting resistors and metrosils. Protective ground is a separate 4 mm screw terminal on the plate.
Page 150: Setting Guidelines
Section 7 1MRK 506 369-UUS - Differential protection AI01 (I) CT 1500/5 Star/Wye AI02 (I) SMAI2 Connected BLOCK G2AI3P REVROT G2AI1 AI03 (I) ^GRP2_A G2AI2 ^GRP2_B G2AI3 ^GRP2_C G2AI4 AI04 (I) ^GRP2_N AI05 (I) Protected Object AI06 (I) 1-Ph Plate with Metrosil and Resistor ANSI09000170-5-en.vsdx ANSI09000170 V5 EN Figure 52:...
Page 151: Configuration
Section 7 1MRK 506 369-UUS - Differential protection 7.1.4.1 Configuration The configuration is done in the Application Configuration tool. 7.1.4.2 Settings of protection function Operation: The operation of the high impedance differential function can be switched Enabled or Disabled. AlarmPickup: Set the alarm level. The sensitivity can roughly be calculated as a certain percentage of the selected Trip level.
Page 152 Section 7 1MRK 506 369-UUS - Differential protection while the T-zone is protected with a separate differential protection scheme. The 1Ph high impedance differential HZPDIF (87) function in the IED allows this to be done efficiently, see Figure 53. en05000165_ansi.vsd ANSI05000165 V1 EN Figure 53: The protection scheme utilizing the high impedance function for the T-...
Page 153 Section 7 1MRK 506 369-UUS - Differential protection Setting example Basic data: Current transformer ratio: 2000/5A CT Class: C800 (At max tap of 2000/5A) Secondary resistance: 0.5 Ohm (2000/5A tap) Cable loop resistance: Max fault current: Equal to switchgear rated fault current 40 kA Calculation: 40000 >...
Page 154: Tertiary Reactor Protection
Section 7 1MRK 506 369-UUS - Differential protection It can clearly be seen that the sensitivity is not so much influenced by the selected voltage level so a sufficient margin should be used. The selection of the stabilizing resistor and the level of the magnetizing current (mostly dependent of the number of turns) are the most important factors.
Page 155 Section 7 1MRK 506 369-UUS - Differential protection 3·87 ANSI05000176-2-en.vsd ANSI05000176 V2 EN Figure 54: Application of the1Ph High impedance differential protection HZPDIF (87) function on a reactor Setting example It is strongly recommended to use the highest tap of the CT whenever high impedance protection is used.
Page 156 Section 7 1MRK 506 369-UUS - Differential protection in the unused taps, owing to auto-transformer action, voltages much higher than design limits might be induced. Basic data: Current transformer ratio: 100/5 A (Note: Must be the same at all locations) CT Class: C200 Secondary resistance:...
Page 157: Alarm Level Operation
Section 7 1MRK 506 369-UUS - Differential protection Where 200mA is the current drawn by the IED circuit and 50mA is the current drawn by each CT just at pickup. The magnetizing current is taken from the magnetizing curve of the current transformer cores, which should be available.
Page 158: Additional Security Logic For Differential Protection Ldrgfc (11)
Section 7 1MRK 506 369-UUS - Differential protection IEC05000749 V1 EN Figure 55: Current voltage characteristics for the non-linear resistors, in the range 10-200 V, the average range of current is: 0.01–10 mA Additional security logic for differential protection LDRGFC (11) 7.2.1 Identification Function description...
Page 159 Section 7 1MRK 506 369-UUS - Differential protection • Phase-to-phase current variation • Zero sequence current criterion • Low voltage criterion • Low current criterion Phase-to-phase current variation takes the current samples (IL1–IL2, IL2–IL3, etc.) as input and it calculates the variation using the sampling value based algorithm. Phase-to- phase current variation function is major one to fulfil the objectives of the start up element.
Page 160: Setting Guidelines
Section 7 1MRK 506 369-UUS - Differential protection Release of line differential LDLPSCH (87L) 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 (11REL) I3P* START U3P*...
Page 161 Section 7 1MRK 506 369-UUS - Differential protection PU 3I0 : Level of high zero sequence current detection given in % of IBase. This setting should be based on fault calculations to find the zero sequence current in case of a fault at the point on the protected line giving the smallest fault current to the protection.
Page 163: Section 8 Impedance Protection
Section 8 1MRK 506 369-UUS - Impedance protection Section 8 Impedance protection Distance measuring zone, quadrilateral characteristic for series compensated lines ZMCPDIS (21), ZMCAPDIS (21), ZDSRDIR (21D) 8.1.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Distance measuring zone, quadrilateral ZMCPDIS characteristic for series compensated...
Page 164: System Grounding
Section 8 1MRK 506 369-UUS - Impedance protection The distance protection function is designed to meet basic requirements for application on transmission and sub transmission lines (solid grounded systems) although it also can be used on distribution levels. 8.1.2.2 System grounding The type of system grounding plays an important roll when designing the protection system.
Page 165 Section 8 1MRK 506 369-UUS - Impedance protection is the zero sequence impedance (Ω/phase) is the fault impedance (Ω), often resistive is the ground return impedance defined as (Z0-Z1)/3 The voltage on the healthy phases is generally lower than 140% of the nominal phase-to- ground voltage.
Page 166: Fault Infeed From Remote End
Section 8 1MRK 506 369-UUS - Impedance protection high resistance faults and must, therefore, always be complemented with other protection function(s) that can carry out the fault clearance in this case. 8.1.2.3 Fault infeed from remote end All transmission and most all sub transmission networks are operated meshed. Typical for this type of network is that we will have fault infeed from remote end when fault occurs on the protected line.
Page 167: Load Encroachment
Section 8 1MRK 506 369-UUS - Impedance protection 8.1.2.4 Load encroachment Sometimes the load impedance might enter the zone characteristic without any fault on the protected line. The phenomenon is called load encroachment and it might occur when an external fault is cleared and high emergency load is transferred on the protected line. The effect of load encroachment is illustrated to the left in figure 59.
Page 168: Long Transmission Line Application
Section 8 1MRK 506 369-UUS - Impedance protection 8.1.2.5 Long transmission line application For long transmission lines the margin to the load impedance that is, to avoid load encroachment, will normally be a major concern. It is difficult to achieve high sensitivity for line to ground-fault at remote end of a long lines when the line is heavy loaded.
Page 169: Parallel Line Application With Mutual Coupling
Section 8 1MRK 506 369-UUS - Impedance protection 8.1.2.6 Parallel line application with mutual coupling General Introduction of parallel lines in the network is increasing due to difficulties to get necessary area for new lines. Parallel lines introduce an error in the measurement due to the mutual coupling between the parallel lines.
Page 170 Section 8 1MRK 506 369-UUS - 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 This type of networks are defined as those networks where the parallel transmission lines terminate at common nodes at both ends.
Page 171 Section 8 1MRK 506 369-UUS - Impedance protection FAULT en05000221_ansi.vsd ANSI05000221 V1 EN Figure 61: Class 1, parallel line in service The equivalent circuit of the lines can be simplified, as shown in figure 62. Z0 m 99000038.vsd IEC99000038 V1 EN Figure 62: Equivalent zero sequence impedance circuit of the double-circuit, parallel, operating line with a single phase-to-ground-fault at the remote...
Page 172 Section 8 1MRK 506 369-UUS - Impedance protection Where: = Z0m/(3 · Z1L) The second part in the parentheses is the error introduced to the measurement of the line impedance. If the current on the parallel line has negative sign compared to the current on the protected line that is, the current on the parallel line has an opposite direction compared to the current on the protected line, the distance function overreaches.
Page 173 Section 8 1MRK 506 369-UUS - Impedance protection   ⋅ ⋅ ⋅   −   p ZI = ⋅  I KN  ⋅     (Equation 36) EQUATION1379 V3 EN Calculation for a 400 kV line, where we for simplicity have excluded the resistance, gives with X1L=0.48 Ohm/Mile, X0L=1.4Ohms/Mile, zone 1 reach is set to 90% of the line reactance p=71% that is, the protection is underreaching with approximately 20%.
Page 174 Section 8 1MRK 506 369-UUS - Impedance protection Z m0 99000039.vsd DOCUMENT11520-IMG7100 V1 EN Figure 64: Equivalent zero-sequence impedance circuit for the double-circuit line that operates with one circuit disconnected and grounded 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 37.
Page 175 Section 8 1MRK 506 369-UUS - Impedance protection Parallel line out of service and not grounded OPEN OPEN CLOSED CLOSED en05000223_ansi.vsd ANSI05000223 V1 EN Figure 65: Parallel line is out of service and not grounded When the parallel line is out of service and not grounded, the zero sequence on that line can only flow through the line admittance to the ground.
Page 176: Tapped Line Application
Section 8 1MRK 506 369-UUS - Impedance protection × × × × × × (Equation 40) EQUATION1284 V1 EN This means that the reach is reduced in reactive and resistive directions. If the real and imaginary components of the constant A are equal to equation and equation 42.
Page 177 Section 8 1MRK 506 369-UUS - Impedance protection ANSI05000224-2-en.vsd ANSI05000224 V2 EN Figure 67: Example of tapped line with Auto transformer This application gives rise to similar problem that was highlighted in section "Fault infeed from remote end" that is, increased measured impedance due to fault current infeed. For example, for faults between the T point and B station the measured impedance at A and C is as follows: ·Z...
Page 178 Section 8 1MRK 506 369-UUS - 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. V2/V1 Transformation ratio for transformation of impedance at V1 side of the transformer to the measuring side V2 (it is assumed that current and voltage distance function is taken...
Page 179: Series Compensation In Power Systems
Section 8 1MRK 506 369-UUS - Impedance protection In practice, the setting of fault resistance for both phase-to-ground (RFPG) and phase-to- phase (RFPP) must be as high as possible without interfering with the load impedance to obtain reliable fault detection. 8.1.2.8 Series compensation in power systems The main purpose of series compensation in power systems is virtual reduction of line...
Page 180 Section 8 1MRK 506 369-UUS - Impedance protection A typical 500 km long 500 kV line is considered with source impedance (Equation 49) EQUATION1896 V1 EN Power line Load Seires capacitor en06000585.vsd IEC06000585 V1 EN Figure 68: A simple radial power system limit 1000 1200...
Page 181 Section 8 1MRK 506 369-UUS - Impedance protection between the generator and the infinite bus increases during the fault. At the time of fault clearing, the angle difference has increased to δ . After reclosing of the system, the transmitted power exceeds the mechanical input power and the generator deaccelerates. The generator decelerates as long as equal area condition A has not been fulfilled.
Page 182 Section 8 1MRK 506 369-UUS - Impedance protection (Mvar) (S.C.) Capacitive Power flow (MW) 1000 1500 (T.L. + S.C.) Inductive Transmission 500 kV (T.L.) 500 km Line Series 1000 Compensation k = 50 % en06000589.vsd IEC06000589 V1 EN Figure 72: Self-regulating effect of reactive power balance Increase in power transfer The increase in power transfer capability as a function of the degree of compensation for...
Page 183 Section 8 1MRK 506 369-UUS - Impedance protection The effect on the power transfer when considering a constant angle difference (δ) between the line ends is illustrated in figure 74. Practical compensation degree runs from 20 to 70 percent. Transmission capability increases of more than two times can be obtained in practice.
Page 184 Section 8 1MRK 506 369-UUS - Impedance protection (Equation 51) EQUATION1899 V1 EN Reduced costs of power transmission due to decreased investment costs for new power line As shown in figure the line loading can easily be increased 1.5-2 times by series compensation.
Page 185 Section 8 1MRK 506 369-UUS - Impedance protection en06000595.vsd IEC06000595 V1 EN Figure 77: Thyristor switched series capacitor en06000596_ansi.vsd ANSI06000596 V1 EN Figure 78: 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 186 Section 8 1MRK 506 369-UUS - Impedance protection 0.02 0.02 0.04 0.04 0.06 0.06 0.08 0.08 0.12 0.12 0.14 0.14 0.16 0.16 0.18 0.18 0.02 0.02 0.04 0.04 0.06 0.06 0.08 0.08 0.12 0.12 0.14 0.14 0.16 0.16 0.18 0.18 0.02 0.02 0.04...
Page 187: Challenges In Protection Of Series Compensated And Adjacent Power Lines
Section 8 1MRK 506 369-UUS - Impedance protection During continuous valve bypass the TCSC represents an inductive impedance of about 20% of the capacitor impedance. Both operation in capacitive boost mode and valve bypass mode can be used for damping of power swings. The utilization of valve bypass increases the dynamic range of the TCSC and improves the TCSC effectiveness in power oscillation damping.
Page 188 Section 8 1MRK 506 369-UUS - Impedance protection drop DV on series capacitor lags the fault current by 90 degrees. Note that line impedance could be divided into two parts: one between the IED point and the capacitor and one between the capacitor and the fault position.
Page 189 Section 8 1MRK 506 369-UUS - Impedance protection without series capacitor. Voltage V in IED point will lag the fault current I in case when: < < (Equation 53) EQUATION1902 V1 EN Where is the source impedance behind the IED The IED point voltage inverses its direction due to presence of series capacitor and its dimension.
Page 190 Section 8 1MRK 506 369-UUS - Impedance protection The relative phase position of fault current I compared to the source voltage V depends in general on the character of the resultant reactance between the source and the fault position. Two possibilities appear: >...
Page 191 Section 8 1MRK 506 369-UUS - Impedance protection shows also big dependence of possible current inversion on series compensated lines on location of series capacitors. X = 0 for faults just behind the capacitor when located at line IED and only the source impedance prevents current inversion. Current inversion has been considered for many years only a theoretical possibility due to relatively low values of source impedances (big power plants) compared to the capacitor reactance.
Page 192 Section 8 1MRK 506 369-UUS - Impedance protection × × = × × + (Equation 57) EQUATION1905 V1 EN The solution over line current is presented by group of equations é ù - × × × + - × × ê...
Page 193 Section 8 1MRK 506 369-UUS - Impedance protection × × + - × × × × × - × æ ö × ç ÷ × è ø × × × é ù × × × ê ú ê ú ê ú...
Page 194 Section 8 1MRK 506 369-UUS - 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 Figure 86: Short circuit currents for the fault at the end of 500 km long 500 kV line without and with SC Location of instrument transformers Location of instrument transformers relative to the line end series capacitors plays an...
Page 195 Section 8 1MRK 506 369-UUS - Impedance protection Bus side instrument transformers 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 196 Section 8 1MRK 506 369-UUS - Impedance protection near the feeding bus will see in different cases fault on remote end bus depending on type of overvoltage protection used on capacitor bank (spark gap or MOV) and SC location on protected power line.
Page 197 Section 8 1MRK 506 369-UUS - Impedance protection 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_ansi.vsd ANSI06000614 V1 EN Figure 90:...
Page 198 Section 8 1MRK 506 369-UUS - Impedance protection Extensive studies at Bonneville Power Administration in USA ( ref. Goldsworthy, D,L “A Linearized Model for MOV-Protected series capacitors” Paper 86SM357–8 IEEE/PES summer meeting in Mexico City July 1986) have resulted in construction of a non-linear equivalent circuit with series connected capacitor and resistor.
Page 199: Impact Of Series Compensation On Protective Ied Of Adjacent Lines
Section 8 1MRK 506 369-UUS - Impedance protection • Series capacitor becomes nearly completely bridged by MOV when the line current becomes higher than 10-times the protective current level (I £ 10· k · I 8.1.2.10 Impact of series compensation on protective IED of adjacent lines Voltage inversion is not characteristic for the buses and IED points closest to the series compensated line only.
Page 200: Distance Protection
Section 8 1MRK 506 369-UUS - Impedance protection equation indicates the deepness of the network to which it will feel the influence of series compensation through the effect of voltage inversion. It is also obvious that the position of series capacitor on compensated line influences in great extent the deepness of voltage inversion in adjacent system.
Page 201 Section 8 1MRK 506 369-UUS - Impedance protection compensated and adjacent lines are concentrated on finding some parallel ways, which may help eliminating the basic reason for wrong measurement. The most known of them are decrease of the reach due to presence of series capacitor, which apparently decreases the line reactance, and introduction of permanent memory voltage in directional measurement.
Page 202 Section 8 1MRK 506 369-UUS - Impedance protection Equation is applicable for the case when the VTs are located on the bus side of series capacitor. It is possible to remove X from the equation in cases of VTs installed in line side, but it is still necessary to consider the safety factor K If the capacitor is out of service or bypassed, the reach with these settings can be less than 50% of protected line dependent on compensation degree and there will be a section, G in...
Page 203 Section 8 1MRK 506 369-UUS - Impedance protection < < (Equation 67) EQUATION1898 V1 EN and in figure a three phase fault occurs beyond the capacitor. The resultant IED impedance seen from the D IED location to the fault may become negative (voltage inversion) until the spark gap has flashed.
Page 204 Section 8 1MRK 506 369-UUS - Impedance protection en06000621_ansi.vsd ANSI06000621 V1 EN Figure 96: Distance IED on adjacent power lines are influenced by the negative impedance Normally the first zone of this protection must be delayed until the gap flashing has taken place.
Page 205 Section 8 1MRK 506 369-UUS - Impedance protection en06000584_small.vsd en06000625.vsd IEC06000584-SMALL V1 EN IEC06000625 V1 EN Figure 98: Quadrilateral Figure 97: Cross-polarized characteristic with quadrilateral separate impedance and characteristic directional measurement If the distance protection is equipped with a ground-fault measuring unit, the negative impedance occurs when ×...
Page 206 Section 8 1MRK 506 369-UUS - Impedance protection fault current will cause a high voltage on the network. The situation will be the same even if a MOV is used. However, depending upon the setting of the MOV, the fault current will have a resistive component.
Page 207 Section 8 1MRK 506 369-UUS - Impedance protection underreaching distance protection zone 1 for phase-to-ground measuring loops must further be decreased for such operating conditions. en06000628.vsd IEC06000628 V1 EN Figure 100: Zero sequence equivalent circuit of a series compensated double circuit line with one circuit disconnected and grounded 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...
Page 208: Setting Guidelines
Section 8 1MRK 506 369-UUS - Impedance protection blocked for the short period. The disadvantage is that a local communication is needed between two protection devices in the neighboring bays of the same substation. Distance protection used on series compensated lines must have a high overreach to cover the whole transmission line also when the capacitors are bypassed or out of service.
Page 209: Setting Of Overreaching Zone
Section 8 1MRK 506 369-UUS - Impedance protection In case of parallel lines, consider the influence of the mutual coupling according to section "Parallel line application with mutual coupling" and select the case(s) that are valid in your application. We recommend to compensate setting for the cases when the parallel line is in operation, out of service and not grounded and out of service and grounded in both ends.
Page 210: Setting Of Reverse Zone
Section 8 1MRK 506 369-UUS - Impedance protection Z AC Z CB Z CF I A+ IB ANSI05000457-2-en.vsd ANSI05000457 V2 EN Figure 102: 8.1.3.4 Setting of reverse zone The reverse zone is applicable for purposes of scheme communication logic, current reversal logic, weak-end-infeed logic, and so on.
Page 211 Section 8 1MRK 506 369-UUS - Impedance protection (ZMCPDIS,ZMCAPDIS, 21). This function is necessary in the protection on compensated lines as well as all non-compensated lines connected to this busbar (adjacent lines). All protections that can be exposed to voltage reversal must have the special directional function, including the protections on busbar where the voltage can be reversed by series compensated lines not terminated to this busbar.
Page 212 Section 8 1MRK 506 369-UUS - Impedance protection 100 % 99000202.vsd IEC99000202 V1 EN Figure 103: Reduced reach due to the expected sub-harmonic oscillations at different degrees of compensation æ ö c degree of compensation ç ÷ ç ÷ è ø...
Page 213 Section 8 1MRK 506 369-UUS - Impedance protection Reactive Reach Compensated lines with the capacitor into the zone 1 reach : LLOC en07000063.vsd IEC07000063 V1 EN Figure 104: Simplified single line diagram of series capacitor located at X LLOC from A station Line distance protection REL670 2.2 ANSI Application manual...
Page 214 Section 8 1MRK 506 369-UUS - Impedance protection line LLOC en06000584-2.vsd IEC06000584 V2 EN Figure 105: 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 215 Section 8 1MRK 506 369-UUS - Impedance protection When the calculation of XFw gives a negative value the zone 1 must be permanently blocked. For protection on non compensated lines facing series capacitor on next line. The setting is thus: •...
Page 216: Setting Of Zones For Parallel Line Application
Section 8 1MRK 506 369-UUS - Impedance protection The safety factor of 1.5 appears due to speed requirements and possible under reaching caused by the sub harmonic oscillations. The increased reach related to the one used in non compensated system is recommended for all protections in the vicinity of series capacitors to compensate for delay in the operation caused by the sub harmonic swinging.
Page 217 Section 8 1MRK 506 369-UUS - Impedance protection (Equation 80) EQUATION554 V1 EN Check the reduction of a reach for the overreaching zones due to the effect of the zero sequence mutual coupling. The reach is reduced for a factor: ×...
Page 218: Setting Of Reach In Resistive Direction
Section 8 1MRK 506 369-UUS - Impedance protection 8.1.3.7 Setting of reach in resistive direction Set the resistive reach independently for each zone, and separately for phase-to-phase (R1PP), and phase-to-ground loop (R1PG) measurement. Set separately the expected fault resistance for phase-to-phase faults (R1PP) and for the phase-to-ground faults (RFPG) for each zone.
Page 219 Section 8 1MRK 506 369-UUS - Impedance protection loa d min (Equation 90) EQUATION1718 V1 EN 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: loa d ×...
Page 220: Load Impedance Limitation, With Load Encroachment Function Activated
Section 8 1MRK 506 369-UUS - Impedance protection é × ù £ × × ¶ - × ¶ RFPG ê ú ë û load × (Equation 93) EQUATION1721 V2 EN Where: ϑ is a maximum load-impedance angle, related to the minimum load impedance conditions. 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 221: Setting Of Timers For Distance Protection Zones
Section 8 1MRK 506 369-UUS - Impedance protection The default setting of IMinPUPP and IMinPUPG is 20% of IBase where IBase is the chosen base current for the analog input channels. The value has been proven in practice to be suitable in most of the applications. However, there might be applications where it is necessary to increase the sensitivity by reducing the minimum operating current down to 10% of IED base current.
Page 222: Application
Section 8 1MRK 506 369-UUS - Impedance protection 8.2.2 Application The operation of transmission networks today is in many cases close to the stability limit. The ability to accurately and reliably classify the different types of fault, so that single pole tripping and autoreclosing can be used plays an important role in this matter.
Page 223 Section 8 1MRK 506 369-UUS - Impedance protection direction, RFltFwdPG and RFltRevPG for phase-to-ground faults and RFltRevPP and RFltRevPP for phase-to-phase faults have to be increased to avoid that FDPSPDIS (21) characteristic shall cut off some part of the zone characteristic. The necessary increased setting of the fault resistance coverage can be derived from trigonometric evaluation of the basic characteristic for respectively fault type.
Page 224 Section 8 1MRK 506 369-UUS - Impedance protection ( / loop) 60° 60° ( / loop) IEC09000043_1_en.vsd IEC09000043 V1 EN Figure 106: Relation between distance protection phase selection (FDPSPDIS) (21) and impedance zone (ZMQPDIS) (21) for phase-to-ground fault φloop>60° (setting parameters in italic) 1 FDPSPDIS (phase selection)(21) (red line) 2 ZMQPDIS (Impedance protection zone)(21) RFltRevPG...
Page 225 Section 8 1MRK 506 369-UUS - Impedance protection Reactive reach 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. ³...
Page 226 Section 8 1MRK 506 369-UUS - Impedance protection Resistive reach 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 227 Section 8 1MRK 506 369-UUS - Impedance protection ( / phase) 60° 60° ( / phase) IEC09000257_1_en.vsd IEC09000257 V1 EN Figure 107: Relation between distance protection (ZMQPDIS) (21) and FDPSPDIS (21) characteristic for phase-to-phase fault for φline>60° (setting parameters in italic) 1 FDPSPDIS (phase selection)(21) (red line) 2 ZMQPDIS (Impedance protection zone) (21) RFltRevPP...
Page 228: Resistive Reach With Load Encroachment Characteristic
Section 8 1MRK 506 369-UUS - Impedance protection 8.2.3.2 Resistive reach with load encroachment characteristic The procedure for calculating the settings for the load encroachment consist basically to define the load angle LdAngle, the blinder RLdFwd in forward direction and blinder RLdRev in reverse direction, as shown in figure 108.
Page 229: Minimum Operate Currents
Section 8 1MRK 506 369-UUS - Impedance protection The resistive boundary RLdRev for load encroachment characteristic in reverse direction can be calculated in the same way as RLdFwd, but use maximum importing power that might occur instead of maximum exporting power and the relevant Vmin voltage for this condition.
Page 230: Application
Section 8 1MRK 506 369-UUS - Impedance protection 8.3.2 Application Sub-transmission networks are being extended and often become more and more complex, consisting of a high number of multi-circuit and/or multi terminal lines of very different lengths. These changes in the network will normally impose more stringent demands on the fault clearing equipment in order to maintain an unchanged or increased security level of the power system.
Page 231 Section 8 1MRK 506 369-UUS - Impedance protection Where: is the phase-to-ground voltage (kV) in the faulty phase before fault is the positive sequence impedance (Ω/phase) is the negative sequence impedance (Ω/phase), is considered to be equal to Z is the zero sequence impedance (Ω/phase) is the fault impedance (Ω), often resistive is the ground-return impedance defined as (Z The voltage on the healthy phases is generally lower than 140% of the nominal phase-to-...
Page 232 Section 8 1MRK 506 369-UUS - Impedance protection Where is the zero sequence source resistance is the zero sequence source reactance is the positive sequence source resistance is the positive sequence source reactance The magnitude of the ground-fault current in effectively grounded networks is high enough for impedance measuring elements to detect ground faults.
Page 233: Fault Infeed From Remote End
Section 8 1MRK 506 369-UUS - Impedance protection × × (Equation 109) EQUATION1272 V1 EN ANSI05000216 V2 EN Figure 110: High impedance grounded network The operation of high impedance grounded networks is different compared to solid grounded networks where all major faults have to be cleared very fast. In high impedance grounded networks, some system operators do not clear single phase-to-ground faults immediately;...
Page 234: Load Encroachment
Section 8 1MRK 506 369-UUS - Impedance protection × × (Equation 111) EQUATION1274 V2 EN The infeed factor (I can be very high, 10-20 depending on the differences in source impedances at local and remote end. p*ZL (1-p)*ZL en05000217_ansi.vsd ANSI05000217 V1 EN Figure 111: Influence of fault current infeed from remote line end The effect of fault current infeed from remote line end is one of the most driving factors...
Page 235: Short Line Application
Section 8 1MRK 506 369-UUS - Impedance protection encroachment, quadrilateral characteristic function (FDPSPDIS, 21), the resistive blinder for the zone measurement can be expanded according to the figure given higher fault resistance coverage without risk for unwanted operation due to load encroachment. This is valid in both directions.
Page 236: Long Transmission Line Application
Section 8 1MRK 506 369-UUS - Impedance protection In short line applications, the major concern is to get sufficient fault resistance coverage. Load encroachment is not so common. The line length that can be recognized as a short line is not a fixed length; it depends on system parameters such as voltage and source impedance, see table 19.
Page 237: Parallel Line Application With Mutual Coupling
Section 8 1MRK 506 369-UUS - Impedance protection 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-ground fault together with load encroachment algorithm improves the possibility to detect high resistive faults at the same time as the security is improved (risk for unwanted trip due to load encroachment is eliminated), see figure 113.
Page 238 Section 8 1MRK 506 369-UUS - Impedance protection It can be shown from analytical calculations of line impedances that the mutual impedances for positive and negative sequence are very small (< 1-2%) of the self impedance and it is a practice to neglect them. 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.
Page 239 Section 8 1MRK 506 369-UUS - Impedance protection Parallel line in service This type of application is very common and applies to all normal sub-transmission and transmission networks. Let us analyze what happens when a fault occurs on the parallel line see figure 114. From symmetrical components, we can derive the impedance Z at the relay point for normal lines without mutual coupling according to equation 112.
Page 240 Section 8 1MRK 506 369-UUS - Impedance protection IEC09000253_1_en.vsd IEC09000253 V1 EN Figure 115: Equivalent zero sequence impedance circuit of the double-circuit, parallel, operating line with a single phase-to-ground fault at the remote busbar When mutual coupling is introduced, the voltage at the relay point A will be changed according to equation 113.
Page 241 Section 8 1MRK 506 369-UUS - Impedance protection × × × (Equation 115) EQUATION1278 V4 EN One can also notice that the following relationship exists between the zero sequence currents: ⋅ ⋅ − (Equation 116) EQUATION1279 V3 EN Simplification of equation 116, solving it for 3I0p and substitution of the result into equation gives that the voltage can be drawn as: æ...
Page 242 Section 8 1MRK 506 369-UUS - Impedance protection OPEN OPEN CLOSED CLOSED en05000222_ansi.vsd ANSI05000222 V1 EN Figure 116: The parallel line is out of service and grounded When the parallel line is out of service and grounded at both line ends on the bus bar side of the line CTs so that zero sequence current can flow on the parallel line, the equivalent zero sequence circuit of the parallel lines will be according to figure 117.
Page 243 Section 8 1MRK 506 369-UUS - Impedance protection   ⋅       (Equation 120) DOCUMENT11520-IMG3502 V2 EN   ⋅ −       (Equation 121) DOCUMENT11520-IMG3503 V2 EN Parallel line out of service and not grounded OPEN OPEN CLOSED...
Page 244 Section 8 1MRK 506 369-UUS - Impedance protection IEC09000255_1_en.vsd IEC09000255 V1 EN Figure 119: Equivalent zero-sequence impedance circuit for a double-circuit line with one circuit disconnected and not grounded The reduction of the reach is equal to equation 122. × ×...
Page 245: Tapped Line Application
Section 8 1MRK 506 369-UUS - Impedance protection Ensure that the underreaching zones from both line ends will overlap a sufficient amount (at least 10%) in the middle of the protected circuit. 8.3.2.7 Tapped line application ANSI05000224-2-en.vsd ANSI05000224 V2 EN Figure 120: Example of tapped line with Auto transformer This application gives rise to similar problem that was highlighted in section...
Page 246 Section 8 1MRK 506 369-UUS - Impedance protection × × Z ) ( (Equation 128) EQUATION1714 V1 EN 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. V2/V1 Transformation ratio for transformation of impedance at V1 side of the transformer to the measuring side V2 (it is assumed that current and voltage distance function is taken...
Page 247: Setting Guidelines
Section 8 1MRK 506 369-UUS - Impedance protection × 28707 L Rarc (Equation 129) EQUATION1456 V1 EN where: represents the length of the arc (in meters). This equation applies for the distance protection zone 1. Consider approximately three times arc foot spacing for the zone 2 and to give extra margin to the influence of wind speed and temperature.
Page 248: Setting Of Zone 1
Section 8 1MRK 506 369-UUS - Impedance protection 8.3.3.2 Setting of zone 1 The different errors mentioned earlier usually require a limitation of the underreaching zone (normally zone 1) to 75 - 90% of the protected line. In case of parallel lines, consider the influence of the mutual coupling according to section "Parallel line application with mutual coupling"...
Page 249: Setting Of Reverse Zone
Section 8 1MRK 506 369-UUS - Impedance protection     ⋅ ⋅  ⋅  ⋅       (Equation 130) EQUATION302 V5 EN Z AC Z CB Z CF I A+ IB ANSI05000457-2-en.vsd ANSI05000457 V2 EN Figure 121: Setting of overreaching zone 8.3.3.4...
Page 250: Setting Of Zones For Parallel Line Application
Section 8 1MRK 506 369-UUS - Impedance protection 8.3.3.5 Setting of zones for parallel line application Parallel line in service – Setting of zone 1 With reference to section "Parallel line applications", the zone reach can be set to 85% of the protected line.
Page 251: Setting Of Reach In Resistive Direction
Section 8 1MRK 506 369-UUS - Impedance protection × (Equation 136) EQUATION1428 V2 EN Parallel line is out of service and grounded in both ends Apply the same measures as in the case with a single set of setting parameters. This means that an underreaching zone must not overreach the end of a protected circuit for the single phase-to-ground faults.
Page 252: Load Impedance Limitation, Without Load Encroachment Function246
Section 8 1MRK 506 369-UUS - Impedance protection Setting of the resistive reach for the underreaching zone 1 should follow the condition to minimize the risk for overreaching:   RFPEZx 4.5 X1Zx (Equation 141) IECEQUATION2305 V2 EN The fault resistance for phase-to-phase faults is normally quite low, compared to the fault resistance for phase-to-ground faults.
