Page 1 — R E L I O N ® 670 SERIES Transformer protection RET670 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 In case any errors are detected, the reader is kindly requested to notify the manufacturer. Other than under explicit contractual commitments, in no event shall ABB be responsible or liable for any loss or damage resulting from the use of this manual or the application of the equipment.
Page 6 (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................27 This manual.................... 27 Intended audience.................. 27 Product documentation................28 Product documentation set..............28 Document revision history..............29 Related documents................30 Document symbols and conventions............30 Symbols.....................30 Document conventions..............31 IEC 61850 edition 1 / edition 2 mapping..........32 Section 2 Application................43 General IED application................43 Main protection functions................45...
Page 8 Table of contents Examples on how to connect, configure and set CT inputs for most commonly used CT connections........75 Example on how to connect a wye connected three-phase CT set to the IED................76 Example how to connect delta connected three-phase CT set to the IED................81 Example how to connect single-phase CT to the IED....
Page 9 Table of contents 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 Transformer differential protection T2WPDIF and T3WPDIF (87T)..135 Identification..................
Page 10 Table of contents T-feeder protection..............167 Tertiary reactor protection............170 Restricted earth fault protection (87N)........173 Alarm level operation..............175 Low impedance restricted earth fault protection REFPDIF (87N)..176 Identification..................176 Application..................176 Transformer winding, solidly grounded........177 Transformer winding, grounded through Zig-Zag grounding transformer.................
Page 11 Table of contents Setting guidelines................235 General..................235 Setting of zone1................236 Setting of overreaching zone............236 Setting of reverse zone...............237 Series compensated and adjacent lines........237 Setting of zones for parallel line application....... 243 Setting of reach in resistive direction..........245 Load impedance limitation, without load encroachment function..................
Page 12 Table of contents Setting of reach in resistive direction..........279 Load impedance limitation, without load encroachment function..................280 Load impedance limitation, with Phase selection with load encroachment, quadrilateral characteristic function activated ...282 Setting of minimum operating currents........282 Directional impedance element for quadrilateral characteristics 282 Setting of timers for distance protection zones......285 Full-scheme distance measuring, Mho characteristic ZMHPDIS (21)..
Page 13 Table of contents Additional distance protection directional function for earth faults ZDARDIR....................312 Identification..................313 Application..................313 Setting guidelines................313 Mho impedance supervision logic ZSMGAPC........315 Identification..................315 Application..................315 Setting guidelines................316 Faulty phase identification with load encroachment FMPSPDIS (21).. 317 Identification..................
Page 14 Table of contents Application..................345 Load encroachment characteristics..........351 Phase-to-ground fault in forward direction........352 Phase-to-ground fault in reverse direction........354 Phase-to-phase fault in forward direction........355 Setting guidelines................357 Resistive reach with load encroachment characteristic....358 Minimum operate currents............359 Phase selection, quad, fixed angle, load encroachment FDPSPDIS (21)..................
Page 15 Table of contents Identification..................396 Application..................396 System grounding...............397 Fault infeed from remote end............. 399 Load encroachment..............400 Short line application..............401 Long transmission line application..........402 Parallel line application with mutual coupling......403 Tapped line application...............410 Series compensation in power systems.......... 413 Steady state voltage regulation and increase of voltage collapse limit................
Page 16 Table of contents Setting guidelines................460 Scheme communication and tripping for faults occurring during power swinging over the protected line......460 Blocking and tripping logic for evolving power swings....465 Pole slip protection PSPPPAM (78)............466 Identification..................466 Application..................467 Setting guidelines................469 Setting example for line application..........471 Setting example for generator application........
Page 17 Table of contents Load encroachment..............509 Under voltage seal-in..............510 Section 9 Current protection..............513 Instantaneous phase overcurrent protection PHPIOC (50)....513 Identification..................513 Application..................513 Setting guidelines................514 Meshed network without parallel line..........515 Meshed network with parallel line..........517 Directional phase overcurrent protection, four steps OC4PTOC(51_67)................
Page 18 Table of contents Identification..................556 Application..................556 Setting guidelines................558 Thermal overload protection, one time constant Fahrenheit/ Celsius LFPTTR/LCPTTR (26)............. 567 Identification..................567 Thermal overload protection, two time constants TRPTTR (49)...567 Identification..................567 Application..................567 Setting guideline................568 Breaker failure protection CCRBRF(50BF)...........571 Identification..................
Page 19 Table of contents Negativ sequence time overcurrent protection for machines NS2PTOC (46I2).................. 600 Identification..................600 Application..................600 Features..................601 Generator continuous unbalance current capability....602 Setting guidelines................604 Operate time characteristic............604 Pickup sensitivity................ 605 Alarm function................606 Voltage-restrained time overcurrent protection VRPVOC (51V)...606 Identification..................
Page 20 Table of contents High impedance grounded systems........... 619 The following settings can be done for the two step overvoltage protection..............619 Two step residual overvoltage protection ROV2PTOV (59N)....621 Identification..................621 Application..................621 Setting guidelines................622 Equipment protection, such as for motors, generators, reactors and transformersEquipment protection for transformers................
Page 21 Table of contents Setting guidelines................639 Rate-of-change of frequency protection SAPFRC (81)......640 Identification..................640 Application..................640 Setting guidelines................641 Section 12 Multipurpose protection............. 643 General current and voltage protection CVGAPC........ 643 Identification..................643 Application..................643 Current and voltage selection for CVGAPC function....644 Base quantities for CVGAPC function........
Page 22 Table of contents General..................669 Setting of common parameters..........670 Negative sequence based............670 Zero sequence based..............671 Delta V and delta I ..............672 Dead line detection..............672 Fuse failure supervision VDSPVC (60)..........673 Identification..................673 Application..................673 Setting guidelines................674 Section 15 Control................677 Synchronism check, energizing check, and synchronizing SESRSYN (25)..................
Page 23 Table of contents Switch controller (SCSWI)............714 Switch (SXCBR/SXSWI).............715 Proxy for signals from switching device via GOOSE XLNPROXY................716 Bay Reserve (QCRSV)...............717 Reservation input (RESIN)............717 Interlocking (3)..................717 Configuration guidelines..............718 Interlocking for line bay ABC_LINE (3)..........719 Application.................. 719 Signals from bypass busbar............
Page 24 Table of contents Interlocking for breaker-and-a-half diameter BH (3)......752 Application.................. 752 Configuration setting..............753 Voltage control..................754 Identification..................754 Application..................754 Setting guidelines................790 TR1ATCC or TR8ATCC general settings........790 TR1ATCC (90) or TR8ATCC (90) Setting group ....... 791 TCMYLTC and TCLYLTC (84) general settings......801 Logic rotating switch for function selection and LHMI presentation SLGAPC....................
Page 25 Table of contents Application..................811 Blocking schemes...............812 Delta blocking scheme............... 813 Permissive schemes..............814 Intertrip scheme................818 Setting guidelines................818 Blocking scheme................ 818 Delta blocking scheme............... 819 Permissive underreaching scheme..........819 Permissive overreaching scheme..........819 Unblocking scheme..............819 Intertrip scheme................820 Phase segregated scheme communication logic for distance protection ZC1PPSCH (85)..............
Page 26 Table of contents Identification..................832 Application..................832 Setting guidelines................833 Current reversal and weak-end infeed logic for residual overcurrent protection ECRWPSCH (85)..........834 Identification..................834 Application..................834 Fault current reversal logic............834 Weak-end infeed logic..............835 Setting guidelines................835 Current reversal................836 Weak-end infeed................
Page 27 Table of contents Configurable logic blocks..............848 Application..................848 Setting guidelines................848 Configuration................849 Fixed signal function block FXDSIGN...........850 Identification..................850 Application..................850 Boolean 16 to Integer conversion B16I..........851 Identification..................851 Application..................852 Boolean to integer conversion with logical node representation, 16 bit BTIGAPC..................
Page 28 Table of contents Zero clamping..................865 Setting guidelines................866 Setting examples................ 869 Gas medium supervision SSIMG (63)..........876 Identification..................876 Application..................876 Setting guidelines................877 Liquid medium supervision SSIML (71)..........878 Identification..................878 Application..................878 Setting guidelines................878 Breaker monitoring SSCBR..............879 Identification..................
Page 29 Table of contents Application..................898 Setting guidelines................898 Running hour-meter TEILGAPC............898 Identification..................898 Application..................898 Setting guidelines................899 Estimation of transformer insulation life LOLSPTR (26/49HS)..... 899 Application..................899 Setting guidelines................904 Setting example................913 Transformer Rated Data.............913 Setting parameters for insulation loss of life calculation function (LOL1)................914 Section 19 Metering................
Page 30 Table of contents IEC 61850-8-1 communication protocol..........931 Application IEC 61850-8-1...............931 Setting guidelines................933 Horizontal communication via GOOSE........... 933 Sending data................933 Receiving data................934 LON communication protocol............... 936 Application..................936 MULTICMDRCV and MULTICMDSND..........938 Identification................938 Application.................. 938 Setting guidelines............... 938 SPA communication protocol..............938 Application..................
Page 31 Table of contents Application..................961 Setting guidelines................962 Section 24 Basic IED functions............963 IED identifiers TERMINALID..............963 Application..................963 Product information PRODINF............. 963 Application..................963 Factory defined settings..............964 Measured value expander block RANGE_XP........964 Identification..................965 Application..................965 Setting guidelines................965 Parameter setting groups..............
Page 32 Table of contents Test mode functionality TESTMODE............976 Application..................976 IEC 61850 protocol test mode............ 976 Setting guidelines................977 Time synchronization TIMESYNCHGEN..........978 Application..................978 Setting guidelines................979 System time................979 Synchronization................979 Section 25 Requirements..............983 Current transformer requirements............983 Current transformer basic classification and requirements..... 983 Conditions..................985 Fault current..................986 Secondary wire resistance and additional load.......
Page 33: Section 1 Introduction
Section 1 1MRK 504 163-UUS A Introduction Section 1 Introduction This manual GUID-AB423A30-13C2-46AF-B7FE-A73BB425EB5F v18 The application manual contains application descriptions and setting guidelines sorted per function. The manual can be used to find out when and for what purpose a typical protection function can be used.
Page 34: Product Documentation
Section 1 1MRK 504 163-UUS A Introduction Product documentation 1.3.1 Product documentation set GUID-3AA69EA6-F1D8-47C6-A8E6-562F29C67172 v15 Engineering manual Installation manual Commissioning manual Operation manual Application manual Technical manual Communication protocol manual Cyber security deployment guideline IEC07000220-4-en.vsd IEC07000220 V4 EN-US Figure 1: The intended use of manuals throughout the product lifecycle The engineering manual contains instructions on how to engineer the IEDs using the various tools available within the PCM600 software.
Page 35: Document Revision History
Section 1 1MRK 504 163-UUS A 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 36: Related Documents
Section 1 1MRK 504 163-UUS A Introduction 1.3.3 Related documents GUID-94E8A5CA-BE1B-45AF-81E7-5A41D34EE112 v5 Documents related to RET670 Document numbers Application manual 1MRK 504 163-UUS Commissioning manual 1MRK 504 165-UUS Product guide 1MRK 504 166-BEN Technical manual 1MRK 504 164-UUS Type test certificate 1MRK 504 166-TUS 670 series manuals Document numbers...
Page 37: Document Conventions
Section 1 1MRK 504 163-UUS A 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 38: Iec 61850 Edition 1 / Edition 2 Mapping
Section 1 1MRK 504 163-UUS A 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 39 Section 1 1MRK 504 163-UUS A Introduction Function block name Edition 1 logical nodes Edition 2 logical nodes BCZTPDIF BCZTPDIF BCZTPDIF 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...
Page 40 Section 1 1MRK 504 163-UUS A 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 41 Section 1 1MRK 504 163-UUS A 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 42 Section 1 1MRK 504 163-UUS A 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 43 Section 1 1MRK 504 163-UUS A 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 44 Section 1 1MRK 504 163-UUS A 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 45 Section 1 1MRK 504 163-UUS A 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 46 Section 1 1MRK 504 163-UUS A 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 47 Section 1 1MRK 504 163-UUS A 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 Transformer protection RET670 2.2 ANSI...
Page 49: Section 2 Application
Section 2 1MRK 504 163-UUS A Application Section 2 Application General IED application M16637-3 v14 The Intelligent Electronic Device (IED) provides fast and selective protection, monitoring and control for two- and three-winding transformers, autotransformers, step-up transformers and generator-transformer block units, phase shifting transformers, special railway transformers and shunt reactors.
Page 50 Section 2 1MRK 504 163-UUS A Application Positive, negative and zero sequence overcurrent functions, which can optionally be made directional and/or voltage controlled, provide further alternative backup protection. Thermal overload, overexcitation, over/under voltage and over/under frequency protection functions are also available. Breaker failure protection for each transformer breaker allows high speed back-up tripping of surrounding breakers.
Page 51: Main Protection Functions
Section 2 1MRK 504 163-UUS A Application GUID-F5776DD1-BD04-4872-BB89-A0412B4B5CC3 v1 The following tables list all the functions available in the IED. Those functions that are not exposed to the user or do not need to be configured are not described in this manual. Main protection functions GUID-66BAAD98-851D-4AAC-B386-B38B57718BD2 v13 Table 2:...
Page 52: Back-Up Protection Functions
Section 2 1MRK 504 163-UUS A Application IEC 61850 or ANSI Function description Transformer function name RET670 (Customized) ZSMGAPC Mho impedance supervision logic FMPSPDIS Faulty phase identification with load enchroachment ZMRPDIS, Distance measuring zone, quad characteristic separate Ph-Ph ZMRAPDIS and Ph-E settings FRPSPDIS Phase selection, quadrilateral characteristic with settable angle ZMFPDIS...
Page 53 Section 2 1MRK 504 163-UUS A Application IEC 61850 or ANSI Function description function name RET670 (Customized) LFPTTR Thermal overload protection, one time constant, Fahrenheit TRPTTR Thermal overload protection, two time constants CCRBRF 50BF Breaker failure protection STBPTOC 50STB Stub protection CCPDSC 52PD Pole discordance protection...
Page 54: Control And Monitoring Functions
Section 2 1MRK 504 163-UUS A Application Control and monitoring functions GUID-E3777F16-0B76-4157-A3BF-0B6B978863DE v15 IEC 61850 or ANSI Function description Transformer function name RET670 (Customized) Control SESRSYN Synchrocheck, energizing check and synchronizing APC30 Control functionality for up to 6 bays, max 30 objects (6CBs), including interlocking (see Table 4) QCBAY Bay control...
Page 55 Section 2 1MRK 504 163-UUS A Application IEC 61850 or ANSI Function description Transformer function name RET670 (Customized) VDSPVC Fuse failure supervision based on voltage difference Logic SMPPTRC Tripping logic SMAGAPC General start matrix block TMAGAPC Trip matrix logic ALMCALH Logic for group alarm WRNCALH Logic for group warning...
Page 56 Section 2 1MRK 504 163-UUS A Application Table 3: Total number of instances for basic configurable logic blocks Basic configurable logic block Total number of instances GATE PULSETIMER RSMEMORY SRMEMORY TIMERSET Table 4: Number of function instances in APC30 Function name Function description Total number of instances SCILO...
Page 57 Section 2 1MRK 504 163-UUS A Application Function name Function description Total number of instances LOCREM Handling of LR-switch positions XLNPROXY Proxy for signals from switching device via GOOSE GOOSEXLNRCV GOOSE function block to receive a switching device Table 5: Total number of instances for configurable logic blocks Q/T Configurable logic blocks Q/T Total number of instances...
Page 58 Section 2 1MRK 504 163-UUS A Application IEC 61850 or ANSI Function description Transformer function name RET670 (Customized) Monitoring CVMMXN Power system measurement CMMXU Current measurement VMMXU Voltage measurement phase-phase CMSQI Current sequence measurement VMSQI Voltage sequence measurement VNMMXU Voltage measurement phase-ground AISVBAS General service value presentation of analog inputs EVENT...
Page 59: Communication
Section 2 1MRK 504 163-UUS A Application IEC 61850 or ANSI Function description Transformer function name RET670 (Customized) Metering PCFCNT Pulse-counter logic ETPMMTR Function for energy calculation and demand handling Communication GUID-5F144B53-B9A7-4173-80CF-CD4C84579CB5 v15 IEC 61850 or function ANSI Function description Transformer name RET670...
Page 60 Section 2 1MRK 504 163-UUS A Application IEC 61850 or function ANSI Function description Transformer name RET670 (Customized) GOOSEVCTRCONF GOOSE VCTR configuration for send and receive MULTICMDRCV, Multiple command and transmit 60/10 MULTICMDSND OPTICAL103 IEC 60870-5-103 Optical serial communication RS485103 IEC 60870-5-103 serial communication for RS485 AGSAL Generic security application component...
Page 61 Section 2 1MRK 504 163-UUS A Application IEC 61850 or function ANSI Function description Transformer name RET670 (Customized) BinSignTrans1_1 Binary signal transfer transmit 3/3/6 BinSignTrans1_2 BinSignTransm2 BinSigRec1_12M Binary signal transfer, 2Mbit receive/transmit BinSigRec1_22M BinSigTran1_12M BinSigTran1_22M LDCMTRN Transmission of analog data from LDCM LDCMTRN_2M Transmission of analog data from LDCM, 2Mbit LDCMRecBinStat1...
Page 62: Basic Ied Functions
Section 2 1MRK 504 163-UUS A Application Basic IED functions GUID-C8F0E5D2-E305-4184-9627-F6B5864216CA v12 Table 8: Basic IED functions IEC 61850 or function Description name INTERRSIG Self supervision with internal event list TIMESYNCHGEN Time synchronization module BININPUT, Time synchronization SYNCHCAN, SYNCHGPS, SYNCHCMPPS, SYNCHLON, SYNCHPPH, SYNCHPPS, SNTP,...
Page 63 Section 2 1MRK 504 163-UUS A Application Table 9: Local HMI functions IEC 61850 or function ANSI Description name LHMICTRL Local HMI signals LANGUAGE Local human machine language SCREEN Local HMI Local human machine screen behavior FNKEYTY1–FNKEYTY5 Parameter setting function for HMI in PCM600 FNKEYMD1–...
Page 65: Section 3 Configuration
Section 3 1MRK 504 163-UUS A Configuration Section 3 Configuration Description of configuration RET670 IP14806-1 v2 3.1.1 Introduction IP14807-1 v2 The RET 670 comes preconfigured for several applications. ANSI RET670 Configurations Description RET670-A30 Single breaker, two winding transformer RET670-b30 Double breaker, two winding transformer RET670-B40 Double breaker, three winding transformer Each of these configurations will be described below.
Page 66 Section 3 1MRK 504 163-UUS A Configuration Measuring functions for S, P, Q, I, U, PF, f are available for local presentation on the local HMI and/or remote presentation. The following should be noted. The configuration is made with the binary input and binary output boards in the basic IED delivery, and one 9I + 3U input transformer module.
Page 67 Section 3 1MRK 504 163-UUS A Configuration RET670 A10 – Transformer backup protection W1_QB1 W1_QB2 12AI (9I+3U) 1 → 0 DFR/SER DR Control DRP RDRE S XCBR SMP PTRC W1_QA1 S SIMG S SIML W1_CT 50BF 3I>BF 52PD 4(3I>) 3I>> IN>>...
Page 68: Description Of Configuration A25
Section 3 1MRK 504 163-UUS A Configuration 3.1.1.2 Description of configuration A25 GUID-D7CB2E00-B396-487C-8946-4FF6A2E056D9 v4 The configuration of the IED is shown in Figure 3. This configuration is used when RET670 is used as a separate tap changer control IED. It can be used for single or parallel service where the communication between up to eight control function blocks are either internal or over IEC 61850-8-1.
Page 69: Description Of Configuration B30
Section 3 1MRK 504 163-UUS A Configuration RET670 A25 – Voltage control 12AI (6I+6U) ↑↓ ↑↓ DFR/SER DR TCM YLTC TCM YLTC DRP RDRE Usqi VN MMXU V MSQI V MMXU TRF1 TRF2 Usqi V MMXU V MSQI VN MMXU TRF1_W2_VT ↑↓...
Page 70 Section 3 1MRK 504 163-UUS A Configuration tripping scheme with a synchronism check function for manual closing of the low voltage side breaker. The high voltage breaker is foreseen to always energize the transformer and be interlocked with an open LV side breaker. High voltage circuit breaker synchronism check function is optional for system where synchronism check is required to close the bays/rings.
Page 71 Section 3 1MRK 504 163-UUS A Configuration RET670 B30 - 2 winding transformer in single/multi breaker arrangement 12AI (24AI) (9I+3U, (9I+3U)) 1 → 0 W1_QB1 DFR/DER DR Control W1_QB2 S XCBR SMP PTRC DRP RDRE S SIMG S SIML W1_CT2 Control Control 50BF 3I>...
Page 72: Description Of Configuration B40
Section 3 1MRK 504 163-UUS A Configuration 3.1.1.4 Description of configuration B40 M15203-61 v6 The configuration of the IED is shown in Figure 6. This configuration is used in applications with two winding transformers in multi- breaker arrangement on one or both sides. The protection scheme includes a 3–phase tripping scheme with a synchronism check function for manual closing of the low voltage side breaker.
Page 73 Section 3 1MRK 504 163-UUS A Configuration RET670 B40 - 3 winding transformer in multi breaker arrangement 24AI (9I+3U, 9I+3U) 1 → 0 W1_QB1 DFR/DER DR Control W1_QB2 SMP PTRC DRP RDRE S XCBR S SIMG S SIML W1_CT2 Control Control 50BF 3I>...
Page 75: Section 4 Analog Inputs
Section 4 1MRK 504 163-UUS A Analog inputs Section 4 Analog inputs Introduction SEMOD55003-5 v11 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 76: Example
Section 4 1MRK 504 163-UUS A Analog inputs 4.2.1.1 Example SEMOD55055-11 v5 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 77: Example 1
Section 4 1MRK 504 163-UUS A Analog inputs 4.2.2.1 Example 1 SEMOD55055-23 v6 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...
Page 78: Example 3
Section 4 1MRK 504 163-UUS A Analog inputs 4.2.2.3 Example 3 SEMOD55055-35 v7 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 79 Section 4 1MRK 504 163-UUS A Analog inputs direction 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 80 Section 4 1MRK 504 163-UUS A Analog inputs Busbar Busbar Protection en06000196_ansi.vsd ANSI06000196 V1 EN-US Figure 12: 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 81: For Most Commonly Used Ct Connections
Section 4 1MRK 504 163-UUS A 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 82: Example On How To Connect A Wye Connected Three-Phase Ct Set To The Ied
Section 4 1MRK 504 163-UUS A 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 83 Section 4 1MRK 504 163-UUS A Analog inputs SMAI_20 CT 600/5 Wye Connected Protected Object ANSI13000002-3-en.vsd ANSI13000002 V3 EN-US Figure 14: 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 84 Section 4 1MRK 504 163-UUS A 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 85 Section 4 1MRK 504 163-UUS A 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-US Figure 15: 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 14).
Page 86 Section 4 1MRK 504 163-UUS A Analog inputs SMAI2 BLOCK AI3P AI 01 (I) ^GRP2_A ^GRP2_B ^GRP2_C AI 02 (I) ^GRP2N TYPE AI 03 (I) CT 800/1 Wye Connected AI 04 (I) AI 05 (I) AI 06 (I) Protected Object ANSI06000644-2-en.vsd ANSI06000644 V2 EN-US Figure 16:...
Page 87: Example How To Connect Delta Connected Three-Phase Ct Set To The Ied
Section 4 1MRK 504 163-UUS A 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 88 Section 4 1MRK 504 163-UUS A Analog inputs SMAI_20 IA-IB IB-IC IC-IA ANSI11000027-2-en.vsd Protected Object ANSI11000027 V2 EN-US Figure 17: Delta DAB connected three-phase CT set Transformer protection RET670 2.2 ANSI Application manual...
Page 89 Section 4 1MRK 504 163-UUS A 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 90: Example How To Connect Single-Phase Ct To The Ied
Section 4 1MRK 504 163-UUS A Analog inputs SMAI_20 IA-IC IB-IA IC-IB ANSI11000028-2-en.vsd Protected Object ANSI11000028 V2 EN-US Figure 18: 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 91 Section 4 1MRK 504 163-UUS A 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-US Figure 19: Connections for single-phase CT input Where: shows how to connect single-phase CT input in the IED.
Page 92: Relationships Between Setting Parameter Base Current, Ct Rated Primary Current And Minimum Pickup Of A Protection Ied
Section 4 1MRK 504 163-UUS A Analog inputs 4.2.3 Relationships between setting parameter Base Current, CT rated primary current and minimum pickup of a protection IED GUID-8EB19363-9178-4F04-A6AC-AF0C2F99C5AB v1 Note that for all line protection applications (e.g. distance protection or line differential protection) the parameter Base Current (i.e.
Page 93: Example
Section 4 1MRK 504 163-UUS A Analog inputs 4.2.4.1 Example SEMOD55055-47 v3 Consider a VT with the following data: 132kV 120V (Equation 1) EQUATION1937 V1 EN-US The following setting should be used: VTprim=132 (value in kV) VTsec=120 (value in 4.2.4.2 Examples how to connect, configure and set VT inputs for most commonly used VT connections SEMOD55055-60 v6...
Page 94: Examples On How To Connect A Three Phase-To-Ground Connected Vt To The Ied
Section 4 1MRK 504 163-UUS A Analog inputs • 100 V • 110 V • 115 V • 120 V • 230 V The IED fully supports all of these values and most of them will be shown in the following examples.
Page 95 Section 4 1MRK 504 163-UUS A Analog inputs AI 07 (I) SMAI2 BLOCK AI3P AI 08 (V) ^GRP2_A ^GRP2_B AI 09 (V) ^GRP2_C ^GRP2N #Not used AI 10 (V) TYPE AI 11 (V) AI 12 (V) ANSI06000599-2-en.vsd ANSI06000599 V2 EN-US Figure 21: A Three phase-to-ground connected VT SMAI2...
Page 96: Example On How To Connect A Phase-To-Phase Connected Vt To The Ied
Section 4 1MRK 504 163-UUS A Analog inputs Where: shows how to connect three secondary phase-to-ground voltages to three VT inputs on the is the TRM where these three voltage inputs are located. For these three voltage inputs, the following setting values shall be entered: VTprim = 132 kV VTsec = 110 V Inside the IED, only the ratio of these two parameters is used.
Page 97 Section 4 1MRK 504 163-UUS A Analog inputs 13.8 13.8 AI 07(I) SMAI2 BLOCK AI3P AI 08 (V) ^GRP2_A (A-B) ^GRP2_B (B-C) AI 09 (V) ^GRP2_C (C-A) ^GRP2N #Not Used TYPE AI 10(V) AI 11(V) AI 12(V) ANSI06000600-3-en.vsd ANSI06000600 V3 EN-US Figure 23: A Two phase-to-phase connected VT Where:...
Page 98: Example On How To Connect An Open Delta Vt To The Ied For High Impedance Grounded Or Ungrounded Networks
Section 4 1MRK 504 163-UUS A 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...
Page 99 Section 4 1MRK 504 163-UUS A Analog inputs AI 07 (I) AI 08 (V) SMAI2 AI 09 (V) BLOCK AI3P ^GRP2_A # Not Used AI 10 (V) ^GRP2_B # Not Used ^GRP2_C # Not Used AI 11 (V) +3Vo ^GRP2N TYPE AI 12 (V) ANSI06000601-2-en.vsd...
Page 100 Section 4 1MRK 504 163-UUS A 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 101: Example How To Connect The Open Delta Vt To The Ied For Low Impedance Grounded Or Solidly Grounded Power Systems
Section 4 1MRK 504 163-UUS A 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 SEMOD55055-199 v6 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 102 Section 4 1MRK 504 163-UUS A 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-US Figure 25: Open delta connected VT in low impedance or solidly grounded power system Transformer protection RET670 2.2 ANSI...
Page 103 Section 4 1MRK 504 163-UUS A 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 105: Section 5 Local Hmi
Section 5 1MRK 504 163-UUS A Local HMI Section 5 Local HMI AMU0600442 v14 ANSI13000239-2-en.vsd ANSI13000239 V2 EN-US Figure 26: Local human-machine interface The LHMI of the IED contains the following elements: Transformer protection RET670 2.2 ANSI Application manual...
Page 106: Display
Section 5 1MRK 504 163-UUS A Local HMI • Keypad • Display (LCD) • LED indicators • Communication port for PCM600 The LHMI is used for setting, monitoring and controlling. Display GUID-55739D4F-1DA5-4112-B5C7-217AAF360EA5 v11 The LHMI includes a graphical monochrome liquid crystal display (LCD) with a resolution of 320 x 240 pixels.
Page 107 Section 5 1MRK 504 163-UUS A Local HMI IEC15000270-1-en.vsdx IEC15000270 V1 EN-US 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 504 163-UUS A Local HMI IEC13000281-1-en.vsd GUID-C98D972D-D1D8-4734-B419-161DBC0DC97B V1 EN-US 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-US 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 504 163-UUS A Local HMI LEDs AMU0600427 v13 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.
Page 110: Keypad
Section 5 1MRK 504 163-UUS A Local HMI IEC16000076-1-en.vsd IEC16000076 V1 EN-US Figure 30: OPENCLOSE_LED connected to SXCBR Keypad AMU0600428 v17 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 504 163-UUS A Local HMI ANSI15000157-1-en.vsdx ANSI15000157 V1 EN-US Figure 31: LHMI keypad with object control, navigation and command push- buttons and RJ-45 communication port 1...5 Function button Close Open Escape Left Down Right Enter Remote/Local Uplink LED Not in use Multipage Transformer protection RET670 2.2 ANSI...
Page 112: Local Hmi Functionality
Section 5 1MRK 504 163-UUS A Local HMI Menu Clear Help Communication port Programmable indication LEDs IED status LEDs Local HMI functionality 5.4.1 Protection and alarm indication GUID-09CCB9F1-9B27-4C12-B253-FBE95EA537F5 v15 Protection indicators The protection indicator LEDs are Normal, Pickup and Trip. Table 10: Normal LED (green) LED state...
Page 113: Parameter Management
Section 5 1MRK 504 163-UUS A Local HMI Table 12: 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 504 163-UUS A 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 GUID-FD72A445-C8C1-4BFE-90E3-0AC78AE17C45 v11...
Page 115: C37.118 Phasor Measurement Data Streaming Protocol Configuration Pmuconf
Section 6 1MRK 504 163-UUS A Wide area measurement system Section 6 Wide area measurement system C37.118 Phasor Measurement Data Streaming Protocol Configuration PMUCONF GUID-747C6AD7-E6A1-466E-92D1-68865681F92F v1 6.1.1 Identification GUID-1E140EA0-D198-443A-B445-47CEFD2E6134 v1 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Configuration parameters for IEEE PMUCONF...
Page 116: Short Guidance For Use Of Tcp
Section 6 1MRK 504 163-UUS A Wide area measurement system corresponding PMU ID for 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 504 163-UUS A 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 504 163-UUS A 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 504 163-UUS A 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 504 163-UUS A Wide area measurement system 6.2.2 Application GUID-8DF29209-252A-4E51-9F4A-B14B669E71AB v4 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 504 163-UUS A Wide area measurement system IEC140000118-2-en.vsd IEC140000118 V2 EN-US 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 504 163-UUS A Wide area measurement system IEC140000120-2-en.vsd IEC140000120 V2 EN-US 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 504 163-UUS A 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 504 163-UUS A 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 504 163-UUS A 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 504 163-UUS A 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 504 163-UUS A Wide area measurement system 6.2.3.3 Scaling Factors for ANALOGREPORT channels GUID-0DDAF6A9-8643-4FDD-97CF-9E35EF40AF7E v2 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 504 163-UUS A Wide area measurement system AnalogXRange = 3277.0 IECEQUATION2446 V1 EN-US The scale factor is calculated as follows: ´ (3277.0 2.0 ) sc alefactor 0.1 a nd offse t 65535.0 IECEQUATION2447 V1 EN-US 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 504 163-UUS A Wide area measurement system 6.2.3.4 PMU Report Function Blocks Connection Rules in PCM600 Application Configuration Tool (ACT) GUID-66667179-F3E1-455B-8B99-6D73F37E949B v3 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:...
Page 130 Section 6 1MRK 504 163-UUS A Wide area measurement system 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 similar instance number or only if all the connected PHASORREPORT blocks have similar settings for SvcClass and ReportRate.
Page 131 Section 6 1MRK 504 163-UUS A Wide area measurement system IEC140000127-2-en.vsd IEC140000127 V2 EN-US 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 504 163-UUS A Wide area measurement system IEC140000128-2-en.vsd IEC140000128 V2 EN-US 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 504 163-UUS A Wide area measurement system IEC140000129-2-en.vsd IEC140000129 V2 EN-US Figure 44: An example of correct connection of 3PHSUM and PHASORREPORT blocks in ACT IEC140000130-1-en.vsd IEC140000130 V1 EN-US Figure 45: SMAI1 setting parameters example-showing that SMAI3 is selected as the DFT reference (DFTRefGrp3) Transformer protection RET670 2.2 ANSI Application manual...
Page 134 Section 6 1MRK 504 163-UUS A Wide area measurement system IEC140000131-1-en IEC140000131 V1 EN-US 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 504 163-UUS A Wide area measurement system is 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.
Page 136 Section 6 1MRK 504 163-UUS A 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 504 163-UUS A Wide area measurement system synchrophasors. The 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 jα...
