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ABB REC670 Applications Manual
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ABB REC670 Applications Manual

Relion 670 series, bay control
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Table of Contents

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See also: Operator's Manual , Commissioning Manual
—
R E L I O N ® 670 SERIES
Bay control REC670
Version 2.2 ANSI
Application manual

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Summary of Contents for ABB REC670

  • Page 1 — R E L I O N ® 670 SERIES Bay control REC670 Version 2.2 ANSI Application manual...
  • Page 3 Document ID: 1MRK 511 401-UUS Issued: October 2017 Revision: A Product version: 2.2.1 © Copyright 2017 ABB. All rights reserved...
  • Page 4 Copyright This document and parts thereof must not be reproduced or copied without written permission from ABB, and the contents thereof must not be imparted to a third party, nor used for any unauthorized purpose. The software and hardware described in this document is furnished under a license and may be used or disclosed only in accordance with the terms of such license.
  • Page 5 In case any errors are detected, the reader is kindly requested to notify the manufacturer. Other than under explicit contractual commitments, in no event shall ABB be responsible or liable for any loss or damage resulting from the use of this manual or the application of the equipment.
  • Page 6 (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

    Description of configuration C30..........57 Description of configuration D30..........59 Section 4 Analog inputs...............61 Introduction..................... 61 Setting guidelines................... 61 Setting of the phase reference channel..........61 Example..................62 Setting of current channels..............62 Example 1..................63 Example 2..................63 Example 3..................64 Bay control REC670 2.2 ANSI Application manual...
  • Page 8 Identification..................101 Application..................101 Operation principle................101 Short guidance for use of TCP........... 102 Short guidance for use of UDP...........103 Protocol reporting via IEEE 1344 and C37.118 PMUREPORT.... 105 Identification..................105 Application..................106 Bay control REC670 2.2 ANSI Application manual...
  • Page 9 Meshed network with parallel line..........151 Directional phase overcurrent protection, four steps OC4PTOC(51_67)................153 Identification..................153 Application..................153 Setting guidelines................154 Settings for each step..............156 Setting example................160 Instantaneous residual overcurrent protection EFPIOC (50N)..... 165 Identification..................165 Bay control REC670 2.2 ANSI Application manual...
  • Page 10 Thermal overload protection, two time constants TRPTTR (49)...202 Identification..................202 Application..................202 Setting guideline................203 Breaker failure protection CCRBRF(50BF)...........206 Identification..................206 Application..................206 Setting guidelines................207 Stub protection STBPTOC (50STB)............. 210 Identification..................210 Application..................210 Setting guidelines................211 Bay control REC670 2.2 ANSI Application manual...
  • Page 11 239 Overcurrent protection with undervoltage seal-in....... 239 Section 9 Voltage protection............. 241 Two step undervoltage protection UV2PTUV (27)........241 Identification..................241 Application..................241 Setting guidelines................242 Equipment protection, such as for motors and generators..242 Bay control REC670 2.2 ANSI Application manual...
  • Page 12 Application..................254 Setting guidelines................256 Loss of voltage check LOVPTUV (27)..........258 Identification..................258 Application..................258 Setting guidelines................258 Advanced users settings............258 Section 10 Frequency protection............259 Underfrequency protection SAPTUF (81)..........259 Identification..................259 Bay control REC670 2.2 ANSI Application manual...
  • Page 13 Voltage restrained overcurrent protection for generator and step-up transformer..............283 Loss of excitation protection for a generator......283 Section 12 System protection and control...........287 Multipurpose filter SMAIHPAC..............287 Identification..................287 Application..................287 Setting guidelines................289 Setting example................289 Bay control REC670 2.2 ANSI Application manual...
  • Page 14 Single circuit breaker with single busbar........311 Single circuit breaker with double busbar, external voltage selection..................312 Single circuit breaker with double busbar, internal voltage selection..................313 Double circuit breaker..............314 Breaker-and-a-half..............315 Setting guidelines................318 Bay control REC670 2.2 ANSI Application manual...
  • Page 15 Configuration................336 Auto recloser settings..............345 Apparatus control APC................. 350 Application..................350 Bay control QCBAY..............356 Switch controller SCSWI............357 Switches SXCBR/SXSWI............357 Proxy for signals from switching device via GOOSE XLNPROXY................358 Bay control REC670 2.2 ANSI Application manual...
  • Page 16 Signals in double-breaker arrangement........393 Signals in breaker and a half arrangement.........396 Interlocking for busbar grounding switch BB_ES (3)....... 397 Application.................. 397 Signals in single breaker arrangement........398 Signals in double-breaker arrangement........402 Bay control REC670 2.2 ANSI Application manual...
  • Page 17 Identification..................459 Application..................459 Setting guidelines................459 AutomationBits, command function for DNP3.0 AUTOBITS....459 Identification..................460 Application..................460 Setting guidelines................460 Single command, 16 signals SINGLECMD.......... 460 Identification..................460 Application..................461 Setting guidelines................462 Bay control REC670 2.2 ANSI Application manual...
  • Page 18 Identification..................479 Application..................479 Setting guidelines................480 Current reversal and weak-end infeed logic for residual overcurrent protection ECRWPSCH (85)..........481 Identification..................481 Application..................481 Fault current reversal logic............481 Weak-end infeed logic..............482 Bay control REC670 2.2 ANSI Application manual...
  • Page 19 Identification..................493 Application.................. 494 Setting guidelines............... 494 Configurable logic blocks..............494 Application..................494 Setting guidelines................494 Configuration................495 Fixed signal function block FXDSIGN...........496 Identification..................496 Application..................496 Boolean 16 to Integer conversion B16I..........497 Identification..................497 Bay control REC670 2.2 ANSI Application manual...
  • Page 20 Identification..................509 Application..................510 Zero clamping..................511 Setting guidelines................512 Setting examples................ 515 Gas medium supervision SSIMG (63)..........522 Identification..................522 Application..................522 Setting guidelines................523 Liquid medium supervision SSIML (71)..........524 Identification..................524 Bay control REC670 2.2 ANSI Application manual...
  • Page 21 Limit counter L4UFCNT................ 543 Identification..................543 Application..................544 Setting guidelines................544 Running hour-meter TEILGAPC............544 Identification..................544 Application..................544 Setting guidelines................545 Estimation of transformer insulation life LOLSPTR (26/49HS)..... 545 Application..................545 Setting guidelines................550 Bay control REC670 2.2 ANSI Application manual...
  • Page 22 Communication protocols..............577 IEC 61850-8-1 communication protocol..........577 Application IEC 61850-8-1...............577 Setting guidelines................579 Horizontal communication via GOOSE........... 579 Sending data................579 Receiving data................580 LON communication protocol............... 582 Application..................582 MULTICMDRCV and MULTICMDSND..........584 Bay control REC670 2.2 ANSI Application manual...
  • Page 23 Application..................604 Denial of service SCHLCCH/RCHLCCH ..........605 Application..................605 Setting guidelines................606 Section 23 Basic IED functions............607 IED identifiers TERMINALID..............607 Application..................607 Product information PRODINF............. 607 Application..................607 Factory defined settings..............608 Bay control REC670 2.2 ANSI Application manual...
  • Page 24 Frequency values................614 Setting guidelines................615 Test mode functionality TESTMODE............620 Application..................620 IEC 61850 protocol test mode............ 620 Setting guidelines................621 Time synchronization TIMESYNCHGEN..........622 Application..................622 Setting guidelines................623 System time................623 Synchronization................623 Bay control REC670 2.2 ANSI Application manual...
  • Page 25 Current transformers according to ANSI/IEEE......636 Voltage transformer requirements............637 SNTP server requirements..............637 PTP requirements.................637 Sample specification of communication requirements for the protection and control terminals in digital telecommunication networks....................638 Section 25 Glossary................641 Bay control REC670 2.2 ANSI Application manual...

  • Page 27: Section 1 Introduction

    This manual addresses the protection and control engineer responsible for planning, pre-engineering and engineering. The protection and control engineer must be experienced in electrical power engineering and have knowledge of related technology, such as protection schemes and communication principles. Bay control REC670 2.2 ANSI Application manual...

  • Page 28: Product Documentation

    The installation manual contains instructions on how to install the IED. The manual provides procedures for mechanical and electrical installation. The chapters are organized in the chronological order in which the IED should be installed. Bay control REC670 2.2 ANSI Application manual...

  • Page 29: Document Revision History

    The guideline can be used as a technical reference during the engineering phase, installation and commissioning phase, and during normal service. 1.3.2 Document revision history GUID-C8027F8A-D3CB-41C1-B078-F9E59BB73A6C v4 Document revision/date History –/May 2017 First release Bay control REC670 2.2 ANSI Application manual...

  • Page 30: Related Documents

    The warning icon indicates the presence of a hazard which could result in personal injury. The caution hot surface icon indicates important information or warning about the temperature of product surfaces. Bay control REC670 2.2 ANSI Application manual...

  • Page 31: Document Conventions

    For example, to save the changes in non-volatile memory, select Yes and press • Parameter names are shown in italics. For example, the function can be enabled and disabled with the Operation setting. • Each function block symbol shows the available input/output signal. Bay control REC670 2.2 ANSI Application manual...

  • Page 32: Iec 61850 Edition 1 / Edition 2 Mapping

    Edition 1 logical nodes Edition 2 logical nodes AEGPVOC AEGGAPC AEGPVOC AGSAL AGSAL AGSAL SECLLN0 ALMCALH ALMCALH ALMCALH ALTIM ALTIM ALTMS ALTMS ALTRK ALTRK BCZPDIF BCZPDIF BCZPDIF BCZSPDIF BCZSPDIF BCZSPDIF Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 33 BFPTRC BFPTRC_F24 BFPTRC BFPTRC BICPTRC_01 BICPTRC BICPTRC BICPTRC_02 BICPTRC BICPTRC BICPTRC_03 BICPTRC BICPTRC BICPTRC_04 BICPTRC BICPTRC BICPTRC_05 BICPTRC BICPTRC BRCPTOC BRCPTOC BRCPTOC BRPTOC BRPTOC BRPTOC BTIGAPC B16IFCVI BTIGAPC Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 34 BUTPTRC BUTPTRC_B3 BUTPTRC BUTPTRC BUTPTRC_B4 BUTPTRC BUTPTRC BUTPTRC_B5 BUTPTRC BUTPTRC BUTPTRC_B6 BUTPTRC BUTPTRC BUTPTRC_B7 BUTPTRC BUTPTRC BUTPTRC_B8 BUTPTRC BUTPTRC BZISGGIO BZISGGIO BZISGAPC BZITGGIO BZITGGIO BZITGAPC BZNPDIF_Z1 BZNPDIF BZNPDIF Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 35 CMMXU CMMXU CMMXU CMSQI CMSQI CMSQI COUVGAPC COUVLLN0 COUVPTOV COUVPTOV COUVPTUV COUVPTUV CVGAPC GF2LLN0 GF2MMXN GF2MMXN GF2PHAR GF2PHAR GF2PTOV GF2PTOV GF2PTUC GF2PTUC GF2PTUV GF2PTUV GF2PVOC GF2PVOC PH1PTRC PH1PTRC Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 36 GOPPDOP GOPPDOP PH1PTRC GRPTTR GRPTTR GRPTTR GSPTTR GSPTTR GSPTTR GUPPDUP GUPPDUP GUPPDUP PH1PTRC HZPDIF HZPDIF HZPDIF INDCALCH INDCALH INDCALH ITBGAPC IB16FCVB ITBGAPC L3CPDIF L3CPDIF L3CGAPC L3CPDIF L3CPHAR L3CPTRC Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 37 LMBRFLO LMBRFLO LOLSPTR LOLSPTR LOLSPTR LOVPTUV LOVPTUV LOVPTUV LPHD LPHD LPTTR LPTTR LPTTR LT3CPDIF LT3CPDIF LT3CGAPC LT3CPDIF LT3CPHAR LT3CPTRC LT6CPDIF LT6CPDIF LT6CGAPC LT6CPDIF LT6CPHAR LT6CPTRC MVGAPC MVGGIO MVGAPC Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 38 RCHLCCH RCHLCCH RCHLCCH REFPDIF REFPDIF REFPDIF ROTIPHIZ ROTIPHIZ ROTIPHIZ ROTIPTRC ROV2PTOV GEN2LLN0 PH1PTRC PH1PTRC ROV2PTOV ROV2PTOV SAPFRC SAPFRC SAPFRC SAPTOF SAPTOF SAPTOF SAPTUF SAPTUF SAPTUF SCCVPTOC SCCVPTOC SCCVPTOC Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 39 T2WPHAR T2WPTRC T3WPDIF T3WPDIF T3WGAPC T3WPDIF T3WPHAR T3WPTRC TCLYLTC TCLYLTC TCLYLTC TCSLTC TCMYLTC TCMYLTC TCMYLTC TEIGAPC TEIGGIO TEIGAPC TEIGGIO TEILGAPC TEILGGIO TEILGAPC TMAGAPC TMAGGIO TMAGAPC TPPIOC TPPIOC TPPIOC Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 40 ZMCAPDIS ZMCPDIS ZMCPDIS ZMCPDIS ZMFCPDIS ZMFCLLN0 PSFPDIS PSFPDIS ZMFPDIS ZMFPDIS ZMFPTRC ZMFPTRC ZMMMXU ZMMMXU ZMFPDIS ZMFLLN0 PSFPDIS PSFPDIS PSFPDIS ZMFPDIS ZMFPDIS ZMFPTRC ZMFPTRC ZMMMXU ZMMMXU ZMHPDIS ZMHPDIS ZMHPDIS Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 41 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 Bay control REC670 2.2 ANSI Application manual...