Page 253 Section 8 1MRK 506 369-UUS - Impedance protection Minimum voltage V and maximum current I are related to the same operating conditions. Minimum load impedance occurs normally under emergency conditions. As 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 ground faults, consider both: phase-to-phase and phase-to-ground fault operating characteristics.
Page 254: Load Impedance Limitation, With Phase Selection With Load Encroachment, Quadrilateral Characteristic Function Activated
Section 8 1MRK 506 369-UUS - Impedance protection Set the fault resistance coverage RFRwPP and RFRwPG to the same value as in forward direction, if that suits the application. All this is applicable for all measuring zones when no Power swing detection function ZMRPSB (78) is activated in the IED. Use an additional safety margin of approximately 20% in cases when a ZMRPSB (78) function is activated in the IED, refer to the description of Power swing detection function ZMRPSB (78).
Page 255 Section 8 1MRK 506 369-UUS - Impedance protection For the AB element, the equation in forward direction is according to. × × < < ArgDir L L M ArgNeg (Equation 150) EQUATION1553 V2 EN where: AngDir is the setting for the lower boundary of the forward directional characteristic, by default set to 15 (= -15 degrees) and AngNegRes is the setting for the upper boundary of the forward directional characteristic, by default set to 115 degrees, see figure 122.
Page 256 Section 8 1MRK 506 369-UUS - Impedance protection AngNegRes AngDir en05000722_ansi.vsd ANSI05000722 V1 EN Figure 122: Setting angles for discrimination of forward and reverse fault in Directional impedance quadrilateral function ZDRDIR (21D) The reverse directional characteristic is equal to the forward characteristic rotated by 180 degrees.
Page 257: Setting Of Timers For Distance Protection Zones
Section 8 1MRK 506 369-UUS - Impedance protection 8.3.3.11 Setting of timers for distance protection zones The required time delays for different distance protection zones are independent of each other . Distance protection zone 1 can also have a time delay, if so required for selectivity reasons.
Page 258: System Grounding
Section 8 1MRK 506 369-UUS - Impedance protection 8.4.2.2 System grounding The type of system grounding plays an important role when designing the protection system. In the following some hints with respect to distance protection are highlighted. Solid grounded networks In solid grounded systems the transformer neutrals are connected solidly to ground without any impedance between the transformer neutral and ground.
Page 259 Section 8 1MRK 506 369-UUS - Impedance protection The voltage on the healthy phases is generally lower than 140% of the nominal phase-to- ground voltage. This corresponds to about 80% of the nominal phase-to-phase voltage. The high zero-sequence current in solid grounded networks makes it possible to use impedance measuring technique to detect ground fault.
Page 260 Section 8 1MRK 506 369-UUS - Impedance protection way as for solid grounded networks, distance protection has limited possibilities to detect high resistance faults and should therefore always be complemented with other protection function(s) that can carry out the fault clearance in this case. High impedance grounded networks In high impedance networks the neutral of the system transformers are connected to the ground through high impedance, mostly a reactance in parallel with a high resistor.
Page 261: Fault Infeed From Remote End
Section 8 1MRK 506 369-UUS - Impedance protection IEC05000216 V2 EN Figure 124: High impedance grounding network The operation of high impedance grounded networks is different compared to solid grounded networks where all major faults have to be cleared very fast. In high impedance grounded networks, some system operators do not clear single phase-to-ground faults immediately;...
Page 262: Load Encroachment
Section 8 1MRK 506 369-UUS - Impedance protection × × (Equation 158) EQUATION1274 V2 EN The infeed factor (I can be very high, 10-20 depending on the differences in source impedances at local and remote end. p*ZL (1-p)*ZL ANSI11000086_1_en.vsd ANSI11000086 V1 EN Figure 125: Influence of fault current infeed from remote end.
Page 263 Section 8 1MRK 506 369-UUS - Impedance protection Load Load Load Load Load Load Load Load operation en06000403.vsd IEC06000403 V1 EN Figure 126: Load encroachment phenomena and shaped load encroachment characteristic The Faulty phase identification with load encroachment for mho (FMPSPDIS, 21) function shapes the characteristic according to the diagram on the right in figure 126.
Page 264: Short Line Application
Section 8 1MRK 506 369-UUS - Impedance protection LdAngle LdAngle LdAngle LdAngle en06000404_ansi.vsd ANSI06000404 V1 EN Figure 127: Load encroachment of Faulty phase identification with load encroachment for mho function FMPSPDIS (21) characteristic The use of the load encroachment feature is essential for long heavy loaded lines, where there might be a conflict between the necessary emergency load transfer and necessary sensitivity of the distance protection.
Page 265: Long Transmission Line Application
Section 8 1MRK 506 369-UUS - Impedance protection In short line applications, the major concern is to get sufficient fault resistance coverage. Load encroachment is not so common. The line length that can be recognized as a short line is not a fixed length; it depends on system parameters such as voltage and source impedance, see table 19.
Page 266: Parallel Line Application With Mutual Coupling
Section 8 1MRK 506 369-UUS - Impedance protection increase the security but might also lower the dependability since the blinder might cut off a larger part of the operating area of the circle (see to the right of figure 126). It is recommended to use at least one of the load discrimination functions for long heavy loaded transmission lines.
Page 267 Section 8 1MRK 506 369-UUS - Impedance protection Mutual induction on three-phase transmission lines In case of three phase lines, mutual coupling in the positive and negative sequence components is relatively weak and can be neglected. These are of the order of 5% of the related self-impedance for non-transposed and lower than 3% for transposed lines.
Page 268 Section 8 1MRK 506 369-UUS - Impedance protection Class 1: Parallel line with common positive and zero-sequence network Class 2: Parallel circuits with common positive but isolated or separated zero- sequence network Class 3: Parallel circuits with positive and zero-sequence sources isolated or separated.
Page 269 Section 8 1MRK 506 369-UUS - Impedance protection ground current of faulty line is ground compensation factor for single circuit set at the relay given by equation × (Equation 162) IECEQUATION14005 V1 EN The short circuit voltage can be calculated as: −...
Page 270 Section 8 1MRK 506 369-UUS - Impedance protection Where: ground current of faulty line is ground current of the parallel line is line positive sequence impedance is earth compensation factor for single circuit set at the relay given by equation is the zero sequence mutual coupling between the faulted and the parallel line ×...
Page 271: Tapped Line Application
Section 8 1MRK 506 369-UUS - Impedance protection • Different setting values that influence the ground-return compensation for different distance zones within the same group of setting parameters. • Different groups of setting parameters for different operating conditions of a protected multi circuit line.
Page 272: Setting Guidelines
Section 8 1MRK 506 369-UUS - Impedance protection æ ö æ ö × × ç ÷ ç ÷ è ø è ø (Equation 170) ANSIEQUATION-1750 V1 EN 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 273: Setting Of Zone 1
Section 8 1MRK 506 369-UUS - Impedance protection • Errors introduced by current and voltage instrument transformers, particularly under transient conditions. • Inaccuracies in the line zero-sequence impedance data, and their effect on the calculated value of the ground-return compensation factor. •...
Page 274: Setting Of Zone 2
Section 8 1MRK 506 369-UUS - Impedance protection By proper setting it is possible to compensate for the cases when the parallel line is in operation, out of service and not earthed and out of service and earthed in both ends. 8.4.3.3 Setting of zone 2 Zone 2 distance elements must be set according to the following criteria:...
Page 275 Section 8 1MRK 506 369-UUS - Impedance protection Parallel line in service Setting of zones for parallel line application The distance protection zone reaches vary with the switching state of the parallel line configuration. Below the configurations and the corresponding formulas for the reach calculation are given for the most important cases.
Page 276 Section 8 1MRK 506 369-UUS - Impedance protection Case 2: Parallel line switched off and not earthed or earthed at one line end ANSI13000256 V1 EN Figure 132: Parallel line is out of service and not earthed × = × (Equation 174) IECEQUATION14012 V1 EN Case 3: Both lines in service...
Page 277 Section 8 1MRK 506 369-UUS - Impedance protection The mutual impedance will influence the distance measurement of ground faults and cause either an extension or a reduction of the reach relative to the set reach. The maximum overreach will occur when the parallel line is out of service and grounded at both ends.
Page 278 Section 8 1MRK 506 369-UUS - Impedance protection (Equation 176) IECEQUATION14018 V1 EN This K setting for zone 1 only affects the reach for ground faults while the reach for two and three-phase faults are unaffected. For case 2, when the parallel line is out of operation but not grounded, the zone 1 nominal reach for ground faults is reduced.
Page 279 Section 8 1MRK 506 369-UUS - Impedance protection (Equation 179) IECEQUATION14019 V1 EN For case 1, the measured impedance can be calculated by the following expression: × = × (Equation 180) IECEQUATION14017 V1 EN For case 2, the measured impedance can be calculated by the following expression: ×...
Page 280: Consideration Of Zero Sequence Mutual Coupling For Parallel Circuits
Section 8 1MRK 506 369-UUS - Impedance protection With this method of setting the zero sequence compensation factor K can for zone 1 and zone 2 be even better adapted for the real system conditions. The table describes ground fault compensation settings to be adopted for different groups. Table 23: Different groups of settings Group...
Page 281 Section 8 1MRK 506 369-UUS - Impedance protection Zload (Equation 183) EQUATION1753-ANSI V1 EN 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: Zload = ×...
Page 282 Section 8 1MRK 506 369-UUS - Impedance protection ZPG/2 (Ref) φ γ LdAngle β Load Ohm/phase ANSI06000406-1-en.vsd ANSI06000406 V1 EN Figure 134: Definition of the setting condition to avoid load encroachment for ground- fault loop The maximum setting for phase-to-phase fault can be defined by trigonometric analyze of the same figure 134.
Page 283: Load Impedance Limitation, With Load Encroachment Function Activated
Section 8 1MRK 506 369-UUS - Impedance protection 8.4.3.8 Load impedance limitation, with load encroachment function activated The parameters for load encroachment shaping of the characteristic are found in the description of Faulty phase identification with load encroachment for mho (FMPSPDIS), refer to section "Load encroachment characteristics".
Page 284: Full-Scheme Distance Protection, Quadrilateral For Earth Faults
Section 8 1MRK 506 369-UUS - Impedance protection function of each particular zone can be inhibited by setting the corresponding Operation parameter to OffDisable-Zone. Different time delays are possible for the phase-to-groundtLG and for the phase-to-phase tPP measuring loops in each distance protection zone separately, to further increase the total flexibility of a distance protection.
Page 285: System Grounding
Section 8 1MRK 506 369-UUS - Impedance protection The distance protection function in IED is designed to meet basic requirements for application on transmission and sub transmission lines (solid grounded systems) although it also can be used on distribution levels. 8.5.2.2 System grounding The type of system grounding plays an important roll when designing the protection...
Page 286 Section 8 1MRK 506 369-UUS - Impedance protection The voltage on the healthy phases is generally lower than 140% of the nominal phase-to- ground voltage. This corresponds to about 80% of the nominal phase-to-phase voltage. The high zero sequence current in solid grounded networks makes it possible to use impedance measuring technique to detect ground fault.
Page 287 Section 8 1MRK 506 369-UUS - Impedance protection High impedance grounded networks In high impedance networks the neutral of the system transformers are connected to the ground through high impedance, mostly a reactance in parallel with a high resistor. This type of network is many times operated in radial, but can also be found operating meshed.
Page 288: Fault Infeed From Remote End
Section 8 1MRK 506 369-UUS - Impedance protection IEC05000216 V2 EN Figure 136: High impedance grounding network The operation of high impedance grounded networks is different compare to solid grounded networks where all major faults have to be cleared very fast. In high impedance grounded networks, some system operators do not clear single phase-to-ground faults immediately;...
Page 289: Load Encroachment
Section 8 1MRK 506 369-UUS - Impedance protection × × (Equation 194) EQUATION1274 V2 EN The infeed factor (IA+IB)/IA can be very high, 10-20 depending on the differences in source impedances at local and remote end. p*ZL (1-p)*ZL Z < Z <...
Page 290: Short Line Application
Section 8 1MRK 506 369-UUS - 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. ZMMPDIS (21) function can also preferably be used on heavy loaded medium long lines.
Page 291: Long Transmission Line Application
Section 8 1MRK 506 369-UUS - Impedance protection to-ground fault together with load encroachment algorithm improves the possibility to detect high resistive faults without conflict with the load impedance, see figure 138. For very short line applications the underreaching zone 1 can not be used due to that the voltage drop distribution through out the line will be too low causing risk for overreaching.
Page 292 Section 8 1MRK 506 369-UUS - Impedance protection or more. The reason to the introduced error in measuring due to mutual coupling is the zero sequence voltage inversion that occurs. It can be shown from analytical calculations of line impedances that the mutual impedances for positive and negative sequence are very small (<...
Page 293 Section 8 1MRK 506 369-UUS - Impedance protection parallel line in service. parallel line out of service and grounded. parallel line out of service and not grounded. Parallel line in service This type of application is very common and applies to all normal sub-transmission and transmission networks.
Page 294 Section 8 1MRK 506 369-UUS - Impedance protection Z0 m 99000038.vsd IEC99000038 V1 EN Figure 140: Equivalent zero sequence impedance circuit of the double-circuit, parallel, operating line with a single phase-to-ground 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 295 Section 8 1MRK 506 369-UUS - Impedance protection When the parallel line is out of service and grounded 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 141.
Page 296 Section 8 1MRK 506 369-UUS - Impedance protection Parallel line out of service and not grounded Z< Z< en05000223.vsd IEC05000223 V1 EN Figure 143: Parallel line is out of service and not grounded. When the parallel line is out of service and not grounded, the zero sequence on that line can only flow through the line admittance to the ground.
Page 297: Tapped Line Application
Section 8 1MRK 506 369-UUS - Impedance protection This means that the reach is reduced in reactive and resistive directions. If the real and imaginary components of the constant A are equal to equation and equation 201. × × + × ×...
Page 298 Section 8 1MRK 506 369-UUS - Impedance protection Z< Z< Z< en05000224.vsd DOCUMENT11524-IMG869 V1 EN Figure 145: Example of tapped line with Auto transformer This application gives rise to similar problem that was highlighted in section "Fault infeed from remote end" that is, increased measured impedance due to fault current infeed.
Page 299 Section 8 1MRK 506 369-UUS - Impedance protection For this example with a fault between T and B, the measured impedance from the T point to the fault will be increased by a factor defined as the sum of the currents from T point to the fault divided by the IED current.
Page 300: Setting Guidelines
Section 8 1MRK 506 369-UUS - Impedance protection 8.5.3 Setting guidelines 8.5.3.1 General The settings for the Full-scheme distance protection, quadrilateral for earth faults (ZMMPDIS, 21) 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 (21) function.
Page 301: Setting Of Reverse Zone
Section 8 1MRK 506 369-UUS - Impedance protection adjacent lines at remote end are considerable higher than the fault current at the IED location. The setting shall generally not exceed 80% of the following impedances: • The impedance corresponding to the protected line, plus the first zone reach of the shortest adjacent line.
Page 302: Setting Of Zones For Parallel Line Application
Section 8 1MRK 506 369-UUS - Impedance protection covers the overreaching zone, used at the remote line IED for the telecommunication purposes. Consider the possible enlarging factor that might exist due to fault infeed from adjacent lines. Equation can be used to calculate the reach in reverse direction when the zone is used for blocking scheme, weak-end infeed and so on.
Page 303: Setting Of Reach In Resistive Direction
Section 8 1MRK 506 369-UUS - Impedance protection Check the reduction of a reach for the overreaching zones due to the effect of the zero sequence mutual coupling. The reach is reduced for a factor: × (Equation 211) EQUATION1426 V1 EN If the denominator in equation is called B and Z0m is simplified to X0m, then the real and imaginary part of the reach reduction factor for the overreaching zones can be written...
Page 304: Load Impedance Limitation, With Load Encroachment Function
Section 8 1MRK 506 369-UUS - Impedance protection Set separately the expected fault resistance for the phase-to-ground faults (RFPE) for each zone. Set all remaining reach setting parameters independently of each other for each distance zone. The final reach in resistive direction for phase-to-ground fault loop measurement automatically follows the values of the line-positive and zero-sequence resistance, and at the end of the protected zone is equal to equation 216.
Page 305: Activated
Section 8 1MRK 506 369-UUS - Impedance protection load × (Equation 220) EQUATION1781-ANSI V1 EN Minimum voltage V 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 ground faults, consider both: phase-to-phase and phase-to-ground fault operating...
Page 306: Setting Of Minimum Operating Currents
Section 8 1MRK 506 369-UUS - Impedance protection reach with load encroachment characteristic". If the characteristic for the impedance measurement shall be shaped with the load encroachment algorithm, the parameter OperationLdCmp in the phase selection has to be switched On. 8.5.3.9 Setting of minimum operating currents The operation of the distance function will be blocked if the magnitude of the currents is...
Page 307: Zdardir
Section 8 1MRK 506 369-UUS - Impedance protection 8.6.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Additional distance protection ZDARDIR directional function for earth faults S00346 V1 EN 8.6.2 Application The phase-to-ground impedance elements can be supervised by a phase unselective directional function based on symmetrical components (option).
Page 308 Section 8 1MRK 506 369-UUS - Impedance protection In general the zero sequence voltage is higher than the negative sequence voltage at the fault, but decreases more rapidly the further away from the fault it is measured. This makes the -V polarization preferable in short line applications, where no mutual coupling problems exist.
Page 309: Mho Impedance Supervision Logic Zsmgapc
Section 8 1MRK 506 369-UUS - Impedance protection intended for use in applications where the zero sequence voltage can be too small to be used as the polarizing quantity, and there is no zero sequence polarizing current (transformer neutral current) available. The zero sequence voltage is “boosted” by a portion of the measured line zero sequence current to form the polarizing quantity.
Page 310: Setting Guidelines
Section 8 1MRK 506 369-UUS - Impedance protection In the pilot channel blocking scheme a fault inception detected by a fast acting change detector is used to send a block signal to the remote end in order to block an overreaching zone.
Page 311: Faulty Phase Identification With Load Encroachment Fmpspdis (21)
Section 8 1MRK 506 369-UUS - Impedance protection IMinOp: The minimum operate current for the SIR measurement is by default set to 20% of IBase. Faulty phase identification with load encroachment FMPSPDIS (21) 8.8.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification...
Page 312: Setting Guidelines
Section 8 1MRK 506 369-UUS - Impedance protection 8.8.3 Setting guidelines GlobalBaseSel: Selects the global base value group used by the function to define IBase, VBase and SBase as applicable. INRelPG: The setting of INRelPG for release of the phase-to-ground loop is by default set to 20% of IBase.
Page 313: Load Encroachment
Section 8 1MRK 506 369-UUS - Impedance protection ILoad × VLmn (Equation 226) EQUATION1615-ANSI V1 EN where: Smax is the maximal apparent power transfer during emergency conditions and VLmn is the phase-to-phase voltage during the emergency conditions at the IED location. 8.8.3.1 Load encroachment The load encroachment function has two setting parameters, RLd for the load resistance...
Page 314: Distance Protection Zone, Quadrilateral Characteristic, Separate
Section 8 1MRK 506 369-UUS - Impedance protection Zload (Equation 228) EQUATION1753-ANSI V1 EN Where: is the minimum phase-to-phase voltage in kV is the maximum apparent power in MVA. The load angle LdAngle can be derived according to equation 229: æ...
Page 315: Identification
Section 8 1MRK 506 369-UUS - Impedance protection 8.9.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Distance protection zone, quadrilateral ZMRPDIS characteristic, separate settings (zone S00346 V1 EN Distance protection zone, quadrilateral ZMRAPDIS characteristic, separate settings (zone 2-5) S00346 V1 EN Function description...
Page 316 Section 8 1MRK 506 369-UUS - Impedance protection ANSI05000215 V2 EN Figure 148: Solidly grounded network. The ground-fault current is as high or even higher than the short-circuit current. The series impedances determine the magnitude of the fault current. The shunt admittance has very limited influence on the ground-fault current.
Page 317 Section 8 1MRK 506 369-UUS - Impedance protection Effectively grounded networks A network is defined as effectively grounded if the ground-fault factor f is less than 1.4. The ground-fault factor is defined according to equation 25. (Equation 232) ANSIEQUATION1268 V1 EN Where: is the highest fundamental frequency voltage on one of the healthy phases at single phase- to-ground fault.
Page 318 Section 8 1MRK 506 369-UUS - Impedance protection This type of network is many times operated in radial, but can also be found operating meshed networks. What is typical for this type of network is that the magnitude of the ground fault current is very low compared to the short circuit current.
Page 319: Fault Infeed From Remote End
Section 8 1MRK 506 369-UUS - Impedance protection grounded networks, some system operators do not clear single phase-to- ground faults immediately; they clear the line later when it is more convenient. In case of cross-country faults, many network operators want to selectively clear one of the two ground-faults. To handle this type phenomena, a separate function called Phase preference logic (PPLPHIZ) is needed, which is not common to be used in transmission applications.
Page 320: Load Encroachment
Section 8 1MRK 506 369-UUS - Impedance protection p*ZL (1-p)*ZL en05000217_ansi.vsd ANSI05000217 V1 EN Figure 150: Influence of fault current infeed from remote line end The effect of fault current infeed from remote line end is one of the most driving factors for justify complementary protection to distance protection.
Page 321: Short Line Application
Section 8 1MRK 506 369-UUS - Impedance protection loaded medium long lines. For short lines, the major concern is to get sufficient fault resistance coverage and load encroachment is not a major problem. So, for short lines, the load encroachment function could preferably be switched off. See section "Load impedance limitation, without load encroachment function".
Page 322: Long Transmission Line Application
Section 8 1MRK 506 369-UUS - Impedance protection 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-ground fault together with load encroachment algorithm improves the possibility to detect high resistive faults without conflict with the load impedance, see figure 112.
Page 323 Section 8 1MRK 506 369-UUS - Impedance protection Parallel lines introduce an error in the measurement due to the mutual coupling between the parallel lines. The lines need not be of the same voltage in order to experience mutual coupling, and some coupling exists even for lines that are separated by 100 meters or more.
Page 324 Section 8 1MRK 506 369-UUS - Impedance protection The three most common operation modes are: parallel line in service. parallel line out of service and grounded. parallel line out of service and not grounded. Parallel line in service This type of application is very common and applies to all normal sub-transmission and transmission networks.
Page 325 Section 8 1MRK 506 369-UUS - Impedance protection FAULT en05000221_ansi.vsd ANSI05000221 V1 EN Figure 152: Class 1, parallel line in service. The equivalent zero sequence circuit of the lines can be simplified, see figure 115. IEC09000253_1_en.vsd IEC09000253 V1 EN Figure 153: Equivalent zero sequence impedance circuit of the double-circuit, parallel, operating line with a single phase-to-ground fault at the remote busbar.
Page 326 Section 8 1MRK 506 369-UUS - 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 will overreach.
Page 327 Section 8 1MRK 506 369-UUS - Impedance protection Calculation for a 400 kV line, where we for simplicity have excluded the resistance, gives with X1L=0.48 Ohm/Mile, X0L=1.4Ohms/Mile, zone 1 reach is set to 90% of the line reactance p=71% that is, the protection is underreaching with approximately 20%. The zero sequence mutual coupling can reduce the reach of distance protection on the protected circuit when the parallel line is in normal operation.
Page 328 Section 8 1MRK 506 369-UUS - Impedance protection (Equation 246) EQUATION2002 V4 EN The influence on the distance measurement will be a considerable overreach, which must be considered when calculating the settings. It is recommended to use a separate setting group for this operation condition since it will reduce the reach considerably when the line is in operation.
Page 329: Tapped Line Application
Section 8 1MRK 506 369-UUS - Impedance protection When the parallel line is out of service and not grounded, the zero sequence on that line can only flow through the line admittance to the ground. The line admittance is high which limits the zero sequence current on the parallel line to very low values.
Page 330 Section 8 1MRK 506 369-UUS - Impedance protection This application gives rise to similar problem that was highlighted in section "Fault infeed from remote end" , that is increased measured impedance due to fault current infeed. For example, for faults between the T point and B station the measured impedance at A and C will be ·Z (Equation 249)
Page 331: Setting Guidelines
Section 8 1MRK 506 369-UUS - Impedance protection zone 1 settings, that is without selectivity conflicts. Careful fault calculations are necessary to determine suitable settings and selection of proper scheme communication. Fault resistance The performance of distance protection for single phase-to-ground faults is very important, because normally more than 70% of the faults on transmission lines are single phase-to-ground faults.
Page 332: Setting Of Zone 1
Section 8 1MRK 506 369-UUS - Impedance protection • Errors introduced by current and voltage instrument transformers, particularly under transient conditions. • Inaccuracies in the line zero sequence impedance data, and their effect on the calculated value of the ground-return compensation factor. •...
Page 333: Setting Of Reverse Zone
Section 8 1MRK 506 369-UUS - Impedance protection 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 334: Setting Of Zones For Parallel Line Application
Section 8 1MRK 506 369-UUS - Impedance protection ³ × 1.2 Z2 (Equation 253) EQUATION2314 V1 EN Where: is the protected line impedance is zone 2 setting at remote end of protected line. 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.
Page 335: Setting Of Reach In Resistive Direction
Section 8 1MRK 506 369-UUS - Impedance protection × (Equation 256) EQUATION1426 V1 EN If the denominator in equation is called B and Z0m is simplified to X0m, then the real and imaginary part of the reach reduction factor for the overreaching zones can be written ×...
Page 336: Load Impedance Limitation, Without Load Encroachment Function330
Section 8 1MRK 506 369-UUS - Impedance protection The final reach in resistive direction for phase-to-ground fault loop measurement automatically follows the values of the line-positive and zero-sequence resistance, and at the end of the protected zone is equal to equation 139. ×...
Page 337 Section 8 1MRK 506 369-UUS - Impedance protection loa d min (Equation 265) EQUATION1718 V1 EN 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: loa d ×...
Page 338: Load Impedance Limitation, With Phase Selection With Load Encroachment, Quadrilateral Characteristic Function Activated
Section 8 1MRK 506 369-UUS - Impedance protection é × ù £ × × ¶ - × ¶ RFPG ê ú ë û load × (Equation 268) EQUATION1721 V2 EN 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 339: Setting Of Timers For Distance Protection Zones
Section 8 1MRK 506 369-UUS - Impedance protection The default setting of IMinPUPP and IMinPUPG is 20% of IBase where IBase is the chosen current for the analogue input channels. The value has been proven in practice to be suitable in most of the applications. However, there might be applications where it is necessary to increase the sensitivity by reducing the minimum operating current down to 10% of IBase.
Page 340 Section 8 1MRK 506 369-UUS - Impedance protection accurately select the proper fault loop in the distance measuring function depending on the fault type. 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, the function has a 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 341 Section 8 1MRK 506 369-UUS - Impedance protection RLdFwd LdAngle LdAngle LdAngle LdAngle RLdRev en05000196_ansi.vsd ANSI05000196 V1 EN Figure 160: 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 (21) function. When output signal PHSELZis selected, the characteristic for the FRPSPDIS (21) (and also zone measurement depending on settings) can be reduced by the load encroachment characteristic (as shown in figure 161).
Page 342 Section 8 1MRK 506 369-UUS - Impedance protection PHSELZ DLECND ANSI10000099-1-en.vsd ANSI10000099 V1 EN Figure 161: Operating characteristic when load encroachment is activated When the "phase selection" is set to operate together with a distance measuring zone the resultant operate characteristic could look something like in figure 162. The figure shows a distance measuring zone operating in forward direction.
Page 343 Section 8 1MRK 506 369-UUS - Impedance protection "Phase selection" "quadrilateral" zone Distance measuring zone Load encroachment characteristic Directional line en05000673.vsd IEC05000673 V1 EN Figure 162: Operation characteristic in forward direction when load encroachment is enabled Figure is valid for phase-to-ground. During a three-phase fault, or load, when the "quadrilateral"...
Page 344 Section 8 1MRK 506 369-UUS - Impedance protection (ohm/phase) Phase selection ”Quadrilateral” zone Distance measuring zone (ohm/phase) en05000674.vsd IEC05000674 V1 EN Figure 163: Operation characteristic for FRPSPDIS (21) 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 164.
Page 345: Load Encroachment Characteristics
Section 8 1MRK 506 369-UUS - Impedance protection IEC08000437.vsd IEC08000437 V1 EN Figure 164: 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 346: Phase-To-Ground Fault In Forward Direction
Section 8 1MRK 506 369-UUS - Impedance protection arctan (Equation 271) EQUATION2115 V1 EN But in some applications, for instance cable lines, the angle of the loop might be less than the set angle. In these applications, the settings of fault resistance coverage in forward and reverse direction, RFltFwdPG and RFltRevPG for phase-to-ground faults and RFltRevPP and RFltRevPP for phase-to-phase faults have to be increased to avoid that the phase selection characteristic must cut off some part of the zone characteristic.
Page 347 Section 8 1MRK 506 369-UUS - Impedance protection R PG R PG R PG (Minimum setting) RFRevPG RFFwdPG RFPG RFPG 90° φ loop φ loop (Ohm/loop) RFPG RFPG ANSI08000435-1-en.vsd ANSI08000435 V1 EN Figure 165: Relation between measuring zone and FRPSPDIS (21) characteristic Reactive reach The reactive reach in forward direction must as minimum be set to cover the measuring zone used in the Teleprotection schemes, mostly zone 2.
Page 348: Phase-To-Ground Fault In Reverse Direction
Section 8 1MRK 506 369-UUS - Impedance protection ³ × 1.44 X0 (Equation 273) EQUATION1310 V1 EN where: is the reactive reach for the zone to be covered by FRPSPDIS (21), and the constant 1.44 is a safety margin is the zero-sequence reactive reach for the zone to be covered by FRPSPDIS (21) The reactive reach in reverse direction is automatically set to the same reach as for forward direction.
Page 349: Phase-To-Phase Fault In Forward Direction
Section 8 1MRK 506 369-UUS - Impedance protection Resistive reach 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 350 Section 8 1MRK 506 369-UUS - Impedance protection where: RFPP is the setting of the longest reach of the overreaching zones that must be covered by FRPSPDIS (21). Equation are is also valid for three-phase fault. The proposed margin of 25% will cater for the risk of cut off of the zone measuring characteristic that might occur at three-phase fault when FRPSPDIS (21)characteristic angle is changed from 60 degrees to 90 degrees or from 70 degrees to 100 degrees (rotated 30°...
Page 351: Setting Guidelines
Section 8 1MRK 506 369-UUS - Impedance protection phase R1PP= tan 70° × × 0.5 RFFwdPP 0.5*RFPP 0.5*RFPP phase 0.5*RFPP 0.5*RFPP 0.5*RFPP 0.5*RFPP × R1PP= tan 70° ANSI08000249-1- en.vsd ANSI08000249 V1 EN Figure 166: Relation between measuring zone and FRPSPDIS (21) characteristic for phase-to-phase fault for φline>70°...
Page 352: Resistive Reach With Load Encroachment Characteristic
Section 8 1MRK 506 369-UUS - Impedance protection 8.10.4.1 Resistive reach with load encroachment characteristic The procedure for calculating the settings for the load encroachment consist basically to define the load angle LdAngle, the blinder RLdFwd in forward direction and blinder RLdRev in reverse direction, as shown in figure 108.
Page 353: Minimum Operate Currents
Section 8 1MRK 506 369-UUS - Impedance protection might occur instead of maximum exporting power and the relevant Vmin voltage for this condition. 8.10.4.2 Minimum operate currents FRPSPDIS (21) has two current setting parameters, which blocks the respective phase-to- ground loop and phase-to-phase loop if the RMS value of the phase current (ILn) and phase difference current (ILmILn) is below the settable threshold.
Page 354: Setting Guidelines
Section 8 1MRK 506 369-UUS - 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, the function has a 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 355 Section 8 1MRK 506 369-UUS - Impedance protection Phase-to-ground fault in forward direction With reference to figure 106, the following equations for the setting calculations can be obtained. Index PHS in images and equations reference settings for Phase selection with load encroachment function FDPSPDIS (21) and index Zm reference settings for Distance protection function (ZMQPDIS, 21).
Page 356 Section 8 1MRK 506 369-UUS - Impedance protection ( / loop) 60° 60° ( / loop) IEC09000043_1_en.vsd IEC09000043 V1 EN Figure 168: Relation between distance protection phase selection (FDPSPDIS) (21) and impedance zone (ZMQPDIS) (21) for phase-to-ground fault φloop>60° (setting parameters in italic) 1 FDPSPDIS (phase selection)(21) (red line) 2 ZMQPDIS (Impedance protection zone)(21) RFltRevPG...