Page 138 Section 6 1MRK 504 163-UUS A Wide area measurement system The frequency-deviation and rate-of-change-of-frequency data are sent via the FREQ and DFREQ fields of data frame organization of IEEE C37.118.2 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.
Page 139 Section 6 1MRK 504 163-UUS A Wide area measurement system power system signal at the time it is applied to the PMU input. All of these estimates must be compensated for PMU processing delays including analog input filtering, sampling, and estimation group delay. If the sample time tags are 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...
Page 140 Section 6 1MRK 504 163-UUS A Wide area measurement system This setting is only important if the AnalogDataType setting is selected as Integer. More information is available under the section Scaling Factors for ANALOGREPORT channels. • AnalogXUnitType: Unit type for analog signal X. It refers to the 4-byte ANUNIT field of the configuration frames 1, 2 organization defined in IEEE C37.118.2 message format.
Page 141: Transformer Differential Protection T2Wpdif And T3Wpdif (87T)
Section 7 1MRK 504 163-UUS A Differential protection Section 7 Differential protection Transformer differential protection T2WPDIF and T3WPDIF (87T) IP14639-1 v3 7.1.1 Identification M15074-1 v5 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Transformer differential protection, two- T2WPDIF winding 3Id/I...
Page 142: Setting Guidelines
Section 7 1MRK 504 163-UUS A Differential protection current until it develops into an ground or phase fault. For this reason it is important that the differential protection has a high level of sensitivity and that it is possible to use a sensitive setting without causing unwanted operations during external faults.
Page 143 Section 7 1MRK 504 163-UUS A Differential protection way of defining the bias current has been Ibias = (I1 + I2) / 2, where I1 is the magnitude of the power transformer primary current, and I2 the magnitude of the power transformer secondary current.
Page 144 Section 7 1MRK 504 163-UUS A Differential protection windings or the current transformers will be in breakers that are part of the bus, such as a breaker-and-a-half or a ring bus scheme. For current transformers with primaries in series with the power transformer winding, the current transformer primary current for external faults will be limited by the transformer impedance.
Page 145 Section 7 1MRK 504 163-UUS A Differential protection operate current [ times IBase ] Operate unconditionally UnrestrainedLimit Operate conditionally Section 1 Section 2 Section 3 SlopeSection3 IdMin SlopeSection2 Restrain EndSection1 restrain current [ times IBase ] EndSection2 en05000187-2.vsd IEC05000187 V2 EN-US Figure 48: Representation of the restrained, and the unrestrained operate characteristics...
Page 146: Elimination Of Zero Sequence Currents
Section 7 1MRK 504 163-UUS A Differential protection 7.1.3.2 Elimination of zero sequence currents M15266-286 v7 A differential protection may operate undesirably due to external ground-faults in cases where the zero sequence current can flow on only one side of the power transformer, but not on the other side.
Page 147: Cross-Blocking Between Phases
Section 7 1MRK 504 163-UUS A Differential protection limit the operation is restrained. It is recommended to use I5/I1Ratio = 25% as default value in case no special reasons exist to choose another setting. Transformers likely to be exposed to overvoltage or underfrequency conditions (that is, generator step-up transformers in power stations) should be provided with a dedicated overexcitation protection based on V/Hz to achieve a trip before the core thermal limit is reached.
Page 148 Section 7 1MRK 504 163-UUS A Differential protection This magnitude check, guarantees stability of the algorithm when the power transformer is energized. In cases where the protected transformer can be energized with a load connected on the LV side (e.g. a step-up transformer in a power station with directly connected auxiliary transformer on its LV side) the value for this setting shall be increased to at least 12%.
Page 149: On-Line Compensation For On-Load Tap-Changer Position
Section 7 1MRK 504 163-UUS A Differential protection External faults happen ten to hundred times more often than internal ones as far as the power transformers are concerned. If a disturbance is detected and the internal/external fault discriminator characterizes this fault as an external fault, the conventional additional criteria are posed on the differential algorithm before its trip is allowed.
Page 150: Differential Current Alarm
Section 7 1MRK 504 163-UUS A Differential protection The above parameters are defined for OLTC1. Similar parameters shall be set for second on-load tap-changer designated with OLTC2 in the parameter names, for three– winding differential protection. 7.1.3.8 Differential current alarm M15266-337 v6 Differential protection continuously monitors the level of the fundamental frequency differential currents and gives an alarm if the pre-set value is simultaneously exceeded...
Page 151: Switch Onto Fault Feature
Section 7 1MRK 504 163-UUS A Differential protection 7.1.3.10 Switch onto fault feature M15266-348 v5 The Transformer differential function in the IED has a built-in, advanced switch onto fault feature. This feature can be enabled or disabled by the setting parameter SOTFMode.
Page 152: Typical Main Ct Connections For Transformer Differential Protection
Section 7 1MRK 504 163-UUS A Differential protection intentionally set for √(3)=1.732 times smaller than actual ratio of individual phase CTs (for example, instead of 800/5 set 462/5) In case the ratio is 800/2.88A, often designed for such typical delta connections, set the ratio as 800/5 in the IED. At the same time the power transformer vector group shall be set as Yy0 because the IED shall not internally provide any phase angle shift compensation.
Page 153: Application Examples
Section 7 1MRK 504 163-UUS A Differential protection For wye connected main CTs, the main CT ratio shall be set as it is in actual application. The “WyePoint” parameter, for the particular wye connection shown in figure 49, shall be set ToObject. If wye connected main CTs have their wye point away from the protected transformer this parameter should be set FromObject.
Page 154 Section 7 1MRK 504 163-UUS A Differential protection Input CT channels on the transformer input modules. General settings for the transformer differential protection where specific data about protected power transformer shall be entered. Finally the setting for the differential protection characteristic will be given for all presented applications.
Page 155 Section 7 1MRK 504 163-UUS A Differential protection are rotated by 30° in clockwise direction. Thus the DAC delta CT connection must be used for 69 kV CTs in order to put 69 kV & 12.5 kV currents in phase. To ensure proper application of the IED for this power transformer it is necessary to do the following: 1.
Page 156 Section 7 1MRK 504 163-UUS A Differential protection Table 17: General settings of the differential protection function Setting parameter Select value for solution 1 (wye Selected value for solution 2 (delta connected CT) connected CT) GlobalBaseSelW1 CTPrim / GlobalBaseSelW1 (CTPrim / GlobalBaseSelW1) / sqrt(3) GlobalBaseSelW2 CTPrim / GlobalBaseSelW2...
Page 157 Section 7 1MRK 504 163-UUS A Differential protection CT 400/5 CT 400/5 60 MVA 60 MVA 115/24.9 kV 115/24.9 kV Dyn1 Dyn1 CT 1500/5 CT 1500/5 in Delta (DAB) en06000555_ansi.vsd ANSI06000555 V1 EN-US Figure 51: Two differential protection solutions for delta-wye connected power transformer For this particular power transformer the 115 kV side phase-to-ground no-load voltages lead by 30°...
Page 158 Section 7 1MRK 504 163-UUS A Differential protection Table 18: CT input channels used for the HV side CTs Setting parameter Selected value for both solutions CTprim CTsec CT_WyePoint ToObject 5. Enter the following settings for all three CT input channels used for the LV side CTs, see table "CT input channels used for the LV side CTs".
Page 159 Section 7 1MRK 504 163-UUS A Differential protection Setting parameter selected value for both Solution 1 Selected value for both Solution 2 (wye conected CT) (delta connected CT) LocationOLTC1 Not Used Not Used Other parameters Not relevant for this application. Not relevant for this application.
Page 160 Section 7 1MRK 504 163-UUS A Differential protection shown in the right-hand side in figure 52) in order to put 110 kV & 36.75 kV currents in phase. To ensure proper application of the IED for this power transformer it is necessary to do the following: 1.
Page 161: Summary And Conclusions
Section 7 1MRK 504 163-UUS A Differential protection To compensate for delta connected CTs, see equation 17. 7. Enter the following values for the general settings of the differential protection function, see table Table 22: General settings of the differential protection function Setting parameter Selected value for both Solution 1 Selected value for both Solution 2...
Page 162 Section 7 1MRK 504 163-UUS A Differential protection The ratio for delta connected CTs shall be set √(3)=1.732 times smaller than the actual individual phase CT ratio. The power transformer phase-shift shall typically be set as Yy0 because the compensation for power transformer the actual phase shift is provided by the external delta CT connection.
Page 163: High Impedance Differential Protection, Single Phase Hzpdif (87)
Section 7 1MRK 504 163-UUS A Differential protection IEC vector group ANSI designation Positive sequence no-load Required delta CT connection voltage phasor diagram type on wye side of the protected power transformer and internal vector group setting in the IED Dyn11 DAC/Yy0 IEC06000562 V1 EN-US...
Page 164: Application
Section 7 1MRK 504 163-UUS A Differential protection 7.2.2 Application IP14944-1 v3 SEMOD54734-4 v8 The 1Ph High impedance differential protection function HZPDIF (87) can be used as: • Generator differential protection • Reactor differential protection • Busbar differential protection • Autotransformer differential protection (for common and serial windings only) •...
Page 165 Section 7 1MRK 504 163-UUS A Differential protection presence of heavy CT saturation. The principle is based on the CT secondary current circulating between involved current transformers and not through the IED due to high impedance in the measuring branch. This stabilizing resistance is in the range of hundreds of ohms and sometimes above one kilo Ohm.
Page 166 Section 7 1MRK 504 163-UUS A Differential protection The calculations are made with the worst situations in mind and a minimum operating voltage V is calculated according to equation > × (Equation 18) EQUATION1531-ANSI V1 EN-US where: IF max is the maximum through fault current at the secondary side of the CT is the current transformer secondary winding resistance and is the maximum loop resistance of the circuit at any CT.
Page 167 Section 7 1MRK 504 163-UUS A Differential protection The tables 23, below show, the operating currents for different settings of operating voltages and selected resistances. Adjust as required based on tables 23, or to values in between as required for the application. Minimum ohms can be difficult to adjust due to the small value compared to the total value.
Page 168 Section 7 1MRK 504 163-UUS A Differential protection When the R value has been selected and the TripPickup value has been set, the sensitivity of the scheme IP can be calculated. The IED sensitivity is decided by the total current in the circuit according to equation 19. å...
Page 169 Section 7 1MRK 504 163-UUS A Differential protection Rres I> Protected Object a) Through load situation b) Through fault situation c) Internal faults ANSI05000427-2-en.vsd ANSI05000427 V2 EN-US Figure 55: The high impedance principle for one phase with two current transformer inputs Transformer protection RET670 2.2 ANSI Application manual...
Page 170: Connection Examples For High Impedance Differential Protection
Section 7 1MRK 504 163-UUS A Differential protection 7.2.3 Connection examples for high impedance differential protection GUID-8C58A73D-7C2E-4BE5-AB87-B4C93FB7D62B v5 WARNING! USE EXTREME CAUTION! Dangerously high voltages might be present on this equipment, especially on the plate with resistors. De-energize the primary object protected with this equipment before connecting or disconnecting wiring or performing any maintenance.
Page 171: Connections For 1Ph High Impedance Differential Protection Hzpdif (87)
Section 7 1MRK 504 163-UUS A 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 172: Setting Guidelines
Section 7 1MRK 504 163-UUS A 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-US Figure 57:...
Page 173: Configuration
Section 7 1MRK 504 163-UUS A Differential protection 7.2.4.1 Configuration M13076-5 v4 The configuration is done in the Application Configuration tool. 7.2.4.2 Settings of protection function M13076-10 v6 Operation: The operation of the high impedance differential function can be switched Enabled or Disabled.
Page 174 Section 7 1MRK 504 163-UUS A Differential protection transformers in the feeder circuit (for example, in the transformer bushings). It is often required to separate the protection zones that the feeder is protected with one scheme 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 58.
Page 175 Section 7 1MRK 504 163-UUS A 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 176: Tertiary Reactor Protection
Section 7 1MRK 504 163-UUS A 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 177 Section 7 1MRK 504 163-UUS A Differential protection 3·87 ANSI05000176-2-en.vsd ANSI05000176 V2 EN-US Figure 59: 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 178 Section 7 1MRK 504 163-UUS A Differential protection but 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 179: Restricted Earth Fault Protection (87N)
Section 7 1MRK 504 163-UUS A 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. The current value at TripPickup is taken.
Page 180 Section 7 1MRK 504 163-UUS A Differential protection Setting example It is strongly recommended to use the highest tap of the CT whenever high impedance protection is used. This helps in utilizing maximum CT capability, minimize the current, thereby reducing the stability voltage limit.
Page 181: Alarm Level Operation
Section 7 1MRK 504 163-UUS A Differential protection To calculate the sensitivity at operating voltage, refer to equation which is acceptable as it gives around 10% minimum operating current, ignoring the current drawn by the non-linear resistor. × ° + × - °...
Page 182: Low Impedance Restricted Earth Fault Protection Refpdif (87N)
Section 7 1MRK 504 163-UUS A Differential protection IEC05000749 V1 EN-US Figure 61: Current voltage characteristics for the non-linear resistors, in the range 10-200 V, the average range of current is: 0.01–10 mA Low impedance restricted earth fault protection REFPDIF (87N) IP14640-1 v6 7.3.1 Identification...
Page 183: Transformer Winding, Solidly Grounded
Section 7 1MRK 504 163-UUS A Differential protection Fast and sensitive detection of ground faults in a power transformer winding can be obtained in solidly grounded or low impedance grounded networks by the restricted earth fault protection. The only requirement is that the power transformer winding is connected to ground in the star point (in case of wye-connected windings) or through a separate grounding transformer (in case of delta-connected windings).
Page 184: Transformer Winding, Grounded Through Zig-Zag Grounding Transformer
Section 7 1MRK 504 163-UUS A Differential protection I3PW1CT1 REFPDIF (87N) ANSI05000210_3_en.vsd ANSI05000210 V3 EN-US Figure 62: Connection of the low impedance Restricted earth fault function REFPDIF (87N) for a directly (solidly) grounded transformer winding 7.3.2.2 Transformer winding, grounded through Zig-Zag grounding transformer M13048-8 v10 A common application is for low reactance grounded transformer where the grounding is through separate Zig-Zag grounding transformers.
Page 185: Autotransformer Winding, Solidly Grounded
Section 7 1MRK 504 163-UUS A Differential protection ANSI05000211_3_en.vsd ANSI05000211 V3 EN-US Figure 63: Connection of the low impedance Restricted earth-fault function REFPDIF for a zig-zag grounding transformer 7.3.2.3 Autotransformer winding, solidly grounded M13048-13 v9 Autotransformers can be protected with the low impedance restricted ground fault protection function REFPDIF.
Page 186: Reactor Winding, Solidly Grounded
Section 7 1MRK 504 163-UUS A Differential protection including the HV side, the neutral connection and the LV side. The connection of REFPDIF (87N) for this application is shown in figure 64. I3PW1CT1 REFPDIF (87N) I3PW2CT1 ANSI05000212-4-en.vsd ANSI05000212 V4 EN-US Figure 64: Connection of restricted ground fault, low impedance function REFPDIF (87N) for an autotransformer, solidly grounded...
Page 187: Multi-Breaker Applications
Section 7 1MRK 504 163-UUS A Differential protection ANSI05000213_3_en.vsd ANSI05000213 V3 EN-US Figure 65: Connection of restricted earth-fault, low impedance function REFPDIF (87N) for a solidly grounded reactor 7.3.2.5 Multi-breaker applications M13048-23 v9 Multi-breaker arrangements including ring, one breaker-and-a-half, double breaker and mesh corner arrangements have two sets of current transformers on the phase side.
Page 188: Ct Grounding Direction
Section 7 1MRK 504 163-UUS A Differential protection REFPDIF (87N) I3PW1CT1 I3PW1CT2 ANSI05000214-2-en.vsd ANSI05000214 V2 EN-US Figure 66: Connection of Restricted earth fault, low impedance function REFPDIF (87N) in multi-breaker arrangements 7.3.2.6 CT grounding direction M13048-29 v13 To make the restricted earth fault protection REFPDIF (87N) operate correctly, the main CTs are always supposed to be wye-connected.
Page 189: Settings
Section 7 1MRK 504 163-UUS A Differential protection I3PW1CT1: Phase currents for winding 1 first current transformer set. I3PW1CT2: Phase currents for winding1 second current transformer set for multi- breaker arrangements. When not required configure input to "GRP-OFF". I3PW2CT1: Phase currents for winding 2 first current transformer set. Used for autotransformers.
Page 190: Additional Security Logic For Differential Protection Ldrgfc (11)
Section 7 1MRK 504 163-UUS A Differential protection ROA: Relay operate angle for zero sequence directional feature. It is used to differentiate an internal fault and an external fault based on measured zero sequence current and neutral current. CTFactorPri1: A factor to allow a sensitive function also at multi-breaker arrangement where the rating in the bay is much higher than the rated current of the transformer winding.
Page 191 Section 7 1MRK 504 163-UUS A 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 192: Setting Guidelines
Section 7 1MRK 504 163-UUS A 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 193 Section 7 1MRK 504 163-UUS A 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 195: Compensated Lines Zmcpdis (21), Zmcapdis (21), Zdsrdir 21D)
Section 8 1MRK 504 163-UUS A Impedance protection Section 8 Impedance protection Distance measuring zone, quadrilateral characteristic for series compensated lines ZMCPDIS (21), ZMCAPDIS (21), ZDSRDIR (21D) SEMOD168167-1 v3 8.1.1 Identification SEMOD168165-2 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number...
Page 196: System Grounding
Section 8 1MRK 504 163-UUS A 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. System grounding 8.1.2.2 SEMOD168232-11 v2 The type of system grounding plays an important roll when designing the protection...
Page 197 Section 8 1MRK 504 163-UUS A 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 198: Fault Infeed From Remote End
Section 8 1MRK 504 163-UUS A Impedance protection way as for solid grounded networks, distance protection has limited possibilities to detect 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 SEMOD168232-84 v2...
Page 199: Load Encroachment
Section 8 1MRK 504 163-UUS A Impedance protection 8.1.2.4 Load encroachment SEMOD168232-97 v3 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.
Page 200: Long Transmission Line Application
Section 8 1MRK 504 163-UUS A Impedance protection 8.1.2.5 Long transmission line application SEMOD168232-128 v3 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 201: Parallel Line Application With Mutual Coupling
Section 8 1MRK 504 163-UUS A Impedance protection LdAngle LdAngle LdAngle LdAngle RLdRev RLdFwd en05000220_ansi.vsd ANSI05000220 V1 EN-US Figure 71: Characteristic for zone measurement for long line with load encroachment activated 8.1.2.6 Parallel line application with mutual coupling SEMOD168232-149 v2 General SEMOD168232-151 v2 Introduction of parallel lines in the network is increasing due to difficulties to get...
Page 202 Section 8 1MRK 504 163-UUS A Impedance protection • Parallel line with common positive and zero sequence network • Parallel circuits with common positive but isolated zero-sequence network • Parallel circuits with positive and zero sequence sources isolated One example of class3 networks could be the mutual coupling between a 400 kV line and rail road overhead lines.
Page 203 Section 8 1MRK 504 163-UUS A Impedance protection From symmetrical components, it is possible to derive the impedance Z at the IED point for normal lines without mutual coupling according to equation 35. × × × (Equation 35) EQUATION1275 V3 EN-US Where: is phase-to-ground voltage at the IED point is phase current in the faulty phase...
Page 204 Section 8 1MRK 504 163-UUS A Impedance protection Z0 m 99000038.vsd IEC99000038 V1 EN-US Figure 73: 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 is changed, according to equation 36.
Page 205 Section 8 1MRK 504 163-UUS A Impedance protection line for the case when the fault infeed from remote end is zero, we can draw the voltage V in the faulty phase at A side as in equation 38. × × ×...
Page 206 Section 8 1MRK 504 163-UUS A Impedance protection OPEN OPEN CLOSED CLOSED en05000222_ansi.vsd ANSI05000222 V1 EN-US Figure 74: The parallel line is out of service and grounded 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 74.
Page 207 Section 8 1MRK 504 163-UUS A Impedance protection   ⋅       (Equation 43) DOCUMENT11520-IMG3502 V2 EN-US   ⋅ −       (Equation 44) DOCUMENT11520-IMG3503 V2 EN-US Parallel line out of service and not grounded SEMOD168232-243 v3 OPEN OPEN...
Page 208 Section 8 1MRK 504 163-UUS A Impedance protection 99000040.vsd IEC99000040 V1 EN-US Figure 77: 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 45. × ×...
Page 209: Tapped Line Application
Section 8 1MRK 504 163-UUS A Impedance protection × é ù é ù ë û ë û (Equation 49) EQUATION1288 V2 EN-US Ensure that the underreaching zones from both line ends will overlap a sufficient amount (at least 10%) in the middle of the protected circuit. 8.1.2.7 Tapped line application SEMOD168232-266 v2...
Page 210 Section 8 1MRK 504 163-UUS A Impedance protection ·Z (Equation 50) DOCUMENT11524-IMG3509 V3 EN-US × × Z ) ( (Equation 51) EQUATION1714 V1 EN-US Where: ZAT and ZCT is the line impedance from the B respective C station to the T point. IA and IC is fault current from A respective C station for fault between T and B.
Page 211: Series Compensation In Power Systems
Section 8 1MRK 504 163-UUS A Impedance protection single 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 arc resistance can be calculated according to Warrington's formula: ×...
Page 212 Section 8 1MRK 504 163-UUS A Impedance protection Steady state voltage regulation and increase of voltage collapse limit SEMOD168320-24 v2 A series capacitor is capable of compensating the voltage drop of the series inductance in a transmission line, as shown in figure 79. During low loading, the system voltage drop is lower and at the same time, the voltage drop on the series capacitor is lower.
Page 213 Section 8 1MRK 504 163-UUS A Impedance protection limit 1000 1200 1400 1600 1800 P[MW] en06000586_ansi.vsd ANSI06000586 V1 EN-US Figure 80: Voltage profile for a simple radial power line with 0, 30, 50 and 70% of compensation Increased power transfer capability by raising the first swing stability limit SEMOD168320-32 v2 Consider the simple one-machine and infinite bus system shown in figure 81.
Page 214 Section 8 1MRK 504 163-UUS A Impedance protection without SC with SC Mech Mech en06000588.vsd IEC06000588 V1 EN-US Figure 82: Equal area criterion and first swing stability without and with series compensation This means that the system is stable if A ≤...
Page 215 Section 8 1MRK 504 163-UUS A 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-US Figure 83: Self-regulating effect of reactive power balance Increase in power transfer SEMOD168320-45 v2...
Page 216 Section 8 1MRK 504 163-UUS A Impedance protection from 20 to 70 percent. Transmission capability increases of more than two times can be obtained in practice. Multiple of power over a non-compensated line Power transfer with constant angle difference Degree of Degree of series compensation [%] compensation IEC06000592-2-en.vsd...
Page 217 Section 8 1MRK 504 163-UUS A Impedance protection Reduced costs of power transmission due to decreased investment costs for new power line SEMOD168320-88 v2 As shown in figure the line loading can easily be increased 1.5-2 times by series compensation. Thus, the required number of transmission lines needed for a certain power transfer can be significantly reduced.
Page 218 Section 8 1MRK 504 163-UUS A Impedance protection en06000595.vsd IEC06000595 V1 EN-US Figure 88: Thyristor switched series capacitor en06000596_ansi.vsd ANSI06000596 V1 EN-US Figure 89: 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 219 Section 8 1MRK 504 163-UUS A 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 220: Challenges In Protection Of Series Compensated And Adjacent Power Lines
Section 8 1MRK 504 163-UUS A 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 221 Section 8 1MRK 504 163-UUS A Impedance protection reactive voltage drop D V on X line impedance leads the current by 90 degrees. Voltage drop DV on series capacitor lags the fault current by 90 degrees. Note that line impedance X could be divided into two parts: one between the IED point and the capacitor and one between the capacitor and the fault position.
Page 222 Section 8 1MRK 504 163-UUS A Impedance protection without series capacitor. Voltage V in IED point will lag the fault current I in case when: < < (Equation 58) EQUATION1902 V1 EN-US 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 223 Section 8 1MRK 504 163-UUS A Impedance protection With inserted capacitor Source voltage Pre -fault voltage With bypassed capacitor V’ Fault voltage Source en06000607_ansi.vsd ANSI06000607 V1 EN-US Figure 94: Current inversion on series compensated line 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.
Page 224 Section 8 1MRK 504 163-UUS A Impedance protection With bypassed With inserted capacitor capacitor en06000608_ansi.vsd ANSI06000608 V1 EN-US Figure 95: Phasor diagrams of currents and voltages for the bypassed and inserted series capacitor during current inversion It is a common practice to call this phenomenon current inversion. Its consequences on operation of different protections in series compensated networks depend on their operating principle.
Page 225 Section 8 1MRK 504 163-UUS A Impedance protection network with and without series capacitor. Possible effects of spark gap flashing or MOV conducting are neglected. The time dependence of fault currents and the difference between them are of interest. en06000609.vsd IEC06000609 V1 EN-US Figure 96: Simplified equivalent scheme of SC network during fault conditions...
Page 226 Section 8 1MRK 504 163-UUS A Impedance protection L R s (Equation 64) EQUATION1907 V1 EN-US The basic loop differential equation describing the circuit in figure with series capacitor is presented by equation 65. × × × × × + (Equation 65) EQUATION1908 V1 EN-US The solution over line current is in this case presented by group of equations 66.
Page 227 Section 8 1MRK 504 163-UUS A Impedance protection The transient part has an angular frequency b and is damped out with the time-constant α. The difference in performance of fault currents for a three-phase short circuit at the end of a typical 500 km long 500 kV line is presented in figure 97. The short circuit current on a non-compensated line is lower in magnitude, but comprises at the beginning only a transient DC component, which diminishes completely in approximately 120ms.
Page 228 Section 8 1MRK 504 163-UUS A Impedance protection Figure shows schematically the possible locations of instrument transformers related to the position of line-end series capacitor. - jX CT 1 CT 2 VT 2 en06000611_ansi.vsd ANSI06000611 V1 EN-US Figure 98: Possible positions of instrument transformers relative to line end series capacitor Bus side instrument transformers SEMOD168320-266 v2...
Page 229 Section 8 1MRK 504 163-UUS A Impedance protection installations also in switchyards with double-bus double-breaker and breaker-and-a- half arrangement. The advantage of such schemes is that the unit protections cover also for shunt faults in series capacitors and at the same time the voltage inversion does not appear for faults on the protected line.
Page 230 Section 8 1MRK 504 163-UUS A 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-US Figure 101:...
Page 231 Section 8 1MRK 504 163-UUS A 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 232: Impact Of Series Compensation On Protective Ied Of Adjacent Lines
Section 8 1MRK 504 163-UUS A 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 SEMOD168320-318 v2 Voltage inversion is not characteristic for the buses and IED points closest to the series compensated line only.
Page 233: Distance Protection
Section 8 1MRK 504 163-UUS A 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 234 Section 8 1MRK 504 163-UUS A 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 235 Section 8 1MRK 504 163-UUS A 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...
Page 236 Section 8 1MRK 504 163-UUS A Impedance protection < < (Equation 72) EQUATION1898 V1 EN-US 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 237 Section 8 1MRK 504 163-UUS A Impedance protection en06000621_ansi.vsd ANSI06000621 V1 EN-US Figure 107: 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 238 Section 8 1MRK 504 163-UUS A Impedance protection ordinary fault. However, a good protection system should be able to operate correctly before and after gap flashing occurs. en06000584_small.vsd en06000625.vsd IEC06000584-SMALL V1 EN-US IEC06000625 V1 EN-US Figure 109: Quadrilateral Figure 108: Cross-polarized characteristic with quadrilateral...
Page 239 Section 8 1MRK 504 163-UUS A Impedance protection current in a power line without a capacitor (current inversion). The negative direction of the fault current will persist until the spark gap has flashed. Sometimes there will be no flashover at all, because the fault current is less than the setting value of the spark gap.
Page 240 Section 8 1MRK 504 163-UUS A Impedance protection circuit for a fault at B bus of a double circuit line with one circuit disconnected and grounded at both IEDs. The effect of zero sequence mutual impedance on possible overreaching of distance IEDs at A bus is increased compared to non compensated operation, because series capacitor does not compensate for this reactance.
Page 241: Setting Guidelines
Section 8 1MRK 504 163-UUS A Impedance protection To avoid the unwanted tripping, some manufacturers provide a feature in their distance protection which detects that the fault current has changed in direction and temporarily blocks distance protection. Another method employed is to temporarily block the signals received at the healthy line as soon as the parallel faulty line protection initiates tripping.
Page 242: Setting Of Zone1
Section 8 1MRK 504 163-UUS A Impedance protection 8.1.3.2 Setting of zone1 SEMOD168247-15 v2 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 243: Setting Of Reverse Zone
Section 8 1MRK 504 163-UUS A Impedance protection Z AC Z CB Z CF I A+ IB ANSI05000457-2-en.vsd ANSI05000457 V2 EN-US Figure 113: 8.1.3.4 Setting of reverse zone SEMOD168247-33 v2 The reverse zone is applicable for purposes of scheme communication logic, current reversal logic, weak-end-infeed logic, and so on.
Page 244 Section 8 1MRK 504 163-UUS A 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 245 Section 8 1MRK 504 163-UUS A Impedance protection 100 % 99000202.vsd IEC99000202 V1 EN-US Figure 114: 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 246 Section 8 1MRK 504 163-UUS A Impedance protection Reactive Reach Compensated lines with the capacitor into the zone 1 reach : LLOC en07000063.vsd IEC07000063 V1 EN-US Figure 115: Simplified single line diagram of series capacitor located at X LLOC from A station Transformer protection RET670 2.2 ANSI Application manual...
Page 247 Section 8 1MRK 504 163-UUS A Impedance protection line LLOC en06000584-2.vsd IEC06000584 V2 EN-US Figure 116: 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 248 Section 8 1MRK 504 163-UUS A 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 249: Setting Of Zones For Parallel Line Application
Section 8 1MRK 504 163-UUS A 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 250 Section 8 1MRK 504 163-UUS A Impedance protection (Equation 85) EQUATION554 V1 EN-US 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 251: Setting Of Reach In Resistive Direction
Section 8 1MRK 504 163-UUS A Impedance protection 8.1.3.7 Setting of reach in resistive direction SEMOD168247-76 v2 Set the resistive reach independently for each zone, and separately for phase-to-phase (R1PP), 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 252 Section 8 1MRK 504 163-UUS A Impedance protection loa d min (Equation 95) EQUATION1718 V1 EN-US Where: is the minimum phase-to-phase voltage in kV is the maximum apparent power in MVA. The load impedance [Ω/phase] is a function of the minimum operation voltage and the maximum load current: loa d ×...
Page 253: Load Impedance Limitation, With Load Encroachment Function Activated
Section 8 1MRK 504 163-UUS A Impedance protection é × ù £ × × ¶ - × ¶ RFPG ê ú ë û load × (Equation 98) EQUATION1721 V2 EN-US 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 254: Setting Of Timers For Distance Protection Zones
Section 8 1MRK 504 163-UUS A 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 255: Application
Section 8 1MRK 504 163-UUS A Impedance protection 8.2.2 Application M13138-3 v3 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 256 Section 8 1MRK 504 163-UUS A Impedance protection In some applications, for instance cable lines, the angle of the loop might be less than 60°. In these applications, the settings of fault resistance coverage in forward and reverse direction, 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.
Page 257 Section 8 1MRK 504 163-UUS A Impedance protection ( / loop) 60° 60° ( / loop) IEC09000043_1_en.vsd IEC09000043 V1 EN-US Figure 117: 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 258 Section 8 1MRK 504 163-UUS A Impedance protection Reactive reach M13142-9 v4 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 equation gives the minimum recommended reactive reach. ³...
Page 259 Section 8 1MRK 504 163-UUS A Impedance protection Resistive reach M13142-156 v4 The resistive reach in reverse direction must be set longer than the longest reverse zones. In blocking schemes it must be set longer than the overreaching zone at remote end that is used in the communication scheme.
Page 260 Section 8 1MRK 504 163-UUS A Impedance protection ( / phase) 60° 60° ( / phase) IEC09000257_1_en.vsd IEC09000257 V1 EN-US Figure 118: 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 261: Resistive Reach With Load Encroachment Characteristic
Section 8 1MRK 504 163-UUS A Impedance protection 8.2.3.2 Resistive reach with load encroachment characteristic M13142-312 v4 The procedure for calculating the settings for the load encroachment consist basically to define the load angle LdAngle, the blinder RLdFwd in forward direction and blinder RLdRev in reverse direction, as shown in figure 119.
Page 262: Minimum Operate Currents
Section 8 1MRK 504 163-UUS A Impedance protection × RLdFwd exp max where: P exp max is the maximum exporting active power V min is the minimum voltage for which the Pexp max occurs RLdFwd can be lesser than the calculated is a security factor to ensure that the setting of minimal resistive load.
Page 263: Distance Measuring Zones, Quadrilateral Characteristic Zmqpdis 21), Zmqapdis (21), Zdrdir (21D)
Section 8 1MRK 504 163-UUS A Impedance protection Distance measuring zones, quadrilateral characteristic ZMQPDIS (21), ZMQAPDIS (21), ZDRDIR (21D) IP14498-1 v4 8.3.1 Identification M14852-1 v6 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Distance protection zone, quadrilateral ZMQPDIS characteristic (zone 1) S00346 V1 EN-US...