  • Page 43: Section 2 Application

    The auto-reclose for single-, two-, and/or three-pole reclose includes priority circuits for multi-breaker arrangements. It co-operates with the synchronism check function with high-speed or delayed reclosing. Several breaker failure functions are available to Bay control REC670 2.2 ANSI Application manual...

  • Page 44: Main Protection Functions

    Main protection functions GUID-66BAAD98-851D-4AAC-B386-B38B57718BD2 v13 Table 2: Example of quantities = number of basic instances = option quantities 3-A03 = optional function included in packages A03 (refer to ordering details) Bay control REC670 2.2 ANSI Application manual...

  • Page 45: Back-Up Protection Functions

    GUPPDUP Directional underpower protection GOPPDOP Directional overpower protection BRCPTOC Broken conductor check CBPGAPC Capacitor bank protection VRPVOC Voltage restrained overcurrent protection Voltage protection UV2PTUV Two step undervoltage protection Table continues on next page Bay control REC670 2.2 ANSI Application manual...

  • Page 46: Control And Monitoring Functions

    (2CB), including interlocking (see Table 5) APC30 Control functionality for up to 6 bays, max 30 objects (6CBs), including interlocking (see Table 6) QCBAY Bay control 1+5/APC30 LOCREM Handling of LR-switch positions 1+5/APC30 Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 47 Logic SMPPTRC Tripping logic SMAGAPC General start matrix block TMAGAPC Trip matrix logic ALMCALH Logic for group alarm WRNCALH Logic for group warning INDCALH Logic for group indication Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 48 Comparator for integer inputs REALCOMP Comparator for real inputs Table 3: Total number of instances for basic configurable logic blocks Basic configurable logic block Total number of instances GATE Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 49 Switch controller SXSWI Circuit switch QCRSV Apparatus control RESIN1 RESIN2 POS_EVAL Evaluation of position indication XLNPROXY Proxy for signals from switching device via GOOSE GOOSEXLNRCV GOOSE function block to receive a switching device Bay control REC670 2.2 ANSI Application manual...
  • Page 50 Switch controller SXSWI Circuit switch QCRSV Apparatus control RESIN1 RESIN2 POS_EVAL Evaluation of position indication XLNPROXY Proxy for signals from switching device via GOOSE GOOSEXLNRCV GOOSE function block to receive a switching device Bay control REC670 2.2 ANSI Application manual...
  • Page 51 Table 7: Total number of instances for configurable logic blocks Q/T Configurable logic blocks Q/T Total number of instances ANDQT INDCOMBSPQT INDEXTSPQT INVALIDQT INVERTERQT ORQT PULSETIMERQT Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 52 Current sequence measurement VMSQI Voltage sequence measurement VNMMXU Voltage measurement phase-ground AISVBAS General service value presentation of analog inputs EVENT Event function DRPRDRE, Disturbance report A4RADR, B1RBDR- B22RBDR Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 53 Supervison status for IEC 60870-5-103 I103USRDEF Status for user defined signals for IEC 60870-5-103 L4UFCNT Event counter with limit supervision TEILGAPC Running hour meter Metering PCFCNT Pulse-counter logic ETPMMTR Function for energy calculation and demand handling Bay control REC670 2.2 ANSI Application manual...

  • Page 54: Communication

    OPTICAL103 IEC 60870-5-103 Optical serial communication RS485103 IEC 60870-5-103 serial communication for RS485 AGSAL Generic security application component LD0LLN0 IEC 61850 LD0 LLN0 SYSLLN0 IEC 61850 SYS LLN0 Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 55 Transmission of analog data from LDCM LDCMTRN_2M Transmission of analog data from LDCM, 2Mbit LDCMRecBinStat1 Receive binary status from remote LDCM 6/3/3 LDCMRecBinStat2 LDCMRecBinStat3 LDCMRecBinS2_2M Receive binary status from LDCM, 2Mbit Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 56 Protocol reporting of analog data via IEEE 1344 and C37.118, analogs 1-8 BINARYREPORT1 Protocol reporting of binary data via IEEE 1344 and C37.118, binary 1-8 SMAI1–SMAI12 Signal matrix for analog inputs 3PHSUM Summation block 3 phase PMUSTATUS Diagnostics for C37.118 2011 and IEEE1344 protocol Bay control REC670 2.2 ANSI Application manual...

  • Page 57: Basic Ied Functions

    Summation block 3 phase ATHSTAT Authority status ATHCHCK Authority check AUTHMAN Authority management FTPACCS FTP access with password GBASVAL Global base values for settings ALTMS Time master supervision ALTIM Time management COMSTATUS Protocol diagnostic Bay control REC670 2.2 ANSI Application manual...
  • Page 58 Parameter setting function for HMI in PCM600 FNKEYMD1– FNKEYMD5 LEDGEN General LED indication part for LHMI OPENCLOSE_LED LHMI LEDs for open and close keys GRP1_LED1– Basic part for CP HW LED indication module GRP1_LED15 GRP2_LED1– GRP2_LED15 GRP3_LED1– GRP3_LED15 Bay control REC670 2.2 ANSI Application manual...

  • Page 59: Section 3 Configuration

    IO cards are required. Our proposal for a full version with control is to use two binary input modules and one binary output module. Bay control REC670 2.2 ANSI Application manual...
  • Page 60 Section 3 1MRK 511 401-UUS A Configuration REC670 A30 – Double busbar in single breaker arrangement 12AI (6I + 6U) Control Control Control S CILO S CSWI S XSWI Control Control Control S CILO S CSWI S XSWI WA2_VT VN MMXU...

  • Page 61: Description Of Configuration B30

    For systems without Substation Automation a second binary output board might be required. Bay control REC670 2.2 ANSI Application manual...
  • Page 62 Section 3 1MRK 511 401-UUS A Configuration REC670 B30 - Double breaker arrangement 12AI (6I + 6U) Control Control Control S CILO S CSWI S XSWI WA2_VT Control Control Control SC/VC VN MMXU SES RSYN S CILO S CSWI S XSWI...

  • Page 63: Description Of Configuration C30

    Our proposal for a full version with control is to use three binary input modules and two binary output modules. For systems without Substation Automation a second binary output board might be required. Bay control REC670 2.2 ANSI Application manual...
  • Page 64 SMB RREC STB PTOC TR PTTR TR1 ATCC TR8 ATCC UV2 PTUV VD SPVC VR PVOC ZCLC PSCH ZC PSCH ZCRW PSCH IEC05000839-5-en.vsd IEC05000839 V5 EN-US Figure 4: Configuration diagram for configuration C30 Bay control REC670 2.2 ANSI Application manual...

  • Page 65: Description Of Configuration D30

    Section 3 1MRK 511 401-UUS A Configuration 3.1.1.4 Description of configuration D30 GUID-15D86A4C-4D37-432E-8DC2-518814830097 v1 REC670 D30 – Double busbar in single breaker arrangement with PMU functionality 12AI (6I + 6U) Control Control Control S CILO S CSWI S XSWI Control...
  • Page 66 Analog and control circuits have been pre-defined. Other signals need to be applied as required for each application. The main differences between the packages above are the interlocking modules and the number of apparatuses to control. Bay control REC670 2.2 ANSI Application manual...

  • Page 67: Section 4 Analog Inputs

    All phase angles are calculated in relation to a defined reference. An appropriate analog input channel is selected and used as phase reference. The parameter PhaseAngleRef defines the analog channel that is used as phase angle reference. Bay control REC670 2.2 ANSI Application manual...

  • Page 68: Example

    With correct setting of the primary CT direction, CT_WyePoint set to FromObject or ToObject, a positive quantities always flowing towards the protected object and a direction defined as Forward always is looking towards the protected object. The following examples show the principle. Bay control REC670 2.2 ANSI Application manual...

  • Page 69: Example 1

    IEDs though it is the same current from the same CT that is feeding the two IEDs. With these settings, the directional functions of the line protection shall be set to Forward to look towards the line. Bay control REC670 2.2 ANSI Application manual...

  • Page 70: Example 3

    If the IED has sufficient number of analog current inputs, an alternative solution is shown in Figure 10. The same currents are fed to two separate groups of inputs and the line and transformer protection functions are configured to the different inputs. The CT Bay control REC670 2.2 ANSI Application manual...
  • Page 71 CT_WyePoint with Transformer as Transformer as reference object. reference object. Correct setting is Correct setting is "ToObject" "ToObject" en05000462_ansi.vsd ANSI05000462 V1 EN-US Figure 10: Example how to set CT_WyePoint parameters in the IED Bay control REC670 2.2 ANSI Application manual...
  • Page 72 The second solution will be to use all connected bays as reference objects. In that case for all CT inputs marked with 1 in Figure 11, set CT_WyePoint = FromObject, and for all CT inputs marked with 2 in Figure 11, set CT_WyePoint = ToObject. Bay control REC670 2.2 ANSI Application manual...

  • Page 73: For Most Commonly Used Ct Connections

    (that is, positive) polarity b) and are equivalent symbols and terminal marking used by IEC (ANSI) standard for CTs. Note that for these two cases the CT polarity marking is correct! Bay control REC670 2.2 ANSI Application manual...

  • Page 74: Example On How To Connect A Wye Connected Three-Phase Ct Set To The Ied

    IED. It gives an overview of the actions which are needed to make this measurement available to the built-in protection and control functions within the IED as well. For correct terminal designations, see the connection diagrams valid for the delivered IED. Bay control REC670 2.2 ANSI Application manual...
  • Page 75 Ratio of the first two parameters is only used inside the IED. The third parameter (CTStarPoint=ToObject) as set in this example causes no change on the measured currents. In other words, currents are already measured towards the protected object. Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 76 GRP_A, GRP_B and GRP_C. If GRP2N is connected, the data reflects the measured value of GRP2N. Another alternative is to have the wye point of the three-phase CT set as shown in figure 14: Bay control REC670 2.2 ANSI Application manual...
  • Page 77 IED. A third alternative is to have the residual/neutral current from the three-phase CT set connected to the IED as shown in Figure 14. Bay control REC670 2.2 ANSI Application manual...
  • Page 78 6). Depending on the type of functions, which need this current information, more than one preprocessing block might be connected in parallel to these three CT inputs. Table continues on next page Bay control REC670 2.2 ANSI Application manual...

  • Page 79: Example How To Connect Delta Connected Three-Phase Ct Set To The Ied

    IED. It gives an overview of the required actions by the user in order to make this measurement available to the built-in protection and control functions in the IED as well. For correct terminal designations, see the connection diagrams valid for the delivered IED. Bay control REC670 2.2 ANSI Application manual...
  • Page 80 Section 4 1MRK 511 401-UUS A Analog inputs SMAI_20 IA-IB IB-IC IC-IA ANSI11000027-2-en.vsd Protected Object ANSI11000027 V2 EN-US Figure 16: Delta DAB connected three-phase CT set Bay control REC670 2.2 ANSI Application manual...
  • Page 81 If frequency tracking and compensation is required (this feature is typically required only for DFTReference shall be IEDs installed in the generating stations) then the setting parameters set accordingly. Another alternative is to have the delta connected CT set as shown in figure 17: Bay control REC670 2.2 ANSI Application manual...

  • Page 82: Example How To Connect Single-Phase Ct To The Ied

    CT to the IED. It gives an overview of the required actions by the user in order to make this measurement available to the built-in protection and control functions within the IED as well. Bay control REC670 2.2 ANSI Application manual...
  • Page 83 IED, which are connected to this preprocessing function block. If frequency tracking and compensation is required (this feature is typically required only for DFTReference shall be set IEDs installed in the power plants) then the setting parameters accordingly. Bay control REC670 2.2 ANSI Application manual...