Page 357 Section 8 1MRK 506 369-UUS - Impedance protection Reactive reach 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. ³...
Page 358 Section 8 1MRK 506 369-UUS - Impedance protection Resistive reach 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 359 Section 8 1MRK 506 369-UUS - Impedance protection ( / phase) 60° 60° ( / phase) IEC09000257_1_en.vsd IEC09000257 V1 EN Figure 169: Relation between distance protection (ZMQPDIS) (21) and FDPSPDIS (21) characteristic for phase-to-phase fault for φline>60° (setting parameters in italic) 1 FDPSPDIS (phase selection)(21) (red line) 2 ZMQPDIS (Impedance protection zone) (21) RFltRevPP...
Page 360: Resistive Reach With Load Encroachment Characteristic
Section 8 1MRK 506 369-UUS - Impedance protection 8.11.3.2 Resistive reach with load encroachment characteristic The procedure for calculating the settings for the load encroachment consist basically to define the load angle LdAngle, the blinder RLdFwd in forward direction and blinder RLdRev in reverse direction, as shown in figure 108.
Page 361: Minimum Operate Currents
Section 8 1MRK 506 369-UUS - Impedance protection The resistive boundary RLdRev for load encroachment characteristic in reverse direction can be calculated in the same way as RLdFwd, but use maximum importing power that might occur instead of maximum exporting power and the relevant Vmin voltage for this condition.
Page 362: System Grounding
Section 8 1MRK 506 369-UUS - Impedance protection 8.12.2.1 System grounding The type of system grounding plays an important role when designing the protection system. Some hints with respect to distance protection are highlighted below. Solidly grounded networks In solidly grounded systems, the transformer neutrals are connected directly to ground without any impedance between the transformer neutral and ground.
Page 363 Section 8 1MRK 506 369-UUS - Impedance protection The voltage on the healthy phases during line to ground fault is generally lower than 140% of the nominal phase-to-ground voltage. This corresponds to about 80% of the nominal phase-to-phase voltage. The high zero-sequence current in solidly grounded networks makes it possible to use impedance measuring techniques to detect ground faults.
Page 364 Section 8 1MRK 506 369-UUS - Impedance protection The magnitude of the ground-fault current in effectively grounded networks is high enough for impedance measuring elements to detect ground faults. However, in the same way as for solidly grounded networks, distance protection has limited possibilities to detect high resistance faults and should therefore always be complemented with other protection function(s) that can carry out the fault clearance in this case.
Page 365: Fault Infeed From Remote End
Section 8 1MRK 506 369-UUS - Impedance protection ANSI05000216 V2 EN Figure 172: High impedance grounded network The operation of high impedance grounded networks is different compared to solid grounded networks, where all major faults have to be cleared very fast. In high impedance grounded networks, some system operators do not clear single phase-to-ground faults immediately;...
Page 366: Load Encroachment
Section 8 1MRK 506 369-UUS - Impedance protection × × (Equation 296) EQUATION1274 V2 EN The infeed factor (I can be very high, 10-20 depending on the differences in source impedances at local and remote end. p*ZL (1-p)*ZL en05000217_ansi.vsd ANSI05000217 V1 EN Figure 173: Influence of fault current infeed from remote line end The effect of fault current infeed from the remote line end is one of the most driving factors...
Page 367: Short Line Application
Section 8 1MRK 506 369-UUS - Impedance protection resistance coverage without risk for unwanted operation due to load encroachment. Separate resistive blinder settings are available in forward and reverse direction. The use of the load encroachment feature is essential for long heavily loaded lines, where there might be a conflict between the necessary emergency load transfer and necessary sensitivity of the distance protection.
Page 368: Long Transmission Line Application
Section 8 1MRK 506 369-UUS - Impedance protection Table 28: Definition of short and very short line Line category 110 kV 500 kV Very short line 0.75 -3.5 miles 3-15 miles Short line 4-7 miles 15-30 miles 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-ground fault together with load encroachment algorithm improves the possibility to detect high resistive faults without conflict with the load impedance.
Page 369: Parallel Line Application With Mutual Coupling
Section 8 1MRK 506 369-UUS - Impedance protection 8.12.2.6 Parallel line application with mutual coupling General Introduction of parallel lines in the network is increasing due to difficulties to get necessary land to build new lines. Parallel lines introduce an error in the measurement due to the mutual coupling between the parallel lines.
Page 370 Section 8 1MRK 506 369-UUS - Impedance protection Most multi circuit lines have two parallel operating circuits. Parallel line applications This type of networks is defined as those networks where the parallel transmission lines terminate at common nodes at both ends. The three most common operation modes are: Parallel line in service.
Page 371 Section 8 1MRK 506 369-UUS - Impedance protection FAULT en05000221_ansi.vsd ANSI05000221 V1 EN Figure 175: Class 1, parallel line in service The equivalent circuit of the lines can be simplified, see figure 115. IEC09000253_1_en.vsd IEC09000253 V1 EN Figure 176: Equivalent zero sequence impedance circuit of the double-circuit, parallel, operating line with a single phase-to-ground fault at the remote busbar When mutual coupling is introduced, the voltage at the relay point A will be changed...
Page 372 Section 8 1MRK 506 369-UUS - 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 will overreach.
Page 373 Section 8 1MRK 506 369-UUS - Impedance protection The zero sequence mutual coupling can reduce the reach of distance protection on the protected circuit when the parallel line is in normal operation. The reduction of the reach is most pronounced with no current infeed in the IED closest to the fault. This reach reduction is normally less than 15%.
Page 374 Section 8 1MRK 506 369-UUS - Impedance protection The influence on the distance measurement will be a considerable overreach, which must be considered when calculating the settings. It is recommended to use a separate setting group for this operation condition since it will reduce the reach considerably when the line is in operation.
Page 375 Section 8 1MRK 506 369-UUS - Impedance protection distance protection zone is reduced if, due to operating conditions, the equivalent zero sequence impedance is set according to the conditions when the parallel system is out of operation and grounded at both ends. IEC09000255_1_en.vsd IEC09000255 V1 EN Figure 180:...
Page 376: Tapped Line Application
Section 8 1MRK 506 369-UUS - Impedance protection × é ù é ù ë û ë û (Equation 311) EQUATION1288 V2 EN Ensure that the underreaching zones from both line ends will overlap a sufficient amount (at least 10%) in the middle of the protected circuit. 8.12.2.7 Tapped line application ANSI05000224-2-en.vsd...
Page 377 Section 8 1MRK 506 369-UUS - Impedance protection ·Z (Equation 312) DOCUMENT11524-IMG3509 V3 EN × × Z ) ( (Equation 313) EQUATION1714 V1 EN 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 378: Setting Guidelines
Section 8 1MRK 506 369-UUS - Impedance protection phase-to-ground faults. At these faults, the fault resistance is composed of three parts: arc resistance, resistance of a tower construction, and tower-footing resistance.The resistance is also depending on the presence of ground shield conductor at the top of the tower, connecting tower-footing resistance in parallel.
Page 379: Setting Of Zone 1
Section 8 1MRK 506 369-UUS - Impedance protection • The phase impedance of non transposed lines is not identical for all fault loops. The difference between the impedances for different phase-to-ground loops can be as large as 5-10% of the total line impedance. •...
Page 380: Setting Of Reverse Zone
Section 8 1MRK 506 369-UUS - Impedance protection The requirement that the zone 2 shall not reach more than 80% of the shortest adjacent line at remote end is highlighted in the example below. If a fault occurs at point F see figure 121, the IED at point A senses the impedance: ...
Page 381: Setting Of Zones For Parallel Line Application
Section 8 1MRK 506 369-UUS - 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. 8.12.3.5 Setting of zones for parallel line application Parallel line in service –...
Page 382: Setting The Reach With Respect To Load
Section 8 1MRK 506 369-UUS - Impedance protection × (Equation 321) EQUATION1428 V2 EN Parallel line is out of service and grounded in both ends Apply the same measures as in the case with a single set of setting parameters. This means that an underreaching zone must not overreach the end of a protected circuit for the single phase-to-ground faults.
Page 383: Zone Reach Setting Lower Than Minimum Load Impedance
Section 8 1MRK 506 369-UUS - Impedance protection Setting of the resistive reach for the underreaching zone 1 should follow the condition to minimize the risk for overreaching: £ × RFPG 4.5 X1 (Equation 326) ANSIEQUATION2305 V1 EN The fault resistance for phase-to-phase faults is normally quite low compared to the fault resistance for phase-to-ground faults.
Page 384 Section 8 1MRK 506 369-UUS - Impedance protection loa d min (Equation 328) EQUATION1718 V1 EN Where: the minimum phase-to-phase voltage in kV the maximum apparent power in MVA. The load impedance [Ω/phase] is a function of the minimum operation voltage and the maximum load current: loa d ×...
Page 385: Zone Reach Setting Higher Than Minimum Load Impedance
Section 8 1MRK 506 369-UUS - Impedance protection é × ù £ × × ¶ - × ¶ RFPG ê ú ë û load × (Equation 331) EQUATION1721 V2 EN 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 386: Other Settings
Section 8 1MRK 506 369-UUS - Impedance protection phase-to-ground fault, it corresponds to the per-loop impedance, including the ground return impedance. RLdFwd RLdFwd LdAngle LdAngle LdAngle LdAngle LdAngle Possible LdAngle LdAngle LdAngle load RLdRev RLdRev ANSI12000176-1-en.vsd ANSI12000176 V1 EN Figure 183: Load impedance limitation with load encroachment During the initial current change for phase-to-phase and for phase-to-ground faults, operation may be allowed also when the apparent impedance of the load encroachment...
Page 387 Section 8 1MRK 506 369-UUS - Impedance protection Both current limits IMinOpPGZx and IMinOpPPZx are automatically reduced to 75% of regular set values if the zone is set to operate in reverse direction, that is, OperationDir is set to Reverse. OpModePPZx and OpModePEZx These settings, two per zone (x=1,2..5&RV), with options {Off, Quadrilateral, Mho, Offset}, are used to set the operation and characteristic for phase-to-earth and phase-to-...
Page 388 Section 8 1MRK 506 369-UUS - Impedance protection TimerModeZx = Enable Ph-Ph, Ph-G PPZx tPPZx PGZx tPPZx BLOCK LOVBZ BLKZx BLKTRZx TimerLinksZx LoopLink (tPP-tPG) ZoneLinkStart LoopLink & ZoneLink no links PUPHS Phase Selection 1st pickup zone LNKZ1 FALSE (0) LNKZ2 LNKZx LNKZRV LNKZ3...
Page 389: High Speed Distance Protection For Series Compensated Lines Zmfcpdis (21)
Section 8 1MRK 506 369-UUS - Impedance protection 3I0Enable_PG This setting opens up an opportunity to enable phase-to-ground measurement for phase- to-phase-ground faults. It determines the level of residual current (3I0) above which phase-to-ground measurement is activated (and phase-to-phase measurement is blocked). The relations are defined by equation 334.
Page 390: Application
Section 8 1MRK 506 369-UUS - Impedance protection 8.13.2 Application Sub-transmission networks are being extended and often become more and more complex, consisting of a high number of multi-circuit and/or multi terminal lines of very different lengths. These changes in the network will normally impose more stringent demands on the fault clearing equipment in order to maintain an unchanged or increased security level of the power system.
Page 391 Section 8 1MRK 506 369-UUS - Impedance protection × (Equation 335) EQUATION1710 V2 EN Where: is the phase-to-ground 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.
Page 392: Fault Infeed From Remote End
Section 8 1MRK 506 369-UUS - Impedance protection < × (Equation 337) EQUATION2122 V1 EN £ (Equation 338) EQUATION2123 V1 EN Where is the resistive zero sequence of the source is the reactive zero sequence of the source is the resistive positive sequence of the source is the reactive positive sequence of the source The magnitude of the ground-fault current in effectively grounded networks is high enough for impedance measuring elements to detect ground faults.
Page 393: Load Encroachment
Section 8 1MRK 506 369-UUS - Impedance protection × × (Equation 340) EQUATION1274 V2 EN The infeed factor (I can be very high, 10-20 depending on the differences in source impedances at local and remote end. p*ZL (1-p)*ZL en05000217_ansi.vsd ANSI05000217 V1 EN Figure 187: Influence of fault current infeed from remote line end The effect of fault current infeed from remote line end is one of the most driving factors...
Page 394: Short Line Application
Section 8 1MRK 506 369-UUS - Impedance protection coverage without risk for unwanted operation due to load encroachment. This is valid in both directions. The use of the load encroachment feature is essential for long heavily loaded lines, where there might be a conflict between the necessary emergency load transfer and necessary sensitivity of the distance protection.
Page 395: Long Transmission Line Application
Section 8 1MRK 506 369-UUS - Impedance protection Table 30: Definition of short and very short line Line category 110 kV 500 kV Very short line 0.75 -3.5 miles 3-15 miles Short line 4-7 miles 15-30 miles 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-ground fault together with load encroachment algorithm improves the possibility to detect high resistive faults without conflict with the load impedance, see figure 188.
Page 396: Parallel Line Application With Mutual Coupling
Section 8 1MRK 506 369-UUS - Impedance protection detect high resistive faults at the same time as the security is improved (risk for unwanted trip due to load encroachment is eliminated), see figure 113. LdAngle LdAngle LdAngle LdAngle RLdRev RLdFwd en05000220_ansi.vsd ANSI05000220 V1 EN Figure 189:...
Page 397 Section 8 1MRK 506 369-UUS - 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 separated zero sequence network Parallel circuits with positive and zero sequence sources separated.
Page 398 Section 8 1MRK 506 369-UUS - Impedance protection Parallel line in service This type of application is very common and applies to all normal sub-transmission and transmission networks. Let us analyze what happens when a fault occurs on the parallel line see figure 114. From symmetrical components, we can derive the impedance Z at the relay point for normal lines without mutual coupling according to equation 112.
Page 399 Section 8 1MRK 506 369-UUS - Impedance protection IEC09000253_1_en.vsd IEC09000253 V1 EN Figure 191: Equivalent zero sequence impedance circuit of the double-circuit, parallel, operating line with a single phase-to-ground fault at the remote busbar When mutual coupling is introduced, the voltage at the relay point A will be changed according to equation 113.
Page 400 Section 8 1MRK 506 369-UUS - Impedance protection × × × (Equation 344) EQUATION1278 V4 EN One can also notice that the following relationship exists between the zero sequence currents: ⋅ ⋅ − (Equation 345) EQUATION1279 V3 EN Simplification of equation 116, solving it for 3I0 and substitution of the result into equation gives that the voltage can be drawn as:...
Page 401 Section 8 1MRK 506 369-UUS - Impedance protection OPEN OPEN CLOSED CLOSED en05000222_ansi.vsd ANSI05000222 V1 EN Figure 192: The parallel line is out of service and grounded When the parallel line is out of service and grounded at both line ends on the bus bar side of the line CTs so that zero sequence current can flow on the parallel line, the equivalent zero sequence circuit of the parallel lines will be according to figure 117.
Page 402 Section 8 1MRK 506 369-UUS - Impedance protection according to equation and equation for each particular line section and use them for calculating the reach for the underreaching zone.   ⋅       (Equation 349) DOCUMENT11520-IMG3502 V2 EN ...
Page 403 Section 8 1MRK 506 369-UUS - Impedance protection IEC09000255_1_en.vsd IEC09000255 V1 EN Figure 195: Equivalent zero-sequence impedance circuit for a double-circuit line with one circuit disconnected and not grounded The reduction of the reach is equal to equation 122. × ×...
Page 404: Tapped Line Application
Section 8 1MRK 506 369-UUS - Impedance protection Ensure that the underreaching zones from both line ends will overlap a sufficient amount (at least 10%) in the middle of the protected circuit. 8.13.2.7 Tapped line application ANSI05000224-2-en.vsd ANSI05000224 V2 EN Figure 196: Example of tapped line with Auto transformer This application gives rise to a similar problem that was highlighted in section...
Page 405 Section 8 1MRK 506 369-UUS - Impedance protection 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. V2/V1 Transformation ratio for transformation of impedance at V1 side of the transformer to the measuring side V2 (it is assumed that current and voltage distance function is taken...
Page 406: Series Compensation In Power Systems
Section 8 1MRK 506 369-UUS - Impedance protection × 28707 L Rarc (Equation 358) EQUATION1456 V1 EN Where: represents the length of the arc (in meters). This equation applies for the distance protection zone 1. Consider approximately three times arc foot spacing for zone 2 to get a reasonable margin against the influence of wind.
Page 407 Section 8 1MRK 506 369-UUS - Impedance protection capacitor increases and therefore the system voltage at the receiving line end can be regulated. Series compensation also extends the region of voltage stability by reducing the reactance of the line and consequently the SC is valuable for prevention of voltage collapse. Figure presents the voltage dependence at receiving bus B (as shown in figure 68) on line loading and compensation degree K , which is defined according to equation 48.
Page 408: Increase In Power Transfer
Section 8 1MRK 506 369-UUS - Impedance protection 8.13.3.2 Increase in power transfer 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 73. The power transfer on the transmission line is given by the equation 50: ×...
Page 409: Voltage And Current Inversion
Section 8 1MRK 506 369-UUS - Impedance protection 8.13.3.3 Voltage and current inversion Series capacitors influence the magnitude and the direction of fault currents in series compensated networks. They consequently influence phase angles of voltages measured in different points of series compensated networks and this performances of different protection functions, which have their operation based on properties of measured voltage and current phasors.
Page 410 Section 8 1MRK 506 369-UUS - Impedance protection With bypassed With inserted capacitor capacitor Source voltage Pre -fault voltage V’ Fault voltage Source en06000605_ansi.vsd ANSI06000605 V1 EN Figure 201: Voltage inversion on series compensated line With bypassed With inserted capacitor capacitor en06000606_ansi.vsd ANSI06000606 V1 EN...
Page 411 Section 8 1MRK 506 369-UUS - Impedance protection The IED point voltage inverses its direction due to presence of series capacitor and its dimension. It is a common practice to call this phenomenon voltage inversion. Its consequences on operation of different protections in series compensated networks depend on their operating principle.
Page 412 Section 8 1MRK 506 369-UUS - Impedance protection diagram in figure 84. The resultant reactance is in this case of inductive nature and the fault currents lags source voltage by 90 electrical degrees. The resultant reactance is of capacitive nature in the second case. Fault current will for this reason lead the source voltage by 90 electrical degrees, which means that reactive current will flow from series compensated line to the system.
Page 413 Section 8 1MRK 506 369-UUS - Impedance protection impedance (a number of power transformers connected in parallel) must be considered as practical possibility in many modern networks. Location of instrument transformers Location of instrument transformers relative to the line end series capacitors plays an important role regarding the dependability and security of a complete protection scheme.
Page 414 Section 8 1MRK 506 369-UUS - Impedance protection teleprotection schemes. Series capacitors located between the voltage instruments transformers and the buses reduce the apparent zero sequence source impedance and may cause voltage as well as current inversion in zero sequence equivalent networks for line faults.
Page 415 Section 8 1MRK 506 369-UUS - 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 Figure 207: Apparent impedances seen by distance IED for different SC locations and spark gaps used for overvoltage protection...
Page 416 Section 8 1MRK 506 369-UUS - Impedance protection compensation at 50% of line length and 33% compensation located on 33% and 66% of line length. The remote end compensation has the same effect. • The voltage inversion occurs in cases when the capacitor reactance between the IED point and fault appears bigger than the corresponding line reactance, Figure 89, 80% compensation at local end.
Page 417: Impact Of Series Compensation On Protective Ied Of Adjacent Lines
Section 8 1MRK 506 369-UUS - Impedance protection Figure presents three typical cases for series capacitor located at line end (case LOC=0% in figure 89). • Series capacitor prevails the scheme as long as the line current remains lower or equal to its protective current level (I £...
Page 418 Section 8 1MRK 506 369-UUS - Impedance protection é ù æ ö × × ê ç ÷ ú è ø ë û (Equation 368) EQUATION1999-ANSI V1 EN (Equation 369) EQUATION2000-ANSI V1 EN Equation indicates the fact that the infeed current I increases the apparent value of capacitive reactance in system: bigger the infeed of fault current, bigger the apparent series capacitor in a complete series compensated network.
Page 419: Distance Protection
Section 8 1MRK 506 369-UUS - Impedance protection 8.13.3.5 Distance protection Distance protection due to its basic characteristics, is the most used protection principle on series compensated and adjacent lines worldwide. It has at the same time caused a lot of challenges to protection society, especially when it comes to directional measurement and transient overreach.
Page 420 Section 8 1MRK 506 369-UUS - Impedance protection Zone 2 Zone 1 Zone 1 Zone 2 en06000618.vsd IEC06000618 V1 EN Figure 211: Underreaching (Zone 1) and overreaching (Zone 2) on series compensated line The underreaching zone will have reduced reach in cases of bypassed series capacitor, as shown in the dashed line in figure 93.
Page 421 Section 8 1MRK 506 369-UUS - Impedance protection For that reason permissive underreaching schemes can hardly be used as a main protection. Permissive overreaching distance protection or some kind of directional or unit protection must be used. The overreach must be of an order so it overreaches when the capacitor is bypassed or out of service.
Page 422 Section 8 1MRK 506 369-UUS - Impedance protection ⋅ − (Equation 373) EQUATION1916 V2 EN ⋅ − (Equation 374) EQUATION1917 V2 EN ⋅ − (Equation 375) EQUATION1918 V2 EN en06000621_ansi.vsd ANSI06000621 V1 EN Figure 214: Distance IED on adjacent power lines are influenced by the negative impedance Normally the first zone of this protection must be delayed until the gap flashing has taken place.
Page 423 Section 8 1MRK 506 369-UUS - 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 424 Section 8 1MRK 506 369-UUS - Impedance protection the source impedance and calculations must be made on a case by case basis, as shown in figure 97. Distance IEDs with separate impedance and directional measurement offer additional setting and operational flexibility when it comes to measurement of negative apparent impedance (as shown in figure 98).
Page 425 Section 8 1MRK 506 369-UUS - Impedance protection m0AC m0CB en06000627.vsd IEC06000627 V1 EN Figure 217: Double circuit, parallel operating line Zero sequence mutual impedance Z cannot significantly influence the operation of distance protection as long as both circuits are operating in parallel and all precautions related to settings of distance protection on series compensated line have been considered.
Page 426: Setting Guidelines
Section 8 1MRK 506 369-UUS - Impedance protection CSAB CRBB CSAB CRBB en06000629_ansi.vsd ANSI06000629 V1 EN Figure 219: Current reversal phenomenon on parallel operating circuits It is possible to expect faster IED operation and breaker opening at the bus closer to fault, which will reverse the current direction on the healthy circuit.
Page 427: Setting Of Zone 1
Section 8 1MRK 506 369-UUS - Impedance protection input card is used to automatically convert the measured secondary input signals to primary values used in ZMFCPDIS. The following basics must be considered, depending on application, when doing the setting calculations: •...
Page 428: Setting Of Reverse Zone
Section 8 1MRK 506 369-UUS - 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 429: Series Compensated And Adjacent Lines
Section 8 1MRK 506 369-UUS - Impedance protection covers the overreaching zone, used at the remote line IED for the telecommunication purposes. Consider the possible enlarging factor that might exist due to fault infeed from adjacent lines. The equation can be used to calculate the reach in reverse direction when the zone is used for blocking scheme, weak-end infeed, and so on.
Page 430 Section 8 1MRK 506 369-UUS - Impedance protection 100 % 99000202.vsd IEC99000202 V1 EN Figure 221: Reduced reach due to the expected sub-harmonic oscillations at different degrees of compensation æ ö c degree of compensation ç ÷ ç ÷ è ø...
Page 431 Section 8 1MRK 506 369-UUS - Impedance protection Reactive Reach line LLOC en06000584-2.vsd IEC06000584 V2 EN Figure 222: 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 (XLine-X ) ·...
Page 432 Section 8 1MRK 506 369-UUS - Impedance protection For protection on non compensated lines facing series capacitor on next line. The setting is thus: • X1Fw is set to (XLine-XC · K) · p/100. • X1Rvcan be set to the same value as X1Fw •...
Page 433: Setting Of Zones For Parallel Line Application
Section 8 1MRK 506 369-UUS - Impedance protection The increased reach related to the one used in non compensated system is recommended for all protections in the vicinity of series capacitors to compensate for delay in the operation caused by the sub harmonic swinging. Settings of the resistive reaches are limited according to the minimum load impedance.
Page 434 Section 8 1MRK 506 369-UUS - Impedance protection (Equation 384) EQUATION554 V1 EN Check the reduction of a reach for the overreaching zones due to the effect of the zero sequence mutual coupling. The reach is reduced for a factor: ×...
Page 435: Setting Of Reach In Resistive Direction
Section 8 1MRK 506 369-UUS - Impedance protection 8.13.4.7 Setting of reach in resistive direction Set the resistive reach R1 independently for each zone. Set separately the expected fault resistance for phase-to-phase faults RFPP and for the phase-to-ground faults RFPG for each zone. For each distance zone, set all remaining reach setting parameters independently of each other.
Page 436: Load Impedance Limitation, Without Load Encroachment Function430
Section 8 1MRK 506 369-UUS - Impedance protection 8.13.4.8 Load impedance limitation, without load encroachment function The following instructions are valid when setting the resistive reach of the distance zone itself with a sufficient margin towards the maximum load, that is, without the common load encroachment characteristic (set by RLdFwd, RldRev and ArgLd).
Page 437: Zone Reach Setting Higher Than Minimum Load Impedance
Section 8 1MRK 506 369-UUS - Impedance protection é × ù £ × × ¶ - × ¶ RFPG ê ú ë û load × (Equation 397) GUID-11DD90FA-8FB5-425F-A46F-6553C00025BE V1 EN Where: ϑ 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 438: Parameter Setting Guidelines
Section 8 1MRK 506 369-UUS - Impedance protection phase-to-ground fault, it corresponds to the per-loop impedance, including the ground return impedance. RLdFwd RLdFwd LdAngle LdAngle LdAngle LdAngle LdAngle Possible LdAngle LdAngle LdAngle load RLdRev RLdRev ANSI12000176-1-en.vsd ANSI12000176 V1 EN Figure 223: Load impedance limitation with load encroachment During the initial current change for phase-to-phase and for phase-to-ground faults, operation may be allowed also when the apparent impedance of the load encroachment...
Page 439 Section 8 1MRK 506 369-UUS - Impedance protection Both current limits IMinOpPGZx and IMinOpPPZx are automatically reduced to 75% of regular set values if the zone is set to operate in reverse direction, that is, OperationDir=Reverse. OpModePPZx and OpModePEZx These settings, two per zone (x=1,2..5&RV), with options {Off, Quadrilateral, Mho, Offset}, are used to set the operation and characteristic for phase-to-earth and phase-to- phase faults, respectively.
Page 440 Section 8 1MRK 506 369-UUS - Impedance protection Choose the setting value SeriesComp if the protected line or adjacent lines are compensated with series capacitors. Otherwise maintain the NoSeriesComp setting value. CVTtype If possible, the type of capacitive voltage transformer (CVT) that is used for measurement should be identified.
Page 441: Power Swing Detection Zmrpsb (68)
Section 8 1MRK 506 369-UUS - Impedance protection 8.14 Power swing detection ZMRPSB (68) 8.14.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Power swing detection ZMRPSB Zpsb SYMBOL-EE V1 EN 8.14.2 Application 8.14.2.1 General Various changes in power system may cause oscillations of rotating units.
Page 442: Basic Characteristics
Section 8 1MRK 506 369-UUS - Impedance protection Operating characteristic Impedance locus at power swing IEC09000224_1_en.vsd IEC09000224 V1 EN Figure 225: Impedance plane with Power swing detection operating characteristic and impedance locus at power swing 8.14.2.2 Basic characteristics Power swing detection function (ZMRPSB, 78) detects reliably power swings with periodic time of swinging as low as 200 ms (which means slip frequency as high as 10% of the rated frequency on the 50 Hz basis).
Page 443 Section 8 1MRK 506 369-UUS - Impedance protection = const = f(t) 99001019_ansi.vsd ANSI99001019 V1 EN Figure 226: Protected power line as part of a two-machine system 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.
Page 444 Section 8 1MRK 506 369-UUS - Impedance protection Line positive sequence impedance 10.71 75.6 EQUATION1328 V1 EN Positive sequence source impedance behind A bus 1.15 43.5 EQUATION1329 V1 EN Positive sequence source impedance behind B bus 35.7 EQUATION1330 V1 EN Maximum expected load in direction from A to B (with minimum 1000 system operating voltage V...
Page 445 Section 8 1MRK 506 369-UUS - Impedance protection The minimum load resistance R at maximum load and minimum system voltage is Lmin equal to equation 403. × × 144.4 0.95 137.2 (Equation 403) EQUATION1338 V1 EN The system impedance Z is determined as a sum of all impedance in an equivalent two- machine system, see figure 226.
Page 446 Section 8 1MRK 506 369-UUS - Impedance protection ANSI05000283 V1 EN Figure 227: Impedance diagrams with corresponding impedances under consideration The outer boundary of oscillation detection characteristic in forward direction RLdOutFw should be set with certain safety margin K compared to the minimum expected load resistance R .
Page 447 Section 8 1MRK 506 369-UUS - Impedance protection • = 0.9 for lines longer than 100 miles • = 0.85 for lines between 50 and 100 miles • = 0.8 for lines shorter than 50 miles Multiply the required resistance for the same safety factor K with the ratio between actual voltage and 400kV when the rated voltage of the line under consideration is higher than 400kV.
Page 448 Section 8 1MRK 506 369-UUS - Impedance protection The general tendency should be to set the tP1 time to at least 30 ms, if possible. Since it is not possible to further increase the external load angle δ , it is necessary to reduce the inner boundary of the oscillation detection characteristic.
Page 449 Section 8 1MRK 506 369-UUS - Impedance protection Do not forget to adjust the setting of load encroachment resistance RLdFwd in Phase selection with load encroachment (FDPSPDIS, 21 or FRPSPDIS, 21) to the value equal to or less than the calculated value RLdInFw.
Page 450: Power Swing Logic Pslpsch
Section 8 1MRK 506 369-UUS - Impedance protection to continuous swinging. Consider the minimum possible speed of power swinging in a particular system. The tR1 inhibit timer delays the influence of the detected residual current on the inhibit criteria for ZMRPSB(68). It prevents operation of the function for short transients in the residual current measured by the IED.
Page 451 Section 8 1MRK 506 369-UUS - Impedance protection distance protection. The second fault can, but does not need to, occur within this time interval. • Fault on an adjacent line (behind the B substation, see figure 228) causes the measured impedance to enter the operate area of ZMRPSB (68) function and, for example, the zone 2 operating characteristic (see figure 229).
Page 452: Setting Guidelines
Section 8 1MRK 506 369-UUS - 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 Figure 229: Impedance trajectory within the distance protection zones 1 and 2 during and after the fault on line B –...
Page 453 Section 8 1MRK 506 369-UUS - Impedance protection • They must generally be blocked during normal operation and released during power swings. • Their operation must be time delayed but shorter (with sufficient margin) than the set time delay of normal distance protection zone 2, which is generally blocked by the power swing.
Page 454 Section 8 1MRK 506 369-UUS - Impedance protection PUDOG AR1P1 PUPSD 0-tCS BLOCK CSUR BLKZMUR 0-tBlkTr 0-tTrip PLTR_CRD TRIP en06000236_ansi.en ANSI06000236 V1 EN Figure 230: Simplified logic diagram - power swing communication and tripping logic Configuration Configure the BLOCK input to any combination of conditions, which are supposed to block the operation of logic.
Page 455 Section 8 1MRK 506 369-UUS - Impedance protection 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. The CS functional output signal should be configured to either output relay or to corresponding input of the “Binary signal transfer to remote end”...
Page 456 Section 8 1MRK 506 369-UUS - Impedance protection × × RFPP v tnPP (Equation 422) EQUATION1538 V1 EN × V tnPG × RFPG (Equation 423) EQUATION1993-ANSI V1 EN Here is factor 0.8 considered for safety reasons and: RFPG phase-to-ground resistive reach setting for a power swing distance protection zone n in Ω...
Page 457: Blocking And Tripping Logic For Evolving Power Swings
Section 8 1MRK 506 369-UUS - Impedance protection protection to eliminate the initial fault and still make possible for the power swing zones to operate for possible consecutive faults. A time delay between 150 and 300 ms is generally sufficient. 8.15.3.2 Blocking and tripping logic for evolving power swings The second part of a complete Power swing logic (PSLPSCH) functionality is a blocking...