Page 264 Section 8 1MRK 504 163-UUS A Impedance protection ANSI05000215 V2 EN-US Figure 120: 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 265 Section 8 1MRK 504 163-UUS A Impedance protection Effectively grounded networks M17048-38 v6 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 110. (Equation 110) ANSIEQUATION1268 V1 EN-US Where: is the highest fundamental frequency voltage on one of the healthy phases at single...
Page 266 Section 8 1MRK 504 163-UUS A 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 267: Fault Infeed From Remote End
Section 8 1MRK 504 163-UUS A Impedance protection 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 of phenomenon, a separate function called Phase preference logic (PPLPHIZ) is needed in medium and subtransmission network.
Page 268: Load Encroachment
Section 8 1MRK 504 163-UUS A Impedance protection p*ZL (1-p)*ZL en05000217_ansi.vsd ANSI05000217 V1 EN-US Figure 122: 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 269: Short Line Application
Section 8 1MRK 504 163-UUS A Impedance protection sufficient fault resistance coverage. 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 270: Long Transmission Line Application
Section 8 1MRK 504 163-UUS A 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 123.
Page 271: Parallel Line Application With Mutual Coupling
Section 8 1MRK 504 163-UUS A Impedance protection LdAngle LdAngle LdAngle LdAngle RLdRev RLdFwd en05000220_ansi.vsd ANSI05000220 V1 EN-US Figure 124: Characteristic for zone measurement for a long line 8.3.2.6 Parallel line application with mutual coupling M17048-417 v2 General M17048-567 v3 Introduction of parallel lines in the network is increasing due to difficulties to get necessary area for new lines.
Page 272 Section 8 1MRK 504 163-UUS A Impedance protection Parallel line with common positive and zero sequence network Parallel circuits with common positive but isolated zero sequence network Parallel circuits with positive and zero sequence sources isolated. One example of class 3 networks could be the mutual coupling between a 400kV line and rail road overhead lines.
Page 273 Section 8 1MRK 504 163-UUS A Impedance protection From symmetrical components, we can derive the impedance Z at the relay point for normal lines without mutual coupling according to equation 117. × × × (Equation 117) EQUATION1275 V3 EN-US Where: is phase to ground voltage at the relay point is phase current in the faulty phase is ground fault current...
Page 274 Section 8 1MRK 504 163-UUS A Impedance protection When mutual coupling is introduced, the voltage at the relay point A will be changed according to equation 118. æ ö × × ç ÷ × × è ø (Equation 118) EQUATION1276 V4 EN-US By dividing equation by equation and after some simplification we can write...
Page 275 Section 8 1MRK 504 163-UUS A Impedance protection Simplification of equation 121, solving it for 3I0p and substitution of the result into equation gives that the voltage can be drawn as: æ ö × ç ÷ × × × è ø...
Page 276 Section 8 1MRK 504 163-UUS A Impedance protection 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 128.
Page 277 Section 8 1MRK 504 163-UUS A Impedance protection Parallel line out of service and not grounded M17048-537 v5 OPEN OPEN CLOSED CLOSED en05000223_ansi.vsd ANSI05000223 V1 EN-US Figure 129: 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 278: Tapped Line Application
Section 8 1MRK 504 163-UUS A 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 129. × × + × ×...
Page 279 Section 8 1MRK 504 163-UUS A Impedance protection M17048-245 v4 ANSI05000224-2-en.vsd ANSI05000224 V2 EN-US Figure 131: 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 280 Section 8 1MRK 504 163-UUS A 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...
Page 281: Setting Guidelines
Section 8 1MRK 504 163-UUS A Impedance protection × 28707 L Rarc (Equation 134) EQUATION1456 V1 EN-US 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 282: Setting Of Zone 1
Section 8 1MRK 504 163-UUS A Impedance protection 8.3.3.2 Setting of zone 1 SEMOD55087-22 v3 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 283: Setting Of Reverse Zone
Section 8 1MRK 504 163-UUS A Impedance protection     ⋅ ⋅  ⋅  ⋅       (Equation 135) EQUATION302 V5 EN-US Z AC Z CB Z CF I A+ IB ANSI05000457-2-en.vsd ANSI05000457 V2 EN-US Figure 132: Setting of overreaching zone 8.3.3.4...
Page 284: Setting Of Zones For Parallel Line Application
Section 8 1MRK 504 163-UUS A Impedance protection 8.3.3.5 Setting of zones for parallel line application SEMOD55087-50 v2 Parallel line in service – Setting of zone 1 SEMOD55087-52 v3 With reference to section "Parallel line applications", the zone reach can be set to 85% of the protected line.
Page 285: Setting Of Reach In Resistive Direction
Section 8 1MRK 504 163-UUS A Impedance protection × (Equation 141) EQUATION1428 V2 EN-US Parallel line is out of service and grounded in both ends SEMOD55087-77 v3 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 286: Load Impedance Limitation, Without Load Encroachment Function
Section 8 1MRK 504 163-UUS A 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 146) IECEQUATION2305 V2 EN-US The fault resistance for phase-to-phase faults is normally quite low, compared to the fault resistance for phase-to-ground faults.
Page 287 Section 8 1MRK 504 163-UUS A 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...
Page 288: Load Impedance Limitation, With Phase Selection With Load Encroachment, Quadrilateral Characteristic Function Activated
Section 8 1MRK 504 163-UUS A Impedance protection   RFFwPP ≤ ⋅ ⋅ ∂ − ⋅ ∂ load     (Equation 153) IEC13000276 V1 EN-US Set the fault resistance coverage RFRwPP and RFRwPG to the same value as in forward direction, if that suits the application.
Page 289 Section 8 1MRK 504 163-UUS A Impedance protection × × < < ArgDir ArgNeg (Equation 154) EQUATION1552 V2 EN-US For the AB element, the equation in forward direction is according to. × × < < ArgDir L L M ArgNeg (Equation 155) EQUATION1553 V2 EN-US where:...
Page 290 Section 8 1MRK 504 163-UUS A Impedance protection AngNegRes AngDir en05000722_ansi.vsd ANSI05000722 V1 EN-US Figure 133: 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 291: Setting Of Timers For Distance Protection Zones
Section 8 1MRK 504 163-UUS A Impedance protection 8.3.3.11 Setting of timers for distance protection zones SEMOD55087-147 v6 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 292: Setting Guidelines
Section 8 1MRK 504 163-UUS A Impedance protection 8.4.3 Setting guidelines SEMOD154496-1 v2 8.4.3.1 Configuration GUID-5EB33045-361C-4849-8E53-C793A209E3FA v3 First of all it is required to configure the Mho function in the way shown in figure 134. Note that a directional function block (that is ZDMPDIR) and a required number of zones (that is ZMHPDIS) shall only be configured.
Page 293 Section 8 1MRK 504 163-UUS A Impedance protection HV Substation HV CB 65MVA Step-up 123/13kV Transformer =10% Auxiliary Transformer Generator CB REG670 Excitation Transformer VT: 13,5kV/110V 70MVA 13,2kV 3062A CT: 4000/5 Z< ZMH PDIS IEC10000102 V1 EN-US Figure 135: Application example for generator under-impedance function The first under-impedance protection zone shall cover 100% of the step-up transformer impedance with a time delay of 1.0s.
Page 294 Section 8 1MRK 504 163-UUS A Impedance protection Calculate the step-up transformer impedance, in primary ohms, from the 13kV side as follows: 10 13 × × 0, 26 100 65 IEC-EQUATION2318 V1 EN-US Then the reach in primary ohms shall be set to 100% of transformer impedance. Thus the reach shall be set to 0,26Ω...
Page 295 Section 8 1MRK 504 163-UUS A Impedance protection ZAngPP IEC10000105-1-en.vsd IEC10000105 V1 EN-US Figure 136: Operating characteristic for phase-to-phase loops Transformer protection RET670 2.2 ANSI Application manual...
Page 296: Full-Scheme Distance Protection, Quadrilateral For Earth Faults Zmmpdis (21), Zmmapdis (21)
Section 8 1MRK 504 163-UUS A Impedance protection Full-scheme distance protection, quadrilateral for earth faults ZMMPDIS (21), ZMMAPDIS (21) SEMOD154561-1 v2 8.5.1 Identification SEMOD154542-2 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Fullscheme distance protection, ZMMPDIS quadrilateral for earth faults (zone 1) S00346 V1 EN-US...
Page 297 Section 8 1MRK 504 163-UUS A Impedance protection ANSI05000215 V2 EN-US Figure 137: 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 ground fault current. The shunt admittance has very limited influence on the ground fault current.
Page 298 Section 8 1MRK 504 163-UUS A Impedance protection Effectively grounded networks SEMOD154680-40 v4 A network is defined as effectively grounded if the ground fault factor fe is less than 1.4. The ground fault factor is defined according to equation 157. (Equation 157) ANSIEQUATION1268 V1 EN-US Where:...
Page 299 Section 8 1MRK 504 163-UUS A Impedance protection voltage (3U0) will have the same magnitude in different places in the network due to low voltage drop distribution. The magnitude of the total fault current can be calculated according to the formula below: (Equation 160) EQUATION1271 V3 EN-US...
Page 300: Fault Infeed From Remote End
Section 8 1MRK 504 163-UUS A Impedance protection preference logic (PPLPHIZ) is needed, which is not common to be used in transmission applications. In this type of network, it is mostly not possible to use distance protection for detection and clearance of ground-faults. The low magnitude of the ground-fault current might not give start of the zero sequence measurement element or the sensitivity will be too low for acceptance.
Page 301: Load Encroachment
Section 8 1MRK 504 163-UUS A Impedance protection p*ZL (1-p)*ZL Z < Z < en05000217.vsd IEC05000217 V1 EN-US Figure 139: Influence of fault infeed from remote end. The effect of fault current infeed from remote end is one of the most driving factors for justify complementary protection to distance protection.
Page 302: Short Line Application
Section 8 1MRK 504 163-UUS A Impedance protection The settings of the parameters for load encroachment are done in the Phase selection with load enchroachment, quadrilateral characteristic (FDPSPDIS,21). Load impedance area in LdAngle forward direction LdAngle LdAngle LdAngle RLdFwd RldRev ANSI05000495_2_en.vsd ANSI05000495 V2 EN-US Figure 140:...
Page 303: Long Transmission Line Application
Section 8 1MRK 504 163-UUS A Impedance protection Load encroachment is normally no problems for short line applications so the load encroachment function could be switched off (OperationLdCmp = Off). This will increase the possibility to detect resistive close-in faults. 8.5.2.6 Long transmission line application SEMOD154680-127 v2...
Page 304 Section 8 1MRK 504 163-UUS A Impedance protection From an application point of view there exists three types of network configurations (classes) that must be considered when making the settings for the protection function. Those are: Parallel line with common positive and zero sequence network Parallel circuits with common positive but isolated zero-sequence network Parallel circuits with positive and zero sequence sources isolated.
Page 305 Section 8 1MRK 504 163-UUS A Impedance protection Parallel line in service SEMOD154680-175 v2 This type of application is very common and applies to all normal sub-transmission and transmission networks. A simplified single line diagram is shown in figure 141. ×...
Page 306 Section 8 1MRK 504 163-UUS A Impedance protection Z0 m 99000038.vsd IEC99000038 V1 EN-US Figure 142: 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 307 Section 8 1MRK 504 163-UUS A 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 143.
Page 308 Section 8 1MRK 504 163-UUS A Impedance protection Parallel line out of service and not grounded SEMOD154680-242 v2 Z< Z< en05000223.vsd IEC05000223 V1 EN-US Figure 145: 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 309: Tapped Line Application
Section 8 1MRK 504 163-UUS A 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 170. × × + × ×...
Page 310 Section 8 1MRK 504 163-UUS A Impedance protection SEMOD154680-267 v2 Z< Z< Z< en05000224.vsd DOCUMENT11524-IMG869 V1 EN-US Figure 147: 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 311 Section 8 1MRK 504 163-UUS A 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 312: Setting Guidelines
Section 8 1MRK 504 163-UUS A Impedance protection 8.5.3 Setting guidelines SEMOD154701-1 v1 8.5.3.1 General SEMOD154704-4 v2 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 313: Setting Of Reverse Zone
Section 8 1MRK 504 163-UUS A Impedance protection from 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 314: Setting Of Zones For Parallel Line Application
Section 8 1MRK 504 163-UUS A 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 315: Setting Of Reach In Resistive Direction
Section 8 1MRK 504 163-UUS A 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 180) EQUATION1426 V1 EN-US 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...
Page 316: Load Impedance Limitation, Without Load Encroachment Function
Section 8 1MRK 504 163-UUS A 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 185.
Page 317 Section 8 1MRK 504 163-UUS A Impedance protection The load impedance [Ω/phase] is a function of the minimum operation voltage and the maximum load current: load × (Equation 189) EQUATION1781-ANSI V1 EN-US Minimum voltage V and maximum current Imax are related to the same operating conditions.
Page 318: Load Impedance Limitation, With Load Encroachment Function Activated
Section 8 1MRK 504 163-UUS A Impedance protection 8.5.3.8 Load impedance limitation, with load encroachment function activated SEMOD154704-129 v1 The parameters for load encroachment shaping of the characteristic are found in the description of the phase selection with load encroachment function, section "Resistive reach with load encroachment characteristic".
Page 319: Identification
Section 8 1MRK 504 163-UUS A Impedance protection 8.6.1 Identification GUID-39299546-12A2-4D9D-86D0-A33F423944E4 v2 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-US 8.6.2 Application SEMOD154885-5 v9 The phase-to-ground impedance elements can be supervised by a phase unselective directional function based on symmetrical components (option).
Page 320 Section 8 1MRK 504 163-UUS A Impedance protection The negative-sequence voltage polarized ground directional unit compares correspondingly I with -V2. 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 321: Mho Impedance Supervision Logic Zsmgapc
Section 8 1MRK 504 163-UUS A Impedance protection voltage added by a phase-shifted portion of zero-sequence current (see equation 192) at the location of the protection. The factor k = setting K . This type of polarization is 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.
Page 322: Setting Guidelines
Section 8 1MRK 504 163-UUS A Impedance protection transformer winding or connection. This will block all trips by the distance protection since they are based on voltage measurement. 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 323: Faulty Phase Identification With Load Encroachment Fmpspdis (21)
Section 8 1MRK 504 163-UUS A Impedance protection SIRLevel: The setting of the parameter SIRLevel is by default set to 10. This is a suitable setting for applications with CVT to avoid transient overreach due to the CVT dynamics. If magnetic voltage transformers are used, set SIRLevel to 15 the highest level.
Page 324: Setting Guidelines
Section 8 1MRK 504 163-UUS A Impedance protection The load encroachment algorithm and the blinder functions are always activated in the phase selector. The influence from these functions on the zone measurement characteristic has to be activated by switching the setting parameter LoadEnchMode for the respective measuring zone(s) to Enabled.
Page 325: Load Encroachment
Section 8 1MRK 504 163-UUS A Impedance protection ILoad × VLmn (Equation 195) EQUATION1615-ANSI V1 EN-US 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 SEMOD154782-39 v4...
Page 326: Distance Protection Zone, Quadrilateral Characteristic, Separate Settings Zmrpdis (21), Zmrapdis (21) And Zdrdir (21D)
Section 8 1MRK 504 163-UUS A Impedance protection Zload (Equation 197) EQUATION1753-ANSI V1 EN-US 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 198: æ...
Page 327: Identification
Section 8 1MRK 504 163-UUS A Impedance protection 8.9.1 Identification GUID-420DD49A-C65B-4F04-B317-9558DCCE7A52 v1 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-US Distance protection zone, quadrilateral ZMRAPDIS characteristic, separate settings (zone 2-5)
Page 328 Section 8 1MRK 504 163-UUS A Impedance protection ANSI05000215 V2 EN-US Figure 150: 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 329 Section 8 1MRK 504 163-UUS A Impedance protection Effectively grounded networks GUID-5F4CCC18-2BAC-4140-B56C-B9002CD36318 v1 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 201. (Equation 201) ANSIEQUATION1268 V1 EN-US Where: is the highest fundamental frequency voltage on one of the healthy phases at single...
Page 330 Section 8 1MRK 504 163-UUS A 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 331: Fault Infeed From Remote End
Section 8 1MRK 504 163-UUS A Impedance protection 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 332: Load Encroachment
Section 8 1MRK 504 163-UUS A Impedance protection p*ZL (1-p)*ZL en05000217_ansi.vsd ANSI05000217 V1 EN-US Figure 152: 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 333: Short Line Application
Section 8 1MRK 504 163-UUS A Impedance protection 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 334: Long Transmission Line Application
Section 8 1MRK 504 163-UUS A 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 153.
Page 335 Section 8 1MRK 504 163-UUS A Impedance protection General GUID-8136A6E6-085F-46A1-9BB4-F02730393D02 v1 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 336 Section 8 1MRK 504 163-UUS A Impedance protection Parallel line applications GUID-9980E92C-EDB1-4E0C-A4BD-167C896199A1 v1 This type of networks are 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 337 Section 8 1MRK 504 163-UUS A Impedance protection FAULT en05000221_ansi.vsd ANSI05000221 V1 EN-US Figure 154: Class 1, parallel line in service. The equivalent zero sequence circuit of the lines can be simplified, see figure 155. IEC09000253_1_en.vsd IEC09000253 V1 EN-US Figure 155: Equivalent zero sequence impedance circuit of the double-circuit, parallel, operating line with a single phase-to-ground fault at the remote busbar.
Page 338 Section 8 1MRK 504 163-UUS A 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 339 Section 8 1MRK 504 163-UUS A 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%.
Page 340 Section 8 1MRK 504 163-UUS A Impedance protection (Equation 215) EQUATION2002 V4 EN-US 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 341: Tapped Line Application
Section 8 1MRK 504 163-UUS A Impedance protection high which limits the zero sequence current on the parallel line to very low values. In practice, the equivalent zero sequence impedance circuit for faults at the remote bus bar can be simplified to the circuit shown in figure The line zero sequence mutual impedance does not influence the measurement of the distance protection in a faulty circuit.
Page 342 Section 8 1MRK 504 163-UUS A Impedance protection infeed. For example, for faults between the T point and B station the measured impedance at A and C will be ·Z (Equation 218) DOCUMENT11524-IMG3509 V3 EN-US × × Z ) ( (Equation 219) EQUATION1714 V1 EN-US Where:...
Page 343: Setting Guidelines
Section 8 1MRK 504 163-UUS A Impedance protection necessary to determine suitable settings and selection of proper scheme communication. Fault resistance GUID-115D7410-1398-45FB-BDDD-E778740E1641 v1 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 344: Setting Of Zone 1
Section 8 1MRK 504 163-UUS A 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 345: Setting Of Reverse Zone
Section 8 1MRK 504 163-UUS A Impedance protection Larger overreach than the mentioned 80% can often be acceptable due to fault current infeed from other lines. This requires however analysis by means of fault calculations. If any of the above indicates a zone 2 reach less than 120%, the time delay of zone 2 must be increased by approximately 200ms to avoid unwanted operation in cases when the telecommunication for the short adjacent line at remote end is down during faults.
Page 346: Setting Of Zones For Parallel Line Application
Section 8 1MRK 504 163-UUS A Impedance protection ³ × 1.2 Z2 (Equation 222) EQUATION2314 V1 EN-US 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 347: Setting Of Reach In Resistive Direction
Section 8 1MRK 504 163-UUS A Impedance protection × (Equation 225) EQUATION1426 V1 EN-US 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 as: ×...
Page 348: Load Impedance Limitation, Without Load Encroachment Function
Section 8 1MRK 504 163-UUS A 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 230. ×...
Page 349 Section 8 1MRK 504 163-UUS A Impedance protection loa d min (Equation 234) EQUATION1718 V1 EN-US Where: is the minimum phase-to-phase voltage in kV is the maximum apparent power in MVA. The load impedance [Ω/phase] is a function of the minimum operation voltage and the maximum load current: loa d ×...
Page 350: Load Impedance Limitation, With Phase Selection With Load Encroachment, Quadrilateral Characteristic Function Activated
Section 8 1MRK 504 163-UUS A Impedance protection é × ù £ × × ¶ - × ¶ RFPG ê ú ë û load × (Equation 237) EQUATION1721 V2 EN-US Where: ∂ is a maximum load-impedance angle, related to the maximum load power. To avoid load encroachment for the phase-to-phase measuring elements, the set resistive reach of any distance protection zone must be less than 160% of the minimum load impedance.
Page 351: Setting Of Timers For Distance Protection Zones
Section 8 1MRK 504 163-UUS A 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 352 Section 8 1MRK 504 163-UUS A Impedance protection matter. Phase selection, quadrilateral characteristic with settable angle (FRPSPDIS, 21) is designed to 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.
Page 353 Section 8 1MRK 504 163-UUS A Impedance protection RLdFwd LdAngle LdAngle LdAngle LdAngle RLdRev en05000196_ansi.vsd ANSI05000196 V1 EN-US Figure 162: 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 163).
Page 354 Section 8 1MRK 504 163-UUS A Impedance protection PHSELZ DLECND ANSI10000099-1-en.vsd ANSI10000099 V1 EN-US Figure 163: 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 164. The figure shows a distance measuring zone operating in forward direction.
Page 355 Section 8 1MRK 504 163-UUS A Impedance protection "Phase selection" "quadrilateral" zone Distance measuring zone Load encroachment characteristic Directional line en05000673.vsd IEC05000673 V1 EN-US Figure 164: 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 356 Section 8 1MRK 504 163-UUS A Impedance protection (ohm/phase) Phase selection ”Quadrilateral” zone Distance measuring zone (ohm/phase) en05000674.vsd IEC05000674 V1 EN-US Figure 165: 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 166.
Page 357: Load Encroachment Characteristics
Section 8 1MRK 504 163-UUS A Impedance protection IEC08000437.vsd IEC08000437 V1 EN-US Figure 166: 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 358: Phase-To-Ground Fault In Forward Direction
Section 8 1MRK 504 163-UUS A Impedance protection For normal overhead lines, the angle for the loop impedance φ for phase-to-ground fault defined according to equation 240. arctan (Equation 240) EQUATION2115 V1 EN-US But in some applications, for instance cable lines, the angle of the loop might be less than the set angle.
Page 359 Section 8 1MRK 504 163-UUS A 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-US Figure 167: Relation between measuring zone and FRPSPDIS (21) characteristic Reactive reach GUID-8C693495-10FA-47D5-BEFC-E72C8577E88B v1 The reactive reach in forward direction must as minimum be set to cover the measuring...
Page 360: Phase-To-Ground Fault In Reverse Direction
Section 8 1MRK 504 163-UUS A Impedance protection ³ × 1.44 X0 (Equation 242) EQUATION1310 V1 EN-US 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 361: Phase-To-Phase Fault In Forward Direction
Section 8 1MRK 504 163-UUS A Impedance protection Resistive reach M13142-156 v4 The resistive reach in reverse direction must be set longer than the longest reverse zones. In blocking schemes it must be set longer than the overreaching zone at remote end that is used in the communication scheme.
Page 362 Section 8 1MRK 504 163-UUS A 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 363: Setting Guidelines
Section 8 1MRK 504 163-UUS A 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-US Figure 168: Relation between measuring zone and FRPSPDIS (21) characteristic for phase-to-phase fault for φline>70°...
Page 364: Resistive Reach With Load Encroachment Characteristic
Section 8 1MRK 504 163-UUS A Impedance protection 8.10.4.1 Resistive reach with load encroachment characteristic M13142-312 v4 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 169.
Page 365: Minimum Operate Currents
Section 8 1MRK 504 163-UUS A 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 366: Setting Guidelines
Section 8 1MRK 504 163-UUS A Impedance protection to 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 367 Section 8 1MRK 504 163-UUS A Impedance protection Phase-to-ground fault in forward direction M13142-6 v7 With reference to figure 170, 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 368 Section 8 1MRK 504 163-UUS A Impedance protection ( / loop) 60° 60° ( / loop) IEC09000043_1_en.vsd IEC09000043 V1 EN-US Figure 170: 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 369 Section 8 1MRK 504 163-UUS A Impedance protection Reactive reach M13142-9 v4 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 equation gives the minimum recommended reactive reach. ³...
Page 370 Section 8 1MRK 504 163-UUS A Impedance protection Resistive reach M13142-156 v4 The resistive reach in reverse direction must be set longer than the longest reverse zones. In blocking schemes it must be set longer than the overreaching zone at remote end that is used in the communication scheme.
Page 371 Section 8 1MRK 504 163-UUS A Impedance protection ( / phase) 60° 60° ( / phase) IEC09000257_1_en.vsd IEC09000257 V1 EN-US Figure 171: 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 372: Resistive Reach With Load Encroachment Characteristic
Section 8 1MRK 504 163-UUS A Impedance protection 8.11.3.2 Resistive reach with load encroachment characteristic M13142-312 v4 The procedure for calculating the settings for the load encroachment consist basically to define the load angle LdAngle, the blinder RLdFwd in forward direction and blinder RLdRev in reverse direction, as shown in figure 172.
Page 373: Minimum Operate Currents
Section 8 1MRK 504 163-UUS A Impedance protection × RLdFwd exp max where: P exp max is the maximum exporting active power V min is the minimum voltage for which the Pexp max occurs RLdFwd can be lesser than the calculated is a security factor to ensure that the setting of minimal resistive load.
Page 374: Application
Section 8 1MRK 504 163-UUS A Impedance protection 8.12.2 Application IP14961-1 v2 GUID-2F952D87-6BEB-4425-B823-DF8511B9E742 v3 The fast distance protection function ZMFPDIS in the IED is designed to provide sub- cycle, down to half-cycle operating time for basic faults. At the same time, it is specifically designed for extra care during difficult conditions in high-voltage transmission networks, like faults on long heavily loaded lines and faults generating heavily distorted signals.
Page 375 Section 8 1MRK 504 163-UUS A 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 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 during line to ground fault is generally lower than 140% of the nominal phase-to-ground voltage.
Page 376 Section 8 1MRK 504 163-UUS A Impedance protection £ (Equation 261) EQUATION2123 V1 EN-US 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 377: Fault Infeed From Remote End
Section 8 1MRK 504 163-UUS A Impedance protection The neutral point reactor is normally designed so that it can be tuned to a position where the reactive current balances the capacitive current from the network: × × (Equation 263) EQUATION1272 V1 EN-US ANSI05000216 V2 EN-US Figure 174: High impedance grounded network...
Page 378: Load Encroachment
Section 8 1MRK 504 163-UUS A Impedance protection × × × I p Z (Equation 264) EQUATION1273 V1 EN-US If we divide V by I we get Z present to the IED at A side. × × (Equation 265) EQUATION1274 V2 EN-US The infeed factor (I can be very high, 10-20 depending on the differences in source impedances at local and remote end.
Page 379: Short Line Application
Section 8 1MRK 504 163-UUS A Impedance protection The IED has a built in feature which shapes the characteristic according to the characteristic shown in figure 176. The load encroachment algorithm will increase the possibility to detect high fault resistances, especially for phase-to-ground faults at remote line end.
Page 380: Long Transmission Line Application
Section 8 1MRK 504 163-UUS A Impedance protection In short line applications, the major concern is to get sufficient fault resistance coverage. Load encroachment is not such a common problem. 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 32.
Page 381: Parallel Line Application With Mutual Coupling
Section 8 1MRK 504 163-UUS A 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 176.
Page 382 Section 8 1MRK 504 163-UUS A Impedance protection The distance protection within the IED can compensate for the influence of a zero sequence mutual coupling on the measurement at single phase-to-ground faults in the following ways, by using: • The possibility of different setting values that influence the ground-return compensation for different distance zones within the same group of setting parameters.
Page 383 Section 8 1MRK 504 163-UUS A Impedance protection FAULT en05000221_ansi.vsd ANSI05000221 V1 EN-US Figure 177: Class 1, parallel line in service The equivalent circuit of the lines can be simplified, see figure 178. IEC09000253_1_en.vsd IEC09000253 V1 EN-US Figure 178: 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 384 Section 8 1MRK 504 163-UUS A 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 385 Section 8 1MRK 504 163-UUS A 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 386 Section 8 1MRK 504 163-UUS A 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 387 Section 8 1MRK 504 163-UUS A 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-US Figure 182:...
Page 388: Tapped Line Application
Section 8 1MRK 504 163-UUS A Impedance protection × é ù é ù ë û ë û (Equation 280) EQUATION1288 V2 EN-US Ensure that the underreaching zones from both line ends will overlap a sufficient amount (at least 10%) in the middle of the protected circuit. 8.12.2.7 Tapped line application GUID-740E8C46-45EE-4CE8-8718-9FAE658E9FCE v1...
Page 389 Section 8 1MRK 504 163-UUS A Impedance protection ·Z (Equation 281) DOCUMENT11524-IMG3509 V3 EN-US × × Z ) ( (Equation 282) EQUATION1714 V1 EN-US Where: and Z is the line impedance from the A respective C station to the T point. and I is fault current from A respective C station for fault between T and B.
Page 390: Setting Guidelines
Section 8 1MRK 504 163-UUS A Impedance protection Fault resistance GUID-83E3E475-3243-4308-9A91-B8DD9B47C276 v4 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. 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 391: Setting Of Zone 1
Section 8 1MRK 504 163-UUS A 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 392: Setting Of Reverse Zone
Section 8 1MRK 504 163-UUS A Impedance protection zone 2 must not be reduced below 120% of the protected line section. The whole line must be covered under all conditions. The requirement that the zone 2 shall not reach more than 80% of the shortest adjacent line at remote end is highlighted in the example below.
Page 393: Setting Of Zones For Parallel Line Application
Section 8 1MRK 504 163-UUS A 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. Setting of zones for parallel line application 8.12.3.5 GUID-4E0C3824-41B6-410F-A10E-AB9C3BFE9B12 v1 Parallel line in service –...
Page 394: Setting The Reach With Respect To Load
Section 8 1MRK 504 163-UUS A Impedance protection × (Equation 290) EQUATION1428 V2 EN-US Parallel line is out of service and grounded in both ends GUID-345B36A6-B5FB-46DD-B5AE-81A1599FFC6E v1 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 395: Zone Reach Setting Lower Than Minimum Load Impedance
Section 8 1MRK 504 163-UUS A 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 295) ANSIEQUATION2305 V1 EN-US The fault resistance for phase-to-phase faults is normally quite low compared to the fault resistance for phase-to-ground faults.
Page 396 Section 8 1MRK 504 163-UUS A Impedance protection loa d min (Equation 297) EQUATION1718 V1 EN-US 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 397: Zone Reach Setting Higher Than Minimum Load Impedance
Section 8 1MRK 504 163-UUS A Impedance protection é × ù £ × × ¶ - × ¶ RFPG ê ú ë û load × (Equation 300) EQUATION1721 V2 EN-US Where: ∂ is a maximum load-impedance angle, related to the maximum load power. To avoid load encroachment for the phase-to-phase measuring elements, the set resistive reach of any distance protection zone must be less than 160% of the minimum load impedance.
Page 398: Other Settings
Section 8 1MRK 504 163-UUS A Impedance protection impedance. For a 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-US Figure 185: Load impedance limitation with load encroachment During the initial current change for phase-to-phase and for phase-to-ground faults,...
Page 399 Section 8 1MRK 504 163-UUS A 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 400 Section 8 1MRK 504 163-UUS A 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 401: Zmmmxu Settings
Section 8 1MRK 504 163-UUS A 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).
Page 402: High Speed Distance Protection For Series Compensated Lines Zmfcpdis (21)
Section 8 1MRK 504 163-UUS A Impedance protection Hysteresis value in % of range (ZMax-ZMin), common for all limits. It is used to avoid the frequent update of the value for the attribute “range”. ZMax Estimated maximum impedance value. An impedance that is higher than ZMax has the quality attribute as “Out of Range”.
Page 403: System Grounding
Section 8 1MRK 504 163-UUS A Impedance protection 8.13.2.1 System grounding GUID-FC9BF10E-8CA1-4B23-887D-2EAB6A2A0A6E v1 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 GUID-6870F6A8-EB28-47CF-AF26-7CE758BF934E v1 In solidly grounded systems, the transformer neutrals are connected directly to ground without any impedance between the transformer neutral and ground.
Page 404 Section 8 1MRK 504 163-UUS A 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 solidly grounded networks makes it possible to use impedance measuring techniques to detect ground faults.
Page 405: Fault Infeed From Remote End
Section 8 1MRK 504 163-UUS A 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 406: Load Encroachment
Section 8 1MRK 504 163-UUS A Impedance protection p*ZL (1-p)*ZL en05000217_ansi.vsd ANSI05000217 V1 EN-US Figure 189: 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 to justify complementary protection to distance protection.
Page 407: Short Line Application
Section 8 1MRK 504 163-UUS A Impedance protection Nevertheless, always set RLdFwd, RldRev and LdAngleaccording to the expected maximum load since these settings are used internally in the function as reference points to improve the performance of the phase selection. Load impedance area in LdAngle forward direction...
Page 408: Long Transmission Line Application
Section 8 1MRK 504 163-UUS A Impedance protection possibility to detect high resistive faults without conflict with the load impedance, see figure 190. For very short line applications, the underreaching zone 1 cannot be used due to the voltage drop distribution throughout the line will be too low causing risk for overreaching.
Page 409: Parallel Line Application With Mutual Coupling
Section 8 1MRK 504 163-UUS A Impedance protection LdAngle LdAngle LdAngle LdAngle RLdRev RLdFwd en05000220_ansi.vsd ANSI05000220 V1 EN-US Figure 191: Characteristic for zone measurement for a long line 8.13.2.6 Parallel line application with mutual coupling GUID-1F856628-0CEE-4679-BB71-40177187390D v1 General GUID-1D633249-8BF6-4992-A06E-E8BD23B2C315 v2 Introduction of parallel lines in the network is increasing due to difficulties to get necessary area for new lines.