  • Page 84: Relationships Between Setting Parameter Base Current, Ct Rated Primary Current And Minimum Pickup Of A Protection Ied

    IED. This is done by setting the two parameters VTsec and VTprim for each voltage channel. The phase-to-phase value can be used even if each channel is connected to a phase-to-ground voltage from the VT. Bay control REC670 2.2 ANSI Application manual...

  • Page 85: Example

    IEC (ANSI) standard for phase-to-phase connected VTs It shall be noted that depending on national standard and utility practices the rated secondary voltage of a VT has typically one of the following values: Bay control REC670 2.2 ANSI Application manual...

  • Page 86: Examples On How To Connect A Three Phase-To-Ground Connected Vt To The Ied

    VT to the IED. It gives an overview of required actions by the user in order to make this measurement available to the built-in protection and control functions within the IED. For correct terminal designations, see the connection diagrams valid for the delivered IED. Bay control REC670 2.2 ANSI Application manual...
  • Page 87 AI 11 (V) AI 12 (V) ANSI06000599-2-en.vsd ANSI06000599 V2 EN-US Figure 20: A Three phase-to-ground connected VT SMAI2 BLOCK AI2P ^GRP2L1 ^GRP2L2 ^GRP2L1L2 ^GRP2N IEC16000140-1-en.vsdx IEC16000140 V1 EN-US Figure 21: A two phase-to-earth connected VT Bay control REC670 2.2 ANSI Application manual...

  • Page 88: Example On How To Connect A Phase-To-Phase Connected Vt To The Ied

    IED. It shall be noted that this VT connection is only used on lower voltage levels (that is, rated primary voltage below 40 kV). Bay control REC670 2.2 ANSI Application manual...
  • Page 89 VTprim =13.8 kV VTsec =120 V Please note that inside the IED only ratio of these two parameters is used. Table continues on next page Bay control REC670 2.2 ANSI Application manual...

  • Page 90: Example On How To Connect An Open Delta Vt To The Ied For High Impedance Grounded Or Ungrounded Networks

    VT secondary voltage (110/3V in this particular example). Figure gives overview of required actions by the user in order to make this measurement available to the built-in protection and control functions within the IED as well. Bay control REC670 2.2 ANSI Application manual...
  • Page 91 ^GRP2_B # Not Used ^GRP2_C # Not Used AI 11 (V) +3Vo ^GRP2N TYPE AI 12 (V) ANSI06000601-2-en.vsd ANSI06000601 V2 EN-US Figure 23: Open delta connected VT in high impedance grounded power system Bay control REC670 2.2 ANSI Application manual...
  • Page 92 For this application most of the preprocessing settings can be left to the default values. If frequency tracking and compensation is required (this feature is typically required only for DFTReference shall IEDs installed in the generating stations ) then the setting parameters be set accordingly. Bay control REC670 2.2 ANSI Application manual...

  • Page 93: Example How To Connect The Open Delta Vt To The Ied For Low Impedance Grounded Or Solidly Grounded Power Systems

    VT secondary voltage, that is, 115V or 115/√3V as in this particular example. Figure gives an overview of the actions which are needed to make this measurement available to the built-in protection and control functions within the IED. Bay control REC670 2.2 ANSI Application manual...
  • Page 94 # Not Used ^GRP2_B # Not Used ^GRP2_C +3Vo AI11 (V) ^GRP2N TYPE AI12 (V) ANSI06000602-2-en.vsd ANSI06000602 V2 EN-US Figure 24: Open delta connected VT in low impedance or solidly grounded power system Bay control REC670 2.2 ANSI Application manual...
  • Page 95 If frequency tracking and compensation is required (this feature is typically required only for IEDs installed in the generating stations) then the setting parameters DFTReference shall be set accordingly. Bay control REC670 2.2 ANSI Application manual...

  • Page 97: Section 5 Local Hmi

    Section 5 1MRK 511 401-UUS A Local HMI Section 5 Local HMI AMU0600442 v14 ANSI13000239-2-en.vsd ANSI13000239 V2 EN-US Figure 25: Local human-machine interface The LHMI of the IED contains the following elements: Bay control REC670 2.2 ANSI Application manual...

  • Page 98: 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. The character size can vary. The display view is divided into four basic areas. Bay control REC670 2.2 ANSI Application manual...
  • Page 99 Each function button has a LED indication that can be used as a feedback signal for the function button control action. The LED is connected to the required signal with PCM600. Bay control REC670 2.2 ANSI Application manual...
  • Page 100 Multipage button. Pressing the ESC button clears the panel from the display. Both panels have a dynamic width that depends on the label string length. Bay control REC670 2.2 ANSI Application manual...

  • Page 101: Leds

    These LEDs can indicate the status of two arbitrary binary signals by configuring the OPENCLOSE_LED function block. For instance, OPENCLOSE_LED can be connected to a circuit breaker to indicate the breaker open/close status on the LEDs. Bay control REC670 2.2 ANSI Application manual...

  • Page 102: Keypad

    The push-buttons are also used to acknowledge alarms, reset indications, provide help and switch between local and remote control mode. The keypad also contains programmable push-buttons that can be configured either as menu shortcut or control buttons. Bay control REC670 2.2 ANSI Application manual...
  • Page 103 Figure 30: 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 Bay control REC670 2.2 ANSI Application manual...

  • Page 104: Local Hmi Functionality

    The blocking of functions through the IEC61850 protocol can be reset in Main menu/Test/Reset IEC61850 Mod. The yellow LED changes to either On or Off state depending on the state of operation. Bay control REC670 2.2 ANSI Application manual...

  • Page 105: Parameter Management

    5.4.2 Parameter management GUID-5EE466E3-932B-4311-9FE1-76ECD8D6E245 v9 The LHMI is used to access the relay parameters. Three types of parameters can be read and written. • Numerical values • String values • Enumerated values Bay control REC670 2.2 ANSI Application manual...

  • Page 106: Front Communication

    Do not connect the IED front port to a LAN. Connect only a single local PC with PCM600 to the front port. It is only intended for temporary use, such as commissioning and testing. Bay control REC670 2.2 ANSI Application manual...

  • Page 107: C37.118 Phasor Measurement Data Streaming Protocol Configuration Pmuconf

    However, multiple clients can communicate with the same instance of PMUREPORT function block at the same time. For TCP clients, each client can decide to communicate with an existing instance of PMUREPORT by knowing the Bay control REC670 2.2 ANSI Application manual...

  • Page 108: Short Guidance For Use Of Tcp

    The following parameters are used to define the TCP connection between the IED and the TCP clients: 1344TCPport– TCP port for control of IEEE 1344 data for TCP clients C37.118TCPport – TCP port for control of IEEE C37.118 data for TCP clients Bay control REC670 2.2 ANSI Application manual...

  • Page 109: Short Guidance For Use Of Udp

    [x] at the end of each parameter is referring to the UDP stream number (UDP client group) and is a number between 1 and 6. Each of the 6 UDP groups in the IED has the following settings: Bay control REC670 2.2 ANSI Application manual...
  • Page 110 PMUREPORT instances at the same time. This is defined in the PMU by the parameter PMUReportUDP[x] which is used to define the instance number of PMUREPORT function block that must send data on this UDP stream (UDP client group[x]). Bay control REC670 2.2 ANSI Application manual...

  • Page 111: Protocol Reporting Via Ieee 1344 And C37.118 Pmureport

    Protocol reporting via IEEE 1344 and C37.118 PMUREPORT GUID-0C45D2FA-1B95-4FCA-B23B-A28C2770B817 v1 6.2.1 Identification GUID-0090956B-48F1-4E8B-9A40-90044C71DF20 v1 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Protocol reporting via IEEE 1344 and PMUREPORT C37.118 Bay control REC670 2.2 ANSI Application manual...

  • Page 112: Application

    03-00: Trigger Reason defined in STAT field of the Data frame in IEEE C37.118.2 standard. These are predefined inputs for Frequency Trigger, Rate of Change of Frequency trigger, Magnitude High and Magnitude Low triggers. Bay control REC670 2.2 ANSI Application manual...
  • Page 113 (8 Analog signals in each ANALOGREPORT block). These can include for example transfer of active and reactive power or reporting the milliampere input signals to the PDC clients as defined in IEEE C37.118 data frame format. Bay control REC670 2.2 ANSI Application manual...

  • Page 114: Operation Principle

    IEC140000121-2-en.vsd IEC140000121 V2 EN-US Figure 36: Multiple instances of BINARYREPORT blocks 6.2.3 Operation principle GUID-EB2B9096-2F9D-4264-B2D2-8D9DC65697E8 v3 The Phasor Measurement Unit (PMU) features three main functional principles: Bay control REC670 2.2 ANSI Application manual...
  • Page 115 PMUREPORT (PMUREPORT1) is shown. Note that connection of different signals to the PMUREPORT, in this figure, is only an example and the actual connections and reported signals on the IEEEC37.118/1344 can be defined by the user. Bay control REC670 2.2 ANSI Application manual...

  • Page 116: Frequency Reporting

    IED. Then IED can adapt its filtering algorithm in order to properly measure phasors of all current and voltage signals connected to the IED. This feature is essential for proper operation of the PMUREPORT function or for protection during generator start-up and shut-down procedure. Bay control REC670 2.2 ANSI Application manual...
  • Page 117 Table 16: PMUREPORT Monitored data Name Type Values (Range) Unit Description TIMESTAT BOOLEAN 1=Ready Time synchronization status 0=Fail FREQ REAL Frequency FREQGRAD REAL Rate of change of frequency Table continues on next page Bay control REC670 2.2 ANSI Application manual...

  • Page 118: Reporting Filters

    C37.118, where the passband is defined relative to a fixed nominal frequency as shown in the equation 12. ± (Equation 12) IECEQUATION2418 V1 EN-US where, is the nominal frequency is the reporting rate Bay control REC670 2.2 ANSI Application manual...

  • Page 119: Scaling Factors For Analogreport Channels

    CFG-3 in order to recalculate analog values, will get a better resolution than using the scale factors in CFG-2. The following examples show how the scale factor is calculated. Example 1: Bay control REC670 2.2 ANSI Application manual...
  • Page 120 The scale factor will be sent as 3051804 on configuration frame 2, and 305180.43 on configuration frame 3. The range of analog values that can be transmitted in this case is -305181 to -10000000000 and +305181 to +10000000000. Bay control REC670 2.2 ANSI Application manual...

  • Page 121: Pmu Report Function Blocks Connection Rules In Pcm600 Application Configuration Tool (Act)

    Violation of rule 1 results in PMU applications not running at all. The reason is the inconsistent cycle time. For example, in Figure 39, the SMAI block is updating its output every 3 ms while the PHASORREPORT block is expecting input every 0.9 ms. Bay control REC670 2.2 ANSI Application manual...
  • Page 122 PHASORREPORT blocks with different instance numbers. In this example, as the PHASORREPORT blocks have different instance numbers and different settings for SvcClass and ReportRate, a separate SMAI block is used for each PHASORREPORT block. Bay control REC670 2.2 ANSI Application manual...
  • Page 123 SMAI1 will adapt its filtering according to PHASORREPORT instance 1 (because of higher priority) and therefore PHASORREPORT instance 2 will receive data which does not match its performance class and report rate. Bay control REC670 2.2 ANSI Application manual...
  • Page 124 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). Figures show the corresponding setting parameters. Bay control REC670 2.2 ANSI Application manual...
  • Page 125 Figure 43: An example of correct connection of 3PHSUM and PHASORREPORT blocks in ACT IEC140000130-1-en.vsd IEC140000130 V1 EN-US Figure 44: SMAI1 setting parameters example-showing that SMAI3 is selected as the DFT reference (DFTRefGrp3) Bay control REC670 2.2 ANSI Application manual...
  • Page 126 SvcClass or ReportRate, then the synchrophasor reported by PHASOR2 connection from PHASORREPORT1 instance 2 will not be compliant with IEEE C37.118 standard. The reason is as in the rule 2, the filtering in SMAI/3PHSUM block Bay control REC670 2.2 ANSI Application manual...