Page 458: Pole Slip Protection Pspppam (78)
Section 8 1MRK 506 369-UUS - Impedance protection Configure the functional input PUZMUR to the pickup output of the instantaneous underreaching distance protection zone (usually PICKUP of distance protection zone 1). The function will determine whether the pickup signal of this zone is permitted to be used in further logic or not, dependent on time difference on appearance of overreaching distance protection zone (usually zone 2).
Page 459: Application
Section 8 1MRK 506 369-UUS - Impedance protection 8.16.2 Application 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. If the phase angle between the generators gets too large the stable operation of the system cannot be maintained.
Page 460 Section 8 1MRK 506 369-UUS - Impedance protection The relative angle of the generator is shown for different fault duration at a three-phase short circuit close to the generator. As the fault duration increases the angle swing amplitude increases. When the critical fault clearance time is reached the stability cannot be maintained.
Page 461: Setting Guidelines
Section 8 1MRK 506 369-UUS - Impedance protection 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. If the excitation of the generator gets too low there is a risk that the generator cannot maintain synchronous operation.
Page 462 Section 8 1MRK 506 369-UUS - Impedance protection Zone 1 Zone 2 X’ Pole slip impedance movement Zone 2 TripAngle Zone 1 WarnAngle IEC06000548_2_en.vsd IEC06000548 V2 EN Figure 234: Settings for the Pole slip detection function The ImpedanceZA is the forward impedance as show in figure 234. ZA should be the sum of the transformer impedance XT and the equivalent impedance of the external system ZS.
Page 463: Setting Example For Line Application
Section 8 1MRK 506 369-UUS - Impedance protection The ImpedanceZB is the reverse impedance as show in figure 234. ZB should be equal to the generator transient reactance X'd. The impedance is given in % of the base impedance, see equation 425. The ImpedanceZC is the forward impedance giving the borderline between zone 1 and zone 2.
Page 464 Section 8 1MRK 506 369-UUS - Impedance protection ZA = forward source impedance Line impedance = ZC IEC07000014_2_en.vsd IEC07000014 V2 EN Figure 235: Line application of pole slip protection If the apparent impedance crosses the impedance line ZB – ZA this is the detection criterion of out of step conditions, see figure 236.
Page 465 Section 8 1MRK 506 369-UUS - Impedance protection Apparent anglePhi impedance at normal load IEC07000015_2_en.vsd IEC07000015 V2 EN Figure 236: 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 466 Section 8 1MRK 506 369-UUS - Impedance protection With all phase voltages and phase currents available and fed to the protection IED, it is recommended to set the MeasureMode to positive sequence. The impedance settings are set in pu with ZBase as reference: UBase ZBase SBase...
Page 467 Section 8 1MRK 506 369-UUS - Impedance protection The warning angle (StartAngle) should be chosen not to cross into normal operating area. The maximum line power is assumed to be 2000 MVA. This corresponds to apparent impedance: 2000 (Equation 432) EQUATION1967 V1 EN Simplified, the example can be shown as a triangle, see figure 237.
Page 468: Setting Example For Generator Application
Section 8 1MRK 506 369-UUS - Impedance protection Set StartAngle to 110° For the TripAngle it is recommended to set this parameter to 90° to assure limited stress for the circuit breaker. In a power system it is desirable to split the system into predefined parts in case of pole slip.
Page 469 Section 8 1MRK 506 369-UUS - Impedance protection Apparent anglePhi impedance at normal load IEC07000015_2_en.vsd IEC07000015 V2 EN Figure 239: Impedances to be set for pole slip protection PSPPPAM (78) The setting parameters of the protection are: Block transformer + source impedance in the forward direction The generator transient reactance The block transformer reactance AnglePhi...
Page 470 Section 8 1MRK 506 369-UUS - Impedance protection Use the following block transformer data: VBase : 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 471 Section 8 1MRK 506 369-UUS - Impedance protection × 0.15 (Equation 439) EQUATION1974 V1 EN This corresponds to: Ð 0.15 0.15 90 (Equation 440) EQUATION1975 V2 EN Set ZC to 0.15 and AnglePhi to 90°. The warning angle (StartAngle) should be chosen not to cross into normal operating area. The maximum line power is assumed to be 200 MVA.
Page 472 Section 8 1MRK 506 369-UUS - Impedance protection Zload en07000016.vsd IEC07000016 V1 EN Figure 240: Simplified figure to derive StartAngle 0.25 0.19 ³ » angleStart arctan arctan arctan + arctan = 7.1 + 5.4 Zload Zload (Equation 442) EQUATION1977 V2 EN In case of minor damped oscillations at normal operation we do not want the protection to start.
Page 473: Out-Of-Step Protection Oosppam (78)
Section 8 1MRK 506 369-UUS - Impedance protection 8.17 Out-of-step protection OOSPPAM (78) 8.17.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Out-of-step protection OOSPPAM < 8.17.2 Application Under balanced and stable conditions, a generator operates with a constant rotor (power) angle, delivering an active electrical power to the power system, which is equal to the mechanical input power on the generator axis, minus the small losses in the generator.
Page 474 Section 8 1MRK 506 369-UUS - Impedance protection Synchronous Synchronous Synchronous Synchronous machine 1 machine 1 machine 2 machine 2 Voltages of all phases V, I to ground are zero in the center of oscillation Center of oscillation ANSI10000107_3_en.vsd ANSI10000107 V3 EN Figure 241: The center of electromechanical oscillation The center of the electromechanical oscillation can be in the generator unit (or generator-...
Page 475 Section 8 1MRK 506 369-UUS - Impedance protection The out-of-step condition of a generator can be caused by different reasons. Sudden events in an electrical power system such as large changes in load, fault occurrence or slow fault clearance, can cause power oscillations, that are called power swings. In a non- recoverable situation, the power swings become so severe that the synchronism is lost: this condition is called pole slipping.
Page 476: Setting Guidelines
Section 8 1MRK 506 369-UUS - Impedance protection • Stator windings are under high stress due to electrodynamic forces. • The current levels during an out-of-step condition can be higher than those during a three-phase fault and, therefore, there is significant torque impact on the generator- turbine shaft.
Page 477 Section 8 1MRK 506 369-UUS - Impedance protection Rt = 0.0054 pu (transf. ZBase) 1-st step in ZBase = 0.9522 Ω (generator) ZBase (13.8 kV) = 0.6348 Ω calculation Xd' = 0.2960 · 0.952 = 0.282 Ω Xt = 0.100 · 0.6348 = 0.064 Ω Xline = 300 ·...
Page 478 Section 8 1MRK 506 369-UUS - Impedance protection • For the synchronous machines as the generator in Table 32, 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 479 InvertCTCurr: If the currents fed to the Out-of-step protection are measured on the protected generator neutral side (LV-side) then inversion is not necessary (InvertCTCurr = Disabled), provided that the CT’s orientation complies with ABB recommendations, as shown in Table 32. If the currents fed to the Out-of-step protection are measured on the protected generator output terminals side (HV-side), Line distance protection REL670 2.2 ANSI...
Page 480: Automatic Switch Onto Fault Logic Zcvpsof
Section 8 1MRK 506 369-UUS - Impedance protection then invertion is necessary (InvertCTCurr = Enabled), provided that the CT’s actual direction complies with ABB recommendations, as shown in Table 32. 8.18 Automatic switch onto fault logic ZCVPSOF 8.18.1 Identification Function description...
Page 481: Setting Guidelines
Section 8 1MRK 506 369-UUS - Impedance protection 8.18.3 Setting guidelines The parameters for automatic switch onto fault logic, voltage- and current-based function ZCVPSOF are set via the local HMI or Protection and Control Manager PCM600. The distance protection zone used for instantaneous trip by ZCVPSOF has to be set to cover the entire protected line with a safety margin of minimum 20%.
Page 482: Phase Preference Logic Pplphiz
Section 8 1MRK 506 369-UUS - Impedance protection tDLD: The time delay for activating ZCVPSOF by the internal dead-line detection is, by default, set to 0.2 seconds. It is suitable in most applications. The delay shall not be set too short to avoid unwanted activations during transients in the system.
Page 483 Section 8 1MRK 506 369-UUS - Impedance protection transmission) to achieve the correct phase selective tripping during two simultaneous single-phase ground-faults in different phases on different line sections. Due to the resonance/high resistive grounding principle, the ground faults in the system gives very low fault currents, typically below 25 A.
Page 484 Section 8 1MRK 506 369-UUS - Impedance protection en06000551_ansi.vsd ANSI06000551 V1 EN Figure 244: The voltage increase on healthy phases and occurring neutral point voltage (3V0) at a single phase-to-ground fault and an occurring cross- country fault on different feeders in a sub-transmission network, high impedance (resistance, reactance) grounded PPLPHIZ is connected between Distance protection zone, quadrilateral characteristic function ZMQPDIS (21) and ZMQAPDIS (21) and Phase selection with load...
Page 485 Section 8 1MRK 506 369-UUS - Impedance protection ZMQAPDIS (21) FDPSPDIS (21) I3P* TRIP W2_CT_B_I3P I3P* TRIP TR_A W2_VT_B_v3P V3P* V3P* FALSE BLOCK TR_B BLOCK FWD_A PHS_L1 LOVBZ TR_C W2_FSD1-BLKZ DIRCND FWD_B PHS_L2 PICKUP FALSE BLKTR FWD_C PHS_L3 PHSEL PU_A FWD_G DIRCND PU_B...
Page 486: Setting Guidelines
Section 8 1MRK 506 369-UUS - Impedance protection IC=IG IA=IG en06000553_ansi.vsd ANSI06000553 V1 EN Figure 246: The currents in the phases at a double ground fault The function has a block input (BLOCK) to block start from the function if required in certain conditions.
Page 487: Phase Preference Logic Ppl2Phiz
Section 8 1MRK 506 369-UUS - Impedance protection impedance grounded system, the voltage drop is big and the setting can typically be set to 70% of base voltage (VBase) PU27PP: The setting of the phase-to-phase voltage level (line voltage) which is used by the evaluation logic to verify that a fault exists in two or more phases.
Page 488 Section 8 1MRK 506 369-UUS - Impedance protection (Petersen coil) or high resistive grounded systems where phase preference based tripping is required for so-called cross-country faults, two simultaneous single phase-to-ground- faults in different phases and on different line sections. Due to the resonance/high resistive grounding, single phase-to-ground faults give relatively low fault currents.
Page 489 Section 8 1MRK 506 369-UUS - Impedance protection en06000551_ansi.vsd ANSI06000551 V1 EN Figure 248: Voltage distribution before and during a single phase-to-ground fault During a cross-country fault, the fault current path for the fault that is not on the protected feeder will not go through the relay.
Page 490 Section 8 1MRK 506 369-UUS - Impedance protection IC=IG IA=IG en06000553_ansi.vsd ANSI06000553 V1 EN Figure 249: The currents in the phases at a double ground fault However, it should be considered that a quite substantial residual current can also appear temporarily at the onset of a single phase fault.
Page 491: Setting Guidelines
Section 8 1MRK 506 369-UUS - Impedance protection The phase-to-phase measuring loops have actually nothing to do with phase preference and are always enabled. The ZREL output of the PPL2PHIZ function should be connected to the RELCNDZx inputs of the High speed distance protection ZMFPDIS. Figure shows how the information from PPL2PHIZ is affecting the interior of the distance protection.
Page 492 Section 8 1MRK 506 369-UUS - Impedance protection impedance grounded system, the voltage drop is big and the setting can typically be set to 70%, which is 70% of UBase divided by √3. PU27PP: The setting of the phase-to-phase voltage level (line voltage) which is used by the evaluation logic to verify that a fault exists in two or more phases.
Page 493: Instantaneous Phase Overcurrent Protection Phpioc (50)
Section 9 1MRK 506 369-UUS - Current protection Section 9 Current protection Instantaneous phase overcurrent protection PHPIOC (50) 9.1.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Instantaneous phase overcurrent PHPIOC protection 3I>> SYMBOL-Z V1 EN 9.1.2 Application Long transmission lines often transfer great quantities of electric power from generation...
Page 494: Setting Guidelines
Section 9 1MRK 506 369-UUS - Current protection operate very quickly for faults very close to the generation (and relay) point, for which very high fault currents are characteristic. The instantaneous phase overcurrent protection PHPIOC (50) can operate in 10 ms for faults characterized by very high currents.
Page 495: Meshed Network Without Parallel Line
Section 9 1MRK 506 369-UUS - Current protection 9.1.3.1 Meshed network without parallel line The following fault calculations have to be done for three-phase, single-phase-to-ground and two-phase-to-ground faults. With reference to Figure 251, apply a fault in B and then calculate the current through-fault phase current I .
Page 496 Section 9 1MRK 506 369-UUS - Current protection ³ Imin MAX I (Equation 443) EQUATION78 V1 EN A safety margin of 5% for the maximum protection static inaccuracy and a safety margin of 5% for the maximum possible transient overreach have to be introduced. An additional 20% is suggested due to the inaccuracy of the instrument transformers under transient conditions and inaccuracy in the system data.
Page 497: Meshed Network With Parallel Line
Section 9 1MRK 506 369-UUS - Current protection 9.1.3.2 Meshed network with parallel line 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 254, where the two lines are connected to the same busbars.
Page 498: Directional Phase Overcurrent Protection, Four Steps Oc4Ptoc(51_67)
Section 9 1MRK 506 369-UUS - Current protection The protection function can be used for the specific application only if this setting value is equal or less than the maximum phase fault current that the IED has to clear. The IED setting value Pickup is given in percentage of the primary base current value, IBase.
Page 499 Section 9 1MRK 506 369-UUS - Current protection Non-directional / Directional function: In most 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 500: Setting Guidelines
Section 9 1MRK 506 369-UUS - Current protection 9.2.3 Setting guidelines When inverse time overcurrent characteristic is selected, the trip time of the stage will be the sum of the inverse time delay and the set definite time delay. Thus, if only the inverse time delay is required, it is important to set the definite time delay for that stage to zero.
Page 501: Settings For Each Step
Section 9 1MRK 506 369-UUS - Current protection ANSI09000636-1-en.vsd ANSI09000636 V1 EN Figure 255: Directional function characteristic 1. RCA = Relay characteristic angle 2. ROA = Relay operating angle 3. Reverse 4. Forward 9.2.3.1 Settings for each step x means step 1, 2, 3 and 4. DirModeSelx: The directional mode of step x.
Page 502 Section 9 1MRK 506 369-UUS - Current protection Characteristx: Selection of time characteristic for step x. Definite time delay and different types of inverse time characteristics are available according to Table 33. Table 33: Inverse time characteristics Curve name ANSI Extremely Inverse ANSI Very Inverse ANSI Normal Inverse ANSI Moderately Inverse...
Page 503 Section 9 1MRK 506 369-UUS - Current protection IMinx: Minimum pickup current for step x in % of IBase. Set IMinx below Pickupx for every step to achieve ANSI reset characteristic according to standard. If IMinx is set above Pickupx for any step the ANSI reset works as if current is zero when current drops below IMinx.
Page 504 Section 9 1MRK 506 369-UUS - Current protection Table 34: Reset possibilities Curve name Curve index no. Instantaneous IEC Reset (constant time) ANSI Reset (inverse time) The delay characteristics are described in Technical manual. There are some restrictions regarding the choice of the reset delay. For the definite time delay characteristics, the possible delay time setting instantaneous (1) and IEC (2 = set constant time reset).
Page 505: Setting Example
Section 9 1MRK 506 369-UUS - Current protection 9.2.3.2 Setting example Directional phase overcurrent protection, four steps can be used in different ways, depending on the application where the protection is used. A general description is given below. The pickup current setting of the inverse time protection, or the lowest current step of the definite time protection, must be defined so that the highest possible load current does not cause protection operation.
Page 506 Section 9 1MRK 506 369-UUS - Current protection Im ax ³ × Ipu 1.2 (Equation 450) EQUATION1262 V2 EN where: is a safety factor is the reset ratio of the protection Imax is the maximum load current The load current up to the present situation can be found from operation statistics. The current setting must remain valid for several years.
Page 507 Section 9 1MRK 506 369-UUS - Current protection fault current calculation gives the largest current of faults, Iscmax, at the most remote part of the primary protected zone. The risk of transient overreach must be considered, due to a possible DC component of the short circuit current. The lowest current setting of the fastest stage can be written according to ³...
Page 508 Section 9 1MRK 506 369-UUS - Current protection Time-current curves tfunc1 tfunc2 n 0.01 10000 Fault Current en05000204.ai IEC05000204 V2 EN Figure 258: Fault time with maintained selectivity The operation time can be set individually for each overcurrent protection. To assure selectivity between different protection functions in the radial network, there has to be a minimum time difference Dt between the time delays of two protections.
Page 509 Section 9 1MRK 506 369-UUS - Current protection Example for time coordination Assume two substations A and B directly connected to each other via one line, as shown in the Figure 259. Consider a fault located at another line from the station B. The fault current to the overcurrent protection of IED B1 has a magnitude so that the overcurrent protection will start and subsequently trip, and the overcurrent protection of IED A1 must have a delayed operation in order to avoid maloperation.
Page 510: Instantaneous Residual Overcurrent Protection Efpioc (50N)
Section 9 1MRK 506 369-UUS - Current protection D ³ (Equation 454) EQUATION1266 V1 EN where it is considered that: the operate time of overcurrent protection B1 is 40 ms the breaker open time is 100 ms the resetting time of protection A1 is 40 ms and the additional margin is 40 ms...
Page 511 Section 9 1MRK 506 369-UUS - Current protection Common base IED values for primary current (IBase), primary voltage (VBase) and primary power (SBase) are set in the global base values for settings function GBASVAL. GlobalBaseSel: This is used to select GBASVAL function for reference of base values. The basic requirement is to assure selectivity, that is EFPIOC (50N) shall not be allowed to operate for faults at other objects than the protected object (line).
Page 512 Section 9 1MRK 506 369-UUS - Current protection The function shall not operate for any of the calculated currents to the protection. The minimum theoretical current setting (Imin) will be:    in MAX I (Equation 455) EQUATION284 V2 EN A safety margin of 5% for the maximum static inaccuracy and a safety margin of 5% for maximum possible transient overreach have to be introduced.
Page 513: Identification
Section 9 1MRK 506 369-UUS - Current protection Considering the safety margins mentioned previously, the minimum setting (Is) is: = 1.3 × I (Equation 458) EQUATION288 V3 EN The IED setting value IN>> is given in percent of the primary base current value, IBase. The value for IN>>...
Page 514: Application
Section 9 1MRK 506 369-UUS - Current protection 9.4.2 Application The directional residual overcurrent protection, four steps EF4PTOC (51N_67N) is used in several applications in the power system. Some applications are: • Ground-fault protection of feeders in effectively grounded distribution and subtransmission systems.
Page 515 Section 9 1MRK 506 369-UUS - Current protection Table 35: Time characteristics Curve name ANSI Extremely Inverse ANSI Very Inverse ANSI Normal Inverse ANSI Moderately Inverse ANSI/IEEE Definite time ANSI Long Time Extremely Inverse ANSI Long Time Very Inverse ANSI Long Time Inverse IEC Normal Inverse IEC Very Inverse IEC Inverse...
Page 516: Setting Guidelines
Section 9 1MRK 506 369-UUS - Current protection 9.4.3 Setting guidelines When inverse time overcurrent characteristic is selected, the trip time of the stage will be the sum of the inverse time delay and the set definite time delay. Thus, if only the inverse time delay is required, it is important to set the definite time delay for that stage to zero.
Page 517 Section 9 1MRK 506 369-UUS - Current protection V pol = 3V or V Operation IDirPU en 05000135-4- ansi. vsd ANSI05000135 V3 EN Figure 263: Relay characteristic angle given in degree In a normal transmission network a normal value of RCA is about 65°. The setting range is -180°...
Page 518: Nd Harmonic Restrain
Section 9 1MRK 506 369-UUS - Current protection protection. The maximum ground-fault current at the local source can be used to calculate the value of ZN as V/(√3 · 3I ) Typically, the minimum ZNPol (3 · zero sequence source) is set.
Page 519: Switch Onto Fault Logic
Section 9 1MRK 506 369-UUS - Current protection 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. Therefore, we will have high 2 harmonic current initially.
Page 520: Settings For Each Step (X = 1, 2, 3 And 4)
Section 9 1MRK 506 369-UUS - Current protection The function is divided into two parts. The SOTF function will give operation from step 2 or 3 during a set time after change in the position of the circuit breaker. The SOTF function has a set time delay.
Page 521 Section 9 1MRK 506 369-UUS - Current protection To assure selectivity between different protections, in the radial network, there has to be a minimum time difference Dt between the time delays of two protections. To determine the shortest possible time difference, the operation time of protections, breaker opening time and protection resetting time must be known.
Page 522 Section 9 1MRK 506 369-UUS - Current protection Trip time txMin Pickup current ANSI10000058-1-en.vsdx ANSI10000058 V1 EN Figure 265: Minimum pickup current and trip time for inverse time characteristics In order to fully comply with the curves definition, the setting parameter txMin shall be set to the value which is equal to the operate time of the selected IEC inverse curve for measured current of twenty times the set current pickup value.
Page 523: Line Application Example
Section 9 1MRK 506 369-UUS - Current protection Further description can be found in the technical reference manual. tPRCrvx, tTRCrvx, tCRCrvx: Parameters for user programmable of inverse reset time characteristic curve. Further description can be found in the technical reference manual. 9.4.3.6 Line application example Four step residual overcurrent protection can be used in different ways.
Page 524 Section 9 1MRK 506 369-UUS - Current protection One- or two-phase ground-fault ANSI05000150_2_en.vsd ANSI05000150 V2 EN Figure 267: Step 1, first calculation The residual current out on the line is calculated at a fault on the remote busbar (one- or two-phase-to-ground fault).
Page 525 Section 9 1MRK 506 369-UUS - Current protection The requirement is now according to Equation 462. ³ × 1.2 3I (remote busbar with one line out) step1 (Equation 462) EQUATION1200 V3 EN A higher value of step 1 might be necessary if a big power transformer (Y0/D) at remote bus bar is disconnected.
Page 526 Section 9 1MRK 506 369-UUS - Current protection 50/51N One- or two-phase ground-fault ANSI05000154_2_en.vsd ANSI05000154 V2 EN Figure 270: Step 2, check of reach calculation The residual current, out on the line, is calculated at an operational case with minimal ground-fault current.
Page 527 Section 9 1MRK 506 369-UUS - Current protection Step 3 This step has directional function and a time delay slightly larger than step 2, often 0.8 s. Step 3 shall enable selective trip of ground faults having higher fault resistance to ground, compared to step 2.
Page 528: Four Step Directional Negative Phase Sequence Overcurrent Protection Ns4Ptoc (46I2)
Section 9 1MRK 506 369-UUS - Current protection Four step directional negative phase sequence overcurrent protection NS4PTOC (46I2) 9.5.1 Identification Function description IEC 61850 IEC 60617 identification ANSI/IEEE C37.2 identification device number Four step negative sequence NS4PTOC 46I2 overcurrent protection IEC10000053 V1 EN 9.5.2 Application...
Page 529 Section 9 1MRK 506 369-UUS - Current protection communication schemes, which enables fast clearance of unsymmetrical faults on transmission lines. The directional function uses the voltage polarizing quantity. Choice of time characteristics: There are several types of time characteristics available such as definite time delay and different types of inverse time characteristics.
Page 530: Setting Guidelines
Section 9 1MRK 506 369-UUS - Current protection MultPUx to the negative sequence current pick-up level. This multiplication factor is activated from a binary input signal MULTPUx to the function. 9.5.3 Setting guidelines The parameters for Four step negative sequence overcurrent protection NS4PTOC (46I2) are set via the local HMI or Protection and Control Manager (PCM600).
Page 531 Section 9 1MRK 506 369-UUS - Current protection Curve name 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 User Programmable ASEA RI RXIDG (logarithmic)
Page 532 Section 9 1MRK 506 369-UUS - Current protection Operate time txMin IMinx Current IEC10000058 IEC10000058 V2 EN Figure 273: Minimum operate current and operation time for inverse time characteristics ResetTypeCrvx: The reset of the delay timer can be made in different ways. By choosing setting there are the following possibilities: Curve name Instantaneous...
Page 533: Common Settings For All Steps
Section 9 1MRK 506 369-UUS - Current protection tPCrvx, tACrvx, tBCrvx, tCCrvx: Parameters for programmable inverse time characteristic curve. The time characteristic equation is according to equation 460: æ ö ç ÷ ç ÷ × ç ÷ æ ö ç ÷...
Page 534: Sensitive Directional Residual Overcurrent And Power Protection Sdepsde (67N)
Section 9 1MRK 506 369-UUS - Current protection Reverse Area AngleRCA Vpol=-V2 Forward Area Iop = I2 ANSI10000031-1-en.vsd ANSI10000031 V1 EN Figure 274: Relay characteristic angle given in degree In a transmission network a normal value of RCA is about 80°. VPolMin: Minimum polarization (reference) voltage % of VBase.
Page 535: Identification
Section 9 1MRK 506 369-UUS - Current protection 9.6.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Sensitive directional residual over SDEPSDE current and power protection 9.6.2 Application In networks with high impedance grounding, the phase-to-ground fault current is significantly smaller than the short circuit currents.
Page 536 Section 9 1MRK 506 369-UUS - Current protection When should the sensitive directional residual overcurrent protection be used and when should the sensitive directional residual power protection be used? Consider the following: • Sensitive directional residual overcurrent protection gives possibility for better sensitivity.
Page 537: Setting Guidelines
Section 9 1MRK 506 369-UUS - Current protection 9.6.3 Setting guidelines The sensitive ground-fault protection is intended to be used in high impedance grounded systems, or in systems with resistive grounding where the neutral point resistor gives an ground-fault current larger than what normal high impedance gives but smaller than the phase to phase short circuit current.
Page 538 Section 9 1MRK 506 369-UUS - Current protection Where is the capacitive ground fault current at a non-resistive phase-to-ground fault is the capacitive reactance to ground In a system with a neutral point resistor (resistance grounded system) the impedance Z can be calculated as: ×...
Page 539 Section 9 1MRK 506 369-UUS - 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 ground fault en06000654_ansi.vsd ANSI06000654 V1 EN Figure 276: Equivalent of power system for calculation of setting The residual fault current can be written:...
Page 540 Section 9 1MRK 506 369-UUS - Current protection × 3I (Z 3R ) T ,0 (Equation 474) EQUATION2024-ANSI V1 EN × 3I (Z T ,0 lineAB,0 (Equation 475) EQUATION2025-ANSI V1 EN The residual power, measured by the sensitive ground fault protections in A and B will be: ×...
Page 541 Section 9 1MRK 506 369-UUS - Current protection RotResU: It is a setting for rotating the polarizing quantity (3V ) by 0 or 180 degrees. This parameter is set to 180 degrees by default in order to inverse the residual voltage (3V ) to -jRCADir calculate the reference voltage (-3V...
Page 542 Section 9 1MRK 506 369-UUS - Current protection RCA = -90°, ROA = 90° ) – ang(V = ang(3I en06000649_ansi.vsd ANSI06000649 V1 EN Figure 278: Characteristic for RCADir equal to -90° When OpModeSel is set to 3I03V0Cosfi the apparent residual power component in the direction is measured.
Page 543 Section 9 1MRK 506 369-UUS - Current protection RCA = 0º ROA = 80º Operate area =-3V ANSI06000652-2-en.vsd ANSI06000652 V2 EN Figure 279: Characteristic for RCADir = 0° and ROADir = 80° DirMode is set Forward or Reverse to set the direction of the operation for the directional function selected by the OpModeSel.
Page 544 Section 9 1MRK 506 369-UUS - Current protection ROADir is Relay Operating Angle. ROADir is identifying a window around the reference direction in order to detect directionality. ROADir is set in degrees. For angles differing more than ROADir from RCADir the function is blocked. The setting can be used to prevent unwanted operation for non-faulted feeders, with large capacitive ground fault current contributions, due to CT phase angle error.
Page 545 Section 9 1MRK 506 369-UUS - Current protection Table 38: Inverse time characteristics Curve name ANSI Extremely Inverse ANSI Very Inverse ANSI Normal Inverse ANSI Moderately Inverse ANSI/IEEE Definite time ANSI Long Time Extremely Inverse ANSI Long Time Very Inverse ANSI Long Time Inverse IEC Normal Inverse IEC Very Inverse...
Page 546: Breaker Failure Protection Ccrbrf(50Bf)
Section 9 1MRK 506 369-UUS - Current protection tVN is the definite time delay for the trip function of the residual voltage protection, given in s. Breaker failure protection CCRBRF(50BF) 9.7.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number...
Page 547 Section 9 1MRK 506 369-UUS - Current protection GlobalBaseSel: Selects the global base value group used by the function to define IBase, VBase and SBase as applicable. Operation: Disabled/Enabled FunctionMode This parameter can be set Current or Contact. This states the way the detection of failure of the breaker is performed.
Page 548 Section 9 1MRK 506 369-UUS - Current protection breaker failure. 1 out of 4 means that at least one current of the three-phase currents or the residual current shall be high to indicate breaker failure. In most applications 1 out of 3 is sufficient.
Page 549 Section 9 1MRK 506 369-UUS - Current protection It is often required that the total fault clearance time shall be less than a given critical time. This time is often dependent of the ability to maintain transient stability in case of a fault close to a power plant.
Page 550: Stub Protection Stbptoc (50Stb)
Section 9 1MRK 506 369-UUS - Current protection Stub protection STBPTOC (50STB) 9.8.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Stub protection STBPTOC 50STB 3I>STUB SYMBOL-T V1 EN 9.8.2 Application In a breaker-and-a-half switchyard the line protection and the busbar protection normally have overlap when a connected object is in service.
Page 551: Setting Guidelines
Section 9 1MRK 506 369-UUS - Current protection ANSI05000465 V2 EN Figure 281: Typical connection for STBPTOC (50STB) in breaker-and-a-half arrangement. 9.8.3 Setting guidelines The parameters for Stub protection STBPTOC (50STB) are set via the local HMI or PCM600. The following settings can be done for the stub protection. GlobalBaseSel: Selects the global base value group used by the function to define IBase, VBase and SBase as applicable.
Page 552: Pole Discrepancy Protection Ccpdsc(52Pd)
Section 9 1MRK 506 369-UUS - Current protection t: Time delay of the operation. Normally the function shall be instantaneous. Pole discrepancy protection CCPDSC(52PD) 9.9.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Pole discrepancy protection CCPDSC 52PD SYMBOL-S V1 EN...
Page 553: Setting Guidelines
Section 9 1MRK 506 369-UUS - Current protection 9.9.3 Setting guidelines The parameters for the Pole discordance protection CCPDSC (52PD) are set via the local HMI or PCM600. The following settings can be done for the pole discrepancy protection. GlobalBaseSel: Selects the global base value group used by the function to define IBase, VBase and SBase as applicable.
Page 554: Identification
Section 9 1MRK 506 369-UUS - Current protection 9.10.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Directional underpower protection GUPPDUP P < SYMBOL-LL V2 EN 9.10.2 Application The task of a generator in a power plant is to convert mechanical energy available as a torque on a rotating shaft to electric energy.
Page 555 Section 9 1MRK 506 369-UUS - Current protection soon become overheated and damaged. The turbine overheats within minutes if the turbine loses the vacuum. The critical time to overheating a steam turbine varies from about 0.5 to 30 minutes depending on the type of turbine. A high-pressure turbine with small and thin blades will become overheated more easily than a low-pressure turbine with long and heavy blades.
Page 556: Setting Guidelines
Section 9 1MRK 506 369-UUS - Current protection Underpower protection Overpower protection Operate Operate Line Line Margin Margin Operating point Operating point without without turbine torque turbine torque IEC09000019-2-en.vsd IEC09000019 V2 EN Figure 282: Reverse power protection with underpower or overpower protection 9.10.3 Setting guidelines GlobalBaseSel: Selects the global base value group used by the function to define IBase,...
Page 557 Section 9 1MRK 506 369-UUS - Current protection Mode Set value Formula used for complex power calculation × (Equation 489) EQUATION2059-ANSI V1 EN × (Equation 490) EQUATION2060-ANSI V1 EN = × × (Equation 491) EQUATION2061-ANSI V1 EN = × × (Equation 492) EQUATION2062-ANSI V1 EN = ×...