Page 410 Section 8 1MRK 504 163-UUS A Impedance protection The different network configuration classes are: Parallel line with common positive and zero sequence network Parallel circuits with common positive but separated zero sequence network Parallel circuits with positive and zero sequence sources separated. One example of class 3 networks could be the mutual coupling between a 400 kV line and rail road overhead lines.
Page 411 Section 8 1MRK 504 163-UUS A Impedance protection From symmetrical components, we can derive the impedance Z at the relay point for normal lines without mutual coupling according to equation 310. × × × (Equation 310) EQUATION1275 V3 EN-US Where: is phase to ground voltage at the relay point.
Page 412 Section 8 1MRK 504 163-UUS A Impedance protection When mutual coupling is introduced, the voltage at the relay point A will be changed according to equation 311. æ ö × × ç ÷ × × è ø (Equation 311) EQUATION1276 V4 EN-US By dividing equation by equation and after some simplification we can write...
Page 413 Section 8 1MRK 504 163-UUS A Impedance protection Simplification of equation 314, solving it for 3I0 and substitution of the result into equation gives that the voltage can be drawn as: æ ö × ç ÷ × × × è ø...
Page 414 Section 8 1MRK 504 163-UUS A Impedance protection 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 195.
Page 415 Section 8 1MRK 504 163-UUS A Impedance protection Parallel line out of service and not grounded GUID-DF8B0C63-E6D1-4E11-A8CB-D0C8EAE10FF0 v1 OPEN OPEN CLOSED CLOSED en05000223_ansi.vsd ANSI05000223 V1 EN-US Figure 196: 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 416: Tapped Line Application
Section 8 1MRK 504 163-UUS A 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 322. × × + × ×...
Page 417 Section 8 1MRK 504 163-UUS A Impedance protection GUID-77388095-4EE8-4915-A1D4-D0767D1E04F5 v1 ANSI05000224-2-en.vsd ANSI05000224 V2 EN-US Figure 198: Example of tapped line with Auto transformer This application gives rise to a similar problem that was highlighted in section Fault infeed from remote end, that is increased measured impedance due to fault current infeed.
Page 418 Section 8 1MRK 504 163-UUS A Impedance protection 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 from V2 side of the transformer). is the line impedance from the T point to the fault (F).
Page 419: Series Compensation In Power Systems
Section 8 1MRK 504 163-UUS A Impedance protection In practice, the setting of fault resistance for both phase-to-ground RFPE and phase-to- phase RFPP should be as high as possible without interfering with the load impedance in order to obtain reliable fault detection. 8.13.3 Series compensation in power systems GUID-7F3BBF91-4A17-4B31-9828-F2757672C440 v2...
Page 420: Increase In Power Transfer
Section 8 1MRK 504 163-UUS A Impedance protection Line (Equation 328) EQUATION1895 V1 EN-US A typical 500 km long 500 kV line is considered with source impedance (Equation 329) EQUATION1896 V1 EN-US Power line Load Seires capacitor en06000585.vsd IEC06000585 V1 EN-US Figure 199: A simple radial power system limit...
Page 421: Voltage And Current Inversion
Section 8 1MRK 504 163-UUS A Impedance protection en06000590_ansi.vsd ANSI06000590 V1 EN-US Figure 201: Transmission line with series capacitor The effect on the power transfer when considering a constant angle difference (δ) between the line ends is illustrated in figure 202. Practical compensation degree runs from 20 to 70 percent.
Page 422 Section 8 1MRK 504 163-UUS A Impedance protection Voltage distribution on faulty lossless serial compensated line from fault point F to the bus is linearly dependent on distance from the bus, if there is no capacitor included in scheme (as shown in figure 204). Voltage V measured at the bus is equal to voltage drop D V on the faulty line and lags the current I...
Page 423 Section 8 1MRK 504 163-UUS A Impedance protection With bypassed With inserted capacitor capacitor en06000606_ansi.vsd ANSI06000606 V1 EN-US Figure 204: Phasor diagrams of currents and voltages for the bypassed and inserted series capacitor during voltage inversion It is obvious that voltage V will lead the fault current I as long as X >...
Page 424 Section 8 1MRK 504 163-UUS A Impedance protection With inserted capacitor Source voltage Pre -fault voltage With bypassed capacitor V’ Fault voltage Source en06000607_ansi.vsd ANSI06000607 V1 EN-US Figure 205: Current inversion on series compensated line 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.
Page 425 Section 8 1MRK 504 163-UUS A Impedance protection With bypassed With inserted capacitor capacitor en06000608_ansi.vsd ANSI06000608 V1 EN-US Figure 206: Phasor diagrams of currents and voltages for the bypassed and inserted series capacitor during current inversion It is a common practice to call this phenomenon current inversion. Its consequences on operation of different protections in series compensated networks depend on their operating principle.
Page 426 Section 8 1MRK 504 163-UUS A Impedance protection Figure shows schematically the possible locations of instrument transformers related to the position of line-end series capacitor. - jX CT 1 CT 2 VT 2 en06000611_ansi.vsd ANSI06000611 V1 EN-US Figure 207: Possible positions of instrument transformers relative to line end series capacitor Bus side instrument transformers GUID-B7D1F10A-5467-4F91-9BC1-AB8906357428 v1...
Page 427 Section 8 1MRK 504 163-UUS A Impedance protection installations also in switchyards with double-bus double-breaker and breaker-and-a- half arrangement. The advantage of such schemes is that the unit protections cover also for shunt faults in series capacitors and at the same time the voltage inversion does not appear for faults on the protected line.
Page 428 Section 8 1MRK 504 163-UUS A 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-US Figure 210:...
Page 429 Section 8 1MRK 504 163-UUS A 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 430: Impact Of Series Compensation On Protective Ied Of Adjacent Lines
Section 8 1MRK 504 163-UUS A 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 8.13.3.4 Impact of series compensation on protective IED of adjacent lines GUID-DA1DBB5B-0AFD-49F4-87C7-0E8AB5006051 v2 Voltage inversion is not characteristic for the buses and IED points closest to the series compensated line only.
Page 431: Distance Protection
Section 8 1MRK 504 163-UUS A 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 432: Underreaching And Overreaching Schemes
Section 8 1MRK 504 163-UUS A 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 433 Section 8 1MRK 504 163-UUS A 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...
Page 434 Section 8 1MRK 504 163-UUS A Impedance protection < < (Equation 340) EQUATION1898 V1 EN-US 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 435 Section 8 1MRK 504 163-UUS A Impedance protection en06000621_ansi.vsd ANSI06000621 V1 EN-US Figure 216: 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 436 Section 8 1MRK 504 163-UUS A Impedance protection ordinary fault. However, a good protection system should be able to operate correctly before and after gap flashing occurs. en06000584_small.vsd en06000625.vsd IEC06000584-SMALL V1 EN-US IEC06000625 V1 EN-US Figure 218: Quadrilateral Figure 217: Cross-polarized characteristic with quadrilateral...
Page 437 Section 8 1MRK 504 163-UUS A Impedance protection However, depending upon the setting of the MOV, the fault current will have a resistive component. > (Equation 347) EQUATION2036 V2 EN-US The problems described here are accentuated with a three phase or phase-to-phase fault, but the negative fault current can also exist for a single-phase fault.
Page 438 Section 8 1MRK 504 163-UUS A Impedance protection grounded at both IEDs. The effect of zero sequence mutual impedance on possible overreaching of distance IEDs at A bus is increased compared to non compensated operation, because series capacitor does not compensate for this reactance. The reach of underreaching distance protection zone 1 for phase-to-ground measuring loops must further be decreased for such operating conditions.
Page 439: Setting Guidelines
Section 8 1MRK 504 163-UUS A Impedance protection blocks distance protection. Another method employed is to temporarily block the signals received at the healthy line as soon as the parallel faulty line protection initiates tripping. The second mentioned method has an advantage in that not the whole protection is blocked for the short period.
Page 440: Setting Of Zone 1
Section 8 1MRK 504 163-UUS A Impedance protection 8.13.4.2 Setting of zone 1 GUID-12E84C05-93A2-4FA3-B7BA-0963FB1C098F v1 The different errors mentioned earlier usually require a limitation of the underreaching zone (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 441: Setting Of Reverse Zone
Section 8 1MRK 504 163-UUS A Impedance protection     ⋅ ⋅  ⋅  ⋅       (Equation 349) EQUATION302 V5 EN-US Z AC Z CB Z CF I A+ IB ANSI05000457-2-en.vsd ANSI05000457 V2 EN-US Figure 222: Setting of overreaching zone 8.13.4.4...
Page 442 Section 8 1MRK 504 163-UUS A Impedance protection Setting of zone 1 GUID-69E8535D-F3E2-483D-8463-089063712C67 v2 A voltage reversal can cause an artificial internal fault (voltage zero) on faulty line as well as on the adjacent lines. This artificial fault always have a resistive component, this is however small and can mostly not be used to prevent tripping of a healthy adjacent line.
Page 443 Section 8 1MRK 504 163-UUS A Impedance protection is the reactance of the series capacitor p is the maximum allowable reach for an under-reaching zone with respect to the sub- harmonic swinging related to the resulting fundamental frequency reactance the zone is not allowed to over-reach.
Page 444 Section 8 1MRK 504 163-UUS A Impedance protection Reactive Reach line LLOC en06000584-2.vsd IEC06000584 V2 EN-US Figure 224: 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 445 Section 8 1MRK 504 163-UUS A 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 446: Setting Of Zones For Parallel Line Application
Section 8 1MRK 504 163-UUS A 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 447 Section 8 1MRK 504 163-UUS A Impedance protection (Equation 353) EQUATION554 V1 EN-US 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 448: Setting Of Reach In Resistive Direction
Section 8 1MRK 504 163-UUS A Impedance protection 8.13.4.7 Setting of reach in resistive direction GUID-43EE13AF-BEBC-4A13-95B3-53C28B9164CB v3 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 449: Load Impedance Limitation, Without Load Encroachment Function
Section 8 1MRK 504 163-UUS A Impedance protection 8.13.4.8 Load impedance limitation, without load encroachment function GUID-16C2EB30-7FEA-42E4-98C8-52CCC36644C6 v5 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 450: Zone Reach Setting Higher Than Minimum Load Impedance
Section 8 1MRK 504 163-UUS A Impedance protection times the load-impedance angle, more accurate calculations are necessary according to equation 366. é × ù £ × × ¶ - × ¶ RFPG ê ú ë û load × (Equation 366) GUID-11DD90FA-8FB5-425F-A46F-6553C00025BE V1 EN-US Where: ϑ...
Page 451: Parameter Setting Guidelines
Section 8 1MRK 504 163-UUS A Impedance protection phase-to-phase faults, this corresponds to the per-phase, or positive-sequence, impedance. For a 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...
Page 452 Section 8 1MRK 504 163-UUS A Impedance protection The output of a phase-to-phase loop mn is blocked if Imn < IMinOpPPZx. Imn is the RMS value of the vector difference between phase currents m and n. 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.
Page 453 Section 8 1MRK 504 163-UUS A Impedance protection OperationSC 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 454: Zmmmxu Settings
Section 8 1MRK 504 163-UUS A Impedance protection unless there are very specific reasons to enable phase-to-ground measurement. Please note that, even with the default setting value, phase-to-ground measurement is activated whenever appropriate, like in the case of simultaneous faults: two ground faults at the same time, one each on the two circuits of a double line.
Page 455: Application
Section 8 1MRK 504 163-UUS A Impedance protection 8.14.2 Application IP14969-1 v1 8.14.2.1 General M13874-3 v3 Various changes in power system may cause oscillations of rotating units. The most typical reasons for these oscillations are big changes in load or changes in power system configuration caused by different faults and their clearance.
Page 456: Setting Guidelines
Section 8 1MRK 504 163-UUS A Impedance protection 10% of the rated frequency on the 50 Hz basis). It detects the swings under normal system operate conditions as well as during dead time of a single-pole automatic reclosing cycle. ZMRPSB (78) function is able to secure selective operation for internal faults during power.
Page 457 Section 8 1MRK 504 163-UUS A Impedance protection Rated system voltage EQUATION1728 V1 EN-US Minimum expected system voltage under critical system conditions EQUATION1729 V1 EN-US Rated system frequency EQUATION1730 V1 EN-US Rated primary voltage of voltage protection transformers used EQUATION1731 V1 EN-US Rated secondary voltage of voltage instrument transformers 0.115 used...
Page 458 Section 8 1MRK 504 163-UUS A Impedance protection fact that all settings are performed in primary values. The impedance transformation factor is presented for orientation and testing purposes only. 1200 0.115 × × KIMP 0.069 (Equation 370) EQUATION1735 V1 EN-US The minimum load impedance at minimum expected system voltage is equal to equation 371.
Page 459 Section 8 1MRK 504 163-UUS A Impedance protection (Equation 375) EQUATION1342 V1 EN-US resides the center of oscillation on impedance point, see equation 376. 7.43 33.9 (Equation 376) EQUATION1341 V1 EN-US Transformer protection RET670 2.2 ANSI Application manual...
Page 460 Section 8 1MRK 504 163-UUS A Impedance protection ANSI05000283 V1 EN-US Figure 229: 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 461 Section 8 1MRK 504 163-UUS A Impedance protection is not known, the following approximations may be considered for lines with rated voltage 400 kV: • = 0.9 for lines longer than 100 miles • = 0.85 for lines between 50 and 100 miles •...
Page 462 Section 8 1MRK 504 163-UUS A Impedance protection ° - ° 76.5 64.5 13.3 × ° × ° 2.5 360 (Equation 381) EQUATION1347 V1 EN-US 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...
Page 463 Section 8 1MRK 504 163-UUS A Impedance protection tP2 = 10 ms Consider RLdInFw = 75.0Ω. 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 464: Power Swing Logic Pslpsch
Section 8 1MRK 504 163-UUS A Impedance protection System studies should determine the settings for the hold timer tH. The purpose of this timer is, to secure continuous output signal from Power swing detection function (ZMRPSB, 68) during the power swing, even after the transient impedance leaves ZMRPSB (68) operating characteristic and is expected to return within a certain time due to continuous swinging.
Page 465 Section 8 1MRK 504 163-UUS A Impedance protection • A fault occurs on a so far healthy power line, over which the power swing has been detected and the fast distance protection zone has been blocked by ZMRPSB (68) element. •...
Page 466: Setting Guidelines
Section 8 1MRK 504 163-UUS A Impedance protection Measured impedance at initital fault position Zone 2 Zone 1 Impedance locus at initial power swing after the fault clearance ZMRPSB operating characteristic IEC99000181_2_en.vsd IEC99000181 V2 EN-US Figure 231: Impedance trajectory within the distance protection zones 1 and 2 during and after the fault on line B –...
Page 467 Section 8 1MRK 504 163-UUS A 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 468 Section 8 1MRK 504 163-UUS A Impedance protection PUDOG AR1P1 PUPSD 0-tCS BLOCK CSUR BLKZMUR 0-tBlkTr 0-tTrip PLTR_CRD TRIP en06000236_ansi.en ANSI06000236 V1 EN-US Figure 232: Simplified logic diagram - power swing communication and tripping logic Configuration SEMOD131360-17 v2 Configure the BLOCK input to any combination of conditions, which are supposed to block the operation of logic.
Page 469 Section 8 1MRK 504 163-UUS A 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 470 Section 8 1MRK 504 163-UUS A Impedance protection × × RFPP v tnPP (Equation 391) EQUATION1538 V1 EN-US × V tnPG × RFPG (Equation 392) EQUATION1993-ANSI V1 EN-US 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 471: Blocking And Tripping Logic For Evolving Power Swings
Section 8 1MRK 504 163-UUS A Impedance protection O/C EF 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 SEMOD131360-55 v3...
Page 472: Pole Slip Protection Pspppam (78)
Section 8 1MRK 504 163-UUS A 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 473: Application
Section 8 1MRK 504 163-UUS A Impedance protection 8.16.2 Application SEMOD143248-4 v3 Normally, the generator operates synchronously with the power system, that is, all the generators in the system have the same angular velocity and approximately the same phase angle difference. If the phase angle between the generators gets too large the stable operation of the system cannot be maintained.
Page 474 Section 8 1MRK 504 163-UUS A Impedance protection amplitude increases. When the critical fault clearance time is reached the stability cannot be maintained. Un-damped oscillations occur in the power system, where generator groups at different locations, oscillate against each other. If the connection between the generators is too weak the amplitude of the oscillations will increase until the angular stability is lost.
Page 475: Setting Guidelines
Section 8 1MRK 504 163-UUS A 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 476 Section 8 1MRK 504 163-UUS A Impedance protection Zone 1 Zone 2 X’ Pole slip impedance movement Zone 2 TripAngle Zone 1 WarnAngle IEC06000548_2_en.vsd IEC06000548 V2 EN-US Figure 236: Settings for the Pole slip detection function The ImpedanceZA is the forward impedance as show in figure 236. ZA should be the sum of the transformer impedance XT and the equivalent impedance of the external system ZS.
Page 477: Setting Example For Line Application
Section 8 1MRK 504 163-UUS A Impedance protection The ImpedanceZB is the reverse impedance as show in figure 236. ZB should be equal to the generator transient reactance X'd. The impedance is given in % of the base impedance, see equation 394. The ImpedanceZC is the forward impedance giving the borderline between zone 1 and zone 2.
Page 478 Section 8 1MRK 504 163-UUS A Impedance protection ZA = forward source impedance Line impedance = ZC IEC07000014_2_en.vsd IEC07000014 V2 EN-US Figure 237: 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 238.
Page 479 Section 8 1MRK 504 163-UUS A Impedance protection Apparent anglePhi impedance at normal load IEC07000015_2_en.vsd IEC07000015 V2 EN-US Figure 238: 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 480 Section 8 1MRK 504 163-UUS A 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 481 Section 8 1MRK 504 163-UUS A 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 401) EQUATION1967 V1 EN-US Simplified, the example can be shown as a triangle, see figure 239.
Page 482: Setting Example For Generator Application
Section 8 1MRK 504 163-UUS A Impedance protection 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 483 Section 8 1MRK 504 163-UUS A Impedance protection Apparent anglePhi impedance at normal load IEC07000015_2_en.vsd IEC07000015 V2 EN-US Figure 241: 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 484 Section 8 1MRK 504 163-UUS A 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 485 Section 8 1MRK 504 163-UUS A Impedance protection × 0.15 (Equation 408) EQUATION1974 V1 EN-US This corresponds to: Ð 0.15 0.15 90 (Equation 409) EQUATION1975 V2 EN-US Set ZC to 0.15 and AnglePhi to 90°. The warning angle (StartAngle) should be chosen not to cross into normal operating area.
Page 486 Section 8 1MRK 504 163-UUS A Impedance protection Zload en07000016.vsd IEC07000016 V1 EN-US Figure 242: Simplified figure to derive StartAngle 0.25 0.19 ³ » angleStart arctan arctan arctan + arctan = 7.1 + 5.4 Zload Zload (Equation 411) EQUATION1977 V2 EN-US In case of minor damped oscillations at normal operation we do not want the protection to start.
Page 487: Out-Of-Step Protection Oosppam (78)
Section 8 1MRK 504 163-UUS A Impedance protection 8.17 Out-of-step protection OOSPPAM (78) GUID-8321AC72-187C-4E43-A0FC-AAC7829397C3 v1 8.17.1 Identification GUID-BF2F1533-BA39-48F0-A55C-0B13A393F780 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Out-of-step protection OOSPPAM < 8.17.2 Application GUID-11643CF1-4EF5-47F0-B0D4-6715ACEEC8EC v6 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 488 Section 8 1MRK 504 163-UUS A 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-US Figure 243: The center of electromechanical oscillation The center of the electromechanical oscillation can be in the generator unit (or...
Page 489 Section 8 1MRK 504 163-UUS A 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 490: Setting Guidelines
Section 8 1MRK 504 163-UUS A 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 491 Section 8 1MRK 504 163-UUS A 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 492 Section 8 1MRK 504 163-UUS A Impedance protection • For the synchronous machines as the generator in Table 36, 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 493 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 36. If the currents fed to the Out-of-step Transformer protection RET670 2.2 ANSI...
Page 494: Automatic Switch Onto Fault Logic Zcvpsof
(HV- side), then invertion is necessary (InvertCTCurr = Enabled), provided that the CT’s actual direction complies with ABB recommendations, as shown in Table 36. 8.18 Automatic switch onto fault logic ZCVPSOF SEMOD153633-1 v3 8.18.1...
Page 495: Setting Guidelines
Section 8 1MRK 504 163-UUS A Impedance protection 8.18.3 Setting guidelines M13855-4 v10 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 496: Phase Preference Logic Pplphiz
Section 8 1MRK 504 163-UUS A Impedance protection tSOTF: the drop delay of ZCVPSOF is, by default, set to 1.0 seconds, which is suitable for most applications. tDLD: The time delay for activating ZCVPSOF by the internal dead-line detection is, by default, set to 0.2 seconds.
Page 497: Application
Section 8 1MRK 504 163-UUS A Impedance protection 8.19.2 Application SEMOD167856-4 v5 Phase preference logic function PPLPHIZ is an auxiliary function to Distance protection zone, quadrilateral characteristic ZMQPDIS (21) and Phase selection with load encroachment, quadrilateral characteristic function FDPSPDIS (21). The purpose is to create the logic in resonance or high resistive grounded systems (normally sub- transmission) to achieve the correct phase selective tripping during two simultaneous single-phase ground-faults in different phases on different line sections.
Page 498 Section 8 1MRK 504 163-UUS A Impedance protection en06000551_ansi.vsd ANSI06000551 V1 EN-US Figure 246: 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 499 Section 8 1MRK 504 163-UUS A 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 500: Setting Guidelines
Section 8 1MRK 504 163-UUS A Impedance protection IC=IG IA=IG en06000553_ansi.vsd ANSI06000553 V1 EN-US Figure 248: 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 501: Phase Preference Logic Ppl2Phiz
Section 8 1MRK 504 163-UUS A Impedance protection PU27PN: The setting of the phase-to- ground voltage level (phase voltage) which is used by the evaluation logic to verify that a fault exists in the phase. Normally in a high 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 502: Application
Section 8 1MRK 504 163-UUS A Impedance protection 8.20.2 Application GUID-FFAB7FE9-8BB8-4EFD-A2B7-20FA759D47D6 v1 The Phase preference logic function PPL2PHIZ provides a supplementary phase selection to the High speed distance protection ZMFPDIS (21). The application is for resonance (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.
Page 503 Section 8 1MRK 504 163-UUS A Impedance protection Load Load ANSI06000550_2_en.vsd ANSI06000550 V2 EN-US Figure 249: A typical cross-country fault situation en06000551_ansi.vsd ANSI06000551 V1 EN-US Figure 250: 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 504 Section 8 1MRK 504 163-UUS A Impedance protection a residual current of the same magnitude. This residual current may be used as an indication of a cross-country fault. IC=IG IA=IG en06000553_ansi.vsd ANSI06000553 V1 EN-US Figure 251: 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 505: Setting Guidelines
Section 8 1MRK 504 163-UUS A Impedance protection three signals representing the phase-to-phase measuring loops (the ZREL output). This is to simplify the connection between PPL2PHIZ and the distance protection. The phase-to-phase measuring loops have actually nothing to do with phase preference and are always enabled.
Page 506 Section 8 1MRK 504 163-UUS A Impedance protection PU27PN: The setting of the phase-to- ground voltage level (phase voltage) which is used by the evaluation logic to verify that a fault exists in the phase. Normally in a high 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.
Page 507: Under Impedance Protection For Generators And Transformers Zgvpdis
Section 8 1MRK 504 163-UUS A Impedance protection 8.21 Under impedance protection for generators and transformers ZGVPDIS GUID-1A3A4890-5CFA-417B-BDA4-EA001502AA60 v2 8.21.1 Identification GUID-752C21F4-972E-4E97-AB15-075FF720527F v2 Function description IEC 61850 IEC 60617 ANSI/ identification identification IEEEidentification Under impedance function for ZGVPDIS generators and transformers S00346 V1 EN-US 8.21.2 Application...
Page 508 Section 8 1MRK 504 163-UUS A Impedance protection Phase-to-phase faults in generator Three-phase faults in generator Phase-to-phase faults in the LV winding of the generator transformer or inter- connecting bus or cables Three-phase faults in the LV winding of the generator transformer or inter- connecting bus or cables Faults in the system in the high voltage (HV) side of generator transformer are: Phase-to-ground faults in the HV side of generator transformer and in the power...
Page 509: Operating Zones
Section 8 1MRK 504 163-UUS A Impedance protection 8.21.2.1 Operating zones GUID-FE7ADB29-3A48-41BF-AE43-94884D305A29 v2 Zone3 Zone2 Zone1 REG670 A) Power system model Z3Fwd Z2Fwd ImpedanceAn ImpedanceAn Z3Rev Z2Rev Z1Fwd ImpedanceAn R(ohm) Z1Rev B) Typical setting of zones for under impedance relay IEC11000308-3-en.vsd IEC11000308 V3 EN-US Transformer protection RET670 2.2 ANSI...
Page 510: Zone 1 Operation
Section 8 1MRK 504 163-UUS A Impedance protection Figure 253: Zone characteristics and typical power system model The settings of all the zones is provided in terms of percentage of impedance based on current and voltage ratings of the generator. 8.21.2.2 Zone 1 operation GUID-D5A94DC8-64AB-4623-88B6-64AD0AF5D53C v5...
Page 511: Zone 3 Operation
Section 8 1MRK 504 163-UUS A Impedance protection Phase-to-phase loop Voltage phasor Current phasor Enhanced reach loop Max current Loop selected Voltage phasor Current phasor VAG-V0 VBG-V0 VCG-V0 If the currents are equal, A–G loop has higher priority than B-G and B- G loop has higher priority than C-G.
Page 512: Ct And Vt Positions
Section 8 1MRK 504 163-UUS A Impedance protection Zone 3 provides protection for phase-to-ground, phase-to-phase and three phase faults on the HV side of the system. Hence, all these faults can be detected using three phase- to-phase loops or three phase-to-ground loops similar to zone 2. These options can be selected in the function and their operation is quite similar to the operation of zone 2.
Page 513: External Block Signals
Section 8 1MRK 504 163-UUS A Impedance protection ANSI11000304-1-en.vsd ANSI11000304 V1 EN-US Figure 254: Load Encroachment characteristic in under Impedance function The resistive settings of this function is also provided in percentage of ZBase. It is calculated according to equation 412. ZBase VRated / 3) /...
Page 514: Setting Guidelines
Section 8 1MRK 504 163-UUS A Impedance protection 8.21.3 Setting Guidelines GUID-5867C713-AF93-46B3-9F3C-1A46D253ECA2 v1 8.21.3.1 General GUID-292795EB-0605-4065-971D-169F55E2AFCF v5 The settings for the underimpedance protection for generator (ZGVPDIS) are done in percentage and base impedance is calculated from the VBase and IBase settings. The base impedance is calculated according to equation 413.
Page 515: Load Encroachment
Section 8 1MRK 504 163-UUS A Impedance protection tZ2: Zone 2 trip time delay in seconds. Time delay should be provided in order to coordinate with zone 1 element provided for the outgoing line. Zone 3 Zone 3 in ZGVPDIS function has offset mho characteristic and it can evaluate three phase-to-phase impedance measuring loops or EnhancedReach loop OpModeZ3: Zone 3 distance element can be selected as Disabled, PP Loops or EnhancedReach.
Page 516: Under Voltage Seal-In
Section 8 1MRK 504 163-UUS A Impedance protection æ ö × × ç ÷ è ø exp max (Equation 414) GUID-AF9BD6F2-E64B-424D-B361-49448A1CF690-ANSI V1 EN-US Where, Pexpmax is the maximum exporting active power Vmin Pexpmax occurs is the minimum voltage for which RLd can be lesser than the calculated is the security factor to ensure that the setting of minimal resistive load...
Page 517 Section 8 1MRK 504 163-UUS A Impedance protection triggered with zone 2 pickup, Z2pick up enumeration has to be selected . If zone 3 select Z3pick up enumeration. 27_COMP: The pickup value of the under voltage seal-in feature can be set using 27_COMP.
Page 519: Instantaneous Phase Overcurrent Protection Phpioc (50)
Section 9 1MRK 504 163-UUS A Current protection Section 9 Current protection Instantaneous phase overcurrent protection PHPIOC (50) IP14506-1 v6 9.1.1 Identification M14880-1 v5 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Instantaneous phase overcurrent PHPIOC protection 3I>>...
Page 520: Setting Guidelines
Section 9 1MRK 504 163-UUS A Current protection must 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 521: Meshed Network Without Parallel Line
Section 9 1MRK 504 163-UUS A Current protection MultPU: The set operate current can be changed by activation of the binary input MULTPU to the set factor MultPU. 9.1.3.1 Meshed network without parallel line M12915-9 v8 The following fault calculations have to be done for three-phase, single-phase-to- ground and two-phase-to-ground faults.
Page 522 Section 9 1MRK 504 163-UUS A Current protection Fault ANSI09000023-1-en.vsd ANSI09000023 V1 EN-US Figure 257: Through fault current from B to A: I The IED must not trip for any of the two through-fault currents. Hence the minimum theoretical current setting (Imin) will be: ³...
Page 523: Meshed Network With Parallel Line
Section 9 1MRK 504 163-UUS A Current protection Fault ANSI09000024-1-en.vsd ANSI09000024 V1 EN-US Figure 258: Fault current: I The IED setting value Pickup is given in percentage of the primary base current value, IBase. The value for Pickup is given from this formula: ×...
Page 524 Section 9 1MRK 504 163-UUS A Current protection Line 1 Fault Line 2 ANSI09000025_2_en.vsd ANSI09000025 V2 EN-US Figure 259: Two parallel lines. Influence from parallel line to the through fault current: I The minimum theoretical current setting for the overcurrent protection function (Imin) will be: ³...
Page 525: Directional Phase Overcurrent Protection, Four Steps Oc4Ptoc(51_67)
Section 9 1MRK 504 163-UUS A Current protection Directional phase overcurrent protection, four steps OC4PTOC(51_67) SEMOD129998-1 v8 9.2.1 Identification M14885-1 v6 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Directional phase overcurrent OC4PTOC 51_67 protection, four steps TOC-REVA V2 EN-US 9.2.2 Application...
Page 526: Setting Guidelines
Section 9 1MRK 504 163-UUS A Current protection delay characteristics. The selectivity between different overcurrent protections is normally enabled by co-ordination between the function time delays of the different protections. To enable optimal co-ordination between all overcurrent protections, they should have the same time delay characteristic. Therefore, a wide range of standardized inverse time characteristics are available for IEC and ANSI.
Page 527 Section 9 1MRK 504 163-UUS A Current protection The parameters for the directional phase overcurrent protection, four steps OC4PTOC (51/67) are set via the local HMI or PCM600. The following settings can be done for OC4PTOC (51/67). Common base IED values for primary current (IBase), primary voltage (UBase) and primary power (SBase) are set in the global base values for settings function GBASVAL.
Page 528: Settings For Each Step
Section 9 1MRK 504 163-UUS A Current protection ANSI09000636-1-en.vsd ANSI09000636 V1 EN-US Figure 260: 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 M12982-19 v10 x means step 1, 2, 3 and 4.
Page 529 Section 9 1MRK 504 163-UUS A 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 37. Table 37: Inverse time characteristics Curve name ANSI Extremely Inverse ANSI Very Inverse ANSI Normal Inverse ANSI Moderately Inverse...
Page 530 Section 9 1MRK 504 163-UUS A 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 531 Section 9 1MRK 504 163-UUS A Current protection Table 38: 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 532: Setting Example
Section 9 1MRK 504 163-UUS A Current protection 9.2.3.2 Setting example GUID-20729467-24AB-42F0-9FD1-D2959028732E v1 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 533 Section 9 1MRK 504 163-UUS A Current protection Im ax ³ × Ipu 1.2 (Equation 422) EQUATION1262 V2 EN-US 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 534 Section 9 1MRK 504 163-UUS A Current protection protected zone). A 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 535 Section 9 1MRK 504 163-UUS A Current protection Time-current curves tfunc1 tfunc2 n 0.01 10000 Fault Current en05000204.ai IEC05000204 V2 EN-US Figure 263: 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 536 Section 9 1MRK 504 163-UUS A 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 264. 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 537: Instantaneous Residual Overcurrent Protection Efpioc (50N)
Section 9 1MRK 504 163-UUS A Current protection D ³ (Equation 426) EQUATION1266 V1 EN-US 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 538 Section 9 1MRK 504 163-UUS A Current protection M12762-6 v8 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 539 Section 9 1MRK 504 163-UUS A 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 427) EQUATION284 V2 EN-US 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 540: Identification
Section 9 1MRK 504 163-UUS A Current protection Considering the safety margins mentioned previously, the minimum setting (Is) is: = 1.3 × I (Equation 430) EQUATION288 V3 EN-US The IED setting value IN>> is given in percent of the primary base current value, IBase.
Page 541: Application
Section 9 1MRK 504 163-UUS A Current protection 9.4.2 Application M12509-12 v10 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 542 Section 9 1MRK 504 163-UUS A Current protection Table 39: 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 543: Setting Guidelines
Section 9 1MRK 504 163-UUS A Current protection 9.4.3 Setting guidelines IP14988-1 v1 M15282-3 v11 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.