  • Page 127: Setting Guidelines

    Application Manual under section Basic IED functions. 6.2.4 Setting guidelines GUID-83969957-DABF-4B9B-95C7-B9F0AF6E647A v2 Based on the functionality and appearance in PCM600, the PMU reporting functionality is categorized into 4 different categories (function block) as follows: Bay control REC670 2.2 ANSI Application manual...
  • Page 128 PhasorFormat: It refers to the Bit 0 of the FORMAT field of the configuration frames 1, 2 and 3 organization defined in IEEE C37.118.2 message format. Here the user can select the format of the calculated Bay control REC670 2.2 ANSI Application manual...
  • Page 129 (FREQ/DFREQ) which can be reported along with the synchrophasor data over IEEE C37.118.2 message. The options are Integer or Float data corresponding to the 16-bit integer or 32-bit IEEE floating-point value, respectively. Bay control REC670 2.2 ANSI Application manual...
  • Page 130 RptTimetag: It refers to the method of time-tagging used in the IED which is related to the phasor estimation and filtering technique. The options are FirstSample, MiddleSample and LastSample. The time-stamp of the PMU output represents the phasor equivalent, frequency, and ROCOF of the Bay control REC670 2.2 ANSI Application manual...
  • Page 131 It refers to the 4-byte ANUNIT field of the configuration frames 1, 2 organization and the 8-byte ANSCALE field of the configuration frame 3 organization defined in IEEE C37.118.2 message format. The AnalogXRange value can be a number between 3277.0 and 10000000000. Bay control REC670 2.2 ANSI Application manual...
  • Page 132 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. The options are Single point-on-wave, RMS of analog input and Peak of analog input. Bay control REC670 2.2 ANSI Application manual...

  • Page 133: High Impedance Differential Protection, Single Phase Hzpdif (87)

    Restricted ground fault protection for transformer, generator and shunt reactor windings • Restricted ground fault protection The application is dependent on the primary system arrangements and location of breakers, available CT cores and so on. Bay control REC670 2.2 ANSI Application manual...
  • Page 134 Section 7 1MRK 511 401-UUS A Differential protection 3·87 3·87B 3·87 3·87B 3·87T 3·87 3·87T 3·87G ANSI05000163-1-en.vsd ANSI05000163 V2 EN-US Bay control REC670 2.2 ANSI Application manual...

  • Page 135: The Basics Of The High Impedance Principle

    (that is, pulses) which may appear during an internal fault. Otherwise any flash-over in CT secondary circuits or any other part of the scheme may prevent correct operation of the high impedance differential relay for an actual internal fault. Bay control REC670 2.2 ANSI Application manual...
  • Page 136 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. Bay control REC670 2.2 ANSI Application manual...
  • Page 137 Normally the voltage can be increased to higher values than the calculated minimum TripPickup with a minor change of total operating values as long as this is done by adjusting the resistor to a higher value. Check the sensitivity calculation below for reference. Bay control REC670 2.2 ANSI Application manual...
  • Page 138 14. å = × n IR Ires lmag (Equation 14) EQUATION1747 V1 EN-US where: is the CT ratio primary current at IED pickup, Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 139 Vxxx Series Resistance value does not exceed 200 W. Otherwise injection time shall be reduced to the minimum. Bay control REC670 2.2 ANSI Application manual...
  • Page 140 Rres I> Protected Object a) Through load situation b) Through fault situation c) Internal faults ANSI05000427-2-en.vsd ANSI05000427 V2 EN-US Figure 49: The high impedance principle for one phase with two current transformer inputs Bay control REC670 2.2 ANSI Application manual...

  • Page 141: Connection Examples For High Impedance Differential Protection

    L2 (B) L1 (A) L3 (C) L2 (B) CT 1200/1 L1 (A) Star/Wye Connected 3-Ph Plate with Metrosils and Resistors ANSI09000169-4-en.vsdx ANSI09000169 V4 EN-US Figure 50: CT connections for high impedance differential protection Bay control REC670 2.2 ANSI Application manual...

  • Page 142: Connections For 1Ph High Impedance Differential Protection Hzpdif (87)

    GUID-D68A237F-610C-4AF0-870F-273117F64D92 v10 Restricted earth fault protection is a typical application for 1Ph High impedance differential protection HZPDIF (87). Typical CT connections for the high impedance based protection scheme are shown in figure 51. Bay control REC670 2.2 ANSI Application manual...

  • Page 143: Setting Guidelines

    How to connect the high impedance restricted earth fault protection scheme to one CT input in IED. 7.1.4 Setting guidelines IP14945-1 v1 M13076-3 v2 The setting calculations are individual for each application. Refer to the different application descriptions below. Bay control REC670 2.2 ANSI Application manual...

  • Page 144: Configuration

    7.1.4.3 T-feeder protection M16850-4 v6 In many busbar arrangements such as breaker-and-a-half, ring breaker, mesh corner, there will be a T-feeder from the current transformer at the breakers up to the current Bay control REC670 2.2 ANSI Application manual...
  • Page 145 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 52. Bay control REC670 2.2 ANSI Application manual...
  • Page 146 Section 7 1MRK 511 401-UUS A Differential protection en05000165_ansi.vsd ANSI05000165 V1 EN-US 3·87 ANSI05000739-2-en.vsd ANSI05000739 V2 EN-US Bay control REC670 2.2 ANSI Application manual...
  • Page 147 As this application requires to be so sensitive select R Series= 500 ohm, which gives an IED operating current of 200 mA. Calculate the primary sensitivity at operating voltage using the following equation. Bay control REC670 2.2 ANSI Application manual...

  • Page 148: Tertiary Reactor Protection

    HZPDIF (87) can be used to protect the tertiary reactor for phase faults as well as ground faults if the power system of the tertiary winding is direct or low impedance grounded. Bay control REC670 2.2 ANSI Application manual...
  • Page 149 This helps in utilizing maximum CT capability, minimize the secondary fault, thereby reducing the stability voltage limit. Another factor is that during internal faults, the voltage developed across the selected tap is limited by the non-linear resistor Bay control REC670 2.2 ANSI Application manual...
  • Page 150 A little lower sensitivity could be selected by using a lower resistance value. × + × £ (200 2 30) approx .5.2 (Equation 20) EQUATION1769-ANSI V1 EN-US Bay control REC670 2.2 ANSI Application manual...

  • Page 151: Alarm Level Operation

    A time delay of a few seconds is used before the shorting and alarm are activated. Auxiliary relays with contacts that can withstand high voltage shall be used, like RXMVB types. The metrosil operating characteristic is given in the following figure. Bay control REC670 2.2 ANSI Application manual...
  • Page 152 Section 7 1MRK 511 401-UUS A Differential protection IEC05000749 V1 EN-US Figure 54: Current voltage characteristics for the non-linear resistors, in the range 10-200 V, the average range of current is: 0.01–10 mA Bay control REC670 2.2 ANSI Application manual...

  • Page 153: Instantaneous Phase Overcurrent Protection Phpioc (50)

    The fault current on long transmission lines depends mostly on the fault position and decreases with the distance from the generation point. For this reason the protection Bay control REC670 2.2 ANSI Application manual...

  • Page 154: Setting Guidelines

    IP>>, is used. The limits are used for decreasing the used range of the IP>> setting. If IP>> is set outside IP>>Max and IP>>Min, the closest of the limits to IP>> is used by the function. If IP>>Max is smaller than IP>>Min, the limits are swapped. Bay control REC670 2.2 ANSI Application manual...

  • Page 155: Meshed Network Without Parallel Line

    Then a fault in A has to be applied and the through fault current I has to be calculated, Figure 56. In order to get the maximum through fault current, the minimum value for Z and the maximum value for Z have to be considered. Bay control REC670 2.2 ANSI Application manual...
  • Page 156 The protection function can be used for the specific application only if this setting value is equal to or less than the maximum fault current that the IED has to clear, I Figure 57. Bay control REC670 2.2 ANSI Application manual...

  • Page 157: Meshed Network With Parallel Line

    C point with the C breaker open. A fault in C has to be applied, and then the maximum current seen from the IED (I on the healthy line (this applies for single-phase-to-ground and two-phase-to-ground faults) is calculated. Bay control REC670 2.2 ANSI Application manual...
  • Page 158 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: × Pickup IBase (Equation 26) ANSIEQUATION1147 V1 EN-US Bay control REC670 2.2 ANSI Application manual...

  • Page 159: Directional Phase Overcurrent Protection, Four Steps Oc4Ptoc(51_67)

    DirModeSelx (x = step 1, 2, 3 or 4) shall be left to the default value Non-directional. Choice of time delay characteristics: There are several types of time delay characteristics available such as definite time delay and different types of inverse time Bay control REC670 2.2 ANSI Application manual...

  • Page 160: Setting Guidelines

    Thus, if only the inverse time delay is required, it is important to set the definite time delay for that stage to zero. Bay control REC670 2.2 ANSI Application manual...
  • Page 161 7% of IB. 2ndHarmStab: Operate level of 2nd harmonic current restrain set in % of the fundamental current. The setting range is 5 - 100% in steps of 1%. The default setting is 20%. Bay control REC670 2.2 ANSI Application manual...

  • Page 162: Settings For Each Step

    2. ROA = Relay operating angle 3. Reverse 4. Forward 8.2.3.1 Settings for each step M12982-19 v10 x means step 1, 2, 3 and 4. DirModeSelx: The directional mode of step x. Possible settings are Disabled/Non- directional/Forward/Reverse. Bay control REC670 2.2 ANSI Application manual...
  • Page 163 TDx: Time multiplier for inverse time delay for step x. IMinx: Minimum operate current in % of IB for all inverse time characteristics, below which no operation takes place. Bay control REC670 2.2 ANSI Application manual...
  • Page 164 Note that the operate time is dependent on the selected time multiplier setting kx. ResetTypeCrvx: The reset of the delay timer can be made as shown in Table 20. Bay control REC670 2.2 ANSI Application manual...
  • Page 165 HarmRestrainx: Enables the block of step x from the harmonic restrain function (2nd harmonic). This function should be used when there is a risk of an unwanted trip caused by power transformer inrush currents. It can be set to Disabled/Enabled. Bay control REC670 2.2 ANSI Application manual...

  • Page 166: Setting Example

    Reset current The IED does not reset Time t ANSI09000146-en-1.vsd ANSI09000146 V1 EN-US Figure 61: Pickup and reset current for an overcurrent protection The lowest setting value can be written according to Equation 28. Bay control REC670 2.2 ANSI Application manual...
  • Page 167 It is desirable to have rapid tripping of faults within a large part of the power system to be protected by the protection (primary Bay control REC670 2.2 ANSI Application manual...
  • Page 168 The time setting is chosen to get the shortest fault time with maintained selectivity. Selectivity is assured if the time difference between the curves is larger than a critical time difference. Bay control REC670 2.2 ANSI Application manual...
  • Page 169 These time delays can vary significantly between different protective equipment. The following time delays can be estimated: Protection operation 15-60 ms time: Protection resetting time: 15-60 ms Breaker opening time: 20-120 ms Bay control REC670 2.2 ANSI Application manual...
  • Page 170 There are uncertainties in the values of protection operation time, breaker opening time and protection resetting time. Therefore a safety margin has to be included. With normal values the needed time difference can be calculated according to Equation 32. Bay control REC670 2.2 ANSI Application manual...

  • Page 171: Instantaneous Residual Overcurrent Protection Efpioc (50N)

    M12762-4 v4 The parameters for the Instantaneous residual overcurrent protection EFPIOC (50N) are set via the local HMI or PCM600. Some guidelines for the choice of setting parameter for EFPIOC (50N) is given. Bay control REC670 2.2 ANSI Application manual...
  • Page 172 Fault ANSI09000022-1-en.vsd ANSI09000022 V1 EN-US Figure 64: Through fault current from A to B: I Fault ANSI09000023-1-en.vsd ANSI09000023 V1 EN-US Figure 65: Through fault current from B to A: I Bay control REC670 2.2 ANSI Application manual...
  • Page 173 The minimum theoretical current setting (Imin) will in this case be: ³ I m in M A X I (Equation 35) EQUATION287 V1 EN-US Where: and I have been described for the single line case. Bay control REC670 2.2 ANSI Application manual...

  • Page 174: Identification

    Directional residual overcurrent protection, four steps EF4PTOC (51N/67N) IP14509-1 v8 8.4.1 Identification M14881-1 v6 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Directional residual overcurrent EF4PTOC 51N_67N 4(IN>) protection, four steps TEF-REVA V2 EN-US Bay control REC670 2.2 ANSI Application manual...

  • Page 175: Application

    To enable optimal co- ordination all overcurrent protections, to be co-ordinated against each other, should have the same time characteristic. Therefore a wide range of standardized inverse time characteristics are available for IEC and ANSI. Bay control REC670 2.2 ANSI Application manual...
  • Page 176 This can be used to avoid unwanted operation of the protection. Therefore, EF4PTOC (51N_67N) has a possibility of second harmonic restrain if the level of 2 harmonic current reaches a value above a set percent of the fundamental current. Bay control REC670 2.2 ANSI Application manual...

  • Page 177: Setting Guidelines

    AngleRCA: Relay characteristic angle given in degree. This angle is defined as shown in Figure 67. The angle is defined positive when the residual current lags the reference voltage (Vpol = 3V or V Bay control REC670 2.2 ANSI Application manual...
  • Page 178 · ZNpol. The ZNpol can be defined as (ZS )/3, that is the ground return impedance of the source behind the protection. The maximum ground-fault current at the local source can be used to Bay control REC670 2.2 ANSI Application manual...