Page 558 Section 9 1MRK 506 369-UUS - Current protection Power1(2) Angle1(2) Operate en06000441.vsd IEC06000441 V1 EN Figure 283: Underpower mode The setting Power1(2) gives the power component pick up value in the Angle1(2) direction. The setting is given in p.u. of the generator rated power, see equation 494. Minimum recommended setting is 0.2% of S when metering class CT inputs into the IED are used.
Page 559 Section 9 1MRK 506 369-UUS - Current protection Operate ° Angle1(2) = 0 Power1(2) en06000556.vsd IEC06000556 V1 EN Figure 284: For low forward power the set angle should be 0° in the underpower function TripDelay1(2) is set in seconds to give the time delay for trip of the stage after pick up. Hysteresis1(2) is given in p.u.
Page 560: Directional Overpower Protection Goppdop (32)
Section 9 1MRK 506 369-UUS - Current protection The value of k=0.92 is recommended in generator applications as the trip delay is normally quite long. The calibration factors for current and voltage measurement errors are set % of rated current/voltage: IMagComp5, IMagComp30, IMagComp100 VMagComp5, VMagComp30, VMagComp100 IMagComp5, IMagComp30, IMagComp100...
Page 561 Section 9 1MRK 506 369-UUS - 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 562: Setting Guidelines
Section 9 1MRK 506 369-UUS - Current protection A hydro turbine that rotates in water with closed wicket gates will draw electric power from the rest of the power system. This power will be about 10% of the rated power. If there is only air in the hydro turbine, the power demand will fall to about 3%.
Page 563 Section 9 1MRK 506 369-UUS - Current protection Table 41: Complex power calculation Mode Set value Formula used for complex power calculation A,B,C × × × (Equation 498) EQUATION2038 V1 EN Arone × × (Equation 499) EQUATION2039 V1 EN PosSeq = ×...
Page 564 Section 9 1MRK 506 369-UUS - Current protection Operate Power1(2) Angle1(2) en06000440.vsd IEC06000440 V1 EN Figure 286: Overpower mode The setting Power1(2) gives the power component pick up value in the Angle1(2) direction. The setting is given in p.u. of the generator rated power, see equation 507. Minimum recommended setting is 0.2% of S when metering class CT inputs into the IED are used.
Page 565 Section 9 1MRK 506 369-UUS - Current protection Angle1(2 ) = 180 Operate Power 1(2) IEC06000557-2-en.vsd IEC06000557 V2 EN Figure 287: 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 566: Broken Conductor Check Brcptoc (46)
Section 9 1MRK 506 369-UUS - Current protection S TD S TD S ⋅ − ⋅ Calculated (Equation 509) EQUATION1893-ANSI V1 EN Where is a new measured value to be used for the protection function is the measured value given from the function in previous execution cycle is the new calculated value in the present execution cycle Calculated is settable parameter...
Page 567: Setting Guidelines
Section 9 1MRK 506 369-UUS - Current protection unsymmetrical check on the line where the IED connected will give alarm or trip at detecting broken conductors. 9.12.3 Setting guidelines Broken conductor check BRCPTOC (46) must be set to detect open phase/s (series faults) with different loads on the line.
Page 568: Base Quantities
Section 9 1MRK 506 369-UUS - Current protection fault affects a generator, the fault current amplitude is a function of time, and it depends on generator characteristic (reactances and time constants), its load conditions (immediately before the fault) and excitation system performance and characteristic. So the fault current amplitude may decay with time.
Page 569: Undervoltage Seal-In
Section 9 1MRK 506 369-UUS - Current protection • voltage controlled over-current • voltage restrained over-current In both applications a seal-in of the overcurrent function at under-voltage can be included by configuration. 9.13.2.3 Undervoltage seal-in In the case of a generator with a static excitation system, which receives its power from the generator terminals, the magnitude of a sustained phase short-circuit current depends on the generator terminal voltage.
Page 570: Explanation Of The Setting Parameters
Section 9 1MRK 506 369-UUS - Current protection 9.13.3.1 Explanation of the setting parameters Operation: Set to On in order to activate the function; set to Off to switch off the complete function. Pickup_Curr: 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 571: Step-Up Transformer
Section 9 1MRK 506 369-UUS - Current protection VHighLimit: when the measured phase-to-phase voltage is higher than VHighLimit/ 100*VBase, than the pickup level of the overcurrent stage is Pickup_Curr/100*IBase. In particular, in Slope mode it define the second point of the characteristic (Pickup_Curr/ 100*IBase ;...
Page 572 Section 9 1MRK 506 369-UUS - Current protection characteristic of the generator, the excitation system and the short circuit study, the following settings are required: • Pickup current of the overcurrent stage: 150% of generator rated current at rated generator voltage; •...
Page 573: Two Step Undervoltage Protection Uv2Ptuv (27)
Section 10 1MRK 506 369-UUS - Voltage protection Section 10 Voltage protection 10.1 Two step undervoltage protection UV2PTUV (27) 10.1.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Two step undervoltage protection UV2PTUV 3U< SYMBOL-R-2U-GREATER-THAN V2 EN 10.1.2 Application...
Page 574: Setting Guidelines
Section 10 1MRK 506 369-UUS - Voltage protection The function has a high measuring accuracy and a settable hysteresis to allow applications to control reactive load. In many cases, UV2PTUV (27) is a useful function in circuits for local or remote automation processes in the power system.
Page 575: Backup Protection For Power System Faults
Section 10 1MRK 506 369-UUS - Voltage protection 10.1.3.5 Backup protection for power system faults The setting must be below the lowest occurring "normal" voltage and above the highest occurring voltage during the fault conditions under consideration. 10.1.3.6 Settings for two step undervoltage protection The following settings can be done for Two step undervoltage protection UV2PTUV (27): ConnType: Sets whether the measurement shall be phase-to-ground fundamental value,...
Page 576: Two Step Overvoltage Protection Ov2Ptov (59)
Section 10 1MRK 506 369-UUS - Voltage protection tResetn: Reset time for step n if definite time delay is used, given in s. The default value is 25 ms. tnMin: Minimum operation time for inverse time characteristic for step n, given in s. When using inverse time characteristic for the undervoltage function during very low voltages can give a short operation time.
Page 577: Identification
Section 10 1MRK 506 369-UUS - Voltage protection 10.2.1 Identification Function description IEC 61850 IEC 60617 identification ANSI/IEEE C37.2 identification device number Two step overvoltage protection OV2PTOV 3U> SYMBOL-C-2U-SMALLER-THAN V2 EN 10.2.2 Application Two step overvoltage protection OV2PTOV (59) is applicable in all situations, where reliable detection of high voltage is necessary.
Page 578: Setting Guidelines
Section 10 1MRK 506 369-UUS - Voltage protection 10.2.3 Setting guidelines The parameters for Two step overvoltage protection (OV2PTOV ,59) are set via the local HMI or PCM600. All the voltage conditions in the system where OV2PTOV (59) performs its functions should be considered.
Page 579: High Impedance Grounded Systems
Section 10 1MRK 506 369-UUS - Voltage protection 10.2.3.4 High impedance grounded systems In high impedance grounded systems, ground-faults cause a voltage increase in the non- faulty phases. Two step overvoltage protection (OV2PTOV, 59) is used to detect such faults. The setting must be above the highest occurring "normal" voltage and below the lowest occurring voltage during faults.
Page 580 Section 10 1MRK 506 369-UUS - Voltage protection In most applications it is sufficient that one phase voltage is high to give operation. If the function shall be insensitive for single phase-to-ground faults 1 out of 3 can be chosen, because the voltage will normally rise in the non-faulted phases at single phase-to-ground faults.
Page 581: Two Step Residual Overvoltage Protection Rov2Ptov (59N)
Section 10 1MRK 506 369-UUS - Voltage protection CrvSatn × > (Equation 512) EQUATION1448 V1 EN HystAbsn: Absolute hysteresis set in % of VBase. The setting of this parameter is highly dependent of the application. If the function is used as control for automatic switching of reactive compensation devices the hysteresis must be set smaller than the voltage change after switching of the compensation device.
Page 582: Setting Guidelines
Section 10 1MRK 506 369-UUS - Voltage protection 10.3.3 Setting guidelines All the voltage conditions in the system where ROV2PTOV (59N) performs its functions should be considered. The same also applies to the associated equipment, its voltage withstand capability and time characteristic. All voltage-related settings are made as a percentage of a settable base voltage, which shall be set to the primary nominal voltage (phase-phase) level of the power system or the high-voltage equipment under consideration.
Page 583: High Impedance Grounded Systems
Section 10 1MRK 506 369-UUS - Voltage protection 10.3.3.4 High impedance grounded systems In high impedance grounded systems, ground faults cause a neutral voltage in the feeding transformer neutral. Two step residual overvoltage protection ROV2PTOV (59N) is used to trip the transformer, as a backup protection for the feeder ground fault protection, and as a backup for the transformer primary ground fault protection.
Page 584: Settings For Two Step Residual Overvoltage Protection
Section 10 1MRK 506 369-UUS - Voltage protection ANSI07000189-1-en.vsd ANSI07000189 V1 EN Figure 290: Ground fault in Direct grounded system 10.3.3.6 Settings for two step residual overvoltage protection Operation: Disabled or Enabled VBase (given in GlobalBaseSel) is used as voltage reference for the set pickup values. The voltage can be fed to the IED in different ways: The IED is fed from a normal voltage transformer group where the residual voltage is calculated internally from the phase-to-ground voltages within the protection.
Page 585 Section 10 1MRK 506 369-UUS - Voltage protection OperationStepn: This is to enable/disable operation of step n. Characteristicn: Selected inverse time characteristic for step n. This parameter gives the type of time delay to be used. The setting can be, Definite time or Inverse curve A or Inverse curve B or Inverse curve C or Prog.
Page 586: Overexcitation Protection Oexpvph (24)
Section 10 1MRK 506 369-UUS - Voltage protection CrvSatn: Set tuning parameter for step n. When the denominator in the expression of the programmable curve is equal to zero, the time delay will be infinite. There will be an undesired discontinuity. Therefore, a tuning parameter CrvSatn is set to compensate for this phenomenon.
Page 587 Section 10 1MRK 506 369-UUS - Voltage protection occuring at disturbance where high voltages and/or low frequencies can occur. Overexcitation can occur during start-up and shut-down of the generator if the field current is not properly adjusted. Loss-of load or load-shedding can also result in overexcitation if the voltage control and frequency governor is not functioning properly.
Page 588: Setting Guidelines
Section 10 1MRK 506 369-UUS - Voltage protection any characteristic by setting the operate time for six different figures of overexcitation in the range from 100% to 180% of rated V/Hz. When configured to a single phase-to-phase voltage input, a corresponding phase-to- phase current is calculated which has the same phase angle relative the phase-to-phase voltage as the phase currents have relative the phase voltages in a symmetrical system.
Page 589: Settings
Section 10 1MRK 506 369-UUS - Voltage protection BLOCK: The input will block the operation of the Overexcitation protection OEXPVPH (24), for example, the block input can be used to block the operation for a limited time during special service conditions. RESET: OEXPVPH (24) has a thermal memory, which can take a long time to reset.
Page 590: Service Value Report
Section 10 1MRK 506 369-UUS - Voltage protection of the capability curve of the transformer/generator. Setting should be above the knee- point when the characteristic starts to be straight on the high side. XLeakage: The transformer leakage reactance on which the compensation of voltage measurement with load current is based.
Page 591 Section 10 1MRK 506 369-UUS - Voltage protection The settings Pickup2 and Pickup1 are made in per unit of the rated voltage of the transformer winding at rated frequency. Set the transformer adapted curve for a transformer with overexcitation characteristics in according to figure 292.
Page 592: Voltage Differential Protection Vdcptov (60)
Section 10 1MRK 506 369-UUS - Voltage protection V/Hz transformer capability curve relay operate characteristic Continous 0.05 Time (minutes) en01000377.vsd IEC01000377 V1 EN Figure 292: Example on overexcitation capability curve and V/Hz protection settings for power transformer 10.5 Voltage differential protection VDCPTOV (60) 10.5.1 Identification Function description...
Page 593 Section 10 1MRK 506 369-UUS - Voltage protection indicates a fault, either short-circuited or open element in the capacitor bank. It is mainly used on elements with external fuses but can also be used on elements with internal fuses instead of a current unbalance protection measuring the current between the neutrals of two half’s of the capacitor bank.
Page 594: Setting Guidelines
Section 10 1MRK 506 369-UUS - Voltage protection The application to supervise the voltage on two voltage transformers in the generator circuit is shown in figure 294. To Protection Vd> To Excitation en06000389_ansi.vsd ANSI06000389 V1 EN Figure 294: Supervision of fuses on generator circuit voltage transformers 10.5.3 Setting guidelines The parameters for the voltage differential function are set via the local HMI or PCM600.
Page 595 Section 10 1MRK 506 369-UUS - Voltage protection the differential voltage achieved as a service value for each phase. The factor is defined as V2 · RFLx and shall be equal to the V1 voltage. Each phase has its own ratio factor. VDTrip: The voltage differential level required for tripping is set with this parameter.
Page 596: Loss Of Voltage Check Lovptuv (27)
Section 10 1MRK 506 369-UUS - Voltage protection 10.6 Loss of voltage check LOVPTUV (27) 10.6.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Loss of voltage check LOVPTUV 10.6.2 Application The trip of the circuit breaker at a prolonged loss of voltage at all the three phases is normally used in automatic restoration systems to facilitate the system restoration after a major blackout.
Page 597: Application
Section 10 1MRK 506 369-UUS - Voltage protection 10.7.2 Application The most common application of the PAPGAPC (27) function is to provide tripping at the remote end of lines with passive load or with weak end infeed. The function must be included in the terminal at the weak infeed end of the feeder.
Page 598 Section 10 1MRK 506 369-UUS - Voltage protection Del3PhOp: Enabling of delayed three phase operation. ResCurrOper: Enabling of residual current operation. tResCurr: Time delay for residual current indication. Line distance protection REL670 2.2 ANSI Application manual...
Page 599: Underfrequency Protection Saptuf (81)
Section 11 1MRK 506 369-UUS - Frequency protection Section 11 Frequency protection 11.1 Underfrequency protection SAPTUF (81) 11.1.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Underfrequency protection SAPTUF f < SYMBOL-P V1 EN 11.1.2 Application Underfrequency protection SAPTUF (81) is applicable in all situations, where reliable detection of low fundamental power system frequency is needed.
Page 600: Setting Guidelines
Section 11 1MRK 506 369-UUS - Frequency protection 11.1.3 Setting guidelines All the frequency and voltage magnitude conditions in the system where SAPTUF (81) performs its functions should be considered. The same also applies to the associated equipment, its frequency and time characteristic. There are two specific application areas for SAPTUF (81): to protect equipment against damage due to low frequency, such as generators, transformers, and motors.
Page 601: Identification
Section 11 1MRK 506 369-UUS - Frequency protection 11.2.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Overfrequency protection SAPTOF f > SYMBOL-O V1 EN 11.2.2 Application Overfrequency protection function SAPTOF (81) is applicable in all situations, where reliable detection of high fundamental power system frequency is needed.
Page 602: Rate-Of-Change Of Frequency Protection Sapfrc (81)
Section 11 1MRK 506 369-UUS - Frequency protection Equipment protection, such as for motors and generators The setting has to be well above the highest occurring "normal" frequency and well below the highest acceptable frequency for the equipment. Power system protection, by generator shedding The setting must be above the highest occurring "normal"...
Page 603: Setting Guidelines
Section 11 1MRK 506 369-UUS - Frequency protection 11.3.3 Setting guidelines The parameters for Rate-of-change frequency protection SAPFRC (81) are set via the local HMI or or through the Protection and Control Manager (PCM600). All the frequency and voltage magnitude conditions in the system where SAPFRC (81) performs its functions should be considered.
Page 605: General Current And Voltage Protection Cvgapc
Section 12 1MRK 506 369-UUS - Multipurpose protection Section 12 Multipurpose protection 12.1 General current and voltage protection CVGAPC 12.1.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number General current and voltage protection CVGAPC 2(I>/U<) 12.1.2 Application A breakdown of the insulation between phase conductors or a phase conductor and ground...
Page 606: Current And Voltage Selection For Cvgapc Function
Section 12 1MRK 506 369-UUS - Multipurpose protection • Definite time delay or Inverse Time Overcurrent TOC/IDMT delay for both steps • Second harmonic supervision is available in order to only allow operation of the overcurrent stage(s) if the content of the second harmonic in the measured current is lower than pre-set level •...
Page 607 Section 12 1MRK 506 369-UUS - Multipurpose protection Table 43: Available selection for current quantity within CVGAPC function Set value for parameter Comment "CurrentInput” PhaseA CVGAPC function will measure the phase A current phasor PhaseB CVGAPC function will measure the phase B current phasor PhaseC CVGAPC function will measure the phase C current phasor PosSeq...
Page 608 Section 12 1MRK 506 369-UUS - Multipurpose protection Table 44: Available selection for voltage quantity within CVGAPC function Set value for parameter Comment "VoltageInput" PhaseA CVGAPC function will measure the phase A voltage phasor PhaseB CVGAPC function will measure the phase B voltage phasor PhaseC CVGAPC function will measure the phase C voltage phasor PosSeq...
Page 609: Base Quantities For Cvgapc Function
Section 12 1MRK 506 369-UUS - Multipurpose protection to-phase voltages VAB, VBC and VCA. This information about actual VT connection is entered as a setting parameter for the pre-processing block, which will then take automatically care about it. 12.1.2.2 Base quantities for CVGAPC function The parameter settings for the base quantities, which represent the base (100%) for pickup levels of all measuring stages shall be entered as setting parameters for every CVGAPC function.
Page 610: Inadvertent Generator Energization
Section 12 1MRK 506 369-UUS - Multipurpose protection • 80-95% Stator earth fault protection (measured or calculated 3Vo) (59GN) • Rotor earth fault protection (with external COMBIFLEX RXTTE4 injection unit) (64F) • Underimpedance protection (21) • Voltage Controlled/Restrained Overcurrent protection (51C, 51V) •...
Page 611: Setting Guidelines
Section 12 1MRK 506 369-UUS - Multipurpose protection There is a risk that the current into the generator at inadvertent energization will be limited so that the “normal” overcurrent or underimpedance protection will not detect the dangerous situation. The delay of these protection functions might be too long. The reverse power protection might detect the situation but the operation time of this protection is normally too long.
Page 612 Section 12 1MRK 506 369-UUS - Multipurpose protection minimum pickup of such protection function shall be set above natural system unbalance level. An example will be given, how sensitive-ground-fault protection for power lines can be achieved by using negative-sequence directional overcurrent protection elements within a CVGAPC function.
Page 613: Negative Sequence Overcurrent Protection
Section 12 1MRK 506 369-UUS - Multipurpose protection If required, this CVGAPC function can be used in directional comparison protection scheme for the power line protection if communication channels to the remote end of this power line are available. In that case typically two NegSeq overcurrent steps are required. One for forward and one for reverse direction.
Page 614 Section 12 1MRK 506 369-UUS - Multipurpose protection æ ö ç ÷ è ø (Equation 515) EQUATION1740-ANSI V1 EN 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 615 Section 12 1MRK 506 369-UUS - Multipurpose protection æ ö × ç ÷ è ø (Equation 518) EQUATION1742-ANSI V1 EN where: is the operating time in seconds of the Inverse Time Overcurrent TOC/IDMT algorithm is time multiplier (parameter setting) is ratio between measured current magnitude and set pickup current level A, B, C and P are user settable coefficients which determine the curve used for Inverse Time Overcurrent TOC/IDMT calculation When the equation...
Page 616: Generator Stator Overload Protection In Accordance With Iec Or Ansi Standards
Section 12 1MRK 506 369-UUS - Multipurpose protection 12.1.3.3 Generator stator overload protection in accordance with IEC or ANSI standards Example will be given how to use one CVGAPC function to provide generator stator overload protection in accordance with IEC or ANSI standard if minimum-operating current shall be set to 116% of generator rating.
Page 617 Section 12 1MRK 506 369-UUS - Multipurpose protection In order to achieve such protection functionality with one CVGAPC functions the following must be done: Connect three-phase generator currents to one CVGAPC instance (for example, GF01) Set parameter CurrentInput to value PosSeq Set base current value to the rated generator current in primary amperes Enable one overcurrent step (for example OC1) Select parameter CurveType_OC1 to value Programmable...
Page 618: Open Phase Protection For Transformer, Lines Or Generators And Circuit Breaker Head Flashover Protection For Generators
Section 12 1MRK 506 369-UUS - Multipurpose protection Proper timing of CVGAPC function made in this way can easily be verified by secondary injection. All other settings can be left at the default values. If required delayed time reset for OC1 step can be set in order to insure proper function operation in case of repetitive overload conditions.
Page 619: Voltage Restrained Overcurrent Protection For Generator And Step-Up Transformer
Section 12 1MRK 506 369-UUS - Multipurpose protection 12.1.3.5 Voltage restrained overcurrent protection for generator and step-up transformer 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 620 Section 12 1MRK 506 369-UUS - Multipurpose protection • Maximum generator capability to contentiously absorb reactive power at zero active loading 38% of the generator MVA rating • Generator pull-out angle 84 degrees This functionality can be achieved by using one CVGAPC function. The following shall be done in order to insure proper operation of the function: Connect three-phase generator currents and three-phase generator voltages to one CVGAPC instance (for example, GF02)
Page 621 Section 12 1MRK 506 369-UUS - Multipurpose protection Q [pu] Operating region ILowSet P [pu] -rca -0.2 -0.4 ILowSet Operating Region -0.6 -0.8 en05000535_ansi.vsd ANSI05000535 V1 EN Figure 295: Loss of excitation Line distance protection REL670 2.2 ANSI Application manual...
Page 623: Multipurpose Filter Smaihpac
Section 13 1MRK 506 369-UUS - System protection and control Section 13 System protection and control 13.1 Multipurpose filter SMAIHPAC 13.1.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Multipurpose filter SMAIHPAC 13.1.2 Application The multi-purpose filter, function block with name SMAI HPAC, is arranged as a three- phase filter.
Page 624 Section 13 1MRK 506 369-UUS - System protection and control • Sub-synchronous resonance protection for turbo generators • Sub-synchronous protection for wind turbines/wind farms • Detection of sub-synchronous oscillation between HVDC links and synchronous generators • Super-synchronous protection • Detection of presence of the geo-magnetic induced currents •...
Page 625: Setting Guidelines
Section 13 1MRK 506 369-UUS - System protection and control 13.1.3 Setting guidelines 13.1.3.1 Setting example A relay type used for generator subsynchronous resonance overcurrent protection shall be replaced. The relay had inverse time operating characteristic as given with the following formula: (Equation 523) EQUATION13000029 V1 EN...
Page 626 Section 13 1MRK 506 369-UUS - System protection and control FilterLength 1.0 s OverLap Operation Now the settings for the multi-purpose overcurrent stage one shall be derived in order to emulate the existing relay operating characteristic. To achieve exactly the same inverse time characteristic the programmable IDMT characteristic is used which for multi- purpose overcurrent stage one, which has the following equation (for more information see Section “Inverse time characteristics”...
Page 627 Section 13 1MRK 506 369-UUS - 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 629: Current Circuit Supervision (87)
Section 14 1MRK 506 369-UUS - Secondary system supervision Section 14 Secondary system supervision 14.1 Current circuit supervision (87) 14.1.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Current circuit supervision CCSSPVC 14.1.2 Application Open or short circuited current transformer cores can cause unwanted operation of many protection functions such as differential, ground-fault current and negative-sequence current functions.
Page 630: Setting Guidelines
Section 14 1MRK 506 369-UUS - Secondary system supervision 14.1.3 Setting guidelines GlobalBaseSel: Selects the global base value group used by the function to define IBase, VBase and SBase as applicable. Current circuit supervision CCSSPVC (87) compares the residual current from a three- phase set of current transformer cores with the neutral point current on a separate input taken from another set of cores on the same current transformer.
Page 631: Setting Guidelines
Section 14 1MRK 506 369-UUS - Secondary system supervision protection and monitoring devices are another possibilities. These solutions are combined to get the best possible effect in the fuse failure supervision function (FUFSPVC). FUFSPVC function built into the IED products can operate on the basis of external binary signals from the miniature circuit breaker or from the line disconnector.
Page 632: Negative Sequence Based
Section 14 1MRK 506 369-UUS - Secondary system supervision The voltage threshold VPPU is used to identify low voltage condition in the system. Set VPPU below the minimum operating voltage that might occur during emergency conditions. We propose a setting of approximately 70% of VBase. The drop off time of 200 ms for dead phase detection makes it recommended to always set SealIn to Enabled since this will secure a fuse failure indication at persistent fuse fail when closing the local breaker when the line is already energized from the other end.
Page 633: Zero Sequence Based
Section 14 1MRK 506 369-UUS - Secondary system supervision The setting of the current limit 3I2PU is in percentage of parameter IBase. The setting of 3I2PU must be higher than the normal unbalance current that might exist in the system and can be calculated according to equation 528.
Page 634: Dead Line Detection
Section 14 1MRK 506 369-UUS - Secondary system supervision 14.2.3.5 Delta V and delta I Set the operation mode selector OpDVDI to Enabled if the delta function shall be in operation. The setting of DVPU should be set high (approximately 60% of VBase) and the current threshold DIPU low (approximately 10% of IBase) to avoid unwanted operation due to normal switching conditions in the network.
Page 635: Identification
Section 14 1MRK 506 369-UUS - Secondary system supervision 14.3.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Fuse failure supervision VDSPVC 14.3.2 Application Some protection functions operate on the basis of measured voltage at the relay point. Examples of such protection functions are distance protection function, undervoltage function and energisation-check function.
Page 636: Setting Guidelines
Section 14 1MRK 506 369-UUS - Secondary system supervision Main Vt circuit FuseFailSupvn ANSI12000143-1-en.vsd ANSI12000143 V1 EN Figure 297: Application of VDSPVC 14.3.3 Setting guidelines The parameters for Fuse failure supervision VDSPVC are set via the local HMI or PCM600. The voltage input type (phase-to-phase or phase-to-neutral) is selected using ConTypeMain and ConTypePilot parameters, for main and pilot fuse groups respectively.
Page 637 Section 14 1MRK 506 369-UUS - Secondary system supervision The settings Vdif Main block, Vdif Pilot alarm and VSealIn are in percentage of the base voltage, VBase. Set VBase to the primary rated phase-to-phase voltage of the potential voltage transformer. VBase is available in the Global Base Value groups; the particular Global Base Value group, that is used by VDSPVC (60), is set by the setting parameter GlobalBaseSel.
Page 639: Synchronism Check, Energizing Check, And Synchronizing Sesrsyn (25)
Section 15 1MRK 506 369-UUS - Control Section 15 Control 15.1 Synchronism check, energizing check, and synchronizing SESRSYN (25) 15.1.1 Identification 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 15.1.2 Application...
Page 640 Section 15 1MRK 506 369-UUS - Control • The voltages V-Line and V-Bus are higher than the set values for VHighBusSynch and VHighLineSynch of the respective base voltages GblBaseSelBus and GblBaseSelLine. • The difference in the voltage is smaller than the set value of VDiffSynch. •...
Page 641: Synchronism Check
Section 15 1MRK 506 369-UUS - Control phases used for SESRSYN, with the settings SelPhaseBus1, SelPhaseBus2, SelPhaseLine2 and SelPhaseLine2, a compensation is made automatically for the voltage amplitude difference and the phase angle difference caused if different setting values are selected for the two sides of the breaker.
Page 642 Section 15 1MRK 506 369-UUS - Control • Live line and live bus. • Voltage level difference. • Frequency difference (slip). The bus and line frequency must also be within a range of ±5 Hz from rated frequency. • Phase angle difference. A time delay is available to ensure that the conditions are fulfilled for a minimum period of time.
Page 643: Energizing Check
Section 15 1MRK 506 369-UUS - Control SynchroCheck Bus voltage VHighBusSC > 50 – 120% of GblBaseSelBus Fuse fail VHighLineSC >50 – 120% of GblBaseSelLine Line Line Bus Voltage VDiffSC < 0.02 – 0.50 p.u. reference PhaseDiffM < 5 – 90 degrees voltage PhaseDiffA <...
Page 644: Voltage Selection
Section 15 1MRK 506 369-UUS - Control Bus voltage Line voltage EnergizingCheck VLiveBusEnerg > 50 - 120 % of GblBaseSelBus VLiveLineEnerg > 50 - 120 % of GblBaseSelLine VDeadBusEnerg < 10 - 80 % of GblBaseSelBus VDeadLineEnerg < 10 - 80 % of GblBaseSelLine VMaxEnerg <...
Page 645: 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 646: Application Examples
Section 15 1MRK 506 369-UUS - Control SLGGIO SESRSYN (25) PSTO INTONE NAME1 SWPOSN MENMODE NAME2 NAME3 NAME4 ANSI09000171_1_en.vsd ANSI09000171 V1 EN Figure 301: Selection of the energizing direction from a local HMI symbol through a selector switch function block. 15.1.3 Application examples The synchronism check function block can also be used in some switchyard arrangements,...
Page 647: Single Circuit Breaker With Single Busbar
Section 15 1MRK 506 369-UUS - Control 15.1.3.1 Single circuit breaker with single busbar SESRSYN (25) V3PB1* SYNOK Bus 1 V3PB2* AUTOSYOK V3PL1* AUTOENOK V3PL2* MANSYOK BLOCK MANENOK BLKSYNCH TSTSYNOK BLKSC TSTAUTSY BLKENERG TSTMANSY BUS1_OP TSTENOK BUS1_CL VSELFAIL Fuse BUS2_OP B1SEL BUS2_CL B2SEL...
Page 648: Single Circuit Breaker With Double Busbar, External Voltage Selection
Section 15 1MRK 506 369-UUS - Control 15.1.3.2 Single circuit breaker with double busbar, external voltage selection SESRSYN (25) V3PB1* SYNOK V3PB2* AUTOSYOK V3PL1* AUTOENOK Bus 1 V3PL2* MANSYOK BLOCK MANENOK Bus 2 BLKSYNCH TSTSYNOK BLKSC TSTAUTSY BLKENERG TSTMANSY BUS1_OP TSTENOK Fuse BUS1_CL...
Page 649: Single Circuit Breaker With Double Busbar, Internal Voltage Selection
Section 15 1MRK 506 369-UUS - Control 15.1.3.3 Single circuit breaker with double busbar, internal voltage selection SESRSYN (25) V3PB1* SYNOK V3PB2* AUTOSYOK V3PL1* AUTOENOK V3PL2* MANSYOK Bus 1 BLOCK MANENOK Bus 2 BLKSYNCH TSTSYNOK BLKSC TSTAUTSY BLKENERG TSTMANSY BUS1_OP TSTENOK BUS1_CL VSELFAIL...
Page 650: Double Circuit Breaker
Section 15 1MRK 506 369-UUS - Control 15.1.3.4 Double circuit breaker SESRSYN (25) V3PB1* SYNOK V3PB2* AUTOSYOK V3PL1* AUTOENOK V3PL2* MANSYOK BLOCK MANENOK BLKSYNCH TSTSYNOK BLKSC TSTAUTSY BLKENERG TSTMANSY BUS1_OP TSTENOK BUS1_CL VSELFAIL Fuse BUS2_OP B1SEL Voltage BUS2_CL B2SEL LINE1_OP L1SEL VREF1 LINE1_CL...
Page 651: Breaker-And-A-Half
Section 15 1MRK 506 369-UUS - Control A double breaker arrangement requires two function blocks, one for breaker WA1_QA1 and one for breaker WA2_QA1. No voltage selection is necessary, because the voltage from busbar 1 VT is connected to V3PB1 on SESRSYN for WA1_QA1 and the voltage from busbar 2 VT is connected toV3PB1 on SESRSYN for WA2_QA1.
Page 652 Section 15 1MRK 506 369-UUS - Control Bus 1 CB Bus 1 SESRSYN (25) Bus 2 V3PB1* SYNOK V3PB2* AUTOSYOK V3PL1* AUTOENOK V3PL2* MANSYOK BLOCK MANENOK BLKSYNCH TSTSYNOK BLKSC TSTAUTSY BLKENERG TSTMANSY Fuse BUS1_OP TSTENOK bus1 Voltage BUS1_CL VSELFAIL VREF1 BUS2_OP B1SEL BUS2_CL...
Page 653 Section 15 1MRK 506 369-UUS - Control The connections are similar in all SESRSYN functions, apart from the breaker position indications. The physical analog connections of voltages and the connection to the IED and SESRSYN (25) function blocks must be carefully checked in PCM600. In all SESRSYN functions the connections and configurations must abide by the following rules: Normally apparatus position is connected with contacts showing both open (b-type) and closed positions (a-type).