Page 544 Section 9 1MRK 504 163-UUS A Current protection V pol = 3V or V Operation IDirPU en 05000135-4- ansi. vsd ANSI05000135 V3 EN-US Figure 268: 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 545: Nd Harmonic Restrain
Section 9 1MRK 504 163-UUS A Current protection calculate the value of ZN as V/(√3 · 3I ) Typically, the minimum ZNPol (3 · zero sequence source) is set. The setting is in primary ohms. When the dual polarizing method is used, it is important that the setting Pickupx or the product 3I ·...
Page 546: Switch Onto Fault Logic
Section 9 1MRK 504 163-UUS A Current protection residual fundamental current will however be significant. The inrush current of the transformer in service before the parallel transformer energizing, will be a little delayed compared to the first transformer. Therefore, we will have high 2 harmonic current initially.
Page 547: Settings For Each Step (X = 1, 2, 3 And 4)
Section 9 1MRK 504 163-UUS A Current protection The function is divided into two parts. The SOTF function will give operation from step 2 or 3 during a set time after change in the position of the circuit breaker. The SOTF function has a set time delay.
Page 548 Section 9 1MRK 504 163-UUS A 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 549 Section 9 1MRK 504 163-UUS A Current protection Trip time txMin Pickup current ANSI10000058-1-en.vsdx ANSI10000058 V1 EN-US Figure 270: 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 550: Transformer Application Example
Section 9 1MRK 504 163-UUS A Current protection æ ö ç ÷ ç ÷ × ç ÷ æ ö ç ÷ ç ÷ è ø è ipickup ø (Equation 432) EQUATION1722 V1 EN-US Further description can be found in the technical reference manual. tPRCrvx, tTRCrvx, tCRCrvx: Parameters for user programmable of inverse reset time characteristic curve.
Page 551 Section 9 1MRK 504 163-UUS A Current protection WYE/DELTA or WYE/WYE transformer Three phase CT summated Single CT en05000490_ansi.vsd ANSI05000490 V1 EN-US Figure 271: Residual overcurrent protection application on a directly grounded transformer winding In this case the protection has two different tasks: •...
Page 552 Section 9 1MRK 504 163-UUS A Current protection WYE/DELTA, DELTA/WYE or WYE/WYE transformer Three phase CT summated en05000491_ansi.vsd ANSI05000491 V1 EN-US Figure 272: Residual overcurrent protection application on an isolated transformer winding In the calculation of the fault current fed to the protection, at different ground faults, are highly dependent on the positive and zero sequence source impedances, as well as the division of residual current in the network.
Page 553 Section 9 1MRK 504 163-UUS A Current protection YN/D or YN/Y transformer Three phase CT summated Single phase- Single CT to-ground fault ANSI05000492_3_en.vsd ANSI05000492 V3 EN-US Figure 273: Step 1 fault calculation 1 This calculation gives the current fed to the protection: 3I 0fault1 To assure that step 1, selectivity to other ground-fault protections in the network a short delay is selected.
Page 554 Section 9 1MRK 504 163-UUS A Current protection YN/D or YN/Y transformer Three phase CT summated Single CT Single phase- to- ground fault ANSI05000493_3_en.vsd ANSI05000493 V3 EN-US Figure 274: Step 1 fault calculation 1 The fault is located at the borderline between instantaneous and delayed operation of the line protection, such as Distance protection or line residual overcurrent protection.
Page 555: Four Step Directional Negative Phase Sequence Overcurrent Protection Ns4Ptoc (46I2)
Section 9 1MRK 504 163-UUS A Current protection can be chosen very low. As it is required to detect ground faults in the transformer winding, close to the neutral point, values down to the minimum setting possibilities can be chosen. However, one must consider zero-sequence currents that can occur during normal operation of the power system.
Page 556 Section 9 1MRK 504 163-UUS A Current protection In many applications several steps with different current pickup levels and time delays are needed. NS4PTOC (4612) can have up to four, individual settable steps. The flexibility of each step of NS4PTOC (4612) function is great. The following options are possible: Non-directional/Directional function: In some applications the non-directional functionality is used.
Page 557: Setting Guidelines
Section 9 1MRK 504 163-UUS A Current protection Curve name User Programmable ASEA RI RXIDG (logarithmic) There is also a user programmable inverse time characteristic. Normally it is required that the negative sequence overcurrent function shall reset as fast as possible when the current level gets lower than the operation level. In some cases some sort of delayed reset is required.
Page 558 Section 9 1MRK 504 163-UUS A Current protection DirModeSelx: The directional mode of step x. Possible settings are off/nondirectional/ forward/reverse. Characteristx: Selection of time characteristic for step x. Definite time delay and different types of inverse time characteristics are available. Table 41: Inverse time characteristics Curve name...
Page 559 Section 9 1MRK 504 163-UUS A Current protection MultPUx: Multiplier for scaling of the current setting value. If a binary input signal (ENMULTx) is activated the current operation level is multiplied by this setting constant. txMin: Minimum operation time for inverse time characteristics. At high currents the inverse time characteristic might give a very short operation time.
Page 560: Common Settings For All Steps
Section 9 1MRK 504 163-UUS A Current protection For IEC inverse time delay characteristics the possible delay time settings are instantaneous (1) and IEC (2 = set constant time reset). For the programmable inverse time delay characteristics all three types of reset time characteristics are available;...
Page 561: Sensitive Directional Residual Overcurrent And Power Protection Sdepsde (67N)
Section 9 1MRK 504 163-UUS A Current protection Reverse Area AngleRCA Vpol=-V2 Forward Area Iop = I2 ANSI10000031-1-en.vsd ANSI10000031 V1 EN-US Figure 276: 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 562: Identification
Section 9 1MRK 504 163-UUS A Current protection 9.6.1 Identification SEMOD172025-2 v4 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 SEMOD171959-4 v12 In networks with high impedance grounding, the phase-to-ground fault current is significantly smaller than the short circuit currents.
Page 563 Section 9 1MRK 504 163-UUS A 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 564: Setting Guidelines
Section 9 1MRK 504 163-UUS A Current protection 9.6.3 Setting guidelines SEMOD171961-4 v10 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 565 Section 9 1MRK 504 163-UUS A 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 566 Section 9 1MRK 504 163-UUS A 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-US Figure 278: Equivalent of power system for calculation of setting The residual fault current can be written:...
Page 567 Section 9 1MRK 504 163-UUS A Current protection × 3I (Z 3R ) T ,0 (Equation 441) EQUATION2024-ANSI V1 EN-US × 3I (Z T ,0 lineAB,0 (Equation 442) EQUATION2025-ANSI V1 EN-US The residual power, measured by the sensitive ground fault protections in A and B will ×...
Page 568 Section 9 1MRK 504 163-UUS A Current protection GlobalBaseSel: It is used to select a GBASVAL function for reference of base values. 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 -jRCADir ) to calculate the reference voltage (-3V ).
Page 569 Section 9 1MRK 504 163-UUS A Current protection RCA = -90°, ROA = 90° ) – ang(V = ang(3I en06000649_ansi.vsd ANSI06000649 V1 EN-US Figure 280: Characteristic for RCADir equal to -90° When OpModeSel is set to 3I03V0Cosfi the apparent residual power component in the direction is measured.
Page 570 Section 9 1MRK 504 163-UUS A Current protection RCA = 0º ROA = 80º Operate area =-3V ANSI06000652-2-en.vsd ANSI06000652 V2 EN-US Figure 281: 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 571 Section 9 1MRK 504 163-UUS A 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 572 Section 9 1MRK 504 163-UUS A Current protection Table 42: 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 573: Thermal Overload Protection, One Time Constant Fahrenheit Celsius Lfpttr/Lcpttr (26)
Section 9 1MRK 504 163-UUS A Current protection tVN is the definite time delay for the trip function of the residual voltage protection, given in s. Thermal overload protection, one time constant Fahrenheit/Celsius LFPTTR/LCPTTR (26) IP14512-1 v7 9.7.1 Identification Thermal overload protection, two time constants TRPTTR (49) IP14513-1 v4 9.8.1...
Page 574: Setting Guideline
Section 9 1MRK 504 163-UUS A Current protection overload protection provides information and makes temporary overloading of transformers possible. The permissible load level of a power transformer is highly dependent on the cooling system of the transformer. There are two main principles: •...
Page 575 Section 9 1MRK 504 163-UUS A Current protection GlobalBaseSel: Selects the global base value group used by the function to define (IBase), (UBase) and (SBase). IRef: Reference level of the current given in % of IBase. When the current is equal to IRef the final (steady state) heat content is equal to 1.
Page 576 Section 9 1MRK 504 163-UUS A Current protection If the transformer has forced cooling (FOA) the measurement should be made both with and without the forced cooling in operation, giving Tau2 and Tau1. The time constants can be changed if the current is higher than a set value or lower than a set value.
Page 577: Breaker Failure Protection Ccrbrf(50Bf)
Section 9 1MRK 504 163-UUS A Current protection ThetaInit: Heat content before activation of the function. This setting can be set a little below the alarm level. If the transformer is loaded before the activation of the protection function, its temperature can be higher than the ambient temperature. The start point given in the setting will prevent risk of no trip at overtemperature during the first moments after activation.
Page 578: Setting Guidelines
Section 9 1MRK 504 163-UUS A Current protection 9.9.3 Setting guidelines M11546-4 v9 The parameters for Breaker failure protection 3-phase activation and output CCRBRF (50BF) are set via the local HMI or PCM600. The following settings can be done for the breaker failure protection. GlobalBaseSel: Selects the global base value group used by the function to define IBase, VBase and SBase as applicable.
Page 579 Section 9 1MRK 504 163-UUS A Current protection RetripMode FunctionMode Description No CBPos Check Current re-trip is done without check of current level Contact re-trip is done without check of auxiliary contact position Current/Contact re-trip is done without check of current level or auxiliary contact position BuTripMode: Back-up trip mode is given to state sufficient current criteria to detect...
Page 580 Section 9 1MRK 504 163-UUS A Current protection t2: Time delay of the back-up trip. The choice of this setting is made as short as possible at the same time as unwanted operation must be avoided. Typical setting is 90 –...
Page 581: Stub Protection Stbptoc (50Stb)
Section 9 1MRK 504 163-UUS A Current protection t2MPh: Time delay of the back-up trip at multi-phase initiate. The critical fault clearance time is often shorter in case of multi-phase faults, compared to single phase- to-ground faults. Therefore there is a possibility to reduce the back-up trip delay for multi-phase faults.
Page 582: Setting Guidelines
Section 9 1MRK 504 163-UUS A Current protection Stub protection STBPTOC (50STB) is a simple phase overcurrent protection, fed from the two current transformer groups feeding the object taken out of service. The stub protection is only activated when the disconnector of the object is open. STBPTOC (50STB) enables fast fault clearance of faults at the section between the CTs and the open disconnector.
Page 583: Pole Discrepancy Protection Ccpdsc(52Pd)
Section 9 1MRK 504 163-UUS A Current protection settingContinuous the function is activated independent of presence of any external release signal. IPickup: Current level for the Stub protection, set in % of IBase. This parameter should be set so that all faults on the stub can be detected. The setting should thus be based on fault calculations.
Page 584: Setting Guidelines
Section 9 1MRK 504 163-UUS A Current protection also be realized within the protection itself, by using opened and close signals for each circuit breaker pole, connected to the protection. • Each phase current through the circuit breaker is measured. If the difference between the phase currents is larger than a CurrUnsymPU this is an indication of pole discrepancy, and the protection will operate.
Page 585: Directional Underpower Protection Guppdup (37)
Section 9 1MRK 504 163-UUS A Current protection 9.12 Directional underpower protection GUPPDUP (37) SEMOD156693-1 v4 9.12.1 Identification SEMOD158941-2 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Directional underpower protection GUPPDUP P < SYMBOL-LL V2 EN-US 9.12.2 Application SEMOD151283-4 v5...
Page 586 Section 9 1MRK 504 163-UUS A Current protection When the steam ceases to flow through a turbine, the cooling of the turbine blades will disappear. Now, it is not possible to remove all heat generated by the windage losses. Instead, the heat will increase the temperature in the steam turbine and especially of the blades.
Page 587: Setting Guidelines
Section 9 1MRK 504 163-UUS A Current protection protection (reference angle set to 0) to trip if the active power from the generator is less than about 2%. One should set the overpower protection (reference angle set to 180) to trip if the power flow from the network to the generator is higher than 1%.
Page 588 Section 9 1MRK 504 163-UUS A Current protection Mode Set value Formula used for complex power calculation × (Equation 457) EQUATION2059-ANSI V1 EN-US × (Equation 458) EQUATION2060-ANSI V1 EN-US = × × (Equation 459) EQUATION2061-ANSI V1 EN-US = × × (Equation 460) EQUATION2062-ANSI V1 EN-US = ×...
Page 589 Section 9 1MRK 504 163-UUS A Current protection Power1(2) Angle1(2) Operate en06000441.vsd IEC06000441 V1 EN-US Figure 285: 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 462. Minimum recommended setting is 0.2% of S when metering class CT inputs into the IED are used.
Page 590 Section 9 1MRK 504 163-UUS A Current protection Operate ° Angle1(2) = 0 Power1(2) en06000556.vsd IEC06000556 V1 EN-US Figure 286: 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 591: Directional Overpower Protection Goppdop (32)
Section 9 1MRK 504 163-UUS A 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 592 Section 9 1MRK 504 163-UUS A 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 593: Setting Guidelines
Section 9 1MRK 504 163-UUS A Current protection may cause cavitations. The risk for damages to hydro turbines can justify reverse power protection in unattended plants. A hydro turbine that rotates in water with closed wicket gates will draw electric power from the rest of the power system.
Page 594 Section 9 1MRK 504 163-UUS A Current protection Mode: The voltage and current used for the power measurement. The setting possibilities are shown in table 45. Table 45: Complex power calculation Mode Set value Formula used for complex power calculation A,B,C ×...
Page 595 Section 9 1MRK 504 163-UUS A Current protection Operate Power1(2) Angle1(2) en06000440.vsd IEC06000440 V1 EN-US Figure 288: 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 475. Minimum recommended setting is 0.2% of S when metering class CT inputs into the IED are used.
Page 596 Section 9 1MRK 504 163-UUS A Current protection Angle1(2 ) = 180 Operate Power 1(2) IEC06000557-2-en.vsd IEC06000557 V2 EN-US Figure 289: 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 597: Broken Conductor Check Brcptoc (46)
Section 9 1MRK 504 163-UUS A Current protection S TD S TD S ⋅ − ⋅ Calculated (Equation 477) EQUATION1893-ANSI V1 EN-US Where is a new measured value to be used for the protection function is the measured value given from the function in previous execution cycle is the new calculated value in the present execution cycle Calculated is settable parameter...
Page 598: Application
Section 9 1MRK 504 163-UUS A Current protection 9.14.2 Application SEMOD171858-5 v3 Conventional protection functions can not detect the broken conductor condition. Broken conductor check (BRCPTOC, 46) function, consisting of continuous current unsymmetrical check on the line where the IED connected will give alarm or trip at detecting broken conductors.
Page 599: Application
Section 9 1MRK 504 163-UUS A Current protection 9.15.2 Application GUID-5EC8BAEC-9118-49EC-970C-43D6C416640A v1 GUID-BACAE67B-E64B-4963-B323-ECB0B69031B9 v2 Shunt capacitor banks (SCBs) are somewhat specific and different from other power system elements. These specific features of SCB are briefly summarized in this section. A capacitor unit is the building block used for SCB construction. The capacitor unit is made up of individual capacitor elements, arranged in parallel or series connections.
Page 600 Section 9 1MRK 504 163-UUS A Current protection Rack Capacitor Unit (Can) IEC09000753_1_en.vsd IEC09000753 V1 EN-US Figure 290: Replacement of a faulty capacitor unit within SCB There are four types of the capacitor unit fusing designs which are used for construction of SCBs: Externally where an individual fuse, externally mounted, protects each capacitor unit.
Page 601: Scb Protection
Section 9 1MRK 504 163-UUS A Current protection Which type of fusing is used may depend on can manufacturer or utility preference and previous experience. Because the SCBs are built from the individual capacitor units the overall connections may vary. Typically used SCB configurations are: Delta-connected banks (generally used only at distribution voltages) Single wye-connected banks Double wye-connected banks...
Page 602 Section 9 1MRK 504 163-UUS A Current protection In addition, to fault conditions SCB can be exposed to different types of abnormal operating conditions. In accordance with IEC and ANSI standards capacitors shall be capable of continuous operation under contingency system and bank conditions, provided the following limitations are not exceeded: Capacitor units should be capable of continuous operation including harmonics, but excluding transients, to 110% of rated IED root-mean-square (RMS) voltage...
Page 603: Setting Guidelines
Section 9 1MRK 504 163-UUS A Current protection Short circuit protection for SCB and connecting leads (can be provided by using PHPIOC, OC4PTOC, CVGAPC, T2WPDIF/T3WPDIF or HZPDIF functions) Ground-fault protection for SCB and connecting leads (can be provided by using EFPIOC, EF4PTOC, CVGAPC, T2WPDIF/T3WPDIF or HZPDIF functions) Current or Voltage based unbalance protection for SCB (can be provided by using EF4PTOC, OC4PTOC, CVGAPC or VDCPTOV functions)
Page 604 Section 9 1MRK 504 163-UUS A Current protection × 1000 200[ MVAr × 3 400[ (Equation 478) IEC09000755 V1 EN-US or on the secondary CT side: 0.578 _ ec 500 1 (Equation 479) IEC09000756 V1 EN-US Note that the SCB rated current on the secondary CT side is important for secondary injection of the function.
Page 605: Restrike Detection
Section 9 1MRK 504 163-UUS A Current protection PU_37 =70% (of IBase); Current level for undercurrent pickup tUC =5s; Time delay for undercurrent trip Undercurrent feature is blocked by operation of Reconnection inhibit feature. Reactive power overload feature: Operation QOL =Enabled; to enable this feature UP_QOL =130% (of SCB MVAr rating);...
Page 606: Ns2Ptoc (46I2)
Section 9 1MRK 504 163-UUS A Current protection In simple words this means that the CB is not breaking the current at the first zero crossing after separation of the CB contacts. Instead current is re-ignited and only braked at consecutive current zero crossings. This condition is manifested as high current pulses at the moment of current re-ignition.
Page 607: Features
Section 9 1MRK 504 163-UUS A Current protection To provide an effective protection for the generator for external unbalanced conditions, NS2PTOC (46I2) is able to directly measure the negative sequence current. NS2PTOC (46I2) also have a time delay characteristic which matches the heating characteristic of the generator I t = K as defined in standard.
Page 608: Generator Continuous Unbalance Current Capability
Section 9 1MRK 504 163-UUS A Current protection • Maximum trip time delay for inverse time characteristic, freely settable. • Inverse reset characteristic which approximates generator rotor cooling rates and provides reduced operate time if an unbalance reoccurs before the protection resets.
Page 609 Section 9 1MRK 504 163-UUS A Current protection en08000358.vsd IEC08000358 V1 EN-US Figure 292: Short-time unbalanced current capability of direct cooled generators Continuous I - capability of generators is also covered by the standard. Table below (from ANSI standard C50.13) contains the suggested capability: Table 47: Continous I capability...
Page 610: Setting Guidelines
Section 9 1MRK 504 163-UUS A Current protection • Single phase railroad load • Unbalanced system faults such as • Line to ground faults • Double line to ground faults • Line to line faults • Open conductors, includes • Broken line conductors •...
Page 611: Pickup Sensitivity
Section 9 1MRK 504 163-UUS A Current protection Inverse time delay characteristic of the NS2PTOC (46I2) function is represented in the equation , where the K1 setting is adjustable over the range of 1 – 99 seconds. A typical inverse time overcurrent curve is shown in Figure 293. Negative sequence inverse time characteristic 10000 tMax...
Page 612: Alarm Function
Section 9 1MRK 504 163-UUS A Current protection 9.16.3.3 Alarm function GUID-1B932D89-3233-4841-977A-5B61346B057B v2 The alarm function is operated by PICKUP signal and used to warn the operator for an abnormal situation, for example, when generator continuous negative sequence current capability is exceeded, thereby allowing corrective action to be taken before removing the generator from service.
Page 613: Base Quantities
Section 9 1MRK 504 163-UUS A Current protection • Selectable definite time delay or Inverse Time IDMT characteristic • Voltage restrained/controlled feature is available in order to modify the pick- up level of the overcurrent stage in proportion to the magnitude of the measured voltage •...
Page 614: Setting Guidelines
Section 9 1MRK 504 163-UUS A Current protection and the generator fault current may consequently fall below the pickup level of the overcurrent protection. The short-circuit current may drop below the generator rated current after 0.5...1 s. Also, for generators with an excitation system not fed from the generator terminals, a fault can occur when the automatic voltage regulator is out of service.
Page 615 Section 9 1MRK 504 163-UUS A Current protection added. Note that the value set is the time between activation of the start and the trip outputs. k: Time multiplier for inverse time delay. tMin: Minimum operation time for all inverse time characteristics. At high currents the inverse time characteristic might give a very short operation time.
Page 616: Voltage-Restrained Overcurrent Protection For Generator And Step-Up Transformer
Section 9 1MRK 504 163-UUS A Current protection 9.17.3.2 Voltage-restrained overcurrent protection for generator and step-up transformer GUID-263B960B-2280-461C-B455-F17B7D278F60 v8 An example of how to use VRPVOC (51V) function to provide voltage restrained overcurrent protection for a generator is given below. Let us assume that the time coordination study gives the following required settings: •...
Page 617 Section 9 1MRK 504 163-UUS A Current protection • Pickup current of the overcurrent stage: 150% of generator rated current at rated generator voltage; • Pickup voltage of the undervoltage stage: 70% of generator rated voltage; • Trip time: 3.0 s. The overcurrent stage and the undervoltage stage shall be set in the following way: Set Operation to Enabled.
Page 619: Two Step Undervoltage Protection Uv2Ptuv (27)
Section 10 1MRK 504 163-UUS A Voltage protection Section 10 Voltage protection 10.1 Two step undervoltage protection UV2PTUV (27) IP14544-1 v3 10.1.1 Identification M16876-1 v7 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Two step undervoltage protection UV2PTUV 3U<...
Page 620: Setting Guidelines
Section 10 1MRK 504 163-UUS A 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 621: Backup Protection For Power System Faults
Section 10 1MRK 504 163-UUS A Voltage protection 10.1.3.5 Backup protection for power system faults M13851-62 v3 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 M13851-65 v14 The following settings can be done for Two step undervoltage protection UV2PTUV...
Page 622: Two Step Overvoltage Protection Ov2Ptov (59)
Section 10 1MRK 504 163-UUS A Voltage protection there is a short circuit or ground faults in the system. The time delay must be coordinated to the other short circuit protections. tResetn: Reset time for step n if definite time delay is used, given in s. The default value is 25 ms.
Page 623: Identification
Section 10 1MRK 504 163-UUS A Voltage protection 10.2.1 Identification M17002-1 v8 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-US 10.2.2 Application M13799-3 v9 Two step overvoltage protection OV2PTOV (59) is applicable in all situations, where reliable detection of high voltage is necessary.
Page 624: Setting Guidelines
Section 10 1MRK 504 163-UUS A Voltage protection expectancy. In many cases, it is a useful function in circuits for local or remote automation processes in the power system. 10.2.3 Setting guidelines M13852-4 v10 The parameters for Two step overvoltage protection (OV2PTOV ,59) are set via the local HMI or PCM600.
Page 625: Power Supply Quality
Section 10 1MRK 504 163-UUS A Voltage protection 10.2.3.3 Power supply quality M13852-16 v1 The setting has to be well above the highest occurring "normal" voltage and below the highest acceptable voltage, due to regulation, good practice or other agreements. 10.2.3.4 High impedance grounded systems M13852-19 v6...
Page 626 Section 10 1MRK 504 163-UUS A Voltage protection Characteristicn: This parameter gives the type of time delay to be used. The setting can be Definite time, Inverse Curve A, Inverse Curve B, Inverse Curve C or I/Prog. inv. curve. The choice is highly dependent of the protection application. OpModen: This parameter describes how many of the three measured voltages that should be above the set level to give operation.
Page 627: Two Step Residual Overvoltage Protection Rov2Ptov (59N)
Section 10 1MRK 504 163-UUS A Voltage protection Therefore a tuning parameter CrvSatn is set to compensate for this phenomenon. In the voltage interval Pickup> up to Pickup> · (1.0 + CrvSatn/100) the used voltage will be: Pickup> · (1.0 + CrvSatn/100). If the programmable curve is used, this parameter must be calculated so that: CrvSatn ×...
Page 628: Setting Guidelines
Section 10 1MRK 504 163-UUS A Voltage protection does not provide any guidance in finding the faulted component. Therefore, ROV2PTOV (59N) is often used as a backup protection or as a release signal for the feeder ground fault protection. 10.3.3 Setting guidelines M13853-3 v8 All the voltage conditions in the system where ROV2PTOV (59N) performs its...
Page 629: Power Supply Quality
Section 10 1MRK 504 163-UUS A Voltage protection 10.3.3.3 Power supply quality M13853-15 v3 The setting must be above the highest occurring "normal" residual voltage and below the highest acceptable residual voltage, due to regulation, good practice or other agreements. 10.3.3.4 High impedance grounded systems M13853-18 v10...
Page 630: Direct Grounded System
Section 10 1MRK 504 163-UUS A Voltage protection 10.3.3.5 Direct grounded system GUID-EA622F55-7978-4D1C-9AF7-2BAB5628070A v8 In direct grounded systems, an ground fault on one phase is indicated by voltage collapse in that phase. The other healthy phase will still have normal phase-to-ground voltage.
Page 631 Section 10 1MRK 504 163-UUS A Voltage protection ROV2PTOV (59N) will measure the residual voltage corresponding to the nominal phase-to-ground voltage for a high-impedance grounded system. The measurement will be based on the neutral voltage displacement. The setting parameters described below are identical for the two steps (n = step 1 and 2).
Page 632: Overexcitation Protection Oexpvph (24)
Section 10 1MRK 504 163-UUS A Voltage protection TDn: Time multiplier for inverse time characteristic. This parameter is used for co- ordination between different inverse time delayed undervoltage protections. ACrvn, BCrvn, CCrvn, DCrvn, PCrvn: Parameters for step n, to set to create programmable undervoltage inverse time characteristic.
Page 633 Section 10 1MRK 504 163-UUS A Voltage protection excessive heating and severe damage to insulation and adjacent parts in a relatively short time. Overvoltage, or underfrequency, or a combination of both, will result in an excessive flux density level, which is denominated overfluxing or over-excitation. The greatest risk for overexcitation exists in a thermal power station when the generator-transformer block is disconnected from the rest of the network, or in network “islands”...
Page 634 Section 10 1MRK 504 163-UUS A Voltage protection overexcitation occurs after a short time interval, the heating will start from a higher level, therefore, OEXPVPH (24) must have thermal memory. A fixed cooling time constant is settable within a wide range. The general experience is that the overexcitation characteristics for a number of power transformers are not in accordance with standard inverse time curves.
Page 635: Setting Guidelines
Section 10 1MRK 504 163-UUS A Voltage protection 10.4.3 Setting guidelines IP15039-1 v1 10.4.3.1 Recommendations for input and output signals M6496-75 v4 Recommendations for Input signals M6496-79 v5 Please see the default factory configuration. 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.
Page 636: Service Value Report
Section 10 1MRK 504 163-UUS A Voltage protection Pickup1: Operating level for the inverse characteristic, IEEE or tailor made. The operation is based on the relation between rated voltage and rated frequency and set as a percentage factor. Normal setting is around 108-110% depending of the capability curve for the transformer/generator.
Page 637: Setting Example
Section 10 1MRK 504 163-UUS A Voltage protection flux density VPERHZ, internal thermal content in percentage of trip value THERMSTA. The values are available at local HMI, Substation SAsystem and PCM600. 10.4.3.4 Setting example M6496-108 v5 Sufficient information about the overexcitation capability of the protected object(s) must be available when making the settings.
Page 638: Voltage Differential Protection Vdcptov (60)
Section 10 1MRK 504 163-UUS A Voltage protection Information on the cooling time constant T should be retrieved from the power cool transformer manufacturer. V/Hz transformer capability curve relay operate characteristic Continous 0.05 Time (minutes) en01000377.vsd IEC01000377 V1 EN-US Figure 298: Example on overexcitation capability curve and V/Hz protection settings for power transformer 10.5...
Page 639: Application
Section 10 1MRK 504 163-UUS A Voltage protection 10.5.2 Application SEMOD153893-5 v3 The Voltage differential protection VDCPTOV (60) functions can be used in some different applications. • Voltage unbalance protection for capacitor banks. The voltage on the bus is supervised with the voltage in the capacitor bank, phase- by phase. Difference indicates a fault, either short-circuited or open element in the capacitor bank.
Page 640: Setting Guidelines
Section 10 1MRK 504 163-UUS A Voltage protection Fuse failure supervision (SDDRFUF) function for voltage transformers. In many application the voltages of two fuse groups of the same voltage transformer or fuse groups of two separate voltage transformers measuring the same voltage can be supervised with this function.
Page 641 Section 10 1MRK 504 163-UUS A Voltage protection RFLx: Is the setting of the voltage ratio compensation factor where possible differences between the voltages is compensated for. The differences can be due to different voltage transformer ratios, different voltage levels e.g. the voltage measurement inside the capacitor bank can have a different voltage level but the difference can also e.g.
Page 642: Loss Of Voltage Check Lovptuv (27)
Section 10 1MRK 504 163-UUS A Voltage protection tAlarm: The time delay for alarm is set by this parameter. Normally, few seconds delay can be used on capacitor banks alarm. For fuse failure supervision (SDDRFUF) the alarm delay can be set to zero. 10.6 Loss of voltage check LOVPTUV (27) SEMOD171868-1 v2...
Page 643: Underfrequency Protection Saptuf (81)
Section 11 1MRK 504 163-UUS A Frequency protection Section 11 Frequency protection 11.1 Underfrequency protection SAPTUF (81) IP15746-1 v3 11.1.1 Identification M14865-1 v5 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Underfrequency protection SAPTUF f < SYMBOL-P V1 EN-US 11.1.2 Application...
Page 644: Setting Guidelines
Section 11 1MRK 504 163-UUS A Frequency protection 11.1.3 Setting guidelines M13355-3 v8 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 645: Identification
Section 11 1MRK 504 163-UUS A Frequency protection 11.2.1 Identification M14866-1 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Overfrequency protection SAPTOF f > SYMBOL-O V1 EN-US 11.2.2 Application M14952-3 v4 Overfrequency protection function SAPTOF (81) is applicable in all situations, where reliable detection of high fundamental power system frequency is needed.
Page 646: Rate-Of-Change Of Frequency Protection Sapfrc (81)
Section 11 1MRK 504 163-UUS A 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 647: Setting Guidelines
Section 11 1MRK 504 163-UUS A Frequency protection 11.3.3 Setting guidelines M14971-3 v7 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 649: General Current And Voltage Protection Cvgapc
Section 12 1MRK 504 163-UUS A Multipurpose protection Section 12 Multipurpose protection 12.1 General current and voltage protection CVGAPC IP14552-1 v2 12.1.1 Identification M14886-2 v3 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...
Page 650: Current And Voltage Selection For Cvgapc Function
Section 12 1MRK 504 163-UUS A Multipurpose protection • Definite time delay or Inverse Time Overcurrent TOC/IDMT delay for both steps • Second harmonic supervision is available in order to only allow operation of the overcurrent stage(s) if the content of the second harmonic in the measured current is lower than pre-set level •...
Page 651 Section 12 1MRK 504 163-UUS A Multipurpose protection The user can select, by a setting parameter CurrentInput, to measure one of the following current quantities shown in table 49. Table 49: Available selection for current quantity within CVGAPC function Set value for parameter Comment "CurrentInput”...
Page 652 Section 12 1MRK 504 163-UUS A Multipurpose protection Table 50: 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 653: Base Quantities For Cvgapc Function
Section 12 1MRK 504 163-UUS A Multipurpose protection phase-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 SEMOD53443-112 v3 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...
Page 654: Inadvertent Generator Energization
Section 12 1MRK 504 163-UUS A 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 655: Setting Guidelines
Section 12 1MRK 504 163-UUS A 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 656 Section 12 1MRK 504 163-UUS A Multipurpose protection practically constant. It shall be noted that directional negative sequence OC element offers protection against all unbalance faults (phase-to-phase faults as well). Care shall be taken that the minimum pickup of such protection function shall be set above natural system unbalance level.
Page 657: Negative Sequence Overcurrent Protection
Section 12 1MRK 504 163-UUS A 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.
Page 658 Section 12 1MRK 504 163-UUS A Multipurpose protection æ ö ç ÷ è ø (Equation 485) EQUATION1740-ANSI V1 EN-US where: is the operating time in seconds of the negative sequence overcurrent IED is the generator capability constant in seconds is the measured negative sequence current is the generator rated current By defining parameter x equal to maximum continuous negative sequence rating of the generator in accordance with the following formula...