  • Page 179: Nd Harmonic Restrain

    This is called transferred saturation. The 2 harmonic of the inrush currents of the two transformers will be in phase opposition. The summation of the two currents will thus give a small 2 harmonic current. The Bay control REC670 2.2 ANSI Application manual...

  • Page 180: Switch Onto Fault Logic

    This logic can be used to issue a fast trip if one breaker pole does not close properly at a manual or automatic closing. SOTF and under time are similar functions to achieve fast clearance at asymmetrical closing based on requirements from different utilities. Bay control REC670 2.2 ANSI Application manual...

  • Page 181: Settings For Each Step (X = 1, 2, 3 And 4)

    This is mainly used in radial fed networks but can also be used in meshed networks. In meshed networks, the settings must be based on network fault calculations. Bay control REC670 2.2 ANSI Application manual...
  • Page 182 Minimum operating time for inverse time characteristics. At high currents, the inverse time characteristic might give a very short operation time. By setting this parameter, the operation time of the step can never be shorter than the setting. Bay control REC670 2.2 ANSI Application manual...
  • Page 183 HarmBlockx: This is used to enable block of step x from 2 harmonic restrain function. tPCrvx, tACrvx, tBCrvx, tCCrvx: Parameters for user programmable of inverse time characteristic curve. The time characteristic equation is according to equation 38: Bay control REC670 2.2 ANSI Application manual...

  • Page 184: Line Application Example

    (zero-sequence voltage) is the polarizing quantity. The polarizing voltage and current can be internally generated when a three-phase set of voltage transformers and current transformers are used. Bay control REC670 2.2 ANSI Application manual...
  • Page 185 M15282-123 v6 This step has directional instantaneous function. The requirement is that overreaching of the protected line is not allowed. One- or two-phase ground-fault ANSI05000150_2_en.vsd ANSI05000150 V2 EN-US Figure 71: Step 1, first calculation Bay control REC670 2.2 ANSI Application manual...
  • Page 186 A higher value of step 1 might be necessary if a big power transformer (Y0/D) at remote bus bar is disconnected. A special case occurs at double circuit lines, with mutual zero-sequence impedance between the parallel lines, see Figure 73. Bay control REC670 2.2 ANSI Application manual...
  • Page 187 This step has directional function and a short time delay, often about 0.4 s. Step 2 shall securely detect all ground faults on the line, not detected by step 1. 50/51N One- or two-phase ground-fault ANSI05000154_2_en.vsd ANSI05000154 V2 EN-US Figure 74: Step 2, check of reach calculation Bay control REC670 2.2 ANSI Application manual...
  • Page 188 Step 3 shall enable selective trip of ground faults having higher fault resistance to ground, compared to step 2. The requirement on step 3 is selectivity to other ground- fault protections in the network. One criterion for setting is shown in Figure 76. Bay control REC670 2.2 ANSI Application manual...

  • Page 189: Four Step Directional Negative Phase Sequence Overcurrent Protection Ns4Ptoc (46I2)

    1.2 - 2.0 s is used. In other applications a current dependent inverse time characteristic is used. This enables a higher degree of selectivity also for sensitive ground-fault current protection. Four step directional negative phase sequence overcurrent protection NS4PTOC (46I2) GUID-E8CF8AA2-AF54-4FD1-A379-3E55DCA2FA3A v1 Bay control REC670 2.2 ANSI Application manual...

  • Page 190: Identification

    The directional negative sequence overcurrent protection is also well suited to operate in teleprotection communication schemes, which enables fast clearance of unsymmetrical faults on transmission lines. The directional function uses the voltage polarizing quantity. Bay control REC670 2.2 ANSI Application manual...
  • Page 191 Therefore there is a possibility to give a setting of a multiplication factor MultPUx to the negative sequence current pick-up level. This multiplication factor is activated from a binary input signal MULTPUx to the function. Bay control REC670 2.2 ANSI Application manual...

  • Page 192: Setting Guidelines

    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 Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 193 Minimum operation time for inverse time characteristics. At high currents the inverse time characteristic might give a very short operation time. By setting this parameter the operation time of the step can never be shorter than the setting. Bay control REC670 2.2 ANSI Application manual...
  • Page 194 (1), IEC (2 = set constant time reset) and ANSI (3 = current dependent reset time). If the current dependent type is used settings pr, tr and cr must be given. Bay control REC670 2.2 ANSI Application manual...

  • Page 195: Common Settings For All Steps

    1, 2, 3 and 4. AngleRCA: Relay characteristic angle given in degrees. This angle is defined as shown in figure 78. The angle is defined positive when the residual current lags the reference voltage (Vpol = -) Bay control REC670 2.2 ANSI Application manual...

  • Page 196: Sensitive Directional Residual Overcurrent And Power Protection Sdepsde (67N)

    % of IBase. The pickup forward or pickup reverse signals can be used in a communication scheme. The appropriate signal must be configured to the communication scheme block. Sensitive directional residual overcurrent and power protection SDEPSDE (67N) SEMOD171436-1 v4 Bay control REC670 2.2 ANSI Application manual...

  • Page 197: Identification

    In such networks, the characteristic angle is chosen to 0º. As the magnitude of the residual current is independent of the fault location, the selectivity of the ground fault protection is achieved by time selectivity. Bay control REC670 2.2 ANSI Application manual...
  • Page 198 Directional and power functionality uses IN and VN. If a connection is made to GRPxN this signal is used, else if connection is made to all inputs GRPxA, GRPxB and GRPxC the internally calculated sum of these inputs (3I0 and 3V0) will be used. Bay control REC670 2.2 ANSI Application manual...

  • Page 199: Setting Guidelines

    In an isolated system (without neutral point apparatus) the impedance is equal to the capacitive coupling between the phase conductors and ground: × phase (Equation 48) EQUATION2022-ANSI V1 EN-US Bay control REC670 2.2 ANSI Application manual...
  • Page 200 The series impedances in the system can no longer be neglected. The system with a single phase to ground fault can be described as in Figure 80. Bay control REC670 2.2 ANSI Application manual...
  • Page 201 Z lineAB,1 lineBC,1 is the total zero sequence impedance to the fault point. Z lineAB,0 lineBC,0 is the fault resistance. The residual voltages in stations A and B can be written: Bay control REC670 2.2 ANSI Application manual...
  • Page 202 The inverse time delay is defined as: × × × TDSN (3I 3V cos (reference)) × 3I 3V cos (measured) (Equation 58) EQUATION2069 V1 EN-US The function can be set Enabled/Disabled with the setting of Operation. Bay control REC670 2.2 ANSI Application manual...
  • Page 203 RCA = 0°, ROA = 90° ) - ang(3V = ang(3I en06000648_ansi.vsd ANSI06000648 V1 EN-US Figure 81: Characteristic for RCADir equal to 0° The characteristic is for RCADir equal to -90° is shown in Figure 82. Bay control REC670 2.2 ANSI Application manual...
  • Page 204 INDirPU and the residual current angle is within the sector RCADir ± ROADir. The characteristic for this OpModeSel when RCADir = 0° and ROADir = 80° is shown in figure 83. Bay control REC670 2.2 ANSI Application manual...
  • Page 205 0° in a high impedance grounded network with a neutral point resistor as the active current component is appearing out on the faulted feeder only. RCADir is set equal to -90° in an isolated network as all currents are mainly capacitive. Bay control REC670 2.2 ANSI Application manual...
  • Page 206 TimeChar is the selection of time delay characteristic for the non-directional residual current protection. Definite time delay and different types of inverse time characteristics are available: Bay control REC670 2.2 ANSI Application manual...
  • Page 207 EQUATION2031-ANSI V1 EN-US tINNonDir is the definite time delay for the non directional ground fault current protection, given in s. OpVN is set Enabled to activate the trip function of the residual over voltage protection. Bay control REC670 2.2 ANSI Application manual...

  • Page 208: Thermal Overload Protection, One Time Constant Fahrenheit Celsius Lfpttr/Lcpttr (26)

    It might also cause bubbling in the transformer oil. In stressed situations in the power system it can be required to overload transformers for a limited time. This should be done without the above mentioned risks. The thermal Bay control REC670 2.2 ANSI Application manual...

  • Page 209: Setting Guideline

    HMI or Protection and Control IED Manager (PCM600). The following settings can be done for the thermal overload protection: Operation: Disabled/Enabled Operation: Sets the mode of operation. Disabled switches off the complete function. Bay control REC670 2.2 ANSI Application manual...
  • Page 210 Now the oil temperature above the ambient temperature is DQ . The thermal time constant can now be estimated as: DQ - (Equation 61) EQUATION1180 V1 EN-US Bay control REC670 2.2 ANSI Application manual...
  • Page 211 The signal is released when the estimated heat content is below the set value. This temperature value should be chosen below the alarm temperature. LockoutReset is set in % of the trip heat content level. Bay control REC670 2.2 ANSI Application manual...

  • Page 212: Breaker Failure Protection Ccrbrf(50Bf)

    The re-trip function can be used to increase the probability of operation of the breaker, or it can be used to avoid back-up trip of many breakers in case of mistakes during relay maintenance and testing. Bay control REC670 2.2 ANSI Application manual...

  • Page 213: Setting Guidelines

    Current/Contact both methods according to above are used but taken into account I>BlkCont also Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 214 The setting can be given within the range 2 – 200 % of IBase. t1: Time delay of the re-trip. The setting can be given within the range 0 – 60s in steps of 0.001 s. Typical setting is 0 – 50ms. Bay control REC670 2.2 ANSI Application manual...
  • Page 215 Retrip delay t1 after re-trip cbopen occurs BFPreset Margin Minimum back-up trip delay t2 Critical fault clearance time for stability Time Trip and Pickup CCRBRF (50BF) ANSI05000479_3_en.vsd ANSI05000479 V3 EN-US Figure 84: Time sequence Bay control REC670 2.2 ANSI Application manual...

  • Page 216: Stub Protection Stbptoc (50Stb)

    This is done by opening the disconnector to the protected object. This will, however, disable the normal object protection (for example the distance protection) of the energized part between the circuit breakers and the open disconnector. Bay control REC670 2.2 ANSI Application manual...

  • Page 217: Setting Guidelines

    ENABLE into the function is activated. This signal is normally taken from an auxiliary contact (normally closed) of the line disconnector and connected to a binary input ENABLE of the IED. With the Bay control REC670 2.2 ANSI Application manual...

  • Page 218: Pole Discrepancy Protection Ccpdsc(52Pd)

    • By connecting the auxiliary contacts in the circuit breaker so that logic is created, a signal can be sent to the protection, indicating pole discrepancy. This logic can Bay control REC670 2.2 ANSI Application manual...

  • Page 219: Setting Guidelines

    This is due to the existence of low impedance current paths in the switch yard. This phenomenon must be considered in the setting of the parameter. CurrRelPU: Current magnitude for release of the function in % of IBase. Bay control REC670 2.2 ANSI Application manual...

  • Page 220: Directional Underpower Protection Guppdup (37)

    Earlier disconnection would cause an acceleration of the turbine generator at all routine shutdowns. This should have caused overspeed and high centrifugal stresses. Bay control REC670 2.2 ANSI Application manual...
  • Page 221 The underpower protection gives a higher margin and should provide better dependability. On the other hand, the risk for unwanted operation immediately after synchronization may be higher. One should set the underpower Bay control REC670 2.2 ANSI Application manual...

  • Page 222: Setting Guidelines

    EQUATION2055-ANSI V1 EN-US Arone × × (Equation 65) EQUATION2056-ANSI V1 EN-US PosSeq = × × PosSeq PosSeq (Equation 66) EQUATION2057-ANSI V1 EN-US × (Equation 67) EQUATION2058-ANSI V1 EN-US Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 223 With the parameter OpMode1(2) the function can be set Enabled/Disabled. The function gives trip if the power component in the direction defined by the setting Angle1(2) is smaller than the set pick up power value Power1(2) Bay control REC670 2.2 ANSI Application manual...
  • Page 224 The setting Angle1(2) gives the characteristic angle giving maximum sensitivity of the power protection function. The setting is given in degrees. For active power the set angle should be 0° or 180°. 0° should be used for generator low forward active power protection. Bay control REC670 2.2 ANSI Application manual...
  • Page 225 Calculated is settable parameter Bay control REC670 2.2 ANSI Application manual...

  • Page 226: Directional Overpower Protection Goppdop (32)

    If the generator under consideration is very large and if it consumes lots of electric power, it may be desirable to disconnect it to ease the task for the rest of the power system. Bay control REC670 2.2 ANSI Application manual...
  • Page 227 Ice and snow may block the intake when the outdoor temperature falls far below zero. Branches and leaves may also block the trash gates. A complete blockage of the intake Bay control REC670 2.2 ANSI Application manual...