Page 654: Setting Guidelines
Section 15 1MRK 506 369-UUS - Control 15.1.4 Setting guidelines The setting parameters for the Synchronizing, synchronism check and energizing check function SESRSYN (25) are set via the local HMI (LHMI) or PCM600. This setting guidelines describes the settings of the SESRSYN (25) function via the LHMI.
Page 655 Section 15 1MRK 506 369-UUS - Control • no voltage selection, No voltage sel. • single circuit breaker with double bus, Double bus • breaker-and-a-half arrangement with the breaker connected to busbar 1, 1 1/2 bus CB • breaker-and-a-half arrangement with the breaker connected to busbar 2, 1 1/2 bus alt. •...
Page 656 Section 15 1MRK 506 369-UUS - Control it is better to let the synchronizing function close, as it will close at exactly the right instance if the networks run with a frequency difference. To avoid overlapping of the synchronizing function and the synchrocheck function the setting FreqDiffMin must be set to a higher value than used setting FreqDiffM, respective FreqDiffA used for synchrocheck.
Page 657 Section 15 1MRK 506 369-UUS - Control outside the limits from the start, a margin needs to be added. A typical setting is 600 seconds. tMinSynch The setting tMinSynch is set to limit the minimum time at which the synchronizing closing attempt is given.
Page 658 Section 15 1MRK 506 369-UUS - Control tSCM and tSCA The purpose of the timer delay settings, tSCM and tSCA, is to ensure that the synchrocheck conditions remains constant and that the situation is not due to a temporary interference. Should the conditions not persist for the specified time, the delay timer is reset and the procedure is restarted when the conditions are fulfilled again.
Page 659: Autorecloser For 1 Phase, 2 Phase And/Or 3 Phase Operation Smbrrec (79)
Section 15 1MRK 506 369-UUS - Control A disconnected line can have a considerable potential due to, for instance, induction from a line running in parallel, or by being fed via the extinguishing capacitors in the circuit breakers. This voltage can be as high as 30% or more of the base line voltage.
Page 660: Application
Section 15 1MRK 506 369-UUS - Control 15.2.2 Application Automatic reclosing is a well-established method for the restoration of service in a power system after a transient line fault. The majority of line faults are flashovers, which are transient by nature. When the power line is switched off by the operation of line protection and line breakers, the arc de-ionizes and recovers its ability to withstand voltage at a somewhat variable rate.
Page 661 Section 15 1MRK 506 369-UUS - Control Single-pole tripping and single-phase automatic reclosing is a way of limiting the effect of a single-phase line fault on power system operation. Especially at higher voltage levels, the majority of faults are of single-phase type (around 90%). To maintain system stability in power systems with limited meshing or parallel routing single-phase auto reclosing is of particular value.
Page 662 Section 15 1MRK 506 369-UUS - Control The auto recloser can be selected to perform single-phase and/or three-phase automatic reclosing from several single-shot to multiple-shot reclosing programs. The three-phase auto reclosing dead time can be set to give either High-Speed Automatic Reclosing (HSAR) or Delayed Automatic Reclosing (DAR).
Page 663: Auto Reclosing Operation Off And On
Section 15 1MRK 506 369-UUS - Control • Evolving fault where the fault during the dead-time spreads to another phase. The other two phases must then be tripped and a three phase dead-time and auto reclose initiated • Permanent fault •...
Page 664: Initiate Auto Reclosing From Circuit Breaker Open Information
Section 15 1MRK 506 369-UUS - Control distance protection aided trip. In some cases also directional ground fault protection aided trip can be connected to start an auto reclose attempt. If general trip is used to start the auto recloser it is important to block it from other functions that should not start an auto reclosing sequence.
Page 665: Control Of The Auto Reclosing Dead Time For Shot 1
Section 15 1MRK 506 369-UUS - Control Depending of the starting principle (general trip or only instantaneous trip) adopted above the delayed and back-up zones might not be required. Breaker failure trip local and remote must however always be connected. 15.2.2.5 Control of the auto reclosing dead time for shot 1 Up to four different time settings can be used for the first shot, and one extension time.
Page 666: Armode = 3Ph, (Normal Setting For A Three-Phase Shot)
Section 15 1MRK 506 369-UUS - Control The decision for single- and three-phase trip is also made in the tripping logic (SMPTTRC) function block where the setting 3 phase, 1ph/3Ph (or 1ph/2ph/3Ph) is selected. ARMode = 3ph, (normal setting for a three-phase shot) 15.2.2.8 Three-phase auto reclosing, one to five shots according to the NoOfShots setting.
Page 667: Armode = 1Ph+1*2Ph, 1-Phase Or 2-Phase Reclosing In The First Shot
Section 15 1MRK 506 369-UUS - Control ARMode = 1/2ph , 1-phase or 2-phase reclosing in the first shot 15.2.2.10 At single-pole or two-pole tripping, the operation is as in the example described above, program mode 1/2/3ph. If the first reclosing shot fails, a three-pole trip will be issued and three-pole auto reclosing can follow, if selected.
Page 668: External Selection Of Auto Reclosing Mode
Section 15 1MRK 506 369-UUS - Control MODEINT (integer) ARMode Type of fault 1st shot 2nd-5th shot 1/2/3ph 1/2ph ..1ph + 1*2ph ....1/2ph + 1*3ph ..1ph + 1*2/3ph ..A start of a new auto reclosing cycle during the set “reset time” is blocked when the set number of reclosing shots have been reached.
Page 669: Auto Reclosing Reset Timer
Section 15 1MRK 506 369-UUS - Control 15.2.2.15 Auto reclosing reset timer The tReset timer defines the time it takes from issue of the breaker closing command, until the auto recloser resets. Should a new trip occur during this time, it is treated as a continuation of the first fault.
Page 670: Lock-Out Initiation
Section 15 1MRK 506 369-UUS - Control to generate a lock-out of manual circuit breaker closing until the operator has reset the lock-out, see separate section. 15.2.2.19 Lock-out initiation In many cases there is a requirement that a lock-out is generated when the auto reclosing attempt fails.
Page 671: Evolving Fault
Section 15 1MRK 506 369-UUS - Control SMBRREC (79) BJ-TRIP INHIBIT ZCVPSOF-TRIP UNSUCCL SMPPTRC (94) SETLKOUT CLLOUT CCRBRF (50BF) SOFTWARE RESET LOCK-OUT RSTLOUT OR IO RESET BJTRIP MAN CLOSE SMBO SMBRREC (79) CLOSE SESRSYN (25) AUTO STOP CLOSE COMMAND MAN ENOK ANSI05000316_2_en.vsd ANSI05000316 V2 EN Figure 310:...
Page 672: Thermal Overload Protection Holding The Auto Recloser Back
Section 15 1MRK 506 369-UUS - Control 15.2.2.22 Thermal overload protection holding the auto recloser back If the THOLHOLD input (thermal overload protection holding auto reclosing back) is activated, it will keep the auto recloser on a hold until it is reset. There may thus be a considerable delay between start of the auto recloser and the breaker closing command to the circuit breaker.
Page 673 Section 15 1MRK 506 369-UUS - Control protection trip or from breaker failure protection. When the circuit breaker open position is set to start the auto recloser, then manual opening must also be connected here. The inhibit is often a combination of signals from external IEDs via the I/O and internal functions.
Page 674 Section 15 1MRK 506 369-UUS - Control The START input should be connected to the trip function (SMPPTRC) output, which starts the auto recloser for 1/2/3-phase operation. It can also be connected to a binary input for start from an external contact. A logical OR-gate can be used to combine the number of start sources.
Page 675 Section 15 1MRK 506 369-UUS - Control WAIT Used to hold back reclosing of the “low priority unit” during sequential auto reclosing. See “Recommendation for multi-breaker arrangement” below. The signal is activated from output WFMASTER on the second breaker auto recloser in multi-breaker arrangements. ZONESTEP The ZONESTEP input is used when coordination between local auto reclosers and down stream auto reclosers is needed.
Page 676 Section 15 1MRK 506 369-UUS - Control CLOSECMD Connect to a binary output for circuit breaker closing command. COUNT1P, COUNT2P, COUNT3P1, COUNT3P2, COUNT3P3, COUNT3P4 and COUNT3P5 Indicates the number of auto reclosing shots made for respective shot. COUNTAR Indicates the total number of auto reclosing shots made. INHIBOUT If the INHIBIT input is activated it is reported on the INHIBOUT output.
Page 677 Section 15 1MRK 506 369-UUS - Control SUCCL If the circuit breaker closing command is given and the circuit breaker is closed within the set time interval tUnsucCl, the SUCCL output is activated after the set time interval tSuccessful. SYNCFAIL The SYNCFAIL output indicates that the auto recloser is inhibited because the synchrocheck or energizing check condition has not been fulfilled within the set time interval, tSync.
Page 678 Section 15 1MRK 506 369-UUS - Control SMBRREC (79) INPUT OUTPUT BLOCKED SETON INPROGR BLKON ACTIVE BLKOFF INHIBIT UNSUCCL SUCCL CBREADY PLCLOST CLOSECMD RESET PERMIT1P PREP3P PROTECTION READY xxxx-TRIP RI_HS 1PT1 2PT1 SKIPHS ZCVPSOF-TRIP 3PT1 TRSOTF ZMQPDIS (21)--TRIP 3PT2 3PT3 THOLHOLD 3PT4 TR2P...
Page 679 Section 15 1MRK 506 369-UUS - Control SMBRREC (79) INPUT OUTPUT BLOCKED SETON BLKON INPROGR BLKOFF ACTIVE INHIBIT UNSUCCL SUCCL CBREADY PLCLOST CLOSECB PERMIT1P RESET TRIP-P3PTR PREP3P PROTECTION READY GROUND RELAYS xxxx-TRIP 1PT1 BLOCK 2PT1 3PT1 RI_HS 3PT2 SKIPHS 3PT3 ZCVPSOF-TRIP TRSOTF 3PT4...
Page 680 Section 15 1MRK 506 369-UUS - Control when the WAIT input resets. The mimimum settable time for tSlaveDeadTime is 0.1sec because both master and slave should not send the breaker closing command at the same time. The slave should take the duration of the breaker closing time of the master into consideration before sending the breaker closing command.
Page 681: Auto Recloser Settings
Section 15 1MRK 506 369-UUS - Control Terminal ‘‘ Master ” Priority = High SMBRREC (79) BLOCKED SETON BLKON INPROGR BLKOFF ACTIVE INHIBIT UNSUCCL RESET SUCCL PLCLOST READY CLOSEMD RI_HS PERMIT1P SKIPHS PREP3P THOLHOLD TRSOTF 1PT1 2PT1 CBREADY 3PT1 3PT2 3PT3 SYNC 3PT4...
Page 682 Section 15 1MRK 506 369-UUS - Control General settings Operation: The operation of the auto recloser can be switched Enabled or Disabled. ExternalCtrl: This setting makes it possible to switch the auto recloser On or Off using an external switch via IO or communication ports. ARMode: There are six different possibilities in the selection of auto reclosing programs.
Page 683 Section 15 1MRK 506 369-UUS - Control recloser increases its actual shot number by one and enters “reset time” status. If a start is received during this reclaim time the auto recloser is proceeding as usual but with the dead time for the increased shot number.
Page 684 Section 15 1MRK 506 369-UUS - Control tReset: The reclaim time sets the time for resetting the function to its original state, after which a line fault and tripping will be treated as an independent new case with a new auto reclosing cycle.
Page 685 Section 15 1MRK 506 369-UUS - Control Three-phase auto reclosing dead time: Different local phenomena, such as moisture, salt, pollution, can influence the required dead time. Some users apply Delayed Auto Reclosing (DAR) with delays of 10s or more. Extended t1: The time extension below is controlled by the Extended t1 setting. tExtended t1: A time extension delay, tExtended t1, can be added to the dead time delay for the first shot.
Page 686: Apparatus Control Apc
Section 15 1MRK 506 369-UUS - Control is 0.1sec because both master and slave should not send the circuit breaker closing command at the same time. 15.3 Apparatus control APC 15.3.1 Application The apparatus control is a functionality for control and supervising of circuit breakers, disconnectors, and grounding switches within a bay.
Page 687 Section 15 1MRK 506 369-UUS - Control Features in the apparatus control function: • Operation of primary apparatuses • Select-Execute principle to give high security • Selection and reservation function to prevent simultaneous operation • Selection and supervision of operator place •...
Page 688 Section 15 1MRK 506 369-UUS - Control IEC 61850 QCBAY SXCBR SCSWI SXCBR SXCBR SCILO SCSWI SXSWI SCILO en05000116_ansi.vsd ANSI05000116 V1 EN Figure 315: Signal flow between apparatus control function blocks when all functions are situated within the IED Line distance protection REL670 2.2 ANSI Application manual...
Page 689 Section 15 1MRK 506 369-UUS - Control IEC 61850 on station bus Bay level IED QCBAY SCSWI SCILO GOOSEXLNRCV XLNPROXY SCSWI SCILO GOOSEXLNRCV XLNPROXY GOOSE over process bus Merging Unit XCBR -QB1 XCBR XCBR -QA1 XSWI -QB9 IEC16000070-1-EN.vsdx IEC16000070 V1 EN Figure 316: Signal flow between apparatus control functions with XCBR and XSWI located in a breaker IED...
Page 690 Section 15 1MRK 506 369-UUS - Control Control operation can be performed from the local IED HMI. If users are defined in the IED, then the local/remote switch is under authority control, otherwise the default user can perform control operations from the local IED HMI without logging in. The default position of the local/remote switch is on remote.
Page 691: Bay Control Qcbay
Section 15 1MRK 506 369-UUS - Control 15.3.1.1 Bay control QCBAY The Bay control (QCBAY) is used to handle the selection of the operator place per bay. The function gives permission to operate from two main types of locations either from Remote (for example, control centre or station HMI) or from Local (local HMI on the IED) or from all (Local and Remote).
Page 692: Switch Controller Scswi
Section 15 1MRK 506 369-UUS - Control 15.3.1.2 Switch controller SCSWI 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 693: Proxy For Signals From Switching Device Via Goose Xlnproxy
Section 15 1MRK 506 369-UUS - Control The purpose of these functions is to provide the actual status of positions and to perform the control operations, that is, pass all the commands to the primary apparatus via output boards and to supervise the switching operation and position. Switches have the following functionalities: •...
Page 694 Section 15 1MRK 506 369-UUS - Control IEC16000071 V1 EN Figure 318: Configuration with XLNPROXY and GOOSEXLNRCV where all the IEC 61850 modelled data is used, including selection Line distance protection REL670 2.2 ANSI Application manual...
Page 695 Section 15 1MRK 506 369-UUS - Control IEC16000072 V1 EN Figure 319: Configuration with XLNPROXY and GOOSEXLNRCV where only the mandatory data in the IEC 61850 modelling is used All the information from the XLNPROXY to the SCSWI about command following status, causes for failed command and selection status is transferred in the output XPOS.
Page 696: Reservation Function (Qcrsv And Resin)
Section 15 1MRK 506 369-UUS - Control Table 50: Possible cause values from XLNPROXY Cause No Cause Description Conditions Blocked-by-Mode The BEH input is 5. Blocked-by-switching-hierarchy The LOC input indicates that only local commands are allowed for the breaker IED function. Blocked-for-open-cmd The BLKOPN is active indicating that the switch is blocked for open commands.
Page 697 Section 15 1MRK 506 369-UUS - Control wants the reservation sends a reservation request to other bays and then waits for a reservation granted signal from the other bays. Actual position indications from these bays are then transferred over the station bus for evaluation in the IED. After the evaluation the operation can be executed with high security.
Page 698: Interaction Between Modules
Section 15 1MRK 506 369-UUS - Control SCSWI RES_ EXT SELECTED Other SCSWI in the bay en 05000118_ ansi. vsd ANSI05000118 V2 EN Figure 321: Application principles for reservation with external wiring The solution in Figure can also be realized over the station bus according to the application example in Figure 322.
Page 699 Section 15 1MRK 506 369-UUS - Control • The Switch controller (SCSWI) initializes all operations for one apparatus. It is the command interface of the apparatus. It includes the position reporting as well as the control of the position • The Circuit breaker (SXCBR) is the process interface to the circuit breaker for the apparatus control function.
Page 700 Section 15 1MRK 506 369-UUS - Control Synchronizing OK SMPPTRC SESRSYN (Trip logic) (Synchrocheck & Synchronizer) Trip QCBAY Operator place (Bay control) selection Open cmd Close cmd SCSWI SXCBR Res. req. (Switching control) (Circuit breaker) Res. granted QCRSV (Reservation) Res. req. Close CB SMBRREC (Auto-...
Page 701: Setting Guidelines
Section 15 1MRK 506 369-UUS - Control SMPPTRC ZMQPDIS SECRSYN (Trip logic) (Synchrocheck) (Distance) Trip Synchrocheck QCBAY Operator place (Bay control) selection Open cmd Close cmd Res. req. SCSWI SXCBR (Switching control) Res. granted (Circuit breaker) QCRSV (Reservation) Res. req. Close CB SMBRREC (Auto-...
Page 702: Bay Control (Qcbay)
Section 15 1MRK 506 369-UUS - Control 15.3.3.1 Bay control (QCBAY) If the parameter AllPSTOValid is set to No priority, all originators from local and remote are accepted without any priority. If the parameter RemoteIncStation is set to Yes, commands from IEC 61850-8-1 clients at both station and remote level are accepted, when the QCBAY function is in Remote.
Page 703: Switch (Sxcbr/Sxswi)
Section 15 1MRK 506 369-UUS - Control function. If tSynchrocheck is set to 0, no synchrocheck is done, before starting the synchronizing function. The timer tSynchronizing supervises that the signal synchronizing in progress is obtained in SCSWI after start of the synchronizing function. The start signal for the synchronizing is set if the synchronism check conditions are not fulfilled.
Page 704: Proxy For Signals From Switching Device Via Goose Xlnproxy
Section 15 1MRK 506 369-UUS - Control tClosePulse is the output pulse length for a close command. If AdaptivePulse is set to Adaptive, it is the maximum length of the output pulse for an open command. The default length is set to 200 ms for a circuit breaker (SXCBR) and 500 ms for a disconnector (SXSWI).
Page 705: Reservation Input (Resin)
Section 15 1MRK 506 369-UUS - Control reservation request of other bays (RES_BAYS) will not be activated at selection of apparatus x. 15.3.3.6 Reservation input (RESIN) With the FutureUse parameter set to Bay future use the function can handle bays not yet installed in the SA system.
Page 706: Configuration Guidelines
Section 15 1MRK 506 369-UUS - Control The positions of all switching devices in a bay and from some other bays determine the conditions for operational interlocking. Conditions from other stations are usually not available. Therefore, a line grounding switch is usually not fully interlocked. The operator must be convinced that the line is not energized from the other side before closing the grounding switch.
Page 707: Application
Section 15 1MRK 506 369-UUS - Control 15.4.2.1 Application The interlocking for line bay (ABC_LINE, 3) function is used for a line connected to a double busbar arrangement with a transfer busbar according to figure 324. The function can also be used for a double busbar arrangement without transfer busbar or a single busbar arrangement with/without transfer busbar.
Page 708: Signals From Bus-Coupler
Section 15 1MRK 506 369-UUS - Control For bay n, these conditions are valid: 789OPTR (bay 1) BB7_D_OP 789OPTR (bay 2) ..789OPTR (bay n-1) VP789TR (bay 1) VP_BB7_D VP789TR (bay 2) ..
Page 709 Section 15 1MRK 506 369-UUS - Control Signal BC_12_CL A bus-coupler connection exists between busbar WA1 and WA2. BC_17_OP No bus-coupler connection between busbar WA1 and WA7. BC_17_CL A bus-coupler connection exists between busbar WA1and WA7. BC_27_OP No bus-coupler connection between busbar WA2 and WA7. BC_27_CL A bus-coupler connection exists between busbar WA2 and WA7.
Page 710 Section 15 1MRK 506 369-UUS - Control If the busbar is divided by bus-section circuit breakers, the signals from the bus-section coupler bay (A1A2_BS), rather than the bus-section disconnector bay (A1A2_DC) must be used. For B1B2_BS, corresponding signals from busbar B are used. The same type of module (A1A2_BS) is used for different busbars, that is, for both bus-section circuit breakers A1A2_BS and B1B2_BS.
Page 711 Section 15 1MRK 506 369-UUS - Control BC12CLTR (sect.1) BC_12_CL DCCLTR (A1A2) DCCLTR (B1B2) BC12CLTR (sect.2) VPBC12TR (sect.1) VP_BC_12 VPDCTR (A1A2) VPDCTR (B1B2) VPBC12TR (sect.2) BC17OPTR (sect.1) BC_17_OP DCOPTR (A1A2) BC17OPTR (sect.2) BC17CLTR (sect.1) BC_17_CL DCCLTR (A1A2) BC17CLTR (sect.2) VPBC17TR (sect.1) VP_BC_17 VPDCTR (A1A2) VPBC17TR (sect.2)
Page 712: Configuration Setting
Section 15 1MRK 506 369-UUS - Control 15.4.2.4 Configuration setting If there is no bypass busbar and therefore no 789 disconnector, then the interlocking for 789 is not used. The states for 789, 7189G, BB7_D, BC_17, BC_27 are set to open by setting the appropriate module inputs as follows.
Page 713: Interlocking For Bus-Coupler Bay Abc_Bc (3)
Section 15 1MRK 506 369-UUS - Control 15.4.3 Interlocking for bus-coupler bay ABC_BC (3) 15.4.3.1 Application The interlocking for bus-coupler bay (ABC_BC, 3) function is used for a bus-coupler bay connected to a double busbar arrangement according to figure 328. The function can also be used for a single busbar arrangement with transfer busbar or double busbar arrangement without transfer busbar.
Page 714 Section 15 1MRK 506 369-UUS - Control Signal Q1289OPTR 189 or 289 or both are open. VP1289TR The switch status of 189 and 289 are valid. EXDU_12 No transmission error from the bay that contains the above information. For bus-coupler bay n, these conditions are valid: 1289OPTR (bay 1) BBTR_OP 1289OPTR (bay 2)
Page 715 Section 15 1MRK 506 369-UUS - Control The following signals from each bus-section disconnector bay (A1A2_DC) are 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.
Page 716: Signals From Bus-Coupler
Section 15 1MRK 506 369-UUS - Control For a bus-coupler bay in section 2, the same conditions as above are valid by changing section 1 to section 2 and vice versa. 15.4.3.4 Signals from bus-coupler If the busbar is divided by bus-section disconnectors into bus-sections, the signals BC_12 from the busbar coupler of the other busbar section must be transmitted to the own busbar coupler if both disconnectors are closed.
Page 717: Configuration Setting
Section 15 1MRK 506 369-UUS - Control Signal DCCLTR The bus-section disconnector is closed. VPDCTR The switch status of bus-section disconnector DC is valid. EXDU_DC No transmission error from the bay that contains the above information. If the busbar is divided by bus-section circuit breakers, the signals from the bus-section coupler bay (A1A2_BS), rather than the bus-section disconnector bay (A1A2_DC), must be used.
Page 718: Interlocking For Transformer Bay Ab_Trafo (3)
Section 15 1MRK 506 369-UUS - Control setting the appropriate module inputs as follows. In the functional block diagram, 0 and 1 are designated 0=FALSE and 1=TRUE: • 289_OP = 1 • 289_CL = 0 • 789_OP = 1 • 789_CL = 0 •...
Page 719: Signals From Bus-Coupler
Section 15 1MRK 506 369-UUS - Control WA1 (A) WA2 (B) 189G AB_TRAFO 289G 389G 252 and 489G are not used in this interlocking 489G en04000515_ansi.vsd ANSI04000515 V1 EN Figure 334: Switchyard layout AB_TRAFO (3) The signals from other bays connected to the module AB_TRAFO are described below. 15.4.4.2 Signals from bus-coupler If the busbar is divided by bus-section disconnectors into bus-sections, the busbar-busbar...
Page 720: Configuration Setting
Section 15 1MRK 506 369-UUS - Control Section 1 Section 2 (WA1)A1 (WA2)B1 (WA7)C A1A2_DC(BS) B1B2_DC(BS) AB_TRAFO ABC_BC AB_TRAFO ABC_BC en04000487_ansi.vsd ANSI04000487 V1 EN Figure 335: Busbars divided by bus-section disconnectors (circuit breakers) The project-specific logic for input signals concerning bus-coupler are the same as the specific logic for the line bay (ABC_LINE): Signal BC_12_CL...
Page 721: Interlocking For Bus-Section Breaker A1A2_Bs (3)
Section 15 1MRK 506 369-UUS - Control If there is no second busbar B at the other side of the transformer and therefore no 489 disconnector, then the state for 489 is set to open by setting the appropriate module inputs as follows: •...
Page 722 Section 15 1MRK 506 369-UUS - Control Section 1 Section 2 (WA1)A1 (WA2)B1 (WA7)C A1A2_BS B1B2_BS ABC_BC ABC_BC ABC_LINE AB_TRAFO ABC_LINE AB_TRAFO en04000489_ansi.vsd ANSI04000489 V1 EN Figure 337: Busbars divided by bus-section circuit breakers To derive the signals: Signal BBTR_OP No busbar transfer is in progress concerning this bus-section.
Page 723 Section 15 1MRK 506 369-UUS - Control For a bus-section circuit breaker between A1 and A2 section busbars, these conditions are valid: S1S2OPTR (B1B2) BC12OPTR (sect.1) 1289OPTR (bay 1/sect.2) . . . BBTR_OP . . . 1289OPTR (bay n/sect.2) S1S2OPTR (B1B2) BC12OPTR (sect.2) 1289OPTR (bay 1/sect.1) .
Page 724: Configuration Setting
Section 15 1MRK 506 369-UUS - Control S1S2OPTR (A1A2) BC12OPTR (sect.1) 1289OPTR (bay 1/sect.2) . . . BBTR_OP . . . 1289OPTR (bay n/sect.2) S1S2OPTR (A1A2) BC12OPTR (sect.2) 1289OPTR (bay 1/sect.1) ..1289OPTR (bay n /sect.1) VPS1S2TR (A1A2) VPBC12TR (sect.1) VP1289TR (bay 1/sect.2)
Page 725: Interlocking For Bus-Section Disconnector A1A2_Dc (3)
Section 15 1MRK 506 369-UUS - Control 15.4.6 Interlocking for bus-section disconnector A1A2_DC (3) 15.4.6.1 Application The interlocking for bus-section disconnector (A1A2_DC, 3) function is used for one bus- section disconnector between section 1 and 2 according to figure 340. A1A2_DC (3) function can be used for different busbars, which includes a bus-section disconnector.
Page 726 Section 15 1MRK 506 369-UUS - Control 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. EXDU_BB No transmission error from any bay that contains the above information.
Page 727 Section 15 1MRK 506 369-UUS - Control For a bus-section disconnector, these conditions from the A1 busbar section are valid: 189OPTR (bay 1/sect.A1) S1DC_OP ..189OPTR (bay n/sect.A1) VP189TR (bay 1/sect.A1) VPS1_DC .
Page 728 Section 15 1MRK 506 369-UUS - Control 289OPTR (22089OTR)(bay 1/sect.B1) S1DC_OP ..289OPTR (22089OTR)(bay n/sect.B1) VP289TR (V22089TR)(bay 1/sect.B1) VPS1_DC ..VP289TR (V22089TR)(bay n/sect.B1) EXDU_BB (bay 1/sect.B1) EXDU_BB .
Page 729: Signals In Double-Breaker Arrangement
Section 15 1MRK 506 369-UUS - Control 15.4.6.3 Signals in double-breaker arrangement If the busbar is divided by bus-section disconnectors, the condition for the busbar disconnector bay no other disconnector connected to the bus-section must be made by a project-specific logic. The same type of module (A1A2_DC) is used for different busbars, that is, for both bus- section disconnector A1A2_DC and B1B2_DC.
Page 730 Section 15 1MRK 506 369-UUS - Control The logic is identical to the double busbar configuration “Signals in single breaker arrangement”. For a bus-section disconnector, these conditions from the A1 busbar section are valid: 189OPTR (bay 1/sect.A1) S1DC_OP ..
Page 731: Signals In Breaker And A Half Arrangement
Section 15 1MRK 506 369-UUS - Control 289OPTR (bay 1/sect.B1) S1DC_OP ..289OPTR (bay n/sect.B1) VP289TR (bay 1/sect.B1) VPS1_DC ..VP289TR (bay n/sect.B1) EXDU_DB (bay 1/sect.B1) EXDU_BB .
Page 732: Interlocking For Busbar Grounding Switch Bb_Es (3)
Section 15 1MRK 506 369-UUS - Control Section 1 Section 2 (WA1)A1 (WA2)B1 A1A2_DC(BS) B1B2_DC(BS) BH_LINE BH_LINE BH_LINE BH_LINE en04000503_ansi.vsd ANSI04000503 V1 EN Figure 351: Busbars divided by bus-section disconnectors (circuit breakers) 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.
Page 733: Signals In Single Breaker Arrangement
Section 15 1MRK 506 369-UUS - Control 15.4.7.2 Signals in single breaker arrangement The busbar grounding switch is only allowed to operate if all disconnectors of the bus- section are open. Section 1 Section 2 (WA1)A1 (WA2)B1 (WA7)C A1A2_DC(BS) B1B2_DC(BS) BB_ES ABC_BC BB_ES...
Page 734 Section 15 1MRK 506 369-UUS - Control Signal DCOPTR The bus-section disconnector is open. VPDCTR The switch status of bus-section disconnector DC is valid. EXDU_DC No transmission error from the bay that contains the above information. If no bus-section disconnector exists, the signal DCOPTR, VPDCTR and EXDU_DC are set to 1 (TRUE).
Page 735 Section 15 1MRK 506 369-UUS - Control 189OPTR (bay 1/sect.A2) BB_DC_OP ..189OPTR (bay n/sect.A2) DCOPTR (A1/A2) VP189TR (bay 1/sect.A2) VP_BB_DC ..VP189TR (bay n/sect.A2) VPDCTR (A1/A2) EXDU_BB (bay 1/sect.A2) .
Page 736 Section 15 1MRK 506 369-UUS - Control 289OPTR(22089OTR)(bay 1/sect.B1) BB_DC_OP ..289PTR (22089OTR)(bay n/sect.B1) DCOPTR (B1/B2) VP289TR(V22089TR) (bay 1/sect.B1) VP_BB_DC ..VP289TR(V22089TR) (bay n/sect.B1) VPDCTR (B1/B2) EXDU_BB (bay 1/sect.B1) .
Page 737 Section 15 1MRK 506 369-UUS - Control 289OPTR(22089OTR) (bay 1/sect.B2) BB_DC_OP ..289OPTR(22089OTR) (bay n/sect.B2) DCOPTR (B1/B2) VP289TR(V22089TR) (bay 1/sect.B2) VP_BB_DC ..VP289TR(V22089TR) (bay n/sect.B2) VPDCTR (B1/B2) EXDU_BB (bay 1/sect.B2) .
Page 738: Signals In Double-Breaker Arrangement
Section 15 1MRK 506 369-UUS - Control 15.4.7.3 Signals in double-breaker arrangement The busbar grounding switch is only allowed to operate if all disconnectors of the bus section are open. Section 1 Section 2 (WA1)A1 (WA2)B1 A1A2_DC(BS) B1B2_DC(BS) BB_ES BB_ES DB_BUS DB_BUS en04000511_ansi.vsd...
Page 739: Signals In Breaker And A Half Arrangement
Section 15 1MRK 506 369-UUS - Control The logic is identical to the double busbar configuration described in section “Signals in single breaker arrangement”. 15.4.7.4 Signals in breaker and a half arrangement The busbar grounding switch is only allowed to operate if all disconnectors of the bus- section are open.
Page 740: Configuration Setting
Section 15 1MRK 506 369-UUS - Control WA1 (A) WA2 (B) 189G 489G DB_BUS_B DB_BUS_A 289G 589G 6189 6289 389G DB_LINE 989G en04000518_ansi.vsd ANSI04000518 V1 EN Figure 361: Switchyard layout double circuit breaker Three types of interlocking modules per double circuit breaker bay are defined. DB_BUS_A (3) handles the circuit breaker QA1 that is connected to busbar WA1 and the disconnectors and grounding switches of this section.