Page 659 Section 12 1MRK 504 163-UUS A Multipurpose protection æ ö × ç ÷ è ø (Equation 488) EQUATION1742-ANSI V1 EN-US 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 660: Generator Stator Overload Protection In Accordance With Iec Or Ansi Standards
Section 12 1MRK 504 163-UUS A Multipurpose protection 12.1.3.3 Generator stator overload protection in accordance with IEC or ANSI standards M13088-81 v3 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 661 Section 12 1MRK 504 163-UUS A 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 662: Open Phase Protection For Transformer, Lines Or Generators And Circuit Breaker Head Flashover Protection For Generators
Section 12 1MRK 504 163-UUS A Multipurpose protection Proper timing of CVGAPC function made in this way can easily be verified by secondary injection. All other settings can be left at the default values. If required delayed time reset for OC1 step can be set in order to insure proper function operation in case of repetitive overload conditions.
Page 663: Voltage Restrained Overcurrent Protection For Generator And Step-Up Transformer
Section 12 1MRK 504 163-UUS A Multipurpose protection 12.1.3.5 Voltage restrained overcurrent protection for generator and step-up transformer M13088-158 v4 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 664 Section 12 1MRK 504 163-UUS A Multipurpose protection generator can be achieved. Let us assume that from rated generator data the following values are calculated: • Maximum generator capability to contentiously absorb reactive power at zero active loading 38% of the generator MVA rating •...
Page 665 Section 12 1MRK 504 163-UUS A 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-US Figure 301: Loss of excitation Transformer protection RET670 2.2 ANSI Application manual...
Page 667: Multipurpose Filter Smaihpac
Section 13 1MRK 504 163-UUS A System protection and control Section 13 System protection and control 13.1 Multipurpose filter SMAIHPAC GUID-6B541154-D56B-452F-B143-4C2A1B2D3A1F v1 13.1.1 Identification GUID-8224B870-3DAA-44BF-B790-6600F2AD7C5D v1 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Multipurpose filter SMAIHPAC 13.1.2 Application...
Page 668 Section 13 1MRK 504 163-UUS A 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 669: Setting Guidelines
Section 13 1MRK 504 163-UUS A System protection and control 13.1.3 Setting guidelines 13.1.3.1 Setting example GUID-5A3F67BD-7D48-4734-948C-01DAF9470EF8 v2 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 493) EQUATION13000029 V1 EN-US...
Page 670 Section 13 1MRK 504 163-UUS A System protection and control FreqBandWidth 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 671 Section 13 1MRK 504 163-UUS A System protection and control then exact replica of the existing relay will be achieved. The following table summarizes all required settings for the multi-purpose function: Setting Group1 Operation CurrentInput MaxPh IBase 1000 VoltageInput MaxPh UBase 20.50 OPerHarmRestr...
Page 673: Current Circuit Supervision (87)
Section 14 1MRK 504 163-UUS A Secondary system supervision Section 14 Secondary system supervision 14.1 Current circuit supervision (87) IP14555-1 v5 14.1.1 Identification M14870-1 v5 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Current circuit supervision CCSSPVC 14.1.2 Application...
Page 674: Setting Guidelines
Section 14 1MRK 504 163-UUS A Secondary system supervision 14.1.3 Setting guidelines M12397-17 v8 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 675: Setting Guidelines
Section 14 1MRK 504 163-UUS A Secondary system supervision to the voltage instrument transformers, and shall be equipped with auxiliary contacts that are wired to the IEDs. Separate fuse-failure monitoring IEDs or elements within the protection and monitoring devices are another possibilities. These solutions are combined to get the best possible effect in the fuse failure supervision function (FUFSPVC).
Page 676: Setting Of Common Parameters
Section 14 1MRK 504 163-UUS A Secondary system supervision 14.2.3.2 Setting of common parameters M13683-9 v9 Set the operation mode selector Operation to Enabled to release the fuse failure function. 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.
Page 677: Zero Sequence Based
Section 14 1MRK 504 163-UUS A Secondary system supervision   VBase (Equation 497) EQUATION1757-ANSI V4 EN-US where: V2PU is the maximal negative sequence voltage during normal operation conditions, plus a margin of 10...20% VBase is the base voltage for the function according to the setting GlobalBaseSel The setting of the current limit 3I2PU is in percentage of parameter IBase.
Page 678: Dead Line Detection
Section 14 1MRK 504 163-UUS A Secondary system supervision I PU × IBase (Equation 500) EQUATION2293-ANSI V2 EN-US where: 3I0PU is the maximal zero sequence current during normal operating conditions, plus a margin of 10...20% IBase is the base current for the function according to the setting GlobalBaseSel 14.2.3.5 Delta V and delta I...
Page 679: Fuse Failure Supervision Vdspvc (60)
Section 14 1MRK 504 163-UUS A Secondary system supervision Set the IDLDPU with a sufficient margin below the minimum expected load current. A safety margin of at least 15-20% is recommended. The operate value must however exceed the maximum charging current of an overhead line, when only one phase is disconnected (mutual coupling to the other phases).
Page 680: Setting Guidelines
Section 14 1MRK 504 163-UUS A Secondary system supervision Main Vt circuit FuseFailSupvn ANSI12000143-1-en.vsd ANSI12000143 V1 EN-US Figure 303: Application of VDSPVC 14.3.3 Setting guidelines GUID-0D5A517C-1F92-46B9-AC2D-F41ED4E7C39E v1 GUID-52BF4E8E-0B0C-4F75-99C4-0BCB22CDD166 v2 The parameters for Fuse failure supervision VDSPVC are set via the local HMI or PCM600.
Page 681 Section 14 1MRK 504 163-UUS A Secondary system supervision The connection type for the main and the pilot fuse groups must be consistent. 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.
Page 683: Synchronism Check, Energizing Check, And Synchronizing Sesrsyn (25)
Section 15 1MRK 504 163-UUS A Control Section 15 Control 15.1 Synchronism check, energizing check, and synchronizing SESRSYN (25) IP14558-1 v4 15.1.1 Identification M14889-1 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Synchrocheck, energizing check, and SESRSYN synchronizing sc/vc...
Page 684 Section 15 1MRK 504 163-UUS A 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 685: Synchronism Check
Section 15 1MRK 504 163-UUS A Control The reference voltage can be phase-neutral A, B, C or phase-phase A-B, B-C, C-A or positive sequence (Require a three phase voltage, that is VA, VB and VC) . By setting the 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 686 Section 15 1MRK 504 163-UUS A 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 687: Energizing Check
Section 15 1MRK 504 163-UUS A Control SynchroCheck Bus voltage VHighBusSC > 50 – 120% of GblBaseSelBus Fuse fail VHighLineSC >50 – 120% of GblBaseSelLine Line Line Bus Voltage VDiffSC < 0.02 – 0.50 p.u. reference PhaseDiffM < 5 – 90 degrees voltage PhaseDiffA <...
Page 688: Voltage Selection
Section 15 1MRK 504 163-UUS A 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 689: 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 690: Application Examples
Section 15 1MRK 504 163-UUS A Control SLGGIO SESRSYN (25) PSTO INTONE NAME1 SWPOSN MENMODE NAME2 NAME3 NAME4 ANSI09000171_1_en.vsd ANSI09000171 V1 EN-US Figure 307: Selection of the energizing direction from a local HMI symbol through a selector switch function block. 15.1.3 Application examples M12323-3 v7...
Page 691: Single Circuit Breaker With Single Busbar
Section 15 1MRK 504 163-UUS A Control 15.1.3.1 Single circuit breaker with single busbar M12324-3 v12 SESRSYN (25) V3PB1* SYNOK Bus 1 V3PB2* AUTOSYOK V3PL1* AUTOENOK V3PL2* MANSYOK BLOCK MANENOK BLKSYNCH TSTSYNOK BLKSC TSTAUTSY BLKENERG TSTMANSY BUS1_OP TSTENOK BUS1_CL VSELFAIL Fuse BUS2_OP B1SEL...
Page 692: Single Circuit Breaker With Double Busbar, External Voltage Selection
Section 15 1MRK 504 163-UUS A Control 15.1.3.2 Single circuit breaker with double busbar, external voltage selection M12325-3 v8 SESRSYN (25) V3PB1* SYNOK V3PB2* AUTOSYOK V3PL1* AUTOENOK Bus 1 V3PL2* MANSYOK BLOCK MANENOK Bus 2 BLKSYNCH TSTSYNOK BLKSC TSTAUTSY BLKENERG TSTMANSY BUS1_OP TSTENOK...
Page 693: Single Circuit Breaker With Double Busbar, Internal Voltage Selection
Section 15 1MRK 504 163-UUS A Control 15.1.3.3 Single circuit breaker with double busbar, internal voltage selection M12326-3 v7 SESRSYN (25) V3PB1* SYNOK V3PB2* AUTOSYOK V3PL1* AUTOENOK V3PL2* MANSYOK Bus 1 BLOCK MANENOK Bus 2 BLKSYNCH TSTSYNOK BLKSC TSTAUTSY BLKENERG TSTMANSY BUS1_OP TSTENOK...
Page 694: Double Circuit Breaker
Section 15 1MRK 504 163-UUS A Control 15.1.3.4 Double circuit breaker M12329-3 v7 SESRSYN (25) V3PB1* SYNOK V3PB2* AUTOSYOK V3PL1* AUTOENOK V3PL2* MANSYOK BLOCK MANENOK BLKSYNCH TSTSYNOK BLKSC TSTAUTSY BLKENERG TSTMANSY BUS1_OP TSTENOK BUS1_CL VSELFAIL Fuse BUS2_OP B1SEL Voltage BUS2_CL B2SEL LINE1_OP L1SEL...
Page 695: Breaker-And-A-Half
Section 15 1MRK 504 163-UUS A 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 696 Section 15 1MRK 504 163-UUS A Control Bus 1 CB Bus 1 SESRSYN (25) Bus 2 V3PB1* SYNOK V3PB2* AUTOSYOK V3PL1* AUTOENOK V3PL2* MANSYOK BLOCK MANENOK BLKSYNCH TSTSYNOK BLKSC TSTAUTSY BLKENERG TSTMANSY Fuse BUS1_OP TSTENOK bus1 Voltage BUS1_CL VSELFAIL VREF1 BUS2_OP B1SEL BUS2_CL...
Page 697 Section 15 1MRK 504 163-UUS A 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 698: Setting Guidelines
Section 15 1MRK 504 163-UUS A Control 15.1.4 Setting guidelines M12550-3 v14 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 699 Section 15 1MRK 504 163-UUS A 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 • breaker-and-a-half arrangement with the breaker connected to busbar 2, 1 1/2 bus alt.
Page 700 Section 15 1MRK 504 163-UUS A Control are provided, and 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 701 Section 15 1MRK 504 163-UUS A Control expected to be 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 702 Section 15 1MRK 504 163-UUS A Control PhaseDiffA setting. Fluctuations occurring at high speed autoreclosing limit PhaseDiffA setting. 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.
Page 703: Apparatus Control Apc
Section 15 1MRK 504 163-UUS A Control The threshold voltages VDeadBusEnerg and VDeadLineEnerg, have to be set to a value greater than the value where the network is considered not to be energized. A typical value can be 40% of the base voltages. 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.
Page 704 Section 15 1MRK 504 163-UUS A Control principle for the use of QCBAY, LOCREM, LOCREMCTRL, SCILO, SCSWI, SXCBR. Figure shows from which places the apparatus control function receives commands. The commands to an apparatus can be initiated from the Control Centre (CC), the station HMI or the local HMI on the IED front.
Page 705 Section 15 1MRK 504 163-UUS A Control The apparatus control function is realized by means of a number of function blocks designated: • Switch controller SCSWI • Circuit breaker SXCBR • Circuit switch SXSWI • Bay control QCBAY • Bay reserve QCRSV •...
Page 706 Section 15 1MRK 504 163-UUS A Control IEC 61850 QCBAY SXCBR SCSWI SXCBR SXCBR SCILO SCSWI SXSWI SCILO en05000116_ansi.vsd ANSI05000116 V1 EN-US Figure 314: Signal flow between apparatus control function blocks when all functions are situated within the IED Transformer protection RET670 2.2 ANSI Application manual...
Page 707 Section 15 1MRK 504 163-UUS A 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-US Figure 315: Signal flow between apparatus control functions with XCBR and XSWI located in a breaker IED...
Page 708 Section 15 1MRK 504 163-UUS A 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 709: Bay Control Qcbay
Section 15 1MRK 504 163-UUS A Control 15.2.1.1 Bay control QCBAY M16595-3 v9 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 710: Switch Controller Scswi
Section 15 1MRK 504 163-UUS A Control 15.2.1.2 Switch controller SCSWI M16596-3 v5 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 711: Proxy For Signals From Switching Device Via Goose Xlnproxy
Section 15 1MRK 504 163-UUS A 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 712 Section 15 1MRK 504 163-UUS A Control IEC16000071 V1 EN-US Figure 317: Configuration with XLNPROXY and GOOSEXLNRCV where all the IEC 61850 modelled data is used, including selection Transformer protection RET670 2.2 ANSI Application manual...
Page 713 Section 15 1MRK 504 163-UUS A Control IEC16000072 V1 EN-US Figure 318: 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 714: Reservation Function (Qcrsv And Resin)
Section 15 1MRK 504 163-UUS A Control Table 55: 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 715 Section 15 1MRK 504 163-UUS A 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 716: Interaction Between Modules
Section 15 1MRK 504 163-UUS A Control SCSWI RES_ EXT SELECTED Other SCSWI in the bay en 05000118_ ansi. vsd ANSI05000118 V2 EN-US Figure 320: 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 321.
Page 717 Section 15 1MRK 504 163-UUS A 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 718 Section 15 1MRK 504 163-UUS A 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 719 Section 15 1MRK 504 163-UUS A Control SMPPTRC ZMQPDIS SECRSYN (Trip logic) (Synchrocheck) (Distance) Trip Synchrocheck QCBAY Operator place (Bay control) selection Open cmd Close cmd Res. req. SCSWI SXCBR (Switching control) Res. granted (Circuit breaker) QCRSV (Reservation) Res. req. Close CB SMBRREC (Auto-...
Page 720: Setting Guidelines
Section 15 1MRK 504 163-UUS A Control 15.2.3 Setting guidelines M16669-3 v4 The setting parameters for the apparatus control function are set via the local HMI or PCM600. 15.2.3.1 Bay control (QCBAY) M16670-3 v7 If the parameter AllPSTOValid is set to No priority, all originators from local and remote are accepted without any priority.
Page 721: Switch (Sxcbr/Sxswi)
Section 15 1MRK 504 163-UUS A Control The time parameter tResResponse is the allowed time from reservation request to the feedback reservation granted from all bays involved in the reservation function. When the time has expired, the control function is reset, and a cause-code is given. tSynchrocheck is the allowed time for the synchronism check function to fulfill the close conditions.
Page 722: Proxy For Signals From Switching Device Via Goose Xlnproxy
Section 15 1MRK 504 163-UUS A Control command output pulse remains active until the timer tOpenPulsetClosePulse has elapsed. tOpenPulse is the output pulse length for an open 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 723: Bay Reserve (Qcrsv)
Section 15 1MRK 504 163-UUS A Control 15.2.3.5 Bay Reserve (QCRSV) M16677-3 v3 The timer tCancelRes defines the supervision time for canceling the reservation, when this cannot be done by requesting bay due to for example communication failure. When the parameter ParamRequestx (x=1-8) is set to Only own bay res. individually for each apparatus (x) in the bay, only the own bay is reserved, that is, the output for reservation request of other bays (RES_BAYS) will not be activated at selection of apparatus x.
Page 724: Configuration Guidelines
Section 15 1MRK 504 163-UUS A Control example < 40% of rated voltage) before grounding and some current (for example < 100A) after grounding of a line. Circuit breakers are usually not interlocked. Closing is only interlocked against running disconnectors in the same bay, and the bus-coupler opening is interlocked during a busbar transfer.
Page 725: Interlocking For Line Bay Abc_Line (3)
Section 15 1MRK 504 163-UUS A Control when they are set to 0=FALSE. 15.3.2 Interlocking for line bay ABC_LINE (3) IP14139-1 v2 15.3.2.1 Application M13561-3 v8 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 323.
Page 726: Signals From Bus-Coupler
Section 15 1MRK 504 163-UUS A Control These signals from each line bay (ABC_LINE, 3) except that of the own bay are needed: Signal 789OPTR 789 is open VP789TR The switch status for 789 is valid. EXDU_BPB No transmission error from the bay that contains the above information. For bay n, these conditions are valid: 789OPTR (bay 1) BB7_D_OP...
Page 727 Section 15 1MRK 504 163-UUS A Control Section 1 Section 2 (WA1)A1 (WA2)B1 (WA7)C A1A2_DC(BS) B1B2_DC(BS) ABC_LINE ABC_BC ABC_LINE ABC_BC en04000479_ansi.vsd ANSI04000479 V1 EN-US Figure 325: Busbars divided by bus-section disconnectors (circuit breakers) To derive the signals: Signal BC_12_CL A bus-coupler connection exists between busbar WA1 and WA2. BC_17_OP No bus-coupler connection between busbar WA1 and WA7.
Page 728 Section 15 1MRK 504 163-UUS A Control These signals from each bus-section disconnector bay (A1A2_DC) are also needed. For B1B2_DC, corresponding signals from busbar B are used. The same type of module (A1A2_DC) is used for different busbars, that is, for both bus-section disconnector A1A2_DC and B1B2_DC.
Page 729 Section 15 1MRK 504 163-UUS A Control BC12CLTR (sect.1) BC_12_CL DCCLTR (A1A2) DCCLTR (B1B2) BC12CLTR (sect.2) VPBC12TR (sect.1) VP_BC_12 VPDCTR (A1A2) VPDCTR (B1B2) VPBC12TR (sect.2) BC17OPTR (sect.1) BC_17_OP DCOPTR (A1A2) BC17OPTR (sect.2) BC17CLTR (sect.1) BC_17_CL DCCLTR (A1A2) BC17CLTR (sect.2) VPBC17TR (sect.1) VP_BC_17 VPDCTR (A1A2) VPBC17TR (sect.2)
Page 730: Configuration Setting
Section 15 1MRK 504 163-UUS A Control 15.3.2.4 Configuration setting M13560-108 v4 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 731: Interlocking For Bus-Coupler Bay Abc_Bc (3)
Section 15 1MRK 504 163-UUS A Control 15.3.3 Interlocking for bus-coupler bay ABC_BC (3) IP14144-1 v2 15.3.3.1 Application M13555-3 v8 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 327. The function can also be used for a single busbar arrangement with transfer busbar or double busbar arrangement without transfer busbar.
Page 732 Section 15 1MRK 504 163-UUS A 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 733 Section 15 1MRK 504 163-UUS A 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 734: Signals From Bus-Coupler
Section 15 1MRK 504 163-UUS A Control 15.3.3.4 Signals from bus-coupler M13553-58 v5 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 735: Configuration Setting
Section 15 1MRK 504 163-UUS A 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 736: Interlocking For Transformer Bay Ab_Trafo (3)
Section 15 1MRK 504 163-UUS A Control • 7189G_OP = 1 • 7189G_CL = 0 If there is no second busbar B and therefore no 289 and 2089 disconnectors, then the interlocking for 289 and 2089 are not used. The states for 289, 2089, 2189G, BC_12, BBTR are set to open by setting the appropriate module inputs as follows.
Page 737: Signals From Bus-Coupler
Section 15 1MRK 504 163-UUS A 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-US Figure 333: Switchyard layout AB_TRAFO (3) M13566-4 v4 The signals from other bays connected to the module AB_TRAFO are described below.
Page 738: Configuration Setting
Section 15 1MRK 504 163-UUS A Control Section 1 Section 2 (WA1)A1 (WA2)B1 (WA7)C A1A2_DC(BS) B1B2_DC(BS) AB_TRAFO ABC_BC AB_TRAFO ABC_BC en04000487_ansi.vsd ANSI04000487 V1 EN-US Figure 334: 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 739: Interlocking For Bus-Section Breaker A1A2_Bs (3)
Section 15 1MRK 504 163-UUS A 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 740 Section 15 1MRK 504 163-UUS A 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-US Figure 336: 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 741 Section 15 1MRK 504 163-UUS A Control Signal S1S2OPTR No bus-section coupler connection between bus-sections 1 and 2. VPS1S2TR The switch status of bus-section coupler BS is valid. EXDU_BS No transmission error from the bay that contains the above information. For a bus-section circuit breaker between A1 and A2 section busbars, these conditions are valid: S1S2OPTR (B1B2)
Page 742: Configuration Setting
Section 15 1MRK 504 163-UUS A Control For a bus-section circuit breaker between B1 and B2 section busbars, these conditions are valid: 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) .
Page 743: Interlocking For Bus-Section Disconnector A1A2_Dc (3)
Section 15 1MRK 504 163-UUS A Control 15.3.6 Interlocking for bus-section disconnector A1A2_DC (3) IP14159-1 v2 15.3.6.1 Application M13544-3 v7 The interlocking for bus-section disconnector (A1A2_DC, 3) function is used for one bus-section disconnector between section 1 and 2 according to figure 339. A1A2_DC (3) function can be used for different busbars, which includes a bus-section disconnector.
Page 744 Section 15 1MRK 504 163-UUS A 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 745 Section 15 1MRK 504 163-UUS A 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 746: Signals In Double-Breaker Arrangement
Section 15 1MRK 504 163-UUS A 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 747 Section 15 1MRK 504 163-UUS A Control The same type of module (A1A2_DC) is used for different busbars, that is, for both bus-section disconnector A1A2_DC and B1B2_DC. But for B1B2_DC, corresponding signals from busbar B are used. Section 1 Section 2 (WA1)A1 (WA2)B1 A1A2_DC(BS)
Page 748 Section 15 1MRK 504 163-UUS A Control 189OPTR (bay 1/sect.A1) S1DC_OP ..189OPTR (bay n/sect.A1) VP189TR (bay 1/sect.A1) VPS1_DC ..VP189TR (bay n/sect.A1) EXDU_DB (bay 1/sect.A1) EXDU_BB .
Page 749: Signals In Breaker And A Half Arrangement
Section 15 1MRK 504 163-UUS A Control 289OPTR (bay 1/sect.B1) S1DC_OP ..289OPTR (bay n/sect.B1) VP289TR (bay 1/sect.B1) VPS1_DC ..VP289TR (bay n/sect.B1) EXDU_DB (bay 1/sect.B1) EXDU_BB .
Page 750: Interlocking For Busbar Grounding Switch Bb_Es (3)
Section 15 1MRK 504 163-UUS A 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-US Figure 350: Busbars divided by bus-section disconnectors (circuit breakers) The project-specific logic is the same as for the logic for the double-breaker configuration.
Page 751: Signals In Single Breaker Arrangement
Section 15 1MRK 504 163-UUS A Control 15.3.7.2 Signals in single breaker arrangement M15053-6 v5 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...
Page 752 Section 15 1MRK 504 163-UUS A 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 753 Section 15 1MRK 504 163-UUS A 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 754 Section 15 1MRK 504 163-UUS A Control 289OPTR(22089OTR)(bay 1/sect.B1) BB_DC_OP ..289PTR (22089OTR)(bay n/sect.B1) DCOPTR (B1/B2) VP289TR(V22089TR) (bay 1/sect.B1) VP_BB_DC ..VP289TR(V22089TR) (bay n/sect.B1) VPDCTR (B1/B2) EXDU_BB (bay 1/sect.B1) .
Page 755: Signals In Double-Breaker Arrangement
Section 15 1MRK 504 163-UUS A Control For a busbar grounding switch on bypass busbar C, these conditions are valid: 789OPTR (bay 1) BB_DC_OP ..789OPTR (bay n) VP789TR (bay 1) VP_BB_DC .
Page 756: Signals In Breaker And A Half Arrangement
Section 15 1MRK 504 163-UUS A Control Signal 189OPTR 189 is open. 289OPTR 289 is open. VP189TR The switch status of 189 is valid. VP289TR The switch status of 289 is valid. EXDU_DB No transmission error from the bay that contains the above information. These signals from each bus-section disconnector bay (A1A2_DC) are also needed.
Page 757: Interlocking For Double Cb Bay Db (3)
Section 15 1MRK 504 163-UUS A Control 15.3.8 Interlocking for double CB bay DB (3) IP14167-1 v2 15.3.8.1 Application M13585-3 v10 The interlocking for a double busbar double circuit breaker bay including DB_BUS_A (3), DB_BUS_B (3) and DB_LINE (3) functions are used for a line connected to a double busbar arrangement according to figure 360.
Page 758: Interlocking For Breaker-And-A-Half Diameter Bh (3)
Section 15 1MRK 504 163-UUS A Control • 989_OP = 1 • 989_CL = 0 • 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: •...
Page 759: Configuration Setting
Section 15 1MRK 504 163-UUS A 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-US Figure 361: Switchyard layout breaker-and-a-half M13570-7 v4 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 760: Voltage Control
Section 15 1MRK 504 163-UUS A 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 761 Section 15 1MRK 504 163-UUS A Control secondary side of the power transformer. The control method is based on a step-by-step principle which means that a control pulse, one at a time, will be issued to the tap changer mechanism to move it one position up or down. The length of the control pulse can be set within a wide range to accommodate different types of tap changer mechanisms.
Page 762 Section 15 1MRK 504 163-UUS A Control time delay (inverse or definite time) is set to avoid unnecessary operation during shorter voltage deviations from the target value, and in order to coordinate with other automatic voltage controllers in the system. TCMYLTC and TCLYLTC (84)are an interface between the Automatic voltage control for tap changer, TR1ATCC (90) or TR8ATCC (90) and the transformer load tap changer itself.
Page 763 Section 15 1MRK 504 163-UUS A Control analog quantities are fed to the IED via the transformer input module, the Analog to Digital Converter and thereafter a Pre-Processing Block. In the Pre-Processing Block, a great number of quantities for example, phase-to-phase analog values, sequence values, max value in a three phase group etc., are derived.
Page 764 Section 15 1MRK 504 163-UUS A Control High Voltage Side raise,lower signals/alarms position (Load Current) I 3ph or ph-ph or 1ph Currents 3ph or ph-ph or 1ph Voltages Low Voltage Side VB (Busbar Voltage) Line Impedance R+jX Load Center VL (Load Point Voltage) ANSI10000044-1-en.vsd ANSI10000044 V1 EN-US Figure 362:...
Page 765 Section 15 1MRK 504 163-UUS A Control Automatic voltage control for a single transformer SEMOD159053-73 v6 Automatic voltage control for tap changer, single control TR1ATCC (90) measures the magnitude of the busbar voltage V . If no other additional features are enabled (line voltage drop compensation), this voltage is further used for voltage regulation.
Page 766 Section 15 1MRK 504 163-UUS A Control When V falls below setting Vblock, or alternatively, falls below setting Vmin but still above Vblock, or rises above Vmax, actions will be taken in accordance with settings for blocking conditions (refer to table 60). If the busbar voltage rises above Vmax, TR1ATCC (90) can initiate one or more fast step down commands (VLOWER commands) in order to bring the voltage back into the security range (settings Vmin, and Vmax).
Page 767 Section 15 1MRK 504 163-UUS A Control tMin (Equation 506) EQUATION1848 V2 EN-US Where: absolute voltage deviation from the set point relative voltage deviation in respect to set deadband value For the last equation, the condition t1 > tMin shall also be fulfilled. This practically means that tMin will be equal to the set t1 value when absolute voltage deviation DA is equal to ΔV ( relative voltage deviation D is equal to 1).
Page 768 Section 15 1MRK 504 163-UUS A Control Line voltage drop SEMOD159053-105 v6 The purpose with the line voltage drop compensation is to control the voltage, not at the power transformer low voltage side, but at a point closer to the load point. Figure shows the vector diagram for a line modelled as a series impedance with the voltage V...
Page 769 Section 15 1MRK 504 163-UUS A Control ANSI06000487-2-en.vsd ANSI06000487 V2 EN-US Figure 365: Vector diagram for line voltage drop compensation The calculated load voltage V is shown on the local HMI as value ULOAD under Main menu/Test/Function status/Control/TransformerVoltageControl(ATCC,90)/ TR1ATCC:x/TR8ATCC:x. Load voltage adjustment SEMOD159053-118 v6 Due to the fact that most loads are proportional to the square of the voltage, it is possible to provide a way to shed part of the load by decreasing the supply voltage a...
Page 770 Section 15 1MRK 504 163-UUS A Control With these factors, TR1ATCC (90) or TR8ATCC (90) adjusts the value of the set voltage Vset according to the following formula: × Vsetadjust Vset I Base (Equation 507) EQUATION1978-ANSI V2 EN-US Adjusted set voltage in per unit set, adjust VSet Original set voltage: Base quality is V...
Page 771 Section 15 1MRK 504 163-UUS A Control Assuming for instance that they start out on the same tap position and that the LV is within VSet ± DV, then a gradual increase or decrease in the load busbar voltage V fall outside VSet ±...
Page 772 Section 15 1MRK 504 163-UUS A Control two inputs are pulse activated, and the most recent activation is valid that is, an activation of any of these two inputs overrides previous activations. If none of these inputs has been activated, the default is that the transformer acts as a follower (given of course that the settings are parallel control with the master follower method).
Page 773 Section 15 1MRK 504 163-UUS A Control Figure 368, shows a vector diagram where the principle of reverse reactance has been introduced for the transformers in figure 367. The transformers are here supposed to be on the same tap position, and the busbar voltage is supposed to give a calculated compensated value V that coincides with the target voltage VSet.
Page 774 Section 15 1MRK 504 163-UUS A Control cc..T2 cc..T1 Load en06000491_ansi.vsd ANSI06000491 V1 EN-US Figure 369: Circulating current caused by T1 on a higher tap than T2. The circulating current I is predominantly reactive due to the reactive nature of the transformers.
Page 775 Section 15 1MRK 504 163-UUS A Control that the busbar or load voltage is regulated to a preset target value that the load is shared between parallel transformers in proportion to their ohmic short circuit reactance If the transformers have equal percentage impedance given in the respective transformer MVA base, the load will be divided in direct proportion to the rated power of the transformers when the circulating current is minimized.
Page 776 Section 15 1MRK 504 163-UUS A Control × × cc _ i (Equation 508) EQUATION1979-ANSI V1 EN-US where X is the short-circuit reactance for transformer i and C , is a setting parameter named Comp which serves the purpose of alternatively increasing or decreasing the impact of the circulating current in TR8ATCC control calculations.
Page 777 Section 15 1MRK 504 163-UUS A Control Line voltage drop compensation for parallel control SEMOD159053-186 v3 The line voltage drop compensation for a single transformer is described in section "Line voltage drop". The same principle is used for parallel control with the circulating current method and with the master –...
Page 778 Section 15 1MRK 504 163-UUS A Control HV side, but open on the LV side (hot stand-by), to follow the voltage regulation of loaded parallel transformers, and thus be on a proper tap position when the LV circuit breaker closes. For this function, it is needed to have the LV VTs for each transformer on the cable (tail) side (not the busbar side) of the CB, and to have the LV CB position hardwired to the IED.
Page 779 Section 15 1MRK 504 163-UUS A Control TR8ATCC (90) in adapt mode will continue the calculation of V , but instead of to the measured busbar voltage, it will compare it with the deadband DV. adding V The following control rules are used: is positive and its modulus is greater than DV, then initiate an VLOWER If V command.
Page 780 Section 15 1MRK 504 163-UUS A Control the calculation of circulating currents. The capacitive current is part of the imaginary load current and therefore essential in the calculation. The calculated circulating current and the real circulating currents will in this case not be the same, and they will not reach a minimum at the same time.
Page 781 Section 15 1MRK 504 163-UUS A Control for T2 and T1. This in turn would be misinterpreted as a circulating current, and would upset a correct calculation of I . Thus, if the actual connection is as in the left figure the capacitive current I needs to be compensated for regardless of the operating conditions and in ATCC this is made numerically.
Page 782 Section 15 1MRK 504 163-UUS A Control HV-side Pforward Qforward (inductive) ATCC LV-side ANSI06000536-2-en.vsd ANSI06000536 V2 EN-US Figure 371: Power direction references With the four outputs in the function block available, it is possible to do more than just supervise a level of power flow in one direction. By combining the outputs with logical elements in application configuration, it is also possible to cover for example, intervals as well as areas in the P-Q plane.
Page 783 Section 15 1MRK 504 163-UUS A Control 99000952.VSD ANSI99000952 V1 EN-US Figure 372: Disconnection of one transformer in a parallel group When the busbar arrangement is more complicated with more buses and bus couplers/bus sections, it is necessary to engineer a specific station topology logic. This logic can be built in the application configuration in PCM600 and will keep record on which transformers that are in parallel (in one or more parallel groups).
Page 784 Section 15 1MRK 504 163-UUS A Control TCMYLTC or TCLYLTC (84) function block for the same transformer as TR8ATCC (90) block belongs to. There are 10 binary signals and 6 analog signals in the data set that is transmitted from one TR8ATCC (90) block to the other TR8ATCC (90) blocks in the same parallel group: Table 57:...
Page 785 Section 15 1MRK 504 163-UUS A Control • SetV • VCTRStatus • The transformers controlled in parallel with the circulating current method or the master-follower method must be assigned unique identities. These identities are entered as a setting in each TR8ATCC (90), and they are predefined as T1, T2, T3,..., T8 (transformers 1 to 8).
Page 786 Section 15 1MRK 504 163-UUS A Control For the Automatic voltage control for tap changer function, TR1ATCC (90) for single control and TR8ATCC (90) for parallel control, three types of blocking are used: Partial Block: Prevents operation of the tap changer only in one direction (only VRAISE or VLOWER command is blocked) in manual and automatic control mode.
Page 787 Section 15 1MRK 504 163-UUS A Control Setting Values (Range) Description RevActPartBk(auto Alarm The risk of voltage instability increases as transmission matically reset) Auto Block lines become more heavily loaded in an attempt to maximize the efficient use of existing generation and transmission facilities.