  • Page 228: Setting Guidelines

    Setting guidelines SEMOD172150-4 v7 GlobalBaseSel: Selects the global base value group used by the function to define IBase, VBase and SBase as applicable. Operation: With the parameter Operation the function can be set Enabled/Disabled. Bay control REC670 2.2 ANSI Application manual...
  • Page 229 With the parameter OpMode1(2) the function can be set Enabled/Disabled. The function gives trip if the power component in the direction defined by the setting Angle1(2) is larger than the set pick up power value Power1(2) Bay control REC670 2.2 ANSI Application manual...
  • Page 230 The setting Angle1(2) gives the characteristic angle giving maximum sensitivity of the power protection function. The setting is given in degrees. For active power the set angle should be 0° or 180°. 180° should be used for generator reverse power protection. Bay control REC670 2.2 ANSI Application manual...
  • Page 231 (Equation 87) EQUATION2047 V1 EN-US The drop out power will be Power1(2) - Hysteresis1(2). The possibility to have low pass filtering of the measured power can be made as shown in the formula: Bay control REC670 2.2 ANSI Application manual...

  • Page 232: Broken Conductor Check Brcptoc (46)

    8.14 Broken conductor check BRCPTOC (46) SEMOD171761-1 v3 8.14.1 Identification SEMOD172362-2 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Broken conductor check BRCPTOC Bay control REC670 2.2 ANSI Application manual...

  • Page 233: Application

    Set the time delay tOper = 5 - 60 seconds and reset time tReset = 0.010 - 60.000 seconds. 8.15 Capacitor bank protection CBPGAPC GUID-41731DCF-840C-4717-9F51-899FC648F881 v2 8.15.1 Identification GUID-67FC8DBF-4391-4562-A630-3F244CBB4A33 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Capacitor bank protection CBPGAPC Bay control REC670 2.2 ANSI Application manual...

  • Page 234: Application

    Typically the neighboring capacitor units are mounted in racks. Each rack must be insulated from the other by insulators because the can casing within each rack are at a certain potential. Refer figure for an example: Bay control REC670 2.2 ANSI Application manual...
  • Page 235 SCB is built from series connections of the individual capacitor units (that is, strings) and without any fuses Unfused where, in contrary to the fuseless configuration, a series or parallel connection of the capacitor units is used to form SCB, still without any fuses Bay control REC670 2.2 ANSI Application manual...

  • Page 236: Scb Protection

    HV live parts this can result in a flash-over, can rapture or a cascading failures that might cause extensive damages, fire or even total destruction of the whole SCB, unless the bank is sufficiently fitted with protection IEDs. Bay control REC670 2.2 ANSI Application manual...
  • Page 237 110% of the rated voltage on the remaining capacitors of that serial group. The value of 110% is the maximum continuous overvoltage capability of capacitor units as per IEEE Std 18-1992. The SCB typically requires the following types of IED protection: Bay control REC670 2.2 ANSI Application manual...

  • Page 238: Setting Guidelines

    CBPGAPC 500/1 200MVAr 400kV IEC09000754-1-en.vsd IEC09000754 V1 EN-US Figure 93: Single line diagram for the application example From figure it is possible to calculate the following rated fundamental frequency current for this SCB: Bay control REC670 2.2 ANSI Application manual...
  • Page 239 PU 51 =135% (of IBase); Current level for overcurrent pickup. Selected value gives pickup recommended by international standards. tOC =30s; Time delay for overcurrent trip Undercurrent feature: Operation37 =Enabled; to enable this feature Bay control REC670 2.2 ANSI Application manual...

  • Page 240: Restrike Detection

    8.15.3.1 Restrike detection GUID-114747A5-0F7C-4F48-A32D-0C13BFF6ADCE v1 Opening of SCBs can be quite problematic for certain types of circuit breakers (CBs). Typically such problems are manifested as CB restrikes. Bay control REC670 2.2 ANSI Application manual...

  • Page 241: Voltage-Restrained Time Overcurrent Protection Vrpvoc (51V)

    The IED can be provided with a voltage-restrained time overcurrent protection (VRPVOC, 51V). The VRPVOC (51V) function is always connected to three-phase Bay control REC670 2.2 ANSI Application manual...

  • Page 242: Base Quantities

    VRPVOC (51V) function can be used in one of the following applications: • voltage controlled over-current • voltage restrained over-current In both applications a seal-in of the overcurrent function at under-voltage can be included by configuration. Bay control REC670 2.2 ANSI Application manual...

  • Page 243: Undervoltage Seal-In

    Undervoltage seal-in of current pickup 8.16.3 Setting guidelines GUID-2AE85EC4-669E-47C0-ADD4-3DBA83581096 v2 8.16.3.1 Explanation of the setting parameters GUID-9B777E6D-602B-4214-9170-A44ED2D725BF v3 Operation: Set to On in order to activate the function; set to Off to switch off the complete function. Bay control REC670 2.2 ANSI Application manual...
  • Page 244 VHighLimit: when the measured phase-to-phase voltage is higher than VHighLimit/ 100*VBase, than the pickup level of the overcurrent stage is Pickup_Curr/100*IBase. In particular, in Slope mode it define the second point of the characteristic (Pickup_Curr/100*IBase ; VHighLimit/100*VBase). Bay control REC670 2.2 ANSI Application manual...

  • Page 245: Voltage-Restrained Overcurrent Protection For Generator And Step-Up Transformer

    VRPVOC. Let us assume that, taking into account the characteristic of the generator, the excitation system and the short circuit study, the following settings are required: Bay control REC670 2.2 ANSI Application manual...
  • Page 246 Set tDef_UV to 3.0 s. 10. Set EnBlkLowV to Disabled (default value) to disable the cut-off level for low- voltage of the undervoltage stage. The other parameters may be left at their default value. Bay control REC670 2.2 ANSI Application manual...

  • Page 247: Two Step Undervoltage Protection Uv2Ptuv (27)

    Initiate voltage correction measures, like insertion of shunt capacitor banks to compensate for reactive load and thereby increasing the voltage • Disconnect apparatuses, like electric motors, which will be damaged when subject to service under low voltage conditions. Bay control REC670 2.2 ANSI Application manual...

  • Page 248: Setting Guidelines

    9.1.3.4 Voltage instability mitigation M13851-59 v3 This setting is very much dependent on the power system characteristics, and thorough studies have to be made to find the suitable levels. Bay control REC670 2.2 ANSI Application manual...

  • Page 249: Backup Protection For Power System Faults

    90% of the nominal voltage. tn: time delay of step n, given in s. This setting is dependent on the protection application. In many applications the protection function shall not directly trip when Bay control REC670 2.2 ANSI Application manual...

  • Page 250: Two Step Overvoltage Protection Ov2Ptov (59)

    Time delay to block the undervoltage step n when the voltage level is below IntBlkStValn, given in s. It is important that this delay is shorter than the trip time delay of the undervoltage protection step. Two step overvoltage protection OV2PTOV (59) IP14545-1 v3 Bay control REC670 2.2 ANSI Application manual...

  • Page 251: Identification

    (unsymmetrical voltage increase). OV2PTOV (59) prevents sensitive equipment from running under conditions that could cause their overheating or stress of insulation material, and, thus, shorten their life time Bay control REC670 2.2 ANSI Application manual...

  • Page 252: Setting Guidelines

    M13852-13 v1 High voltage will deteriorate the dielectricum and the insulation. The setting has to be well above the highest occurring "normal" voltage and well below the highest acceptable voltage for the capacitor. Bay control REC670 2.2 ANSI Application manual...

  • Page 253: Power Supply Quality

    × Vpickup (%) VBase(kV) (Equation 92) EQUATION1992-ANSI V1 EN-US The below described setting parameters are identical for the two steps (n = 1 or 2). Therefore the setting parameters are described only once. Bay control REC670 2.2 ANSI Application manual...
  • Page 254 Description of this can be found in the technical reference manual. CrvSatn: When the denominator in the expression of the programmable curve is equal to zero the time delay will be infinity. There will be an undesired discontinuity. Bay control REC670 2.2 ANSI Application manual...

  • Page 255: Two Step Residual Overvoltage Protection Rov2Ptov (59N)

    The highest residual voltage, equal to three times the phase-to-ground voltage, is achieved for a single phase-to-ground fault. The residual voltage increases approximately to the same level in the whole system and Bay control REC670 2.2 ANSI Application manual...

  • Page 256: Setting Guidelines

    (ROV2PTOV, 59N) has to be connected to a neutral or open delta winding. The setting must be above the highest occurring "normal" residual voltage and below the highest acceptable residual voltage for the capacitor. Bay control REC670 2.2 ANSI Application manual...

  • Page 257: Power Supply Quality

    The residual overvoltage will be three times the phase-to-ground voltage. See figure 95. ANSI07000190-1-en.vsd ANSI07000190 V1 EN-US Figure 95: Ground fault in Non-effectively grounded systems Bay control REC670 2.2 ANSI Application manual...

  • Page 258: Direct Grounded System

    In this connection the protection is fed by the voltage VN=V (single input). Section Analog inputs in the Application manual explains how the analog input needs to be set. Bay control REC670 2.2 ANSI Application manual...
  • Page 259 ResetTypeCrvn: Set reset type curve for step n. This parameter can be set: Instantaneous,Frozen time,Linearly decreased. The default setting is Instantaneous. tIResetn: Reset time for step n if inverse time delay is used, given in s. The default value is 25 ms. Bay control REC670 2.2 ANSI Application manual...

  • Page 260: Voltage Differential Protection Vdcptov (60)

    Difference indicates a fault, either short-circuited or open element in the capacitor bank. It is mainly used on elements with external fuses but can also be used on elements with Bay control REC670 2.2 ANSI Application manual...
  • Page 261 It will be an alternative for example, generator units where often two voltage transformers are supplied for measurement and excitation equipment. Bay control REC670 2.2 ANSI Application manual...

  • Page 262: Setting Guidelines

    The setting is normally done at site by evaluating the differential voltage achieved as a service value for each phase. The Bay control REC670 2.2 ANSI Application manual...
  • Page 263 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. Bay control REC670 2.2 ANSI Application manual...

  • Page 264: Loss Of Voltage Check Lovptuv (27)

    (LOVPTUV, 27), if some but not all voltage are low, to typical 5.0 seconds and set the time delay for enabling the function after restoration tRestore to 3 - 40 seconds. Bay control REC670 2.2 ANSI Application manual...

  • Page 265: Underfrequency Protection Saptuf (81)

    If the generator is still energized, the system will experience overexcitation, due to the low frequency. Bay control REC670 2.2 ANSI Application manual...

  • Page 266: Setting Guidelines

    The load shedding is then performed firstly in areas with low voltage magnitude, which normally are the most problematic areas, where the load shedding also is most efficient. 10.2 Overfrequency protection SAPTOF (81) IP15747-1 v3 Bay control REC670 2.2 ANSI Application manual...

  • Page 267: Identification

    VBase. The UBase value should be set as a primary phase-to-phase value. Some applications and related setting guidelines for the frequency level are given below: Bay control REC670 2.2 ANSI Application manual...

  • Page 268: Rate-Of-Change Of Frequency Protection Sapfrc (81)

    In such situations load shedding actions are required at a rather high frequency level, but in combination with a large negative rate-of-change of frequency the underfrequency protection can be used at a rather high setting. Bay control REC670 2.2 ANSI Application manual...

  • Page 269: Setting Guidelines

    - up to 3 Hz/s has been experienced when a small island was isolated from a large system. For more "normal" severe disturbances in large power systems, rate-of-change of frequency is much less, most often just a fraction of 1.0 Hz/s. Bay control REC670 2.2 ANSI Application manual...

  • Page 270: Frequency Time Accumulation Protection Function Ftaqfvr (81A)

    1, mechanical stress on the blades is approximately 300 times the nonresonant operating condition stress values. The stress magnification factor is shown in the typical resonance curve in Figure 99. Bay control REC670 2.2 ANSI Application manual...
  • Page 271 However, the IEEE/ANSI C37.106-2003 standard "Guide for Abnormal Frequency Protection for Power Generating Plants" provides some examples where the time accumulated within each frequency range is as shown in Figure 100. Bay control REC670 2.2 ANSI Application manual...

  • Page 272: Setting Guidelines

    Continuous operation of the machine at rated power outside voltage-frequency limits lead to increased rotor temperatures and reduction of insulation life. Setting of extent, duration and frequency of occurrence should be set according to manufacture’s requirements and recommendations. Bay control REC670 2.2 ANSI Application manual...
  • Page 273 FreqHighLimit and FreqLowLimit setting is derived from the generator manufacturer's operating requirements. Bay control REC670 2.2 ANSI Application manual...