Page 741: Interlocking For Breaker-And-A-Half Diameter Bh (3)
Section 15 1MRK 506 369-UUS - Control If, in this case, line voltage supervision is added, then rather than setting 989 to open state, specify the state of the voltage supervision: • 989_OP = VOLT_OFF • 989_CL = VOLT_ON If there is no voltage supervision, then set the corresponding inputs as follows: •...
Page 742: Configuration Setting
Section 15 1MRK 506 369-UUS - Control WA1 (A) WA2 (B) 189G 189G 289G 289G 389G 389G BH_LINE_B BH_LINE_A 6189 6289 289G 189G 989G 989G BH_CONN en04000513_ansi.vsd ANSI04000513 V1 EN Figure 362: Switchyard layout breaker-and-a-half Three types of interlocking modules per diameter are defined. BH_LINE_A (3) and BH_LINE_B (3) are the connections from a line to a busbar.
Page 743: Logic Rotating Switch For Function Selection And Lhmi Presentation Slgapc
Section 15 1MRK 506 369-UUS - Control • 989G_OP = 1 • 989G_CL = 0 If, in this case, line voltage supervision is added, then rather than setting 989 to open state, specify the state of the voltage supervision: • 989_OP = VOLT_OFF •...
Page 744: Setting Guidelines
Section 15 1MRK 506 369-UUS - Control the number of positions of the switch can be established by settings (see below), one must be careful in coordinating the settings with the configuration (if one sets the number of positions to x in settings – for example, there will be only the first x outputs available from the block in the configuration).
Page 745: Setting Guidelines
Section 15 1MRK 506 369-UUS - Control VSGAPC can be used for both acquiring an external switch position (through the IPOS1 and the IPOS2 inputs) and represent it through the single line diagram symbols (or use it in the configuration through the outputs POS1 and POS2) as well as, a command function (controlled by the PSTO input), giving switching commands through the CMDPOS12 and CMDPOS21 outputs.
Page 746: Application
Section 15 1MRK 506 369-UUS - Control 15.7.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Generic communication function for DPGAPC Double Point indication 15.7.2 Application 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 747: Setting Guidelines
Section 15 1MRK 506 369-UUS - Control 15.7.3 Setting guidelines The function does not have any parameters available in the local HMI or PCM600. 15.8 Single point generic control 8 signals SPC8GAPC 15.8.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification...
Page 748: Automationbits, Command Function For Dnp3.0 Autobits
Section 15 1MRK 506 369-UUS - Control 15.9 AutomationBits, command function for DNP3.0 AUTOBITS 15.9.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number AutomationBits, command function for AUTOBITS DNP3 15.9.2 Application Automation bits, command function for DNP3 (AUTOBITS) is used within PCM600 in order to get into the configuration the commands coming through the DNP3.0 protocol.The AUTOBITS function plays the same role as functions GOOSEBINRCV (for IEC 61850) and MULTICMDRCV (for LON).AUTOBITS function block have 32...
Page 749: Identification
Section 15 1MRK 506 369-UUS - Control 15.10.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Single command, 16 signals SINGLECMD 15.10.2 Application Single command, 16 signals (SINGLECMD) is a common function and always included in the IED.
Page 750 Section 15 1MRK 506 369-UUS - Control Single command function Function n SINGLECMD Function n CMDOUTy OUTy en04000207.vsd IEC04000207 V2 EN Figure 365: Application example showing a logic diagram for control of built-in functions Single command function Configuration logic circuits SINGLESMD Device 1 CMDOUTy...
Page 751: Setting Guidelines
Section 15 1MRK 506 369-UUS - Control 15.10.3 Setting guidelines The parameters for Single command, 16 signals (SINGLECMD) are set via the local HMI or PCM600. Parameters to be set are MODE, common for the whole block, and CMDOUTy which includes the user defined name for each output signal.
Page 753: Scheme Communication Logic For Distance Or Overcurrent Protection Zcpsch(85)
Section 16 1MRK 506 369-UUS - Scheme communication Section 16 Scheme communication 16.1 Scheme communication logic for distance or overcurrent protection ZCPSCH(85) 16.1.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Scheme communication logic for ZCPSCH distance or overcurrent protection 16.1.2...
Page 754: Blocking Schemes
Section 16 1MRK 506 369-UUS - Scheme communication A permissive scheme is inherently faster and has better security against false tripping than a blocking scheme. On the other hand, a permissive scheme depend on a received CR signal for a fast trip, so its dependability is lower than that of a blocking scheme. 16.1.2.1 Blocking schemes In a blocking scheme a reverse looking zone is used to send a block signal to the remote...
Page 755: Delta Blocking Scheme
Section 16 1MRK 506 369-UUS - Scheme communication Z rev TRIP = OR + tCoord+ CR Z rev IEC09000015_2_en.vsd IEC09000015 V2 EN Figure 367: Principle of blocking scheme Overreaching Communication signal received Communication signal send Z rev : Reverse zone 16.1.2.2 Delta blocking scheme In the delta blocking scheme a fault inception detection element using delta based...
Page 756: Permissive Schemes
Section 16 1MRK 506 369-UUS - Scheme communication Since the blocking signal is initiated by the delta based detection which is very fast the time delay tCoord can be set to zero seconds, except in cases where the transmission channel is slow. The timer tSendMin for prolonging the send signal is proposed to set to zero.
Page 757 Section 16 1MRK 506 369-UUS - Scheme communication The underreaching zones at the local and remote end(s) must overlap in reach to prevent a gap between the protection zones where faults would not be detected. If the underreaching zone do not meet the required sensitivity due to for instance fault infeed from the remote end, a blocking or permissive overreaching scheme should be considered.
Page 758 Section 16 1MRK 506 369-UUS - Scheme communication Permissive overreaching scheme In a permissive overreaching scheme there is an overreaching zone that issues the send signal. At the remote end the received signal together with the start of an overreaching zone will give an instantaneous trip.
Page 759: Intertrip Scheme
Section 16 1MRK 506 369-UUS - Scheme communication TRIP = OR + CR + T2 IEC09000014-1-en.vsd IEC09000014 V1 EN Figure 370: Principle of Permissive overreaching scheme OR: Overreaching CR: Communication signal received Communication signal send Timer step 2 Unblocking scheme Metallic communication paths adversely affected by fault generated noise may not be suitable for conventional permissive schemes that rely on a signal transmitted during a protected line fault.
Page 760: Setting Guidelines
Section 16 1MRK 506 369-UUS - Scheme communication In an intertrip scheme, the send signal is initiated by an underreaching zone or from an external protection (transformer or reactor protection). At the remote end, the received signals initiate a trip without any further protection criteria. To limit the risk for an unwanted trip due to the spurious sending of signals, the timer tCoord should be set to 10-30 ms dependant on the type of communication channel.
Page 761: Permissive Underreaching Scheme
Section 16 1MRK 506 369-UUS - Scheme communication Unblock Disabled (Set to NoRestart if Unblocking scheme with no alarm for loss of guard is to be used. Restart if Unblocking scheme with alarm for loss of guard is to be used) Set to tSecurity = 0.035 s...
Page 762: Intertrip Scheme
Section 16 1MRK 506 369-UUS - Scheme communication 16.1.3.6 Intertrip scheme Operation Enabled SchemeType Intertrip tCoord = 50 ms (10 ms + maximal transmission time) tSendMin = 0.1 s (0 s in parallel line applications) Unblock Disabled tSecurity = 0.015 s 16.2 Phase segregated scheme communication logic for distance protection ZC1PPSCH (85)
Page 763 Section 16 1MRK 506 369-UUS - Scheme communication during power system faults, the time during which the protection schemes must perform their tasks flawlessly. The logic supports the following communications schemes: • blocking scheme • permissive schemes (overreach and underreach) •...
Page 764: Blocking Scheme
Section 16 1MRK 506 369-UUS - Scheme communication protection IED. A correct single-pole trip can be achieved on both lines and at both line IEDs. ZC1PPSCH (85) requires three individual channels between the protection IEDs on each line in both directions. In case of single-phase faults, only one channel is activated at a time.
Page 765 Section 16 1MRK 506 369-UUS - Scheme communication Depending on if the sending signal(s) is issued by underreaching or overreaching zone, it is divided into Permissive underreach (PUR) or Permissive overreach (POR) scheme. Permissive underreach scheme Permissive underreach scheme is not suitable to use on short line length due to difficulties for distance protection measurement in general to distinguish between internal and external faults in those applications.
Page 766: Intertrip Scheme
Section 16 1MRK 506 369-UUS - Scheme communication subjected to this type of interference, therefore, they must be properly shielded or otherwise designed to provide an adequate communication signal during power system faults. At the permissive overreaching scheme, the carrier send signal (CS) might be issued in parallel both from an overreaching zone and an underreaching, independent tripping zone.
Page 767: Permissive Underreache Scheme
Section 16 1MRK 506 369-UUS - Scheme communication 16.2.3.1 Permissive underreache scheme Operation Scheme Permissive UR type tCoord 0 ms tSendMin 0.1 s 16.2.3.2 Permissive overreach scheme Operation Scheme Permissive OR type tCoord 0 ms tSendMin 0.1 s 16.2.3.3 Blocking scheme Operation Scheme Blocking...
Page 768: Current Reversal And Weak-End Infeed Logic For Distance Protection 3-Phase Zcrwpsch (85)
Section 16 1MRK 506 369-UUS - Scheme communication 16.3 Current reversal and Weak-end infeed logic for distance protection 3-phase ZCRWPSCH (85) 16.3.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Current reversal and weak-end infeed ZCRWPSCH logic for distance protection 3-phase 16.3.2...
Page 769: Weak-End Infeed Logic
Section 16 1MRK 506 369-UUS - Scheme communication CLOSED FAULT OPEN LINE 1 Weak Strong source source CLOSED CLOSED LINE 2 en99000044_ansi.vsd ANSI99000044 V1 EN Figure 373: Current distribution for a fault close to B side when breaker B1 has opened To handle this the send signal CS or CSLn from B2 is held back until the reverse zone IRVLn has reset and the tDelayRev time has been elapsed.
Page 770: Setting Guidelines
Section 16 1MRK 506 369-UUS - Scheme communication • Only the trip part of the function can be used together with the blocking scheme. It is not possible to use the echo function to send the echo signal to the remote line IED. The echo signal would block the operation of the distance protection at the remote line end and in this way prevents the correct operation of a complete protection scheme.
Page 771: Current Reversal And Weak-End Infeed Logic For Phase Segregated Communication Zc1Wpsch (85)
Section 16 1MRK 506 369-UUS - Scheme communication When single pole tripping is required, a detailed study of the voltages during phase-to-phase and phase-to-ground faults should be done, at different fault locations. 16.4 Current reversal and weak-end infeed logic for phase segregated communication ZC1WPSCH (85) 16.4.1 Identification...
Page 772 Section 16 1MRK 506 369-UUS - Scheme communication When the breaker B1 opens for clearing the fault, the fault current through B2 bay will invert. If the communication signal has not reset at the same time as the distance protection function used in the teleprotection scheme has switched on to forward direction, we will have an unwanted operation of breaker B2 at B side.
Page 773: Setting Guidelines
Section 16 1MRK 506 369-UUS - Scheme communication line end and in this way prevents the correct operation of a complete protection scheme. • A separate direct intertrip channel must be arranged from remote end when a trip or accelerated trip is given there. The intertrip receive signal is connected to input CRL. •...
Page 774: Local Acceleration Logic Zclcpsch
Section 16 1MRK 506 369-UUS - Scheme communication When single phase tripping is required a detailed study of the voltages at phase-to-phase respectively phase-to-earth faults, at different fault locations, is normally required. 16.5 Local acceleration logic ZCLCPSCH 16.5.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2...
Page 775: Scheme Communication Logic For Residual Overcurrent Protection Ecpsch (85)
Section 16 1MRK 506 369-UUS - Scheme communication LoadCurr must be set below the current that will flow on the healthy phase when one or two of the other phases are faulty and the breaker has opened at remote end (three-phase). Calculate the setting according to equation 534.
Page 776: Application
Section 16 1MRK 506 369-UUS - Scheme communication 16.6.2 Application To achieve fast fault clearance of ground faults on the part of the line not covered by the instantaneous step of the residual overcurrent protection, the directional residual overcurrent protection can be supported with a logic that uses communication channels. One communication channel is used in each direction, which can transmit an on/off signal if required.
Page 777: Current Reversal And Weak-End Infeed Logic For Residual Overcurrent Protection Ecrwpsch (85)
Section 16 1MRK 506 369-UUS - Scheme communication Operation: Disabled or Enabled. SchemeType: This parameter can be set to Off , Intertrip, Permissive UR, Permissive OR or Blocking. tCoord: Delay time for trip from ECPSCH (85) function. For Permissive under/ overreaching schemes, this timer shall be set to at least 20 ms plus maximum reset time of the communication channel as a security margin.
Page 778: Weak-End Infeed Logic
Section 16 1MRK 506 369-UUS - Scheme communication CLOSED CLOSED FAULT LINE 1 Weak Strong source source CLOSED CLOSED LINE 2 en99000043_ansi.vsd ANSI99000043 V1 EN Figure 376: Current distribution for a fault close to B side when all breakers are closed CLOSED FAULT OPEN...
Page 779: Setting Guidelines
Section 16 1MRK 506 369-UUS - Scheme communication Strong Weak CLOSED CLOSED source source FAULT LINE 1 en99000054_ansi.vsd ANSI99000054 V1 EN Figure 378: Initial condition for weak-end infeed 16.7.3 Setting guidelines The parameters for the current reversal and weak-end infeed logic for residual overcurrent protection function are set via the local HMI or PCM600.
Page 780: Weak-End Infeed
Section 16 1MRK 506 369-UUS - Scheme communication If the teleprotection equipment is integrated in the protection IED the decision time can be slightly reduced. The principle time sequence of signaling at current reversal is shown. Tele- Tele- Tele- Protection Protection Protection communication...
Page 781: Direct Transfer Trip Logic
Section 16 1MRK 506 369-UUS - Scheme communication 16.8 Direct transfer trip logic 16.8.1 Application The main purpose of the direct transfer trip (DTT) scheme is to provide a local criterion check on receiving a transfer trip signal from remote end before tripping the local end CB. A typical application for this scheme is a power transformer directly connected, without circuit breaker, to the feeding line.
Page 782: Setting Guidelines
Section 16 1MRK 506 369-UUS - Scheme communication The trip signal from local criterion will ensure the fault at the remote end and release the trip signal to the local side circuit breaker. The local criterion must detect the abnormal conditions and permit the CR signal to trip the circuit breaker.
Page 783: Identification
Section 16 1MRK 506 369-UUS - Scheme communication 16.8.3 Low active power and power factor protection LAPPGAPC (37_55) 16.8.3.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Low active power and power factor LAPPGAPC 37_55 protection 16.8.3.2 Application...
Page 784: Identification
Section 16 1MRK 506 369-UUS - Scheme communication TRIP signal if two or more phases have low power. When the remote breaker has opened, there should theoretically be zero power at the protection measurement point. However, when fault current is fed to the fault point the power loss in the fault will be detected. For operation for all unsymmetrical faults 1 out of 3 should be selected.
Page 785 Section 16 1MRK 506 369-UUS - Scheme communication Long transmission line draws substantial quantity of charging current. If such a line is open circuited or lightly loaded at the remote end, the voltage at remote end may exceeds local end voltage. This is known as Ferranti effect and is due to the voltage drop across the line inductance (due to charging current) being in phase with the local end voltages.
Page 786 Section 16 1MRK 506 369-UUS - Scheme communication The trip signal issued by compensated over and under voltage function should be accompanied by a transfer trip signal received from the remote end. The trip signal should be used as a release signal which can permit a remote transfer trip to be used to trip the local circuit breaker.
Page 787: Setting Guidelines
Section 16 1MRK 506 369-UUS - Scheme communication Breaker Status ANSI09000775-1-en.vsd ANSI09000775 V1 EN Figure 383: Breaker status configured with IED 16.8.4.3 Setting guidelines GlobalBaseSel: Selects the global base value group used by the function to define IBase, VBase and SBase as applicable. OperationUV: Used to set the under-voltage function Enabled or Disabled.
Page 788: Sudden Change In Current Variation Sccvptoc (51)
Section 16 1MRK 506 369-UUS - Scheme communication EnShuntReactor: Set Enabled or Disabled to enable the charging current to be involved in the voltage compensation calculation. Xsh: Per phase reactance of the line connected shunt reactor given in ohm. 16.8.5 Sudden change in current variation SCCVPTOC (51) 16.8.5.1 Identification...
Page 789: Carrier Receive Logic Lccrptrc (94)
Section 16 1MRK 506 369-UUS - Scheme communication 16.8.6 Carrier receive logic LCCRPTRC (94) 16.8.6.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Carrier receive logic LCCRPTRC 16.8.6.2 Application In the Direct transfer trip scheme, the received CR signal gives the trip to the circuit breaker after checking certain local criteria functions in order to increase the security of the overall tripping functionality.
Page 790: Application
Section 16 1MRK 506 369-UUS - Scheme communication 16.8.7.2 Application Negative sequence symmetrical components are present in all types of fault condition. In case of three phase short circuits the negative sequence voltages and current have transient nature and will therefore decline to zero after some periods. Negative sequence overvoltage protection (LCNSPTOV, 47) is a definite time stage comparator function.
Page 791: Application
Section 16 1MRK 506 369-UUS - Scheme communication 16.8.8.2 Application Zero sequence symmetrical components are present in all abnormal conditions involving ground. They have a considerably high value during ground faults. Zero sequence overvoltage protection (LCZSPTOV, 59N) is a definite time stage comparator function.
Page 792: Identification
Section 16 1MRK 506 369-UUS - Scheme communication 16.8.9.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Negative sequence overcurrent LCNSPTOC protection 16.8.9.2 Application Negative sequence symmetrical components are present in all types of fault condition. Negative sequence overcurrent protection (LCNSPTOC, 46) is a definite time stage comparator function.
Page 793: Identification
Section 16 1MRK 506 369-UUS - Scheme communication 16.8.10.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Zero sequence overcurrent protection LCZSPTOC 16.8.10.2 Application Zero sequence symmetrical components are present in all abnormal conditions involving ground.
Page 794: Application
Section 16 1MRK 506 369-UUS - Scheme communication 16.8.11.2 Application Three phase overcurrent (LCP3PTOC, 51) is designed for detecting over current conditions due to fault or any other abnormality in the system. LCP3PTOC (51) could be used as a back up for other local criterion checks. 16.8.11.3 Setting guidelines GlobalBaseSel: Selects the global base value group used by the function to define IBase,...
Page 795: Setting Guidelines
Section 16 1MRK 506 369-UUS - Scheme communication 16.8.12.3 Setting guidelines GlobalBaseSel: Selects the global base value group used by the function to define IBase, VBase and SBase as applicable. PU_37: Level of low phase current detection given in % of IBase. This setting is highly depending on the application and therefore can no general rules be given.
Page 797: Tripping Logic Smpptrc (94)
Section 17 1MRK 506 369-UUS - Logic Section 17 Logic 17.1 Tripping logic SMPPTRC (94) 17.1.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Tripping logic SMPPTRC 1 -> 0 IEC15000314 V1 EN 17.1.2 Application All trip signals from the different protection functions shall be routed through the trip logic.
Page 798: Three-Pole Tripping
Section 17 1MRK 506 369-UUS - Logic have single-pole tripping, while the slave breaker could have three-pole tripping and autoreclosing. In the case of a permanent fault, only one of the breakers has to be operated when the fault is energized a second time. In the event of a transient fault the slave breaker performs a three-pole reclosing onto the non-faulted line.
Page 799: Single- And/Or Three-Pole Tripping
Section 17 1MRK 506 369-UUS - Logic 17.1.2.2 Single- and/or three-pole tripping The single-/three-pole tripping will give single-pole tripping for single-phase faults and three-pole tripping for multi-phase fault. The operating mode is always used together with a single-phase autoreclosing scheme. The single-pole tripping can include different options and the use of the different inputs in the function block.
Page 800: Single-, Two- Or Three-Pole Tripping
Section 17 1MRK 506 369-UUS - Logic Other back-up functions are connected to the input TRINP_3P as described above for three-pole tripping. A typical connection for a single-pole tripping scheme is shown in figure 385. Protection functions with 3 SMPPTRC phase trip, for example time BLOCK TRIP...
Page 801: Lock-Out
Section 17 1MRK 506 369-UUS - Logic that the trip is two phases by connecting the output TR2P to the input TR2P in the SMBRREC (79) function. 17.1.2.4 Lock-out The SMPPTRC function block is provided with possibilities to initiate lock-out. The lock- out can be set to only activate the block closing output CLLKOUT or initiate the block closing output and also maintain the trip signal output TR3P (latched trip).
Page 802 Section 17 1MRK 506 369-UUS - Logic SMPPTRC BLOCK TRIP BLKLKOUT TR_A TRIN_3P TR_B TRINP_A TR_C TRINP_B TR1P TRINP_C TR2P PS_A TR3P PS_B CLLKOUT PS_C BFI_3P 1PTRZ BFI_A 1PTRGF BFI_B P3PTR BFI_C SETLKOUT SMAGAPC RSTLKOUT STARTCOMB BLOCK PROTECTION 1 BLOCK PU_DIR1 BFI_3P PU_DIR2...
Page 803: Blocking Of The Function Block
Section 17 1MRK 506 369-UUS - Logic The trip function (SMPPTRC) splits up the directional data as general output data for BFI_3P, BFI_A, BFI_B, BFI_C, FW and REV. All start and directional outputs are mapped to the logical node data model of the trip function and provided via the 61850 dirGeneral, DIRL1, DIRL2, DIRL3.
Page 804: Trip Matrix Logic Tmagapc
Section 17 1MRK 506 369-UUS - Logic tEvolvingFault: Secures two- or three-pole tripping depending on Program selection at evolving faults. 17.2 Trip matrix logic TMAGAPC 17.2.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Trip matrix logic TMAGAPC 17.2.2 Application...
Page 805: Logic For Group Alarm Almcalh
Section 17 1MRK 506 369-UUS - Logic 17.3 Logic for group alarm ALMCALH 17.3.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Logic for group alarm ALMCALH 17.3.2 Application Group alarm logic function ALMCALH is used to route alarm signals to different LEDs and/or output contacts on the IED.
Page 806: Logic For Group Indication Indcalh
Section 17 1MRK 506 369-UUS - Logic 17.5 Logic for group indication INDCALH 17.5.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Logic for group indication INDCALH 17.5.1.1 Application Group indication logic function INDCALH is used to route indication signals to different LEDs and/or output contacts on the IED.
Page 807: Setting Guidelines
Section 17 1MRK 506 369-UUS - Logic 17.6.2 Setting guidelines There are no settings for AND gates, OR gates, inverters or XOR gates. For normal On/Off delay and pulse timers the time delays and pulse lengths are set from the local HMI or via the PST tool. Both timers in the same logic block (the one delayed on pick-up and the one delayed on drop-out) always have a common setting value.
Page 808: Fixed Signal Function Block Fxdsign
Section 17 1MRK 506 369-UUS - Logic IEC09000310-2-en.vsd IEC09000310 V2 EN Figure 388: 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 809 Section 17 1MRK 506 369-UUS - Logic One FXDSIGN function block is included in all IEDs. Example for use of GRP_OFF signal in FXDSIGN The Restricted earth fault function REFPDIF (87N) can be used both for auto- transformers and normal transformers. When used for auto-transformers, information from both windings parts, together with the neutral point current, needs to be available to the function.
Page 810: Boolean 16 To Integer Conversion B16I
Section 17 1MRK 506 369-UUS - Logic 17.8 Boolean 16 to Integer conversion B16I 17.8.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Boolean 16 to integer conversion B16I 17.8.2 Application Boolean 16 to integer conversion function B16I is used to transform a set of 16 binary (logical) signals into an integer.
Page 811: Boolean To Integer Conversion With Logical Node Representation
Section 17 1MRK 506 369-UUS - Logic Name of input Type Default Description Value when Value when activated deactivated IN10 BOOLEAN Input 10 IN11 BOOLEAN Input 11 1024 IN12 BOOLEAN Input 12 2048 IN13 BOOLEAN Input 13 4096 IN14 BOOLEAN Input 14 8192 IN15...
Page 812: Integer To Boolean 16 Conversion Ib16
Section 17 1MRK 506 369-UUS - Logic Values of each of the different OUTx from function block BTIGAPC for 1≤x≤16. The sum of the value on each INx corresponds to the integer presented on the output OUT on the function block BTIGAPC. Name of input Type Default...
Page 813: Application
Section 17 1MRK 506 369-UUS - Logic 17.10.2 Application Integer to boolean 16 conversion function (IB16) is used to transform an integer into a set of 16 binary (logical) signals. It can be used – for example, to connect integer output signals from one function to binary (logical) inputs to another function.
Page 814: Integer To Boolean 16 Conversion With Logic Node Representation It Bgapc
Section 17 1MRK 506 369-UUS - 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 IB16 function block. 17.11 Integer to Boolean 16 conversion with logic node representation ITBGAPC...
Page 815: Supervision Teigapc
Section 17 1MRK 506 369-UUS - Logic Name of OUTx Type Description Value when Value when activated deactivated OUT6 BOOLEAN Output 6 OUT7 BOOLEAN Output 7 OUT8 BOOLEAN Output 8 OUT9 BOOLEAN Output 9 OUT10 BOOLEAN Output 10 OUT11 BOOLEAN Output 11 1024 OUT12...
Page 816: Setting Guidelines
Section 17 1MRK 506 369-UUS - Logic 17.12.3 Setting guidelines The settings tAlarm and tWarning are user settable limits defined in seconds. The achievable resolution of the settings depends on the level of the values defined. A resolution of 10 ms can be achieved when the settings are defined within the range 1.00 second ≤...
Page 817: Setting Example
Section 17 1MRK 506 369-UUS - Logic Setting procedure on the IED: EnaAbs: This setting is used to select the comparison type between signed and absolute values. • Absolute: Comparison is performed on absolute values of input and reference values •...
Page 818: Comparator For Real Inputs - Realcomp
Section 17 1MRK 506 369-UUS - Logic SetValue shall be set between -2000000000 to 2000000000 17.14 Comparator for real inputs - REALCOMP 17.14.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Comparator for real inputs REALCOMP Real<=>...
Page 819: Setting Example
Section 17 1MRK 506 369-UUS - Logic EqualBandHigh: This setting is used to set the equal condition high band limit in % of reference value. This high band limit will act as reset limit for INHIGH output when INHIGH. EqualBandLow: This setting is used to set the equal condition low band limit in % of reference value.
Page 821: Measurement
Section 18 1MRK 506 369-UUS - Monitoring Section 18 Monitoring 18.1 Measurement 18.1.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Power system measurements CVMMXN P, Q, S, I, U, f SYMBOL-RR V1 EN Phase current measurement CMMXU SYMBOL-SS V1 EN Phase-phase voltage measurement...
Page 822: Application
Section 18 1MRK 506 369-UUS - Monitoring 18.1.2 Application Measurement functions are used for power system measurement, supervision and reporting to the local HMI, monitoring tool within PCM600 or to station level for example, via IEC 61850. The possibility to continuously monitor measured values of active power, reactive power, currents, voltages, frequency, power factor etc.
Page 823: Zero Clamping
Section 18 1MRK 506 369-UUS - Monitoring The CVMMXN function calculates three-phase power quantities by using fundamental frequency phasors (DFT values) of the measured current and voltage signals. The measured power quantities are available either, as instantaneously calculated quantities or, averaged values over a period of time (low pass filtered) depending on the selected settings.
Page 824: Setting Guidelines
Section 18 1MRK 506 369-UUS - Monitoring Relevant settings and their values on the local HMI under Main menu/Settings/IED settings/Monitoring/Servicevalues(P_Q)/CVMMXN(P_Q): • When system voltage falls below UGenZeroDB, values for S, P, Q, PF, ILAG, ILEAD, U and F are forced to zero. •...
Page 825 Section 18 1MRK 506 369-UUS - Monitoring VMagCompY: Magnitude compensation to calibrate voltage measurements at Y% of Vn, where Y is equal to 5, 30 or 100. IMagCompY: Magnitude compensation to calibrate current measurements at Y% of In, where Y is equal to 5, 30 or 100. IAngCompY: Angle compensation to calibrate angle measurements at Y% of In, where Y is equal to 5, 30 or 100.
Page 826 Section 18 1MRK 506 369-UUS - Monitoring XDbRepInt: This setting handles all the reporting types. If setting is deadband in XRepTyp, XDbRepInt defines the deadband in m% of the measuring range. For cyclic reporting type (XRepTyp : cyclic), the setting value reporting interval is in seconds. Magnitude deadband is the setting value in m% of measuring range.
Page 827: Setting Examples
Section 18 1MRK 506 369-UUS - Monitoring Magnitude % of In compensation IMagComp5 Measured current IMagComp30 IMagComp100 % of In 0-5%: Constant 5-30-100%: Linear >100%: Constant Angle Degrees compensation Measured IAngComp30 current IAngComp5 IAngComp100 % of In ANSI05000652_3_en.vsd ANSI05000652 V3 EN Figure 391: Calibration curves 18.1.4.1...
Page 828 Section 18 1MRK 506 369-UUS - Monitoring Measurement function application for a 380kV OHL Single line diagram for this application is given in figure 392: 380kV Busbar 800/5 A 380kV 120V 380kV OHL ANSI09000039-1-en.vsd ANSI09000039 V1 EN Figure 392: Single line diagram for 380kV OHL application In order to monitor, supervise and calibrate the active and reactive power as indicated in figure it is necessary to do the following:...
Page 829 Section 18 1MRK 506 369-UUS - Monitoring Table 54: General settings parameters for the Measurement function Setting Short Description Selected Comments value Operation Operation Off/On Function must be PowAmpFact Amplitude factor to scale power 1.000 It can be used during commissioning to calculations achieve higher measurement accuracy.
Page 830 Section 18 1MRK 506 369-UUS - Monitoring Setting Short Description Selected Comments value PHiHiLim High High limit (physical value), % High alarm limit that is, extreme of SBase overload alarm, hence it will be 415 PHiLim High limit (physical value), in % of High warning limit that is, overload SBase warning, hence it will be 371 MW.
Page 831 Section 18 1MRK 506 369-UUS - Monitoring 132kV Busbar 200/5 31.5 MVA 500/5 33kV 120V 33kV Busbar ANSI09000040-1-en.vsd ANSI09000040 V1 EN Figure 393: Single line diagram for transformer application In order to measure the active and reactive power as indicated in figure 393, it is necessary to do the following: Set correctly all CT and VT and phase angle reference channel PhaseAngleRef (see Section...
Page 832 Section 18 1MRK 506 369-UUS - Monitoring Table 57: General settings parameters for the Measurement function Setting Short description Selected Comment value Operation Disabled / Enabled Enabled Enabled Operation Function must be PowAmpFact Magnitude factor to scale power 1.000 Typically no scaling is required calculations PowAngComp Angle compensation for phase...
Page 833 Section 18 1MRK 506 369-UUS - Monitoring 230kV Busbar 300/5 100 MVA 15/0.12kV AB , 100 MVA 15.65kV 4000/5 ANSI09000041-1-en.vsd ANSI09000041 V1 EN Figure 394: Single line diagram for generator application In order to measure the active and reactive power as indicated in figure 394, it is necessary to do the following: Set correctly all CT and VT data and phase angle reference channel PhaseAngleRef (see Section...
Page 834: Gas Medium Supervision Ssimg (63)
Section 18 1MRK 506 369-UUS - Monitoring Table 58: 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 power 1.000 Typically no scaling is required calculations PowAngComp Angle compensation for phase...
Page 835: Setting Guidelines
Section 18 1MRK 506 369-UUS - Monitoring 18.2.3 Setting guidelines The parameters for Gas medium supervision SSIMG can be set via local HMI or Protection and Control Manager PCM600. Operation: This is used to disable/enable the operation of gas medium supervision i.e. Off/On.
Page 836: Liquid Medium Supervision Ssiml (71)
Section 18 1MRK 506 369-UUS - Monitoring 18.3 Liquid medium supervision SSIML (71) 18.3.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Insulation liquid monitoring function SSIML 18.3.2 Application Liquid medium supervision (SSIML ,71) is used for monitoring the transformers and tap changers.
Page 837: Breaker Monitoring Sscbr
Section 18 1MRK 506 369-UUS - Monitoring tResetLevelAlm: This is used for the level alarm indication to reset after a set time delay in s. tResetLevelLO: This is used for the level lockout indication to reset after a set time delay in s.