Page 788 Section 15 1MRK 504 163-UUS A Control Setting Values (Range) Description TapChgBk Alarm If the input TCINPROG of TCMYLTC or TCLYLTC (84) (manually reset Auto Block function block is connected to the tap changer Auto&Man Block mechanism, then this blocking condition will be active if the TCINPROG input has not reset when the tTCTimeout timer has timed out.
Page 789 Section 15 1MRK 504 163-UUS A Control Setting Values (Range) Description TapPosBk Alarm This blocking/alarm is activated by either: (automatically Auto Block The tap changer reaching an end position i.e. one of reset/manually Auto&Man Block the extreme positions according to the setting reset) LowVoltTap and HighVoltTap .
Page 790 Section 15 1MRK 504 163-UUS A Control Setting Values (Range) Description MFPosDiffBk Alarm In the master-follower mode, if the tap difference between (manually reset) Auto Block a follower and the master is greater than the set value MFPosDiffLim ) then this blocking (setting parameter condition is fulfilled and the outputs OUTOFPOS and AUTOBLK (alternatively an alarm) will be set.
Page 791 Section 15 1MRK 504 163-UUS A Control Blockings activated by the operating conditions, without setting or separate external activation possibilities, are listed in table 63. Table 63: Blockings without setting possibilities Activation Type of blocking Description Disconnected Auto Block Automatic control is blocked for a transformer when transformer parallel control with the circulating current method is (automatically reset)
Page 792 Section 15 1MRK 504 163-UUS A Control block is received from any of the group members, automatic operation is blocked in the receiving TR8ATCCs (90) that is, all units of the parallel group. The following conditions in any one of TR8ATCCs (90) in the group will cause mutual blocking when the circulating current method is used: •...
Page 793 Section 15 1MRK 504 163-UUS A Control example, IBLK for over-current blocking. The other TR8ATCCs (90) that receive a mutual block signal will only set its AUTOBLK output. The mutual blocking remains until TR8ATCC (90) that dispatched the mutual block signal is de-blocked.
Page 794 Section 15 1MRK 504 163-UUS A Control Usually the tap changer mechanism can give a signal, “Tap change in progress”, during the time that it is carrying through an operation. This signal from the tap changer mechanism can be connected via a BIM module to TCMYLTC (84) or TCLYLTC (84) input TCINPROG, and it can then be used by TCMYLTC (84) or TCLYLTC (84) function in three ways, which is explained below with the help of figure 373.
Page 795 Section 15 1MRK 504 163-UUS A Control The second use is to detect a jammed tap changer. If the timer tTCTimeout times out before the TCINPROG signal is set back to zero, the output signal TCERRAL is set high and TR1ATCC (90) or TR8ATCC (90) function is blocked. The third use is to check the proper operation of the tap changer mechanism.
Page 796: Setting Guidelines
Section 15 1MRK 504 163-UUS A Control Wearing of the tap changer contacts SEMOD159053-376 v4 Two counters, ContactLife and NoOfOperations are available within the Tap changer control and supervision function, 6 binary inputs TCMYLTC or 32 binary inputs TCLYLTC (84). They can be used as a guide for maintenance of the tap changer mechanism.
Page 797: Tr1Atcc (90) Or Tr8Atcc (90) Setting Group
Section 15 1MRK 504 163-UUS A Control tAutoMSF: Time delay set in a follower for execution of a raise or lower command given from a master. This feature can be used when a parallel group is controlled in the master-follower mode, follow tap, and it is individually set for each follower, which means that different time delays can be used in the different followers in order to avoid simultaneous tapping if this is wanted.
Page 798 Section 15 1MRK 504 163-UUS A Control I1Base: Base current in primary Ampere for the HV-side of the transformer. I2Base: Base current in primary Ampere for the LV-side of the transformer. VBase: Base voltage in primary kV for the LV-side of the transformer. MeasMode: Selection of single phase, or phase-phase, or positive sequence quantity to be used for voltage and current measurement on the LV-side.
Page 799 Section 15 1MRK 504 163-UUS A Control equal to DV . The setting shall be smaller than VDeadband. Typically the inner deadband can be set to 25-70% of the VDeadband value. Vmax: This setting gives the upper limit of permitted busbar voltage (see section "Automatic voltage control for a single transformer", figure 363).
Page 800 Section 15 1MRK 504 163-UUS A Control Rline and Xline: For line voltage drop compensation, these settings give the line resistance and reactance from the station busbar to the load point. The settings for Rline and Xline are given in primary system ohms. If more than one line is connected to the LV busbar, equivalent Rline and Xline values should be calculated and given as settings.
Page 801 Section 15 1MRK 504 163-UUS A Control Assume that we want to achieve that j = -90°, then: ´ ß ´ ß ß = - - (Equation 513) EQUATION1983-ANSI V1 EN-US If for example cosj = 0.8 then j = arcos 0.8 = 37°. With the references in figure 374, j will be negative (inductive load) and we get: j = - - ( 37 ) 90...
Page 802 Section 15 1MRK 504 163-UUS A Control =-79 Rline Xline Zline *Rline *Xline j=30 en06000630_ansi.vsd ANSI06000630 V1 EN-US Figure 375: Transformer with reverse reactance regulation poorly adjusted to the power factor As can be seen in figure 375, the change of power factor has resulted in an increase of j2 which in turn causes the magnitude of V to be greater than V .
Page 803 Section 15 1MRK 504 163-UUS A Control A combination of line voltage drop compensation and parallel control with the negative reactance method is possible to do simply by adding the required Rline values and the required Xline values separately to get the combined impedance. However, the line drop impedance has a tendency to drive the tap changers apart, which means that the reverse reactance impedance normally needs to be increased.
Page 804 Section 15 1MRK 504 163-UUS A Control tWindowHunt: Setting of the time window for the window hunting function. This function is activated when the number of contradictory commands to the tap changer exceeds the specified number given by NoOpWindow within the time tWindowHunt. NoOpWindow: Setting of the number of contradictory tap changer operations (RAISE, LOWER, RAISE, LOWER etc.) required during the time window tWindowHunt to activate the signal HUNTING.
Page 805 Section 15 1MRK 504 163-UUS A Control Q>: When the reactive power exceeds the value given by this setting, the output QGTFWD will be activated after the time delay tPower. It shall be noticed that the setting is given with sign, which effectively means that the function picks up for all values of reactive power greater than the set value, similar to the functionality for P>.
Page 806 Section 15 1MRK 504 163-UUS A Control • a is a safety margin that shall cover component tolerances and other non-linear measurements at different tap positions (for example, transformer reactances changes from rated value at the ends of the regulation range). In most cases a value of a = 1.25 serves well.
Page 807: Tcmyltc And Tclyltc (84) General Settings
Section 15 1MRK 504 163-UUS A Control 15.4.3.3 TCMYLTC and TCLYLTC (84) general settings SEMOD171501-150 v6 LowVoltTap: This gives the tap position for the lowest LV-voltage. HighVoltTap: This gives the tap position for the highest LV-voltage. mALow: The mA value that corresponds to the lowest tap position. Applicable when reading of the tap position is made via a mA signal.
Page 808: Logic Rotating Switch For Function Selection And Lhmi Presentation Slgapc
Section 15 1MRK 504 163-UUS A Control 15.5 Logic rotating switch for function selection and LHMI presentation SLGAPC SEMOD114936-1 v4 15.5.1 Identification SEMOD167845-2 v3 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Logic rotating switch for function SLGAPC selection and LHMI presentation 15.5.2...
Page 809: Selector Mini Switch Vsgapc
Section 15 1MRK 504 163-UUS A Control NrPos: Sets the number of positions in the switch (max. 32). OutType: Steady or Pulsed. tPulse: In case of a pulsed output, it gives the length of the pulse (in seconds). tDelay: The delay between the UP or DOWN activation signal positive front and the output activation.
Page 810: Setting Guidelines
Section 15 1MRK 504 163-UUS A Control INPUT VSGAPC PSTO INTONE IPOS1 IPOS2 SMBRREC_79 NAM_POS1 CMDPOS12 SETON Disabled NAM_POS2 CMDPOS21 Enabled ANSI07000112-3-en.vsd ANSI07000112 V3 EN-US Figure 378: Control of Autorecloser from local HMI through Selector mini switch VSGAPC is also provided with IEC 61850 communication so it can be controlled from SA system as well.
Page 811: Setting Guidelines
Section 15 1MRK 504 163-UUS A Control It is especially intended to be used in the interlocking station-wide logics. To be able to get the signals into other systems, equipment or functions, one must use other tools, described in the Engineering manual, and define which function block in which systems, equipment or functions should receive this information.
Page 812: Identification
Section 15 1MRK 504 163-UUS A Control 15.8.1 Identification SEMOD176456-2 v3 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Single point generic control 8 signals SPC8GAPC 15.8.2 Application SEMOD176511-4 v6 The Single point generic control 8 signals (SPC8GAPC) function block is a collection of 8 single point commands that can be used for direct commands for example reset of LED's or putting IED in "ChangeLock"...
Page 813: Identification
Section 15 1MRK 504 163-UUS A Control 15.9.1 Identification GUID-C3BB63F5-F0E7-4B00-AF0F-917ECF87B016 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number AutomationBits, command function for AUTOBITS DNP3 15.9.2 Application SEMOD158637-5 v4 Automation bits, command function for DNP3 (AUTOBITS) is used within PCM600 in order to get into the configuration the commands coming through the DNP3.0 protocol.The AUTOBITS function plays the same role as functions GOOSEBINRCV (for IEC 61850) and MULTICMDRCV (for LON).AUTOBITS function block have 32...
Page 814: Application
Section 15 1MRK 504 163-UUS A Control 15.10.2 Application M12445-3 v3 Single command, 16 signals (SINGLECMD) is a common function and always included in the IED. The IEDs may be provided with a function to receive commands either from a substation automation system or from the local HMI.
Page 815: Setting Guidelines
Section 15 1MRK 504 163-UUS A Control Single command function Function n SINGLECMD Function n CMDOUTy OUTy en04000207.vsd IEC04000207 V2 EN-US Figure 380: Application example showing a logic diagram for control of built-in functions Single command function Configuration logic circuits SINGLESMD Device 1 CMDOUTy...
Page 816 Section 15 1MRK 504 163-UUS A Control Parameters to be set are MODE, common for the whole block, and CMDOUTy which includes the user defined name for each output signal. The MODE input sets the outputs to be one of the types Disabled, Steady, or Pulse. •...
Page 817: Scheme Communication Logic For Distance Or Overcurrent Protection Zcpsch(85)
Section 16 1MRK 504 163-UUS A Scheme communication Section 16 Scheme communication 16.1 Scheme communication logic for distance or overcurrent protection ZCPSCH(85) IP15749-1 v3 16.1.1 Identification M14854-1 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Scheme communication logic for ZCPSCH distance or overcurrent protection...
Page 818: Blocking Schemes
Section 16 1MRK 504 163-UUS A 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 M16866-24 v5...
Page 819: Delta Blocking Scheme
Section 16 1MRK 504 163-UUS A Scheme communication Z rev TRIP = OR + tCoord+ CR Z rev IEC09000015_2_en.vsd IEC09000015 V2 EN-US Figure 382: Principle of blocking scheme Overreaching Communication signal received Communication signal send Z rev : Reverse zone 16.1.2.2 Delta blocking scheme GUID-D699D2D8-6479-4B40-8B09-7B24CA86C24B v1...
Page 820: Permissive Schemes
Section 16 1MRK 504 163-UUS A 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 821 Section 16 1MRK 504 163-UUS A Scheme communication Permissive underreaching scheme M16866-53 v4 Permissive underreaching scheme is not suitable to use on short line length due to difficulties for distance protection measurement in general to distinguish between internal and external faults in those applications. 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.
Page 822 Section 16 1MRK 504 163-UUS A Scheme communication TRIP: UR or OR+CR IEC09000013-2-en.vsd IEC09000013 V2 EN-US Figure 384: Principle of Permissive underreaching scheme UR: Underreaching OR: Overreaching CR: Communication signal received Communication signal send Permissive overreaching scheme M16866-41 v4 In a permissive overreaching scheme there is an overreaching zone that issues the send signal.
Page 823 Section 16 1MRK 504 163-UUS A Scheme communication The send signal (CS) might be issued in parallel both from an overreaching zone and an underreaching, independent tripping zone. The CS signal from the overreaching zone must not be prolonged while the CS signal from zone 1 can be prolonged. To secure correct operations of current reversal logic in case of parallel lines the send signal CS shall not be prolonged.
Page 824: Intertrip Scheme
Section 16 1MRK 504 163-UUS A Scheme communication 16.1.2.4 Intertrip scheme M16866-71 v4 In some power system applications, there is a need to trip the remote end breaker immediately from local protections. This applies for instance when transformers or reactors are connected to the system without circuit-breakers or for remote tripping following operation of breaker failure protection.
Page 825: Delta Blocking Scheme
Section 16 1MRK 504 163-UUS A Scheme communication 16.1.3.2 Delta blocking scheme GUID-F4359690-F433-46CB-A173-8C14559E3FCF v1 Operation Enabled SchemeType DeltaBlocking tCoord = 0 s tSendMin = 0 s Unblock Disabled NoRestart if Unblocking scheme with no alarm for loss of guard is to be (Set to used.
Page 826: Intertrip Scheme
Section 16 1MRK 504 163-UUS A Scheme communication 16.1.3.6 Intertrip scheme M13869-62 v5 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...
Page 827 Section 16 1MRK 504 163-UUS A Scheme communication important pay attention to the communication channel dependability to ensure that proper signals are communicated during power system faults, the time during which the protection schemes must perform their tasks flawlessly. The logic supports the following communications schemes: •...
Page 828: Blocking Scheme
Section 16 1MRK 504 163-UUS A Scheme communication By using phase-segregated channels for the communication scheme, the correct phase information in the protection IED near the faults can be transferred to the other side protection IED. A correct single-pole trip can be achieved on both lines and at both line IEDs.
Page 829 Section 16 1MRK 504 163-UUS A Scheme communication received signal is present during the time the chosen zone is detected a fault in forward direction. Either end may send a permissive (or command) signal to trip to the other end(s), and the teleprotection equipment need to be able to receive while transmitting. 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.
Page 830: Intertrip Scheme
Section 16 1MRK 504 163-UUS A Scheme communication faults. Inadequate speed or dependability can cause delayed tripping for internal faults or even unwanted operations. This scheme may use virtually any communication media that is not adversely affected by electrical interference from fault generated noise or by electrical phenomena, such as lightning, that cause faults.
Page 831: Permissive Underreache Scheme
Section 16 1MRK 504 163-UUS A Scheme communication Configure the zones used for the CS carrier send and for scheme communication tripping by using the Application Configuration tool. The recommended settings of tCoord timer are based on maximal recommended transmission time for analog channels according to IEC 60834-1.
Page 832: Current Reversal And Weak-End Infeed Logic For Distance Protection 3-Phase Zcrwpsch (85)
Section 16 1MRK 504 163-UUS A Scheme communication 16.3 Current reversal and Weak-end infeed logic for distance protection 3-phase ZCRWPSCH (85) IP15751-1 v4 16.3.1 Identification M15073-1 v5 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 833: Weak-End Infeed Logic
Section 16 1MRK 504 163-UUS A Scheme communication CLOSED FAULT OPEN LINE 1 Weak Strong source source CLOSED CLOSED LINE 2 en99000044_ansi.vsd ANSI99000044 V1 EN-US Figure 388: 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 834: Setting Guidelines
Section 16 1MRK 504 163-UUS A Scheme communication 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. • A separate direct intertrip channel must be arranged from remote end when a trip or accelerated trip is given there.
Page 835: Current Reversal And Weak-End Infeed Logic For Phase Segregated Communication Zc1Wpsch (85)
Section 16 1MRK 504 163-UUS A 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) SEMOD155635-1 v2 16.4.1...
Page 836 Section 16 1MRK 504 163-UUS A Scheme communication IEC14000002-1-en.vsd IEC14000002 V1 EN-US Figure 389: Current distribution for a fault close to B side when all breakers are closed When the breaker B1 opens for clearing the fault, the fault current through B2 bay will invert.
Page 837: Setting Guidelines
Section 16 1MRK 504 163-UUS A Scheme communication The WEI function can be extended to trip also the breaker in the weak side. The trip is achieved when one or more phase voltages are low during an echo function. Together with the blocking teleprotection scheme some limitations apply: •...
Page 838: Scheme Communication Logic For Residual Overcurrent Protection Ecpsch (85)
Section 16 1MRK 504 163-UUS A Scheme communication Set tPickUpWEI to 10 ms, a short delay is recommended to avoid that spurious carrier received signals will activate WEI and cause unwanted communications. Set the voltage criterion UPP< and UPE< for the weak-end trip to 70% of the system base voltage UBase.
Page 839: Setting Guidelines
Section 16 1MRK 504 163-UUS A Scheme communication During a single-phase reclosing cycle, the autoreclosing device must block the directional comparison ground-fault communication scheme. The communication logic module enables blocking as well as permissive under/ overreaching schemes. The logic can also be supported by additional logic for weak- end infeed and current reversal, included in the Current reversal and weak-end infeed logic for residual overcurrent protection (ECRWPSCH, 85) function.
Page 840: Current Reversal And Weak-End Infeed Logic For Residual Overcurrent Protection Ecrwpsch (85)
Section 16 1MRK 504 163-UUS A Scheme communication tSecurity: The absence of CRG signal for a time duration of tSecurity is considered as CR signal. 16.6 Current reversal and weak-end infeed logic for residual overcurrent protection ECRWPSCH (85) IP14365-1 v4 16.6.1 Identification M14883-1 v2...
Page 841: Weak-End Infeed Logic
Section 16 1MRK 504 163-UUS A Scheme communication CLOSED FAULT OPEN LINE 1 Weak Strong source source CLOSED CLOSED LINE 2 en99000044_ansi.vsd ANSI99000044 V1 EN-US Figure 392: Current distribution for a fault close to B side when breaker at B1 is opened When the breaker on the parallel line operates, the fault current on the healthy line is reversed.
Page 842: Current Reversal
Section 16 1MRK 504 163-UUS A Scheme communication Common base IED values for primary current (IBase), primary voltage (VBase) and primary power (SBase) are set in a Global base values for settings function GBASVAL. GlobalBaseSel: It is used to select a GBASVAL function for reference of base values. 16.6.3.1 Current reversal M13933-6 v5...
Page 843: Weak-End Infeed
Section 16 1MRK 504 163-UUS A Scheme communication Tele- Tele- Tele- Protection Protection Protection communication Protection Function Function Equipment System Equipment CS initiation to CS from the CR to the CR selection and protection CS propagation, protection communication decision, operate function, operate propagation function, operate...
Page 845: Tripping Logic Smpptrc (94)
Section 17 1MRK 504 163-UUS A Logic Section 17 Logic 17.1 Tripping logic SMPPTRC (94) IP14576-1 v4 17.1.1 Identification SEMOD56226-2 v7 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Tripping logic SMPPTRC 1 -> 0 IEC15000314 V1 EN-US 17.1.2 Application M12252-3 v10...
Page 846: Three-Pole Tripping
Section 17 1MRK 504 163-UUS A Logic tripping and autoreclosing is used on the line, both breakers are normally set up for 1/3-pole tripping and 1/3-phase autoreclosing. Alternatively, the breaker chosen as master can have single-pole tripping, while the slave breaker could have three-pole tripping and autoreclosing.
Page 847: Single- And/Or Three-Pole Tripping
Section 17 1MRK 504 163-UUS A Logic 17.1.2.2 Single- and/or three-pole tripping M14828-11 v6 The single-/three-pole tripping operation mode will give single-pole tripping for single-phase faults and three-pole tripping for multi-phase fault. This 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 848: Single-, Two- Or Three-Pole Tripping
Section 17 1MRK 504 163-UUS A 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 396. Protection functions with 3 SMPPTRC (94) phase trip, for example time TRIP BLOCK...
Page 849: Lock-Out
Section 17 1MRK 504 163-UUS A Logic 17.1.2.4 Lock-out M14828-18 v5 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). The lock-out can then be manually reset after checking the primary fault by activating the input reset lock-out RSTLKOUT.
Page 850 Section 17 1MRK 504 163-UUS A Logic SMAGAPC SMPPTRC (94) STARTCOMB BLOCK BLOCK TRIP PROTECTION 1 BLOCK PU_DIR1 BLKLKOUT TR_A PU_DIR2 BFI_3P BFI_3P TRINP_3P TR_B PU_DIR3 TRINP_A TR_C PU_DIR4 TRINP_B TR1P BFI_A PU_DIR5 TRINP_C TR2P FW_A PU_DIR6 PS_A TR3P REV_A PU_DIR7 PS_B CLLKOUT...
Page 851: Blocking Of The Function Block
Section 17 1MRK 504 163-UUS A Logic The trip function (SMPPTRC) splits up the directional data as general output data for BFI_3P, BFI_A, BFI_B, BFI_C, STN, FW and REV. All start and directional outputs are mapped to the logical node data model of the trip function and provided via the IEC 61850 attributes dirGeneral, DIRL1, DIRL2, DIRL3 and DIRN.
Page 852: Identification
Section 17 1MRK 504 163-UUS A Logic 17.2.1 Identification SEMOD167882-2 v3 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Trip matrix logic TMAGAPC 17.2.2 Application M15321-3 v12 The trip matrix logic TMAGAPC function is used to route trip signals and other logical output signals to different output contacts on the IED.
Page 853: Application
Section 17 1MRK 504 163-UUS A Logic 17.3.2 Application GUID-70B268A9-B248-422D-9896-89FECFF80B75 v1 Group alarm logic function ALMCALH is used to route alarm signals to different LEDs and/or output contacts on the IED. ALMCALH output signal and the physical outputs allows the user to adapt the alarm signal to physical tripping outputs according to the specific application needs.
Page 854: Application
Section 17 1MRK 504 163-UUS A Logic 17.5.1.1 Application GUID-9BAD30FB-4B75-4E14-82A8-6A59B09FA6EA v1 Group indication logic function INDCALH is used to route indication signals to different LEDs and/or output contacts on the IED. INDCALH output signal IND and the physical outputs allows the user to adapt the indication signal to physical outputs according to the specific application needs.
Page 855: Configuration
Section 17 1MRK 504 163-UUS A Logic For controllable gates, settable timers and SR flip-flops with memory, the setting parameters are accessible via the local HMI or via the PST tool. 17.6.2.1 Configuration GUID-D93E383C-1655-46A3-A540-657141F77CF0 v4 Logic is configured using the ACT configuration tool in PCM600. Execution of functions as defined by the configurable logic blocks runs according to a fixed sequence with different cycle times.
Page 856: Fixed Signal Function Block Fxdsign
Section 17 1MRK 504 163-UUS A Logic Always be careful when connecting function blocks with a fast cycle time to function blocks with a slow cycle time. Remember to design the logic circuits carefully and always check the execution sequence for different functions. In other cases, additional time delays must be introduced into the logic schemes to prevent errors, for example, race between functions.
Page 857: Boolean 16 To Integer Conversion B16I
Section 17 1MRK 504 163-UUS A Logic REFPDIF (87N) I3PW1CT1 I3PW2CT1 ANSI11000083_1_en.vsd ANSI11000083 V1 EN-US Figure 400: REFPDIF (87N) function inputs for autotransformer application For normal transformers only one winding and the neutral point is available. This means that only two inputs are used. Since all group connections are mandatory to be connected, the third input needs to be connected to something, which is the GRP_OFF signal in FXDSIGN function block.
Page 858: Application
Section 17 1MRK 504 163-UUS A Logic 17.8.2 Application SEMOD175832-4 v4 Boolean 16 to integer conversion function B16I is used to transform a set of 16 binary (logical) signals into an integer. It can be used – for example, to connect logical output signals from a function (like distance protection) to integer inputs from another function (like line differential protection).
Page 859: Boolean To Integer Conversion With Logical Node Representation
Section 17 1MRK 504 163-UUS A Logic The sum of the numbers in column “Value when activated” when all INx (where 1≤x≤16) are active that is=1; is 65535. 65535 is the highest boolean value that can be converted to an integer by the B16I function block. 17.9 Boolean to integer conversion with logical node representation, 16 bit BTIGAPC...
Page 860: Integer To Boolean 16 Conversion Ib16
Section 17 1MRK 504 163-UUS A Logic Name of input Type Default Description Value when Value when activated deactivated BOOLEAN Input 4 BOOLEAN Input 5 BOOLEAN Input 6 BOOLEAN Input 7 BOOLEAN Input 8 BOOLEAN Input 9 IN10 BOOLEAN Input 10 IN11 BOOLEAN Input 11...
Page 861: Integer To Boolean 16 Conversion With Logic Node Representation Itbgapc
Section 17 1MRK 504 163-UUS A Logic according to the table below from 0 to 32768. This follows the general formula: INx = where 1≤x≤16. The sum of all the values on the activated INx will be available on the output OUT as a sum of the values of all the inputs INx that are activated. OUT is an integer.
Page 862: Identification
Section 17 1MRK 504 163-UUS A Logic 17.11.1 Identification SEMOD167944-2 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Integer to boolean 16 conversion with ITBGAPC logic node representation 17.11.2 Application SEMOD158512-5 v7 Integer to boolean 16 conversion with logic node representation function (ITBGAPC) is used to transform an integer into a set of 16 boolean signals.
Page 863: Elapsed Time Integrator With Limit Transgression And Overflow Supervision Teigapc
Section 17 1MRK 504 163-UUS A Logic Name of OUTx Type Description Value when Value when activated deactivated OUT14 BOOLEAN Output 14 8192 OUT15 BOOLEAN Output 15 16384 OUT16 BOOLEAN Output 16 32768 The sum of the numbers in column “Value when activated” when all OUTx (1≤x≤16) are active equals 65535.
Page 864: Comparator For Integer Inputs - Intcomp
Section 17 1MRK 504 163-UUS A Logic If the values are above this range, the resolution becomes lower due to the 32 bit float representation 99 999.99 seconds < tAlarm ≤ 999 999.0 seconds 99 999.99 seconds < tWarning ≤ 999 999.0 seconds Note that tAlarm and tWarning are independent settings, that is, there is no check if tAlarm >...
Page 865: Setting Example
Section 17 1MRK 504 163-UUS A Logic RefSource: This setting is used to select the reference source between input and setting for comparison. • Input REF: The function will take reference value from input REF • Set Value: The function will take reference value from setting SetValue SetValue: This setting is used to set the reference value for comparison when setting RefSource is selected as SetValue.
Page 866: Comparator For Real Inputs - Realcomp
Section 17 1MRK 504 163-UUS A Logic 17.14 Comparator for real inputs - REALCOMP 17.14.1 Identification GUID-0D68E846-5A15-4C2C-91A2-F81A74034E81 v1 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Comparator for real inputs REALCOMP Real<=> 17.14.2 Application GUID-5F7B1683-9799-4D27-B333-B184F8861A5B v1 The function gives the possibility to monitor the level of real values in the system relative to each other or to a fixed value.
Page 867: Setting Example
Section 17 1MRK 504 163-UUS A Logic EqualBandLow: This setting is used to set the equal condition low band limit in % of reference value. This low band limit will act as reset limit for INLOW output when INLOW. 17.14.4 Setting example GUID-E7070CF6-B44B-4799-BE18-5C75B9FE2A87 v2 Let us consider a comparison is to be done between current magnitudes in the range of...
Page 869: Measurement
Section 18 1MRK 504 163-UUS A Monitoring Section 18 Monitoring 18.1 Measurement GUID-9D2D47A0-FE62-4FE3-82EE-034BED82682A v1 18.1.1 Identification SEMOD56123-2 v8 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-US Phase current measurement CMMXU...
Page 870: Application
Section 18 1MRK 504 163-UUS A Monitoring 18.1.2 Application SEMOD54488-4 v12 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 871: Zero Clamping
Section 18 1MRK 504 163-UUS A Monitoring • I: phase currents (magnitude and angle) (CMMXU) • V: voltages (phase-to-ground and phase-to-phase voltage, magnitude and angle) (VMMXU, VNMMXU) 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 872: Setting Guidelines
Section 18 1MRK 504 163-UUS A Monitoring System mean voltage, calculated according to selected mode System mean current, calculated according to selected mode Frequency 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 873 Section 18 1MRK 504 163-UUS A Monitoring VGenZeroDb: Minimum level of voltage in % of VBase, used as indication of zero voltage (zero point clamping). If measured value is below VGenZeroDb calculated S, P, Q and PF will be zero. IGenZeroDb: Minimum level of current in % of IBase, used as indication of zero current (zero point clamping).
Page 874 Section 18 1MRK 504 163-UUS A Monitoring Observe the related zero point clamping settings in Setting group N for CVMMXN (VGenZeroDb and IGenZeroDb). If measured value is below VGenZeroDb and/or IGenZeroDb calculated S, P, Q and PF will be zero and these settings will override XZeroDb.
Page 875: Setting Examples
Section 18 1MRK 504 163-UUS A Monitoring Magnitude % of In compensation IMagComp5 Measured current IMagComp30 IMagComp100 % of In 0-5%: Constant 5-30-100%: Linear >100%: Constant Angle Degrees compensation Measured IAngComp30 current IAngComp5 IAngComp100 % of In ANSI05000652_3_en.vsd ANSI05000652 V3 EN-US Figure 402: Calibration curves 18.1.4.1...
Page 876 Section 18 1MRK 504 163-UUS A Monitoring Measurement function application for a 380kV OHL SEMOD54481-12 v11 Single line diagram for this application is given in figure 403: 380kV Busbar 800/5 A 380kV 120V 380kV OHL ANSI09000039-1-en.vsd ANSI09000039 V1 EN-US Figure 403: Single line diagram for 380kV OHL application In order to monitor, supervise and calibrate the active and reactive power as indicated in figure...
Page 877 Section 18 1MRK 504 163-UUS A Monitoring Table 66: 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 calculations to achieve higher measurement accuracy.
Page 878 Section 18 1MRK 504 163-UUS A 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 % High warning limit that is, overload of SBase warning, hence it will be 371 MW.
Page 879 Section 18 1MRK 504 163-UUS A Monitoring 132kV Busbar 200/5 31.5 MVA 500/5 33kV 120V 33kV Busbar ANSI09000040-1-en.vsd ANSI09000040 V1 EN-US Figure 404: Single line diagram for transformer application In order to measure the active and reactive power as indicated in figure 404, it is necessary to do the following: Set correctly all CT and VT and phase angle reference channel PhaseAngleRef (see Section...
Page 880 Section 18 1MRK 504 163-UUS A Monitoring Table 69: 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 881 Section 18 1MRK 504 163-UUS A Monitoring 230kV Busbar 300/5 100 MVA 15/0.12kV AB , 100 MVA 15.65kV 4000/5 ANSI09000041-1-en.vsd ANSI09000041 V1 EN-US Figure 405: Single line diagram for generator application In order to measure the active and reactive power as indicated in figure 405, it is necessary to do the following: Set correctly all CT and VT data and phase angle reference channel PhaseAngleRef (see Section...
Page 882: Gas Medium Supervision Ssimg (63)
Section 18 1MRK 504 163-UUS A Monitoring Table 70: 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 883: Setting Guidelines
Section 18 1MRK 504 163-UUS A Monitoring 18.2.3 Setting guidelines GUID-DF6BEC98-F806-41CE-8C29-BEE9C88FC1FD v2 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 884: Liquid Medium Supervision Ssiml (71)
Section 18 1MRK 504 163-UUS A Monitoring 18.3 Liquid medium supervision SSIML (71) GUID-37669E94-4830-4C96-8A67-09600F847F23 v3 18.3.1 Identification GUID-4CE96EF6-42C6-4F2E-A190-D288ABF766F6 v3 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Insulation liquid monitoring function SSIML 18.3.2 Application GUID-140AA10C-4E93-4C23-AD57-895FADB0DB29 v6 Liquid medium supervision (SSIML ,71) is used for monitoring the transformers and tap changers.
Page 885: Breaker Monitoring Sscbr
Section 18 1MRK 504 163-UUS A Monitoring tTempAlarm: This is used to set the time delay for a temperature alarm indication, given in s. tTempLockOut: This is used to set the time delay for a temperature lockout indication, given in s. tResetLevelAlm: This is used for the level alarm indication to reset after a set time delay in s.
Page 886 Section 18 1MRK 504 163-UUS A Monitoring Circuit breaker status Monitoring the breaker status ensures proper functioning of the features within the protection relay such as breaker control, breaker failure and autoreclosing. The breaker status is monitored using breaker auxiliary contacts. The breaker status is indicated by the binary outputs.
Page 887 Section 18 1MRK 504 163-UUS A Monitoring 100000 50000 20000 10000 5000 2000 1000 Interrupted current (kA) IEC12000623_1_en.vsd IEC12000623 V1 EN-US Figure 406: An example for estimating the remaining life of a circuit breaker Calculation for estimating the remaining life The graph shows that there are 10000 possible operations at the rated operating current and 900 operations at 10 kA and 50 operations at rated fault current.
Page 888 Section 18 1MRK 504 163-UUS A Monitoring rated current. The remaining life of the CB would be (10000 – 10) = 9989 at the rated operating current after one operation at 10 kA. • Breaker interrupts at and above rated fault current, that is, 50 kA, one operation at 50 kA is equivalent to 10000/50 = 200 operations at the rated operating current.