  • Page 275: General Current And Voltage Protection Cvgapc

    Each CVGAPC function module has got four independent protection elements built into it. Two overcurrent steps with the following built-in features: Bay control REC670 2.2 ANSI Application manual...

  • Page 276: Current And Voltage Selection For Cvgapc Function

    (selected current quantity and selected voltage quantity). Bay control REC670 2.2 ANSI Application manual...
  • Page 277 Phase angle will be set to 0° all the time The user can select, by a setting parameter VoltageInput, to measure one of the following voltage quantities shown in table 29. Bay control REC670 2.2 ANSI Application manual...
  • Page 278 It is important to notice that the voltage selection from table is always applicable regardless the actual external VT connections. The three-phase VT inputs can be connected to IED as either three phase-to-groundvoltages VA, VB and VC or three Bay control REC670 2.2 ANSI Application manual...

  • Page 279: Base Quantities For Cvgapc Function

    Overcurrent protection (50, 51, 46, 67, 67N, 67Q) • Phase or phase-to-phase or Negative/Positive/Zero Sequence over/under voltage protection (27, 59, 47) • Special thermal overload protection (49) • Open Phase protection • Unbalance protection Generator protection Bay control REC670 2.2 ANSI Application manual...

  • Page 280: Inadvertent Generator Energization

    Of more critical concern, however, is the bearing, which can be damaged in a fraction of a second due to low oil pressure. Therefore, it is essential that high speed tripping is provided. This tripping should be almost instantaneous (< 100 ms). Bay control REC670 2.2 ANSI Application manual...

  • Page 281: Setting Guidelines

    Additionally, it can be used in applications on underground cables where zero-sequence impedance depends on the fault current return paths, but the cable negative-sequence impedance is Bay control REC670 2.2 ANSI Application manual...
  • Page 282 (10% is typical value) of measured PosSeq current in the power line. To do this the following settings within the same function shall be done: 16. Set EnRestrainCurr to On 17. Set RestrCurrInput to PosSeq 18. Set RestrCurrCoeff to value 0.1 Bay control REC670 2.2 ANSI Application manual...

  • Page 283: Negative Sequence Overcurrent Protection

    20s, and maximum continuous negative sequence rating of 7% of the generator rated current. The capability curve for a generator negative sequence overcurrent protection, often used world-wide, is defined by the ANSI standard in accordance with the following formula: Bay control REC670 2.2 ANSI Application manual...
  • Page 284 Connect three-phase generator currents to one CVGAPC instance (for example, GF01) Set parameter CurrentInput to value NegSeq 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 Bay control REC670 2.2 ANSI Application manual...
  • Page 285 Furthermore the other built-in protection elements can be used for other protection and alarming purposes (for example, use OC2 for negative sequence overcurrent alarm and OV1 for negative sequence overvoltage alarm). Bay control REC670 2.2 ANSI Application manual...

  • Page 286: Generator Stator Overload Protection In Accordance With Iec Or Ansi Standards

    3.5can be re-written in the following way without changing the value for the operate time of the generator stator overload IED: × æ ö ç ÷ × è ø (Equation 102) EQUATION1744-ANSI V1 EN-US Bay control REC670 2.2 ANSI Application manual...
  • Page 287 TD = 37.5 for the IEC standard or TD = 41.4 for the ANSI standard set A_OC1= 1/1.162 = 0.7432 set C_OC1= 1/1.162 = 0.7432 set B_OC1 = 0.0 and P_OC1 = 2.0 set PickupCurr_OC1 = 116% Bay control REC670 2.2 ANSI Application manual...

  • Page 288: Open Phase Protection For Transformer, Lines Or Generators And Circuit Breaker Head Flashover Protection For Generators

    For example, in case of generator application by enabling OC2 step with set pickup to 200% and time delay to 0.1s simple but effective protection against circuit breaker head flashover protection is achieved. Bay control REC670 2.2 ANSI Application manual...

  • Page 289: Voltage Restrained Overcurrent Protection For Generator And Step-Up Transformer

    11.1.3.6 Loss of excitation protection for a generator M13088-182 v3 Example will be given how by using positive sequence directional overcurrent protection element within a CVGAPC function, loss of excitation protection for a Bay control REC670 2.2 ANSI Application manual...
  • Page 290 RCA & ROA angles will be applicable for OC2 step if directional feature is enabled for this step as well. Figure shows overall protection characteristic Furthermore the other build-in protection elements can be used for other protection and alarming purposes. Bay control REC670 2.2 ANSI Application manual...
  • Page 291 Section 11 1MRK 511 401-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 101: Loss of excitation Bay control REC670 2.2 ANSI Application manual...

  • Page 293: Multipurpose Filter Smaihpac

    (e.g. multi-purpose protection function or overcurrent function or over-voltage function or over-power function). In this way many different protection applications can be arranged. For example the following protection, monitoring or measurement features can be realized: Bay control REC670 2.2 ANSI Application manual...
  • Page 294 IEC13000179-1-en.vsd IEC13000179 V1 EN-US Figure 102: Required ACT configuration Such overcurrent arrangement can be for example used to achieve the subsynchronous resonance protection for turbo generators. Bay control REC670 2.2 ANSI Application manual...

  • Page 295: Setting Guidelines

    50Hz signal the SMAI HPAC filter shall be set as given in the following table: Table 30: Proposed settings for SMAIHPAC I_HPAC_31_5Hz: SMAIHPAC:1 ConnectionType Ph — N SetFrequency 31.5 Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 296 ø (Equation 107) EQUATION13000032 V1 EN-US Thus if the following rules are followed when multi-purpose overcurrent stage one is set: • in > = 300A • 35566 118.55 • 0.64 • • • Bay control REC670 2.2 ANSI Application manual...
  • Page 297 PosSeq RestrCurrCoeff 0.00 RCADir ROADir LowVolt_VM Setting Group1 Operation_OC1 StartCurr_OC1 30.0 CurrMult_OC1 CurveType_OC1 Programmable tDef_OC1 0.00 k_OC1 1.00 tMin1 tMin_OC1 1.40 ResCrvType_OC1 Instantaneous tResetDef_OC1 0.00 P_OC1 1.000 A_OC1 118.55 B_OC1 0.640 C_OC1 0.000 Bay control REC670 2.2 ANSI Application manual...

  • Page 299: Current Circuit Supervision (87)

    It can also damage the insulation and cause new problems. The application shall, thus, be done with this in consideration, especially if the protection functions are blocked. Bay control REC670 2.2 ANSI Application manual...

  • Page 300: Setting Guidelines

    IED. It is possible to use different measures to prevent such unwanted operations. Miniature circuit breakers in the voltage measuring circuits should be located as close as possible Bay control REC670 2.2 ANSI Application manual...

  • Page 301: Setting Guidelines

    Common base IED values for primary current (IBase), primary voltage (VBase) and primary power (SBase) are set in Global Base Values GBASVAL. The setting GlobalBaseSel is used to select a particular GBASVAL and used its base values. Bay control REC670 2.2 ANSI Application manual...

  • Page 302: Setting Of Common Parameters

    Negative sequence based M13683-17 v9 The relay setting value 3V2PU is given in percentage of the base voltage VBase and should not be set lower than the value that is calculated according to equation 108. Bay control REC670 2.2 ANSI Application manual...

  • Page 303: Zero Sequence Based

    The setting of the current limit 3I0PU is done in percentage of IBase. The setting of pickup must be higher than the normal unbalance current that might exist in the system. The setting can be calculated according to equation 111. Bay control REC670 2.2 ANSI Application manual...

  • Page 304: Dead Line Detection

    A 5...10% lower value is recommended. 13.2.3.6 Dead line detection M13683-78 v4 The condition for operation of the dead line detection is set by the parameters IDLDPU for the current threshold and UDLD< for the voltage threshold. Bay control REC670 2.2 ANSI Application manual...

  • Page 305: Fuse Failure Supervision Vdspvc (60)

    VDSPVC output can be configured to block voltage dependent protection functions such as high-speed distance protection, undervoltage relays, underimpedance relays and so on. Bay control REC670 2.2 ANSI Application manual...

  • Page 306: Setting Guidelines

    The parameters for Fuse failure supervision VDSPVC are set via the local HMI or PCM600. GUID-0B298162-C939-47E4-A89B-7E6BD7BEBB2C v2 The voltage input type (phase-to-phase or phase-to-neutral) is selected using ConTypeMain and ConTypePilot parameters, for main and pilot fuse groups respectively. Bay control REC670 2.2 ANSI Application manual...
  • Page 307 When SealIn is set to On and the fuse failure has last for more than 5 seconds, the blocked protection functions will remain blocked until normal voltage conditions are restored above the VSealIn setting. The fuse failure outputs are deactivated when the normal voltage conditions are restored. Bay control REC670 2.2 ANSI Application manual...

  • Page 309: Synchronism Check, Energizing Check, And Synchronizing Sesrsyn (25)

    The synchronizing function measures the difference between the V-Line and the V- Bus. It operates and enables a closing command to the circuit breaker when the calculated closing angle is equal to the measured phase angle and the following conditions are simultaneously fulfilled: Bay control REC670 2.2 ANSI Application manual...
  • Page 310 CloseAngleMax = 30 degrees [max with (BusFrequency - [default value] value] LineFrequency) 0.040 0.080 1.000 0.050 0.100 0.800 0.080 0.160 0.500 0.200 0.400 0.200 0.400 0.810 0.100 1.000 0.080 0.800 0.050 1.000 0.040 Bay control REC670 2.2 ANSI Application manual...

  • Page 311: Synchronism Check

    The synchronism check function measures the conditions across the circuit breaker and compares them to set limits. Output is generated only when all measured conditions are within their set limits simultaneously. The check consists of: Bay control REC670 2.2 ANSI Application manual...
  • Page 312 In this case it should be safer to close when the phase angle difference is smaller. To fulfill the above requirements the synchronism check function is provided with duplicate settings, one for steady (Manual) conditions and one for operation under disturbed conditions (Auto). Bay control REC670 2.2 ANSI Application manual...

  • Page 313: Energizing Check

    CB B is energized (DLLB) from substation 1 via the circuit breaker A and energization of station 2 is done by CB B energization check device for that breaker DBLL. (or Both). Bay control REC670 2.2 ANSI Application manual...

  • Page 314: Voltage Selection

    The voltage selection function is used for the connection of appropriate voltages to the synchronism check, synchronizing and energizing check functions. For example, when the IED is used in a double bus arrangement, the voltage that should be selected Bay control REC670 2.2 ANSI Application manual...

  • Page 315: 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 316: Application Examples

    The input used below in example are typical and can be changed by use of configuration and signal matrix tools. The SESRSYN and connected SMAI function block instances must have the same cycle time in the application configuration. Bay control REC670 2.2 ANSI Application manual...

  • Page 317: Single Circuit Breaker With Single Busbar

    The voltage from busbar VT is connected to V3PB1 and the voltage from the line VT is connected to V3PL1. The conditions of the VT fuses shall also be connected as shown above. The voltage selection parameter CBConfig is set to No voltage sel. Bay control REC670 2.2 ANSI Application manual...

  • Page 318: Single Circuit Breaker With Double Busbar, External Voltage Selection

    This means that the connections to the function block will be the same as for the single busbar arrangement. The voltage selection parameter CBConfig is set to No voltage sel. Bay control REC670 2.2 ANSI Application manual...

  • Page 319: Single Circuit Breaker With Double Busbar, Internal Voltage Selection

    V3PB1 and the voltage from busbar 2 is connected to V3PB2. The voltage from the line VT is connected to V3PL1. The positions of the disconnectors and VT fuses shall be connected as shown in figure 110. The voltage selection parameter CBConfig is set to Double bus. Bay control REC670 2.2 ANSI Application manual...

  • Page 320: Double Circuit Breaker

    TSTSYNCH FRDIFFM TSTSC PHDIFFM TSTENERG INADVCLS AENMODE VDIFFME MENMODE FRDIFFME PHDIFFME Vbus VLine MODEAEN MODEMEN ANSI10000096-1-en.vsd ANSI10000096 V1 EN-US Figure 111: Connections of the SESRSYN (25) function block in a double breaker arrangement Bay control REC670 2.2 ANSI Application manual...