Page 838 Section 18 1MRK 506 369-UUS - Monitoring Remaining life of circuit breaker Every time the breaker operates, the circuit breaker life reduces due to wear. The wear in a breaker depends on the interrupted current. For breaker maintenance or replacement at the right time, the remaining life of the breaker must be estimated.
Page 839 Section 18 1MRK 506 369-UUS - Monitoring interrupted current is 10 kA, one operation is equivalent to 10000/900 = 11 operations at the rated current. It is assumed that prior to tripping, the remaining life of a breaker is 10000 operations. Remaining life calculation for three different interrupted current conditions is explained below.
Page 840: Setting Guidelines
Section 18 1MRK 506 369-UUS - Monitoring Circuit breaker gas pressure indication For proper arc extinction by the compressed gas in the circuit breaker, the pressure of the gas must be adequate. Binary input available from the pressure sensor is based on the pressure levels inside the arc chamber.
Page 841: Event Function Event
Section 18 1MRK 506 369-UUS - Monitoring ContTrCorr: Correction factor for time difference in auxiliary and main contacts' opening time. AlmAccCurrPwr: Setting of alarm level for accumulated energy. LOAccCurrPwr: Lockout limit setting for accumulated energy. SpChAlmTime: Time delay for spring charging time alarm. tDGasPresAlm: Time delay for gas pressure alarm.
Page 842: Setting Guidelines
Section 18 1MRK 506 369-UUS - Monitoring events are created from any available signal in the IED that is connected to the Event function (EVENT). The EVENT function block is used for remote communication. Analog, integer and double indication values are also transferred through the EVENT function.
Page 843: Identification
Section 18 1MRK 506 369-UUS - Monitoring 18.6.1 Identification Function description IEC 61850 identification IEC 60617 ANSI/IEEE C37.2 identification device number Disturbance report DRPRDRE Disturbance report A1RADR - A4RADR Disturbance report B1RBDR - B22RBDR 18.6.2 Application 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 844: Setting Guidelines
Section 18 1MRK 506 369-UUS - Monitoring If the IED is connected to a station bus (IEC 61850-8-1), the disturbance recorder (record made and fault number) and the fault locator information are available. The same information is obtainable if IEC 60870-5-103 is used. 18.6.3 Setting guidelines The setting parameters for the Disturbance report function DRPRDRE are set via the local...
Page 845 Section 18 1MRK 506 369-UUS - Monitoring Disturbance Report AxRADR DRPRDRE Analog signals Trip value rec Fault locator Disturbance BxRBDR recorder Binary signals Sequential of events Event recorder Indications ANSI09000336-2-en.vsdx ANSI09000336 V2 EN Figure 396: Disturbance report functions and related function blocks For Disturbance report function there are a number of settings which also influences the sub-functions.
Page 846 Section 18 1MRK 506 369-UUS - Monitoring Red LED: Steady light Triggered on binary signal N with SetLEDx = Trip (or Start and Trip) Flashing The IED is in configuration mode Operation The operation of Disturbance report function DRPRDRE has to be set Enabled or Disabled.
Page 847: Recording Times
Section 18 1MRK 506 369-UUS - Monitoring 18.6.3.1 Recording times Prefault recording time (PreFaultRecT) is the recording time before the starting point of the disturbance. The setting should be at least 0.1 s to ensure enough samples for the estimation of pre-fault values in the Trip value recorder (TVR) function. Postfault recording time (PostFaultRecT) is the maximum recording time after the disappearance of the trig-signal (does not influence the Trip value recorder (TVR) function).
Page 848: Analog Input Signals
Section 18 1MRK 506 369-UUS - Monitoring For each of the 352 signals, it is also possible to select if the signal is to be used as a trigger for the start of the Disturbance report and if the trigger should be activated on positive (1) or negative (0) slope.
Page 849: Sub-Function Parameters
Section 18 1MRK 506 369-UUS - Monitoring 18.6.3.4 Sub-function parameters All functions are in operation as long as Disturbance report is in operation. Indications IndicationMaN: Indication mask for binary input N. If set (Show), a status change of that particular input, will be fetched and shown in the disturbance summary on local HMI. If not set (Hide), status change will not be indicated.
Page 850: Logical Signal Status Report Binstatrep
Section 18 1MRK 506 369-UUS - Monitoring • Should the function record faults only for the protected object or cover more? • How long is the longest expected fault clearing time? • Is it necessary to include reclosure in the recording or should a persistent fault generate a second recording (PostRetrig)? Minimize the number of recordings: •...
Page 851: Setting Guidelines
Section 18 1MRK 506 369-UUS - Monitoring INPUTn OUTPUTn IEC09000732-1-en.vsd IEC09000732 V1 EN Figure 397: BINSTATREP logical diagram 18.7.3 Setting guidelines The pulse time t is the only setting for the Logical signal status report (BINSTATREP). Each output can be set or reset individually, but the pulse time will be the same for all outputs in the entire BINSTATREP function.
Page 852: Setting Guidelines
Section 18 1MRK 506 369-UUS - Monitoring directional OC protection, and so on). The following loops are used for different types of faults: • for 3 phase faults: loop A-B. • for 2 phase faults: the loop between the faulted phases. •...
Page 853: Connection Of Analog Currents
Section 18 1MRK 506 369-UUS - Monitoring DRPRDRE LMBRFLO ANSI05000045_2_en.vsd ANSI05000045 V2 EN Figure 398: Simplified network configuration with network data, required for settings of the fault location-measuring function For a single-circuit line (no parallel line), the figures for mutual zero-sequence impedance ) and analog input are set at zero.
Page 854: Limit Counter L4Ufcnt
Section 18 1MRK 506 369-UUS - Monitoring en07000113_1_ansi.v ANSI07000113 V2 EN Figure 399: Example of connection of parallel line IN for Fault locator LMBRFLO 18.9 Limit counter L4UFCNT 18.9.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Limit counter L4UFCNT...
Page 855: Application
Section 18 1MRK 506 369-UUS - Monitoring 18.9.2 Application Limit counter (L4UFCNT) is intended for applications where positive and/or negative sides on a binary signal need to be counted. The limit counter provides four independent limits to be checked against the accumulated counted value.
Page 856: Setting Guidelines
Section 18 1MRK 506 369-UUS - Monitoring 18.10.3 Setting guidelines The settings tAlarm and tWarning are user settable limits defined in hours. The achievable resolution of the settings is 0.1 hours (6 minutes). tAlarm and tWarning are independent settings, that is, there is no check if tAlarm >...
Page 857: Pulse-Counter Logic Pcfcnt
Section 19 1MRK 506 369-UUS - Metering Section 19 Metering 19.1 Pulse-counter logic PCFCNT 19.1.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Pulse-counter logic PCFCNT S00947 V1 EN 19.1.2 Application 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 858: Function For Energy Calculation And Demand Handling Etpmmtr
Section 19 1MRK 506 369-UUS - Metering Configuration of inputs and outputs of PCFCNT is made via PCM600. On the Binary input module (BIM), the debounce filter default time is set to 1 ms, that is, the counter suppresses pulses with a pulse length less than 1 ms. The input oscillation blocking frequency is preset to 40 Hz meaning that the counter detects the input to oscillate if the input frequency is greater than 40 Hz.
Page 859: Setting Guidelines
Section 19 1MRK 506 369-UUS - Metering ETPMMTR CVMMXN P_ INST Q_ INST STARTACC STOPACC RSTACC RSTDMD IEC130 00190-2-en.vsdx IEC13000190 V2 EN Figure 400: Connection of energy calculation and demand handling function ETPMMTR to the measurements function (CVMMXN) The energy values can be read through communication in MWh and MVArh in monitoring tool of PCM600 and/or alternatively the values can be presented on the local HMI.
Page 860 Section 19 1MRK 506 369-UUS - Metering Operation: Disabled/Enabled EnaAcc: Disabled/Enabled is used to switch the accumulation of energy on and off. tEnergy: Time interval when energy is measured. tEnergyOnPls: gives the pulse length ON time of the pulse. It should be at least 100 ms when connected to the Pulse counter function block.
Page 861: Access Point
Section 20 1MRK 506 369-UUS - Ethernet-based communication Section 20 Ethernet-based communication 20.1 Access point 20.1.1 Application The access points are used to connect the IED to the communication buses (like the station bus) that use communication protocols. The access point can be used for single and redundant data communication.
Page 862: Redundant Communication
Section 20 1MRK 506 369-UUS - Ethernet-based communication IEC61850 Ed2 IEDs and not editable for IEC61850 Ed1 IEDs because in IEC61850 Ed1 only one access point can be modelled in SCL. The IP address can be set in IP address. ECT validates the value, the access points have to be on separate subnetworks.
Page 863: Application
Section 20 1MRK 506 369-UUS - Ethernet-based communication 20.2.2 Application Dynamic access point diagnostic (RCHLCCH) is used to supervise and assure redundant Ethernet communication over two channels. This will secure data transfer even though one communication channel might not be available for some reason Parallel Redundancy Protocol (PRP) and High-availability Seamless Redundancy (HSR) provides redundant communication over station bus running the available communication protocols.
Page 864: Setting Guidelines
Section 20 1MRK 506 369-UUS - Ethernet-based communication Device 1 Device 2 PhyPortA PhyPortB PhyPortA PhyPortB PhyPortB PhyPortA PhyPortB PhyPortA Device 4 Device 3 IEC16000038-1-en.vsdx IEC16000038 V1 EN Figure 402: High-availability Seamless Redundancy (HSR) 20.2.3 Setting guidelines Redundant communication is configured with the Ethernet configuration tool in PCM600. Redundancy: redundant communication is activated when the parameter is set to PRP-0, PRP-1 or HSR.
Page 865: Merging Unit
Section 20 1MRK 506 369-UUS - Ethernet-based communication IEC16000039-1-en.vsdx IEC16000039 V1 EN Figure 403: ECT screen with Redundancy set to PRP-1 on Access point 1 and HSR Access point 3 20.3 Merging unit 20.3.1 Application The IEC/UCA 61850-9-2LE process bus communication protocol enables an IED to communicate with devices providing measured values in digital format, commonly known as Merging Units (MU).
Page 866: Setting Guidelines
Section 20 1MRK 506 369-UUS - Ethernet-based communication IEC17000044-1-en.vsdx IEC17000044 V1 EN Figure 404: Merging unit 20.3.2 Setting guidelines For information on the merging unit setting guidelines, see section IEC/UCA 61850-9-2LE communication protocol. 20.4 Routes 20.4.1 Application Setting up a route enables communication to a device that is located in another subnetwork.
Page 867 Section 20 1MRK 506 369-UUS - Ethernet-based communication Gateway specifies the address of the gateway. Destination specifies the destination. Destination subnet mask specifies the subnetwork mask of the destination. Line distance protection REL670 2.2 ANSI Application manual...
Page 869: Communication Protocols
Section 21 1MRK 506 369-UUS - Station communication Section 21 Station communication 21.1 Communication protocols Each IED is provided with several communication interfaces 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 870 Section 21 1MRK 506 369-UUS - Station communication Engineering Station HSI Workstation Gateway Base System Printer KIOSK 3 KIOSK 1 KIOSK 2 IEC09000135_en.v IEC09000135 V1 EN Figure 405: SA system with IEC 61850–8–1 Figure406 shows the GOOSE peer-to-peer communication. Line distance protection REL670 2.2 ANSI Application manual...
Page 871: Setting Guidelines
Section 21 1MRK 506 369-UUS - Station communication Station HSI MicroSCADA Gateway GOOSE Control Protection Control and protection Control Protection en05000734.vsd IEC05000734 V1 EN Figure 406: Example of a broadcasted GOOSE message 21.2.2 Setting guidelines There are two settings related to the IEC 61850–8–1 protocol: Operation: User can set IEC 61850 communication to Enabled or Disabled.
Page 872: Receiving Data
Section 21 1MRK 506 369-UUS - Station communication Application Generic communication function for Single Point Value (SPGAPC) function is used to send one single logical output to other systems or equipment in the substation. SP16GAPC can be used to send up to 16 single point values from the application functions running in the same cycle time.
Page 873 Section 21 1MRK 506 369-UUS - Station communication Application The GOOSE receive function blocks are used to receive subscribed data from the GOOSE protocol. The validity of the data value is exposed as outputs of the function block as well as the validity of the communication.
Page 874: Lon Communication Protocol
Section 21 1MRK 506 369-UUS - Station communication 21.3 LON communication protocol 21.3.1 Application Control Center Station HSI MicroSCADA Gateway Star coupler RER 111 IEC05000663-1-en.vsd IEC05000663 V2 EN Figure 408: Example of LON communication structure for a substation automation system An optical network can be used within the substation automation system.
Page 875: Multicmdrcv And Multicmdsnd
Section 21 1MRK 506 369-UUS - Station communication The LON Protocol The LON protocol is specified in the LonTalkProtocol Specification Version 3 from Echelon Corporation. This protocol is designed for communication in control networks and is a peer-to-peer protocol where all the devices connected to the network can communicate with each other directly.
Page 876: Identification
Section 21 1MRK 506 369-UUS - Station communication 21.3.2.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Multiple command and receive MULTICMDRCV Multiple command and send MULTICMDSND 21.3.2.2 Application The IED provides two function blocks enabling several IEDs to send and receive signals via the interbay bus.
Page 877: Setting Guidelines
Section 21 1MRK 506 369-UUS - Station communication Utility LAN Remote monitoring Substation LAN ANSI05000715-4-en.vsd ANSI05000715 V4 EN Figure 409: SPA communication structure for a remote monitoring system via a substation LAN, WAN and utility LAN SPA communication is mainly used for the Station Monitoring System. It can include different IEDs with remote communication possibilities.
Page 878 Section 21 1MRK 506 369-UUS - Station communication The SPA communication setting parameters are set on the local HMI under Main menu/ Configuration/Communication/Station communication/SPA/SPA:1. The most important SPA communication setting parameters are SlaveAddress and BaudRate. They are essential for all communication contact to the IED. SlaveAddress and BaudRate can be set only on the local HMI for rear and front channel communication.
Page 879: Iec 60870-5-103 Communication Protocol
Section 21 1MRK 506 369-UUS - Station communication 21.5 IEC 60870-5-103 communication protocol 21.5.1 Application TCP/IP Control Station Center Gateway Star coupler ANSI05000660-4-en.vsd ANSI05000660 V4 EN Figure 410: 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 880: Design
Section 21 1MRK 506 369-UUS - Station communication 60870-5-103, refer to IEC 60870 standard part 5: Transmission protocols, and to the section 103, Companion standard for the informative interface of protection equipment. 21.5.1.2 Design General The protocol implementation consists of the following functions: •...
Page 881 Section 21 1MRK 506 369-UUS - Station communication • Function commands in control direction Function block with user defined functions in control direction, I103UserCMD. These function blocks include the FUNCTION TYPE parameter for each block in the private range, and the INFORMATION NUMBER parameter for each output signal. Status For more information on the function blocks below, refer to the Communication protocol manual, IEC 60870-5-103.
Page 882: Settings
Section 21 1MRK 506 369-UUS - Station communication This block is suitable for distance protection, line differential, transformer differential, over-current and ground-fault protection functions. • Autorecloser indications in monitor direction Function block with defined functions for autorecloser indications in monitor direction, I103AR.
Page 883: Settings For Rs485 And Optical Serial Communication
Section 21 1MRK 506 369-UUS - Station communication 21.5.2.1 Settings for RS485 and optical serial communication 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 additionally can utilize the RS485 port. A single protocol can be active on a given physical port at any time.
Page 884: Settings From Pcm600
Section 21 1MRK 506 369-UUS - Station communication GUID-CD4EB23C-65E7-4ED5-AFB1-A9D5E9EE7CA8 V3 EN GUID-CD4EB23C-65E7-4ED5-AFB1-A9D5E9EE7CA8 V3 EN Figure 411: Settings for IEC 60870-5-103 communication The general settings for IEC 60870-5-103 communication are the following: • SlaveAddress and BaudRate: Settings for slave number and communication speed (baud rate).
Page 885 Section 21 1MRK 506 369-UUS - Station communication In addition there is a setting on each event block for function type. Refer to description of the Main Function type set on the local HMI. Commands As for the commands defined in the protocol there is a dedicated function block with eight output signals.
Page 886: Function And Information Types
Section 21 1MRK 506 369-UUS - 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 887: Dnp3 Communication Protocol
Section 21 1MRK 506 369-UUS - Station communication REG 150 Private range REQ 245 Private range RER 152 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 889: Binary Signal Transfer
Section 22 1MRK 506 369-UUS - Remote communication Section 22 Remote communication 22.1 Binary signal transfer 22.1.1 Identification Function description IEC 61850 identification IEC 60617 ANSI/IEEE C37.2 identification device number BinSignRec1_1 Binary signal transfer, receive BinSignRec1_2 BinSignReceive2 Binary signal transfer, 2Mbit BinSigRec1_12M receive BinSigRec1_22M...
Page 890: Communication Hardware Solutions
Section 22 1MRK 506 369-UUS - Remote communication where the differential current is evaluated. If the evaluation results in a trip, the trip signal will be sent over the two communication links. 3-end differential protection with two communication links Ldcm312 Ldcm312 IED-A IED-B...
Page 891: Setting Guidelines
Section 22 1MRK 506 369-UUS - Remote communication en06000519-2.vsd IEC06000519 V2 EN Figure 413: Direct fibre optical connection between two IEDs with LDCM The LDCM can also be used together with an external optical to galvanic G.703 converter as shown in figure 414. These solutions are aimed for connections to a multiplexer, which in turn is connected to a telecommunications transmission network (for example PDH).
Page 892 Section 22 1MRK 506 369-UUS - Remote communication ChannelMode defines how an IED discards the LDCM information when one of the IEDs in the system is out of service: it can either be done on the IED out of service by setting all local LDCMs to channel mode OutOfService or at the remote end by setting the corresponding LDCM to channel mode Blocked.
Page 893 Section 22 1MRK 506 369-UUS - Remote communication The same is applicable for slot 312-313 and slot 322-323. DiffSync defines the method of time synchronization for the line differential function: Echo or GPS. Using Echo in this case is safe only if there is no risk of varying transmission asymmetry.
Page 894 Section 22 1MRK 506 369-UUS - Remote communication MaxTransmDelay indicates maximum transmission delay. Data for maximum 40 ms transmission delay can be buffered up. Delay times in the range of some ms are common. If data arrive in wrong order, the oldest data is disregarded. MaxtDiffLevel indicates the maximum time difference allowed between internal clocks in respective line ends.
Page 895 Section 22 1MRK 506 369-UUS - Remote communication LinkForwarded is used to configure the LDCM to merge the inter-trip and block signals from another LDCM-receiver. This is used when the analog signals for the LDCM- transmitter is connected to the receiver of another LDCM. Line distance protection REL670 2.2 ANSI Application manual...
Page 897: Authority Status Athstat
Section 23 1MRK 506 369-UUS - Security Section 23 Security 23.1 Authority status ATHSTAT 23.1.1 Application Authority status (ATHSTAT) function is an indication function block, which informs about two events related to the IED and the user authorization: • the fact that at least one user has tried to log on wrongly into the IED and it was blocked (the output USRBLKED) •...
Page 898: Change Lock Chnglck
Section 23 1MRK 506 369-UUS - Security • built-in real time clock (in operation/out of order). • external time synchronization (in operation/out of order). Events are also generated: • whenever any setting in the IED is changed. The internal events are time tagged with a resolution of 1 ms and stored in a list. The list can store up to 40 events.
Page 899: Denial Of Service Schlcch/Rchlcch
CHNGLCK input, that logic must be designed so that it cannot permanently issue a logical one to the CHNGLCK input. If such a situation would occur in spite of these precautions, then please contact the local ABB representative for remedial action. 23.4 Denial of service SCHLCCH/RCHLCCH 23.4.1...
Page 900: Setting Guidelines
Section 23 1MRK 506 369-UUS - Security 23.4.2 Setting guidelines The function does not have any parameters available in the local HMI or PCM600. Line distance protection REL670 2.2 ANSI Application manual...
Page 901: Ied Identifiers Terminalid
Main menu/Diagnostics/IED Status/Identifiers: • ProductVer • ProductDef • FirmwareVer • SerialNo • OrderingNo • ProductionDate • IEDProdType This information is very helpful when interacting with ABB product support (for example during repair and maintenance). Line distance protection REL670 2.2 ANSI Application manual...
Page 902: Factory Defined Settings
Section 24 1MRK 506 369-UUS - Basic IED functions 24.2.2 Factory defined settings The factory defined settings are very useful for identifying a specific version and very helpful in the case of maintenance, repair, interchanging IEDs between different Substation Automation Systems and upgrading. The factory made settings can not be changed by the customer.
Page 903: Identification
Section 24 1MRK 506 369-UUS - Basic IED functions 24.3.1 Identification Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Measured value expander block RANGE_XP 24.3.2 Application The current and voltage measurements functions (CVMMXN, CMMXU, VMMXU and VNMMXU), current and voltage sequence measurement functions (CMSQI and VMSQI) and IEC 61850 generic communication I/O functions (MVGAPC) are provided with measurement supervision functionality.
Page 904: Setting Guidelines
Section 24 1MRK 506 369-UUS - Basic IED functions parameters are available in the IED. Any of them can be activated through the different programmable binary inputs by means of external or internal control signals. A function block, SETGRPS, defines how many setting groups are used. Setting is done with parameter MAXSETGR and shall be set to the required value for each IED.
Page 905: Summation Block 3 Phase 3Phsum
Section 24 1MRK 506 369-UUS - Basic IED functions 24.6 Summation block 3 phase 3PHSUM 24.6.1 Application The analog summation block 3PHSUM function block is used in order to get the sum of two sets of 3 phase analog signals (of the same type) for those IED functions that might need it.
Page 906: Setting Guidelines
Section 24 1MRK 506 369-UUS - Basic IED functions This is an advantage since all applicable functions in the IED use a single source of base values. This facilitates consistency throughout the IED and also facilitates a single point for updating values when necessary. Each applicable function in the IED has a parameter, GlobalBaseSel, defining one out of the twelve sets of GBASVAL functions.
Page 907: Application
Section 24 1MRK 506 369-UUS - Basic IED functions 24.9.1 Application The Signal matrix for binary outputs function SMBO is used within the Application Configuration tool in direct relation with the Signal Matrix tool. SMBO represents the way binary outputs are sent from one IED configuration. 24.9.2 Setting guidelines There are no setting parameters for the Signal matrix for binary outputs SMBO available...
Page 908: Frequency Values
Section 24 1MRK 506 369-UUS - Basic IED functions 24.11.2 Frequency values The SMAI function includes a functionality based on the level of positive sequence voltage, MinValFreqMeas, to validate if the frequency measurement is valid or not. If the positive sequence voltage is lower than MinValFreqMeas, the function freezes the frequency output value for 500 ms and after that the frequency output is set to the nominal value.
Page 909: Setting Guidelines
Section 24 1MRK 506 369-UUS - Basic IED functions The outputs from the above configured SMAI block shall only be used for Overfrequency protection (SAPTOF, 81), Underfrequency protection (SAPTUF, 81) and Rate-of-change frequency protection (SAPFRC, 81) due to that all other information except frequency and positive sequence voltage might be wrongly calculated.
Page 910 Section 24 1MRK 506 369-UUS - Basic IED functions GlobalBaseSel: Selects the global base value group used by the function to define (IBase), (VBase) and (SBase). MinValFreqMeas: The minimum value of the voltage for which the frequency is calculated, expressed as percent of VBase (for each instance n). Settings DFTRefExtOut and DFTReference shall be set to default value InternalDFTRef if no VT inputs are available.
Page 911 Section 24 1MRK 506 369-UUS - 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 912 Section 24 1MRK 506 369-UUS - Basic IED functions down of the machine. In other application the usual setting of the parameter DFTReference of SMAI is InternalDFTRef. Example 1 SMAI1:13 BLOCK SPFCOUT DFTSPFC AI3P ^GRP1_A ^GRP1_B ^GRP1_C SMAI1:1 ^GRP1_N BLOCK SPFCOUT TYPE DFTSPFC...
Page 913 Section 24 1MRK 506 369-UUS - Basic IED functions Example 2 SMAI1:1 BLOCK SPFCOUT DFTSPFC AI3P ^GRP1_A ^GRP1_B ^GRP1_C SMAI1:13 ^GRP1_N BLOCK SPFCOUT TYPE DFTSPFC AI3P ^GRP1_A ^GRP1_B ^GRP1_C ^GRP1_N TYPE SMAI1:25 BLOCK SPFCOUT DFTSPFC AI3P ^GRP1_A ^GRP1_B ^GRP1_C ^GRP1_N TYPE ANSI07000198.vsd ANSI07000199 V1 EN...
Page 914: Test Mode Functionality Testmode
Section 24 1MRK 506 369-UUS - Basic IED functions 24.12 Test mode functionality TESTMODE 24.12.1 Application The protection and control IEDs may have a complex configuration with many included functions. To make the testing procedure easier, the IEDs include the feature that allows individual blocking of a single-, several-, or all functions.
Page 915: Setting Guidelines
Section 24 1MRK 506 369-UUS - Basic IED functions When the setting Operation is set to Off, the behavior is set to Off and it is not possible to override it. When a behavior of a function is Offthe function will not execute. When IEC 61850 Mod of a function is set to Off or Blocked, the Start LED on the LHMI will be set to flashing to indicate the abnormal operation of the IED.
Page 916 Section 24 1MRK 506 369-UUS - Basic IED functions different locations can be easily performed and a more accurate view of the actual sequence of events can be obtained. Time-tagging of internal events and disturbances are an excellent help when evaluating faults.
Page 917: Setting Guidelines
Section 24 1MRK 506 369-UUS - Basic IED functions time synchronization source. Or if GPS and SNTP are selected, when the GPS signal quality is bad, the IED will automatically choose SNTP as the time-source. If PTP is activated, the device with the best accuracy within the synchronizing group will be selected as the source.
Page 918 Section 24 1MRK 506 369-UUS - Basic IED functions • GPS+SPA • GPS+LON • GPS+BIN • SNTP • GPS+SNTP • IRIG-B • GPS+IRIG-B • CoarseSyncSrc which can have the following values: • Disabled • • • • IEC 60870-5-103 The function input to be used for minute-pulse synchronization is called BININPUT. For a description of the BININPUT settings, see the Technical Manual.
Page 919 Section 24 1MRK 506 369-UUS - Basic IED functions PTP can be set to On,Off or Slave only. When set to Slave only the IED is connected to the PTP-group and will synchronize to the grandmaster but cannot function as the grandmaster.
Page 920 Section 24 1MRK 506 369-UUS - Basic IED functions Setting example Station bus Process bus SAM600-TS SAM600-CT SAM600-VT IEC16000167-1-en.vsdx IEC16000167 V1 EN Figure 420: Example system Figure describes an example system. The REC and REL are both using the 9-2 stream from the SAM600, and gets its synch from the GPS.
Page 921: Current Transformer Requirements
Section 25 1MRK 506 369-UUS - Requirements Section 25 Requirements 25.1 Current transformer requirements 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 922 80% have been considered when CT requirements have been decided for ABB IEDs. Even in the future this level of remanent flux probably will be the maximum level that will be considered when decided the CT requirements. If higher remanence levels should be considered, it should often lead to unrealistic CT sizes.
Page 923: Conditions
VHR type CTs (i.e. with new material) to be used together with ABB protection IEDs. However, this may result in unacceptably big CT cores, which can be difficult to manufacture and fit in available space.
Page 924: Fault Current
Section 25 1MRK 506 369-UUS - Requirements security, for example, faults in reverse direction and external faults. Because of the almost negligible risk of additional time delays and the non-existent risk of failure to operate the remanence have not been considered for the dependability cases. The requirements below are therefore fully valid for all normal applications.
Page 925: 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 926 Section 25 1MRK 506 369-UUS - Requirements × æ ö ³ k ma x × ç ÷ a lre q è ø (Equation 536) EQUATION1675 V1 EN × æ ö ³ kzone 1 × ç ÷ a lre q è ø...
Page 927: Breaker Failure Protection
Section 25 1MRK 506 369-UUS - Requirements This factor depends on the design of the protection function and can be a function of the primary DC time constant of the close-in fault current. This factor depends on the design of the protection function and can be a function of the primary DC time constant of the fault current for a fault at the set reach of zone 1.
Page 928: Current Transformer Requirements For Cts According To Other Standards
Section 25 1MRK 506 369-UUS - Requirements 25.1.7 Current transformer requirements for CTs according to other standards All kinds of conventional magnetic core CTs are possible to use with the IEDs if they fulfill the requirements corresponding to the above specified expressed as the rated equivalent limiting secondary e.m.f.
Page 929: Current Transformers According To Ansi/Ieee
Section 25 1MRK 506 369-UUS - Requirements 25.1.7.3 Current transformers according to ANSI/IEEE Current transformers according to ANSI/IEEE are partly specified in different ways. A rated secondary terminal voltage V is specified for a CT of class C. V is the ANSI ANSI secondary terminal voltage the CT will deliver to a standard burden at 20 times rated...
Page 930: Voltage Transformer Requirements
Section 25 1MRK 506 369-UUS - Requirements 25.2 Voltage transformer requirements The performance of a protection function will depend on the quality of the measured input signal. Transients caused by capacitive Coupled voltage transformers (CCVTs) can affect some protection functions. Magnetic or capacitive voltage transformers can be used.
Page 931 Section 25 1MRK 506 369-UUS - Requirements 25.5 Sample specification of communication requirements for the protection and control terminals in digital telecommunication networks The communication requirements are based on echo timing. Bit Error Rate (BER) according to ITU-T G.821, G.826 and G.828 •...
Page 932 Section 25 1MRK 506 369-UUS - Requirements • Format: Transparent • Maximum channel delay • Loop time <40 ms continuous (2 x 20 ms) IED with echo synchronization of differential clock (without GPS clock) • Both channels must have the same route with maximum asymmetry of 0,2-0,5 ms, depending on set sensitivity of the differential protection.
Page 933: Section 26 Glossary
Section 26 1MRK 506 369-UUS - Glossary Section 26 Glossary 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 934 Section 26 1MRK 506 369-UUS - Glossary Circuit breaker Combined backplane module CCITT Consultative Committee for International Telegraph and Telephony. A United Nations-sponsored standards body within the International Telecommunications Union. CAN carrier module CCVT Capacitive Coupled Voltage Transformer Class C Protection Current Transformer class as per IEEE/ ANSI CMPPS Combined megapulses per second...
Page 935 Section 26 1MRK 506 369-UUS - Glossary DBLL Dead bus live line Direct current Data flow control Discrete Fourier transform DHCP Dynamic Host Configuration Protocol DIP-switch Small switch mounted on a printed circuit board Digital input DLLB Dead line live bus Distributed Network Protocol as per IEEE Std 1815-2012 Disturbance recorder DRAM...
Page 936 Section 26 1MRK 506 369-UUS - Glossary File Transfer Protocol Function type G.703 Electrical and functional description for digital lines used by local telephone companies. Can be transported over balanced and unbalanced lines Communication interface module with carrier of GPS receiver module Graphical display editor within PCM600 General interrogation command...
Page 937 Section 26 1MRK 506 369-UUS - Glossary 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 938 Section 26 1MRK 506 369-UUS - Glossary Liquid crystal display LDCM Line data communication module Local detection device Light-emitting diode LON network tool Local operating network Miniature circuit breaker Mezzanine carrier module Milli-ampere module Main processing module MVAL Value of measurement Multifunction vehicle bus.
Page 939 Section 26 1MRK 506 369-UUS - Glossary Permissive overreach POTT Permissive overreach transfer trip Process bus Bus or LAN used at the process level, that is, in near proximity to the measured and/or controlled components Parallel redundancy protocol Power supply module Parameter setting tool within PCM600 Precision time protocol PT ratio...
Page 940 Section 26 1MRK 506 369-UUS - Glossary Signal matrix tool within PCM600 Station monitoring system SNTP Simple network time protocol – is used to synchronize computer clocks on local area networks. This reduces the requirement to have accurate hardware clocks in every embedded system in a network.
Page 941 Section 26 1MRK 506 369-UUS - Glossary 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 944 — ABB AB Grid Automation Products 721 59 Västerås, Sweden Phone: +46 (0) 21 32 50 00 abb.com/protection-control © Copyright 2017 ABB. All rights reserved. Specifications subject to change without notice.

ABB RELION 670 SERIES Applications Manual

Section 1 Introduction

Section 2 Application

Section 3 Configuration

Section 4 Analog Inputs

Section 5 Local HMI

Section 6 Wide Area Measurement System

Section 7 Differential Protection

Section 8 Impedance Protection

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Summary of Contents for ABB RELION 670 SERIES