Page 889: Setting Guidelines
Section 18 1MRK 504 163-UUS A Monitoring 18.4.3 Setting guidelines GUID-AB93AD9B-E6F8-4F1A-B353-AA1008C15679 v2 The breaker monitoring function is used to monitor different parameters of the circuit breaker. The breaker requires maintenance when the number of operations has reached a predefined value. For proper functioning of the circuit breaker, it is also essential to monitor the circuit breaker operation, spring charge indication or breaker wear, travel time, number of operation cycles and accumulated energy during arc extinction.
Page 890: Event Function Event
Section 18 1MRK 504 163-UUS A Monitoring SpChAlmTime: Time delay for spring charging time alarm. tDGasPresAlm: Time delay for gas pressure alarm. tDGasPresLO: Time delay for gas pressure lockout. DirCoef: Directional coefficient for circuit breaker life calculation. RatedOperCurr: Rated operating current of the circuit breaker. RatedFltCurr: Rated fault current of the circuit breaker.
Page 891: Setting Guidelines
Section 18 1MRK 504 163-UUS A Monitoring 18.5.3 Setting guidelines IP14841-1 v1 M12811-3 v3 The input parameters for the Event function (EVENT) can be set individually via the local HMI (Main Menu/Settings / IED Settings / Monitoring / Event Function) or via the Parameter Setting Tool (PST).
Page 892: Identification
Section 18 1MRK 504 163-UUS A Monitoring 18.6.1 Identification M16055-1 v8 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 M12152-3 v9 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 893: Setting Guidelines
Section 18 1MRK 504 163-UUS A Monitoring the PCM600 using the Disturbance handling tool, for report reading or further analysis (using WaveWin, that can be found on the PCM600 installation CD). The user can also upload disturbance report files using FTP or MMS (over 61850–8–1) clients. 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.
Page 894 Section 18 1MRK 504 163-UUS A 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-US Figure 407: Disturbance report functions and related function blocks For Disturbance report function there are a number of settings which also influences the sub-functions.
Page 895 Section 18 1MRK 504 163-UUS A 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 M12179-82 v6 The operation of Disturbance report function DRPRDRE has to be set Enabled or Disabled.
Page 896: Recording Times
Section 18 1MRK 504 163-UUS A Monitoring 18.6.3.1 Recording times M12179-88 v5 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.
Page 897: Analog Input Signals
Section 18 1MRK 504 163-UUS A 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 898: Sub-Function Parameters
Section 18 1MRK 504 163-UUS A Monitoring 18.6.3.4 Sub-function parameters M12179-389 v3 All functions are in operation as long as Disturbance report is in operation. Indications M12179-448 v4 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.
Page 899: Logical Signal Status Report Binstatrep
Section 18 1MRK 504 163-UUS A Monitoring handled if the recording functions do not have proper settings. The goal is to optimize the settings in each IED to be able to capture just valuable disturbances and to maximize the number that is possible to save in the IED. The recording time should not be longer than necessary (PostFaultrecT and TimeLimit).
Page 900: Application
Section 18 1MRK 504 163-UUS A Monitoring 18.7.2 Application GUID-F9D225B1-68F7-4D15-AA89-C9211B450D19 v3 The Logical signal status report (BINSTATREP) function makes it possible to poll signals from various other function blocks. BINSTATREP has 16 inputs and 16 outputs. The output status follows the inputs and can be read from the local HMI or via SPA communication.
Page 901: Setting Guidelines
Section 18 1MRK 504 163-UUS A Monitoring distance to fault is very important for those involved in operation and maintenance. Reliable information on the fault location greatly decreases the downtime of the protected lines and increases the total availability of a power system. The fault locator is started with the input CALCDIST to which trip signals indicating in-line faults are connected, typically distance protection zone 1 and accelerating zone or the line differential protection.
Page 902: Connection Of Analog Currents
Section 18 1MRK 504 163-UUS A Monitoring in the observed bay (no parallel line expected since chosen input is set to zero). Use the Parameter Setting tool within PCM600 for changing analog configuration. The measured phase voltages can be fine tuned with the parameters VAGain, VBGain and VCGain to further increase the accuracy of the fault locator.
Page 903: Limit Counter L4Ufcnt
Section 18 1MRK 504 163-UUS A Monitoring en07000113_1_ansi.v ANSI07000113 V2 EN-US Figure 410: Example of connection of parallel line IN for Fault locator LMBRFLO 18.9 Limit counter L4UFCNT GUID-22E141DB-38B3-462C-B031-73F7466DD135 v1 18.9.1 Identification GUID-F3FB7B33-B189-4819-A1F0-8AC7762E9B7E v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification...
Page 904: Application
Section 18 1MRK 504 163-UUS A Monitoring 18.9.2 Application GUID-41B13135-5069-4A5A-86CE-B7DBE9CFEF38 v2 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 905: Setting Guidelines
Section 18 1MRK 504 163-UUS A Monitoring 18.10.3 Setting guidelines GUID-D3BED56A-BA80-486F-B2A8-E47F7AC63468 v1 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 906 Section 18 1MRK 504 163-UUS A Monitoring transformer MVA rating is based on maximum allowable temperature of the insulation. Design standards express temperature limits for transformers exceeds ambient temperature. Use of ambient temperature as a base ensures that a transformer has adequate thermal capacity and independent of daily environmental conditions.
Page 907 Section 18 1MRK 504 163-UUS A Monitoring empirical formulae given by relevant standards. The hot spot temperature shall be monitored continuously so that it will not exceed the transformer oil flashover value. Figure shows the complex transformer temperature distribution. The assumptions made are: •...
Page 908 Section 18 1MRK 504 163-UUS A Monitoring temperature without separately considering the effects of oil flow blockage and malfunction of cooler groups. Normal life expected of the transformer is a conventional reference based on the designed operating condition and ambient temperature. If the transformer load exceeds its rated condition, ageing will accelerate.
Page 909 Section 18 1MRK 504 163-UUS A Monitoring 140°C 140°C 130°C 130°C 120°C 120°C 110°C 110°C 100°C 100°C 90°C 90°C 80°C 80°C Hours of the day Hours of the day Planned loading beyond nameplate rating Normal life expectancy loading 170°C 160°C 140°C 150°C 130°C...
Page 910: Setting Guidelines
Section 18 1MRK 504 163-UUS A Monitoring Insulation aging or deterioration is a time function of temperature, moisture content, and oxygen content. With modern oil preservation systems, the moisture and oxygen contributions to insulation deterioration can be minimized, leaving insulation temperature as the controlling parameter.
Page 911 Section 18 1MRK 504 163-UUS A Monitoring • Three Phase Trafo: The function considers the given transformer as three phase transformer. • Single Phase Trafo: The function considers the given transformer as single phase transformer. Based on the settings TrafoRating and TrafoType, transformer parameters are selected for temperature calculations.
Page 912 Section 18 1MRK 504 163-UUS A Monitoring • IEC: Transformer parameters like constants, winding and oil exponents will be taken from IEC 60076-7 standard for temperature calculations. • IEEE: Transformer parameters like constants, winding and oil exponents will be taken from IEEE C57.96-1995 standard for temperature calculations. CurrSelectMode: This setting is used to select the current determining method which is used for the load factor calculation.
Page 913 Section 18 1MRK 504 163-UUS A Monitoring • Winding 1&3: Only winding 1 and winding 3 CTs are available. This option can be selected when three winding transformer is considered. • Winding 2&3: Only winding 2 and winding 3 CTs are available. This option can be selected when three winding transformer is considered.
Page 914 Section 18 1MRK 504 163-UUS A Monitoring TankMass: This setting is used to set the transformer tank mass. This mass is only the tank and fittings that are in contact with heated oil. LoadLoss: This setting is used to set the transformer load loss at rated condition. TTLoadLoss: This setting is used to set the transformer load loss arrived from type test.
Page 915 Section 18 1MRK 504 163-UUS A Monitoring GUID-5832E7AF-0A4F-4B50-8045-94BF9433A1BF v1 Winding to oil temperature gradient differs from winding to winding depending on current density in the winding, physical dimensions, cooling system etc., This value can be between 10 to 20 ̊ C for both distribution and power transformers. For low current density winding it can be 10 ̊...
Page 916 Section 18 1MRK 504 163-UUS A Monitoring LowVoltTap: This setting is used to set the position number of tap changer at possible minimum voltage. GUID-E9EC48CC-08D6-498E-BFB7-6F40AD9436A7 v1 The following settings are required to perform the calculation of top oil temperature using monthly model of ambient temperature when AMBVALID is low: JanAmbTmp: This setting is used to set the January month average ambient temperature.
Page 917 Section 18 1MRK 504 163-UUS A Monitoring HPTmpRiseW3: This setting is used to set the hot spot temperature rise of winding 3 above ambient temperature in K (Kelvin). TopOilTmpRise: This setting is used to set the top oil temperature rise above ambient temperature in K (Kelvin).
Page 918 Section 18 1MRK 504 163-UUS A Monitoring ExpectedLife: The transformer expected insulation life in hours can be set by this setting. As per IEEE C57.91-1995 the normal life expectancy at a continuous hot spot temperature of 110 ̊ C is 180,000 Hours. AgeingRateMeth: This setting is used to select the method to be used for transformer insulation relative ageing rate calculation between IEC standard method and IEEE standard method.
Page 919: Setting Example
Section 18 1MRK 504 163-UUS A Monitoring • Top oil temperature = 120°C • Hot spot winding temperature = 200°C • Short-time loading (1/2 h or less) = 300% • For power transformer with 65°C hot spot temperature rise: • Top oil temperature = 110°C •...
Page 920: Setting Parameters For Insulation Loss Of Life Calculation Function (Lol1)
Section 18 1MRK 504 163-UUS A Monitoring Parameter Value Note CT ratio Winding 1 1000/1 A CT ratio Winding 2 2000/1 A CT ratio Winding 3 1000/1 A 18.11.3.2 Setting parameters for insulation loss of life calculation function (LOL1) GUID-6869A06A-4DDC-4FB5-AC56-5463F3709862 v1 Table 74: Setting parameters for insulation loss of life calculation function (LOL1) Setting...
Page 921 Section 18 1MRK 504 163-UUS A Monitoring Setting Short Description Selected value AvgOilTmpRise 45° C Set the transformer average oil temperature rise for the calculation of oil time constant CoilCoreMass 65.0 t Set the transformer coil and core assembly mass for the calculation of oil time constant OilMass 35.0 t...
Page 922 Section 18 1MRK 504 163-UUS A Monitoring Setting Short Description Selected value WdgToOilGrad3 20° C Set the transformer winding to oil temperature gradient for the winding 3 when the winding time constant mode is selected as Calculated CuLossW1 2.0 MW Set the transformer winding loss for the winding 1 when the winding time constant Calculated...
Page 923 Section 18 1MRK 504 163-UUS A Monitoring Setting Short Description Selected value MarchAmbTmp 30° C Set the March month average ambient temperature for the calculation of top oil temperature when ambient temperature sensor failure/absence AprilAmbTmp 30° C Set the April month average ambient temperature for the calculation of top oil temperature when ambient temperature sensor failure/absence...
Page 924 Section 18 1MRK 504 163-UUS A Monitoring Setting Short Description Selected value TopOilTmpRise 55° C Set the top oil temperature rise for the calculation of hot spot to top oil temperature gradient RatedCurrW1 696.0 A Set the rated current of the winding 1 RatedCurrW2 Set the rated current of the winding 2 1255.0 A...
Page 925: Pulse-Counter Logic Pcfcnt
Section 19 1MRK 504 163-UUS A Metering Section 19 Metering 19.1 Pulse-counter logic PCFCNT IP14600-1 v3 19.1.1 Identification M14879-1 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Pulse-counter logic PCFCNT S00947 V1 EN-US 19.1.2 Application M13395-3 v6 Pulse-counter logic (PCFCNT) function counts externally generated binary pulses, for instance pulses coming from an external energy meter, for calculation of energy...
Page 926: Function For Energy Calculation And Demand Handling Etpmmtr
Section 19 1MRK 504 163-UUS A 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 927: Setting Guidelines
Section 19 1MRK 504 163-UUS A Metering ETPMMTR CVMMXN P_ INST Q_ INST STARTACC STOPACC RSTACC RSTDMD IEC130 00190-2-en.vsdx IEC13000190 V2 EN-US Figure 413: 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 928 Section 19 1MRK 504 163-UUS A 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 929: Access Point
Section 20 1MRK 504 163-UUS A Ethernet-based communication Section 20 Ethernet-based communication 20.1 Access point 20.1.1 Application GUID-2942DF07-9BC1-4F49-9611-A5691D2C925C v1 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 930 Section 20 1MRK 504 163-UUS A Ethernet-based communication When saving the ECT configuration after selecting a subnetwork, ECT creates the access point in the SCL model. Unselecting the subnetwork removes the access point from the SCL model. This column is editable for IEC61850 Ed2 IEDs and not editable for IEC61850 Ed1 IEDs because in IEC61850 Ed1 only one access point can be modelled in SCL.
Page 931: Redundant Communication
Section 20 1MRK 504 163-UUS A Ethernet-based communication 20.2 Redundant communication 20.2.1 Identification GUID-B7AE0374-0336-42B8-90AF-3AE1C79A4116 v1 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number IEC 62439-3 Parallel redundancy protocol IEC 62439-3 High-availability seamless redundancy Access point diagnostic for redundant RCHLCCH Ethernet ports 20.2.2...
Page 932 Section 20 1MRK 504 163-UUS A Ethernet-based communication Device 2 Device 1 PhyPortA PhyPortB PhyPortA PhyPortB Switch A Switch B PhyPortA PhyPortB PhyPortA PhyPortB Device 4 Device 3 IEC09000758-4-en.vsd IEC09000758 V4 EN-US Figure 414: Parallel Redundancy Protocol (PRP) Transformer protection RET670 2.2 ANSI Application manual...
Page 933: Setting Guidelines
Section 20 1MRK 504 163-UUS A 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-US Figure 415: High-availability Seamless Redundancy (HSR) 20.2.3 Setting guidelines GUID-887B0AE2-0F2E-414D-96FD-7EC935C5D2D8 v1 Redundant communication is configured with the Ethernet configuration tool in PCM600.
Page 934: Merging Unit
Section 20 1MRK 504 163-UUS A Ethernet-based communication IEC16000039-1-en.vsdx IEC16000039 V1 EN-US Figure 416: 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 GUID-E630C16F-EDB8-40AE-A8A2-94189982D15F v1 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 935: Setting Guidelines
Section 20 1MRK 504 163-UUS A Ethernet-based communication IEC17000044-1-en.vsdx IEC17000044 V1 EN-US Figure 417: Merging unit 20.3.2 Setting guidelines GUID-3449AB24-8C9D-4D9A-BD46-5DDF59A0F8E3 v1 For information on the merging unit setting guidelines, see section IEC/UCA 61850-9-2LE communication protocol. 20.4 Routes 20.4.1 Application GUID-19616AC4-0FFD-4FF4-9198-5E33938E5ABD v1 Setting up a route enables communication to a device that is located in another subnetwork.
Page 936 Section 20 1MRK 504 163-UUS A Ethernet-based communication Destination specifies the destination. Destination subnet mask specifies the subnetwork mask of the destination. Transformer protection RET670 2.2 ANSI Application manual...
Page 937: Communication Protocols
Section 21 1MRK 504 163-UUS A Station communication Section 21 Station communication 21.1 Communication protocols M14815-3 v13 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 938 Section 21 1MRK 504 163-UUS A Station communication Engineering Station HSI Workstation Gateway Base System Printer KIOSK 3 KIOSK 1 KIOSK 2 IEC09000135_en.v IEC09000135 V1 EN-US Figure 418: SA system with IEC 61850–8–1 M16925-3 v4 Figure419 shows the GOOSE peer-to-peer communication. Transformer protection RET670 2.2 ANSI Application manual...
Page 939: Setting Guidelines
Section 21 1MRK 504 163-UUS A Station communication Station HSI MicroSCADA Gateway GOOSE Control Protection Control and protection Control Protection en05000734.vsd IEC05000734 V1 EN-US Figure 419: Example of a broadcasted GOOSE message 21.2.2 Setting guidelines SEMOD55317-5 v7 There are two settings related to the IEC 61850–8–1 protocol: Operation: User can set IEC 61850 communication to Enabled or Disabled.
Page 940: Receiving Data
Section 21 1MRK 504 163-UUS A Station communication Application SEMOD55350-5 v8 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 941 Section 21 1MRK 504 163-UUS A Station communication Function block type Data Type GOOSESPRCV Single point GOOSEVCTRRCV VCTR signals parallel mode GOOSEXLNRCV Switch status Application GUID-808177B7-02CA-40DF-B41B-8B580E38478B v1 The GOOSE receive function blocks are used to receive subscribed data from the GOOSE protocol.
Page 942: Lon Communication Protocol
Section 21 1MRK 504 163-UUS A Station communication 21.3 LON communication protocol IP14420-1 v1 21.3.1 Application IP14863-1 v1 M14804-3 v5 Control Center Station HSI MicroSCADA Gateway Star coupler RER 111 IEC05000663-1-en.vsd IEC05000663 V2 EN-US Figure 421: Example of LON communication structure for a substation automation system An optical network can be used within the substation automation system.
Page 943 Section 21 1MRK 504 163-UUS A Station communication Glass fibre Plastic fibre Wavelength 820-900 nm 660 nm Transmitted power -13 dBm (HFBR-1414) -13 dBm (HFBR-1521) Receiver sensitivity -24 dBm (HFBR-2412) -20 dBm (HFBR-2521) The LON Protocol M14804-32 v2 The LON protocol is specified in the LonTalkProtocol Specification Version 3 from Echelon Corporation.
Page 944: Multicmdrcv And Multicmdsnd
Section 21 1MRK 504 163-UUS A Station communication The node address is transferred to LNT via the local HMI by setting the parameter ServicePinMsg = Yes. The node address is sent to LNT via the LON bus, or LNT can scan the network for new nodes.
Page 945 Section 21 1MRK 504 163-UUS A Station communication When communicating with a PC connected to the utility substation LAN via WAN and the utility office LAN (see Figure 422), and when using the rear optical Ethernet port, the only hardware required for a station monitoring system is: •...
Page 946: Setting Guidelines
Section 21 1MRK 504 163-UUS A Station communication 21.4.2 Setting guidelines M11876-3 v6 SPA, IEC 60870-5-103 and DNP3 use the same rear communication port. This port can be set for SPA use on the local HMI under Main menu /Configuration / Communication /Station communication/Port configuration/SLM optical serial port/PROTOCOL:1.
Page 947: Iec 60870-5-103 Communication Protocol
Section 21 1MRK 504 163-UUS A Station communication 21.5 IEC 60870-5-103 communication protocol IP14615-1 v2 21.5.1 Application IP14864-1 v1 M17109-3 v6 TCP/IP Control Station Center Gateway Star coupler ANSI05000660-4-en.vsd ANSI05000660 V4 EN-US Figure 423: 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 948: Design
Section 21 1MRK 504 163-UUS A Station communication the IEC 60870-5-103 communication messages. For detailed information about IEC 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 M17109-41 v1...
Page 949 Section 21 1MRK 504 163-UUS A Station communication Function block with pre-defined functions in control direction, I103CMD. This block includes the FUNCTION TYPE parameter, and the INFORMATION NUMBER parameter is defined for each output signal. • Function commands in control direction Function block with user defined functions in control direction, I103UserCMD.
Page 950 Section 21 1MRK 504 163-UUS A Station communication Function block with defined functions for fault indications in monitor direction, I103FLTPROT. This block includes the FUNCTION TYPE parameter, and the INFORMATION NUMBER parameter is defined for each input signal. This block is suitable for distance protection, line differential, transformer differential, over-current and ground-fault protection functions.
Page 951: Settings
Section 21 1MRK 504 163-UUS A Station communication connected to the disturbance function blocks A1RADR to A4RADR. The eight first ones belong to the public range and the remaining ones to the private range. 21.5.2 Settings M17109-116 v1 21.5.2.1 Settings for RS485 and optical serial communication M17109-118 v12 General settings SPA, DNP and IEC 60870-5-103 can be configured to operate on the SLM optical...
Page 952: Settings From Pcm600
Section 21 1MRK 504 163-UUS A Station communication GUID-CD4EB23C-65E7-4ED5-AFB1-A9D5E9EE7CA8 V3 EN GUID-CD4EB23C-65E7-4ED5-AFB1-A9D5E9EE7CA8 V3 EN-US Figure 424: 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 953 Section 21 1MRK 504 163-UUS A 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 M17109-138 v2 As for the commands defined in the protocol there is a dedicated function block with eight output signals.
Page 954: Function And Information Types
Section 21 1MRK 504 163-UUS A 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 955: Dnp3 Communication Protocol
Section 21 1MRK 504 163-UUS A Station communication REB 207 Private range 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.
Page 957: Binary Signal Transfer
Section 22 1MRK 504 163-UUS A Remote communication Section 22 Remote communication 22.1 Binary signal transfer IP12423-1 v2 22.1.1 Identification M14849-1 v3 Function description IEC 61850 identification IEC 60617 ANSI/IEEE C37.2 identification device number BinSignRec1_1 Binary signal transfer, BinSignRec1_2 receive BinSignReceive2 Binary signal transfer, 2Mbit BinSigRec1_12M...
Page 958: Communication Hardware Solutions
Section 22 1MRK 504 163-UUS A 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 959: Setting Guidelines
Section 22 1MRK 504 163-UUS A Remote communication en06000519-2.vsd IEC06000519 V2 EN-US Figure 426: 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 427. These solutions are aimed for connections to a multiplexer, which in turn is connected to a telecommunications transmission network (for example PDH).
Page 960 Section 22 1MRK 504 163-UUS A 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 961 Section 22 1MRK 504 163-UUS A 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 962 Section 22 1MRK 504 163-UUS A 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 963 Section 22 1MRK 504 163-UUS A 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. Transformer protection RET670 2.2 ANSI Application manual...
Page 965: Authority Status Athstat
Section 23 1MRK 504 163-UUS A Security Section 23 Security 23.1 Authority status ATHSTAT SEMOD158575-1 v2 23.1.1 Application SEMOD158527-5 v3 Authority status (ATHSTAT) function is an indication function block, which informs about two events related to the IED and the user authorization: •...
Page 966: Change Lock Chnglck
Section 23 1MRK 504 163-UUS A 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 967: 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 968: Setting Guidelines
Section 23 1MRK 504 163-UUS A Security • LINKSTS indicates the Ethernet link status for the rear ports (single communication) • CHALISTS and CHBLISTS indicates the Ethernet link status for the rear ports channel A and B (redundant communication) • LinkStatus indicates the Ethernet link status for the front port 23.4.2 Setting guidelines...
Page 969: Ied Identifiers Terminalid
Diagnostics/IED status/Product identifiers and under 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). Transformer protection RET670 2.2 ANSI Application manual...
Page 970: Factory Defined Settings
Section 24 1MRK 504 163-UUS A Basic IED functions 24.2.2 Factory defined settings M11789-39 v10 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.
Page 971: Identification
Section 24 1MRK 504 163-UUS A Basic IED functions 24.3.1 Identification SEMOD113212-2 v3 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Measured value expander block RANGE_XP 24.3.2 Application SEMOD52434-4 v5 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 972: Setting Guidelines
Section 24 1MRK 504 163-UUS A 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 973: Summation Block 3 Phase 3Phsum
Section 24 1MRK 504 163-UUS A Basic IED functions 24.6 Summation block 3 phase 3PHSUM SEMOD55968-1 v2 24.6.1 Application SEMOD56004-4 v3 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 974: Application
Section 24 1MRK 504 163-UUS A Basic IED functions 24.7.2 Application GUID-D58ECA9A-9771-443D-BF84-8EF582A346BF v4 Global base values function (GBASVAL) is used to provide global values, common for all applicable functions within the IED. One set of global values consists of values for current, voltage and apparent power and it is possible to have twelve different sets.
Page 975: Signal Matrix For Binary Outputs Smbo
Section 24 1MRK 504 163-UUS A Basic IED functions 24.9 Signal matrix for binary outputs SMBO SEMOD55215-1 v2 24.9.1 Application SEMOD55213-5 v4 The Signal matrix for binary outputs function SMBO is used within the Application Configuration tool in direct relation with the Signal Matrix tool. SMBO represents the way binary outputs are sent from one IED configuration.
Page 976: Application
Section 24 1MRK 504 163-UUS A Basic IED functions 24.11.1 Application SEMOD55744-4 v10 Signal matrix for analog inputs (SMAI), also known as the preprocessor function block, analyses the connected four analog signals (three phases and neutral) and calculates all relevant information from them like the phasor magnitude, phase angle, frequency, true RMS value, harmonics, sequence components and so on.
Page 977: Setting Guidelines
Section 24 1MRK 504 163-UUS A Basic IED functions The above described scenario does not work if SMAI setting ConnectionType is Ph-N. If only one phase-ground voltage is available, the same type of connection can be used but the SMAI ConnectionType setting must still be Ph-Ph and this has to be accounted for when setting MinValFreqMeas.
Page 978 Section 24 1MRK 504 163-UUS A Basic IED functions The setting ConnectionType: Connection type for that specific instance (n) of the SMAI (if it is Ph-N or Ph-Ph). Depending on connection type setting the not connected Ph-N or Ph-Ph outputs will be calculated as long as they are possible to calculate. E.g. at Ph-Ph connection A, B and C will be calculated for use in symmetrical situations.
Page 979 Section 24 1MRK 504 163-UUS A Basic IED functions Task time group 1 SMAI instance 3 phase group SMAI1:1 SMAI2:2 SMAI3:3 AdDFTRefCh7 SMAI4:4 SMAI5:5 SMAI6:6 SMAI7:7 SMAI8:8 SMAI9:9 SMAI10:10 SMAI11:11 SMAI12:12 Task time group 2 SMAI instance 3 phase group SMAI1:13 AdDFTRefCh4 SMAI2:14...
Page 980 Section 24 1MRK 504 163-UUS A Basic IED functions shout-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 981 Section 24 1MRK 504 163-UUS A 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-US...
Page 982: Test Mode Functionality Testmode
Section 24 1MRK 504 163-UUS A Basic IED functions 24.12 Test mode functionality TESTMODE IP1647-1 v3 24.12.1 Application M11407-3 v8 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 983: Setting Guidelines
Section 24 1MRK 504 163-UUS A Basic IED functions or LHMI. If a function of an IED is set to Off, the related Beh is set to Off as well. The related mod keeps its current state. When the setting Operation is set to Off, the behavior is set to Off and it is not possible to override it.
Page 984: Time Synchronization Timesynchgen
Section 24 1MRK 504 163-UUS A Basic IED functions 24.13 Time synchronization TIMESYNCHGEN IP1750-1 v2 24.13.1 Application M11345-3 v10 Use time synchronization to achieve a common time base for the IEDs in a protection and control system. This makes it possible to compare events and disturbance data between all IEDs in the system.
Page 985: Setting Guidelines
Section 24 1MRK 504 163-UUS A Basic IED functions • Coarse time messages are sent every minute and contain complete date and time, that is year, month, day, hour, minute, second and millisecond. • Fine time messages are sent every second and comprise only seconds and milliseconds.
Page 986 Section 24 1MRK 504 163-UUS A Basic IED functions HMI is Main menu/Configuration/Time/Synchronization. The parameters are categorized as Time Synchronization (TIMESYNCHGEN) and IRIG-B settings (IRIG- B:1) in case that IRIG-B is used as the external time synchronization source. TimeSynch M11348-167 v15 When the source of the time synchronization is selected on the local HMI, the parameter is called TimeSynch.
Page 987 Section 24 1MRK 504 163-UUS A Basic IED functions • Disabled • SNTP -Server Set the course time synchronizing source (CoarseSyncSrc) to Disabled when GPS time synchronization of line differential function is used. Set the fine time synchronization source (FineSyncSource) to GPS. The GPS will thus provide the complete time synchronization.
Page 988 Section 24 1MRK 504 163-UUS A Basic IED functions Setting example Station bus Process bus SAM600-TS SAM600-CT SAM600-VT IEC16000167-1-en.vsdx IEC16000167 V1 EN-US Figure 433: 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 989: Current Transformer Requirements
Section 25 1MRK 504 163-UUS A Requirements Section 25 Requirements 25.1 Current transformer requirements IP15171-1 v2 M11609-3 v2 The performance of a protection function will depend on the quality of the measured current signal. Saturation of the current transformers (CTs) will cause distortion of the current signals and can result in a failure to operate or cause unwanted operations of some functions.
Page 990 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.
Page 991: 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 992: Fault Current
Section 25 1MRK 504 163-UUS A Requirements acceptable at all maximum remanence has been considered for fault cases critical for the 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.
Page 993: 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. The CT requirements for the different functions below are specified as a rated equivalent limiting secondary e.m.f.
Page 994: Transformer Differential Protection
Section 25 1MRK 504 163-UUS A Requirements 25.1.6.1 Transformer differential protection SEMOD54689-4 v4 The current transformers must have a rated equivalent limiting secondary e.m.f. E that is larger than the maximum of the required rated equivalent limiting secondary e.m.f. E below: alreq æ...
Page 995: Distance Protection
Section 25 1MRK 504 163-UUS A Requirements æ ö × ³ × ç ÷ a lre q è ø (Equation 518) EQUATION1674 V1 EN-US where: Maximum primary fundamental frequency current that passes two main CTs without passing the power transformer (A) 25.1.6.2 Distance protection M11619-3 v5...
Page 996: Breaker Failure Protection
Section 25 1MRK 504 163-UUS A 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 997: Restricted Ground Fault Protection (Low Impedance Differential)
Section 25 1MRK 504 163-UUS A Requirements 25.1.6.4 Restricted ground fault protection (low impedance differential) GUID-AFAFC587-6986-4FF4-A5E1-6F5DC0A72A6B v1 The requirements are specified separately for solidly grounded and impedance grounded transformers. For impedance grounded transformers the requirements for the phase CTs are depending whether it is three individual CTs connected in parallel or it is a cable CT enclosing all three phases.
Page 998 Section 25 1MRK 504 163-UUS A Requirements æ ö ³ × × ç ÷ alreq è ø (Equation 524) EQUATION2239 V2 EN-US Where: Maximum primary fundamental frequency phase-to-ground fault current that passes two main CTs without passing the power transformer neutral (A) Neutral CTs and phase CTs for impedance grounded transformers GUID-FA79C943-A19B-47E2-BFC5-C9D01347302A v3 The neutral CT and phase CTs must have a rated equivalent limiting secondary e.m.f.
Page 999: Current Transformer Requirements For Cts According To Other Standards
Section 25 1MRK 504 163-UUS A Requirements æ ö ³ = × × × ç ÷ alreq è ø (Equation 526) EQUATION2241 V2 EN-US Where: Maximum primary fundamental frequency three-phase fault current that passes the CTs and the power transformer (A). The resistance of the single secondary wire and additional load (Ω).
Page 1000: Current Transformers According To Iec 61869-2, Class P, Pr
Section 25 1MRK 504 163-UUS A Requirements approximately calculate a secondary e.m.f. of the CT comparable with E . By comparing this with the required rated equivalent limiting secondary e.m.f. E it is alreq possible to judge if the CT fulfills the requirements. The requirements according to some other standards are specified below.
Page 1001: Voltage Transformer Requirements
Section 25 1MRK 504 163-UUS A Requirements × × × × × × 20 I 20 I 20 I ANS I bANS I a lANS I (Equation 530) EQUATION1682 V1 EN-US where: The impedance (that is, with a complex quantity) of the standard ANSI burden for the specific C bANSI class (W) The secondary terminal voltage for the specific C class (V)
Page 1002: Sntp Server Requirements
Section 25 1MRK 504 163-UUS A Requirements The transient responses for three different standard transient response classes, T1, T2 and T3 are specified in chapter 6.503 of the standard. CCVTs according to all classes can be used. The protection IED has effective filters for these transients, which gives secure and correct operation with CCVTs.
Page 1003 Section 25 1MRK 504 163-UUS A Requirements During disturbed conditions, the trip security function can cope with high bit error rates up to 10 or even up to 10 . The trip security can be configured to be independent of COMFAIL from the differential protection communication supervision, or blocked when COMFAIL is issued after receive error >100ms.
Page 1005: Section 26 Glossary
Section 26 1MRK 504 163-UUS A Glossary Section 26 Glossary M14893-1 v16 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 1006 Section 26 1MRK 504 163-UUS A 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 1007 Section 26 1MRK 504 163-UUS A 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 1008 Section 26 1MRK 504 163-UUS A 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 1009 Section 26 1MRK 504 163-UUS A 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 1010 Section 26 1MRK 504 163-UUS A Glossary LIB 520 High-voltage software module Liquid crystal display LDCM Line data communication module Local detection device Light-emitting diode LON network tool Local operating network Miniature circuit breaker Mezzanine carrier module Milli-ampere module Main processing module MVAL Value of measurement Multifunction vehicle bus.
Page 1011 Section 26 1MRK 504 163-UUS A Glossary PCI Mezzanine card 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...
Page 1012 Section 26 1MRK 504 163-UUS A Glossary SMA connector Subminiature version A, A threaded connector with constant impedance. 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 1013 Section 26 1MRK 504 163-UUS A Glossary Transformer Module. This module transforms currents and voltages taken from the process into levels suitable for further signal processing. Type identification User management tool Underreach A term used to describe how the relay behaves during a fault condition.
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Page 1016 — 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 RET670 Applications Manual

Table of Contents

Table of Contents

Section 1 Introduction

Section 2 Application

Section 3 Configuration

Section 4 Analog Inputs

Section 5 Local HMI

Section 26 Glossary

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