  • Page 321: Breaker-And-A-Half

    VT is connected to V3PL2 on all three function blocks. The positions of the disconnectors and VT fuses shall be connected as shown in Figure 112. Bay control REC670 2.2 ANSI Application manual...
  • Page 322 INADVCLS AENMODE VDIFFME MENMODE FRDIFFME PHDIFFME Vbus VLine MODEAEN MODEMEN Tie CB ANSI10000097-1-en.vsd ANSI10000097 V1 EN-US Figure 112: Connections of the SESRSYN (25) function block in a breaker-and-a-half arrangement with internal voltage selection Bay control REC670 2.2 ANSI Application manual...
  • Page 323 Setting CBConfig = 1 1/2 bus alt. CB If only two SESRSYN functions are provided in the same IED, the connections and settings are according to the SESRSYN functions for WA1_QA1 and TIE_QA1. Bay control REC670 2.2 ANSI Application manual...

  • Page 324: Setting Guidelines

    2 respectively, which can be a single-phase (phase-neutral), two-phase (phase- phase) or a positive sequence voltage. CBConfig This configuration setting is used to define type of voltage selection. Type of voltage selection can be selected as: Bay control REC670 2.2 ANSI Application manual...
  • Page 325 For frequency differences lower than this value, the systems are considered to be in parallel. A typical value for FreqDiffMin is 10 mHz. Generally, the value should be low if both synchronizing and synchrocheck functions Bay control REC670 2.2 ANSI Application manual...
  • Page 326 FreqDiffMin, which will decide how long it will take maximum to reach phase equality. At the setting of 10 mHz, the beat time is 100 seconds and the setting would thus need to be at least tMinSynch plus 100 seconds. If the network frequencies are Bay control REC670 2.2 ANSI Application manual...
  • Page 327 A typical maximum value in heavy-loaded networks can be 45 degrees, whereas in most networks the maximum occurring angle is below 25 degrees. The PhaseDiffM setting is a limitation to Bay control REC670 2.2 ANSI Application manual...
  • Page 328 The threshold voltages VLiveBusEnerg and VLiveLineEnerg have to be set lower than the value at which the network is considered to be energized. A typical value can be 80% of the base voltages. VDeadBusEnerg and VDeadLineEnerg Bay control REC670 2.2 ANSI Application manual...

  • Page 329: Smbrrec (79)

    IP14559-1 v6 14.2.1 Identification M14890-1 v7 Function Description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Autorecloser for 1 phase, 2 phase and/or 3 SMBRREC phase 5(0 -->1) IEC15000204 V1 EN-US Bay control REC670 2.2 ANSI Application manual...

  • Page 330: Application

    Closing time Break time Fault duration Fault duration AR open time for breaker Set AR open time Reset time Auto-reclosing function en04000146_ansi.vsd ANSI04000146 V1 EN-US Figure 113: Single-shot automatic reclosing at a permanent fault Bay control REC670 2.2 ANSI Application manual...
  • Page 331 One auto recloser per CB is recommended. Arranged in such a way, that sequential reclosing of the two CBs can be arranged with a priority circuit available in the auto recloser. In case of a permanent fault and unsuccessful reclosing of the first Bay control REC670 2.2 ANSI Application manual...
  • Page 332 This inhibit can, for example, be done from an auto recloser for 3-phase operation in progress signal. Bay control REC670 2.2 ANSI Application manual...

  • Page 333: Auto Reclosing Operation Off And On

    READY output is activated (high). Then the auto recloser is ready to accept a start. Bay control REC670 2.2 ANSI Application manual...

  • Page 334: Initiate Auto Reclosing And Conditions For Start Of A Reclosing Cycle

    Blocking of the auto recloser M12391-103 v4 Auto reclose attempts are expected to take place only for faults on the own line. The auto recloser must be blocked by activating the INHIBIT input for the following conditions: Bay control REC670 2.2 ANSI Application manual...

  • Page 335: Control Of The Auto Reclosing Dead Time For Shot 1

    This start pulse duration time is controlled by setting LongStartInhib. When start pulse duration signal is longer than set maximum start pulse duration, the auto reclosing sequence interrupts in the same way as for a signal to the INHIBIT input. Bay control REC670 2.2 ANSI Application manual...

  • Page 336: Maximum Number Of Reclosing Shots

    While any of the auto reclosing dead time timers are running, the INPROGR output is activated. When the dead time runs out, the respective internal signal is transmitted to the output module for further checks and to issue a breaker closing command. Bay control REC670 2.2 ANSI Application manual...

  • Page 337: Armode = 1/2Ph , 1-Phase Or 2-Phase Reclosing In The First Shot

    No more shots are attempted. The expression “1*2/3ph” should be understood as “Only one shot at two-pole or three-pole auto reclosing”. Bay control REC670 2.2 ANSI Application manual...

  • Page 338: External Selection Of Auto Reclosing Mode

    (BTIGAPC). The connection example for selection of the auto reclosing mode is shown in Figure 114. Bay control REC670 2.2 ANSI Application manual...

  • Page 339: Auto Reclosing Reset Timer

    START or TRSOTF input signal appears, after the circuit breaker closing command, the UNSUCCL output (unsuccessful reclosing) is set high. The timer for the first shot can no longer be started. Depending on the set number of auto reclosing shots further shots Bay control REC670 2.2 ANSI Application manual...

  • Page 340: Lock-Out Initiation

    An example of lock-out logic. Bay control REC670 2.2 ANSI Application manual...

  • Page 341: Evolving Fault

    (TR3P). The auto recloser will start a single-phase auto reclosing sequence, if programmed to do so. At the evolving fault clearance there will be a new START signal and three-phase trip information, TR3P. The single-phase auto reclosing sequence will Bay control REC670 2.2 ANSI Application manual...

  • Page 342: Automatic Continuation Of The Auto Reclosing Sequence

    Auto recloser function parameters are set via the local HMI or Parameter Setting Tool (PST). Parameter Setting Tool is a part of PCM600. Recommendations for input signals M12399-7 v10 Please see Figure 117, Figure and Figure and default factory configuration for examples. Bay control REC670 2.2 ANSI Application manual...
  • Page 343 The selected mode is reported as an integer on the MODE output. ON and OFF These inputs can be connected to binary inputs or to a communication interface block for external control. Bay control REC670 2.2 ANSI Application manual...
  • Page 344 This input is connected to the internal synchronism check function when required or to an external device for synchronism. If neither internal nor external synchronism or energizing check is required, it can be connected to a permanently high source, TRUE. Bay control REC670 2.2 ANSI Application manual...
  • Page 345 ZONESTEP input. This functionality is controlled by the setting ZoneSeqCoord. Recommendations for output signals M12399-46 v9 Please see Figure 117, Figure and Figure and default factory configuration for examples. Bay control REC670 2.2 ANSI Application manual...
  • Page 346 Indicates the total number of auto reclosing shots made. INHIBOUT If the INHIBIT input is activated it is reported on the INHIBOUT output. INPROGR Indicates that an auto recloser sequence is in progress, from start until circuit breaker close command. Bay control REC670 2.2 ANSI Application manual...
  • Page 347 Wait from master is used in high priority units to hold back auto reclosing of the low priority unit during sequential auto reclosing. Refer to the recommendation for multi- breaker arrangements in Figure 119. Bay control REC670 2.2 ANSI Application manual...
  • Page 348 TRSOTF ZMQPDIS (21)--TRIP 3PT2 3PT3 THOLHOLD 3PT4 TR2P 3PT5 TRUE TR3P SESRSYN (25)-AUTOOK SYNC WAIT RSTCOUNT WFMASTER ANSI04000135-3-en.vsd ANSI04000135 V3 EN-US Figure 117: Example of I/O-signal connections at a three-phase auto reclosing sequence Bay control REC670 2.2 ANSI Application manual...
  • Page 349 The reason for shortening the time, for the normal dead timers with the value of tSlaveDeadTime, is to give the slave permission to react almost immediately when the WAIT input resets. The mimimum settable time Bay control REC670 2.2 ANSI Application manual...
  • Page 350 If the High priority circuit breaker is not closed the High priority moves to the low priority circuit breaker. Bay control REC670 2.2 ANSI Application manual...

  • Page 351: Auto Recloser Settings

    This setting guideline describes the settings of the auto recloser using the LHMI. The settings for the auto recloser are found under Main menu/Settings/IED Settings/ Control/AutoRecloser(79,5(0->1))/SMBRREC(79,5(0->)):X and have been divided into four different setting groups: General, CircuitBreaker, DeadTime and MasterSlave. Bay control REC670 2.2 ANSI Application manual...
  • Page 352 To ensure reliable interruption and temporary blocking of the auto recloser a resetting time delay tInhibit is used. The auto recloser will be blocked this time after the deactivation of the INHIBIT input. A typical resetting delay is 5.0 s. Bay control REC670 2.2 ANSI Application manual...
  • Page 353 The circuit breaker closing command should be long enough to ensure reliable operation of the circuit breaker. The circuit breaker closing command pulse has a duration set by the tPulse setting. A typical setting may be tPulse = 200 ms. A longer Bay control REC670 2.2 ANSI Application manual...
  • Page 354 (shots) can be motivated. t1 1Ph, t1 2Ph, t1 3Ph: There are separate settings for the first shot for single-, two- and three-phase auto reclosing dead times. Bay control REC670 2.2 ANSI Application manual...
  • Page 355 Typical setting is 2sec. tSlaveDeadTime: When activating the WAIT input, in the auto recloser set as slave, every dead timer is changed to the value of setting tSlaveDeadTime and holds back the Bay control REC670 2.2 ANSI Application manual...

  • Page 356: Apparatus Control Apc

    The commands to an apparatus can be initiated from the Control Centre (CC), the station HMI or the local HMI on the IED front. Bay control REC670 2.2 ANSI Application manual...
  • Page 357 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 Bay control REC670 2.2 ANSI Application manual...
  • Page 358 GOOSE receive for switching device GOOSEXLNRCV • Proxy for signals from switching device via GOOSE XLNPROXY The extension of the signal flow and the usage of the GOOSE communication are shown in Figure 122. Bay control REC670 2.2 ANSI Application manual...
  • Page 359 Control IEC 61850 QCBAY SXCBR SCSWI SXCBR SXCBR SCILO SCSWI SXSWI SCILO en05000116_ansi.vsd ANSI05000116 V1 EN-US Figure 121: Signal flow between apparatus control function blocks when all functions are situated within the IED Bay control REC670 2.2 ANSI Application manual...
  • Page 360 GOOSE over process bus Merging Unit XCBR -QB1 XCBR XCBR -QA1 XSWI -QB9 IEC16000070-1-EN.vsdx IEC16000070 V1 EN-US Figure 122: Signal flow between apparatus control functions with XCBR and XSWI located in a breaker IED Bay control REC670 2.2 ANSI Application manual...
  • Page 361 According to IEC 61850 standard the orCat attribute in originator category are defined Table 34 Table 34: orCat attribute according to IE C61850 Value Description not-supported bay-control station-control remote-control automatic-bay automatic-station automatic-remote maintenance process Bay control REC670 2.2 ANSI Application manual...

  • Page 362: Bay Control Qcbay

    QCBAY also provides blocking functions that can be distributed to different apparatuses within the bay. There are two different blocking alternatives: • Blocking of update of positions • Blocking of commands IEC13000016-2-en.vsd IEC13000016 V2 EN-US Figure 123: APC - Local remote function block Bay control REC670 2.2 ANSI Application manual...

  • Page 363: Switch Controller Scswi

    The intention with these functions is to represent the lowest level of a power-switching device with or without short circuit breaking capability, for example, circuit breakers, disconnectors, grounding switches etc. Bay control REC670 2.2 ANSI Application manual...

  • Page 364: Proxy For Signals From Switching Device Via Goose Xlnproxy

    To make it easy to choose which data to use for the XLNPROXY function, their usage is controlled by the connection of each data’s signal input and valid input. These connections are usually from the GOOSEXLNRCV function (see Figure and Figure 125). Bay control REC670 2.2 ANSI Application manual...
  • Page 365 Section 14 1MRK 511 401-UUS A Control IEC16000071 V1 EN-US Figure 124: Configuration with XLNPROXY and GOOSEXLNRCV where all the IEC 61850 modelled data is used, including selection Bay control REC670 2.2 ANSI Application manual...
  • Page 366 SCSWI function. This cause is also shown on the output L_CAUSE as indicated in the following table: Bay control REC670 2.2 ANSI Application manual...

  • Page 367: Reservation Function (Qcrsv And Resin)

    To ensure that the interlocking information is correct at the time of operation, a unique reservation method is available in the IEDs. With this reservation method, the bay that Bay control REC670 2.2 ANSI Application manual...
  • Page 368 The reservation can also be realized with external wiring according to the application example in Figure 127. This solution is realized with external auxiliary relays and extra binary inputs and outputs in each IED, but without use of function blocks QCRSV and RESIN. Bay control REC670 2.2 ANSI Application manual...

  • Page 369: Interaction Between Modules

    Application principle for an alternative reservation solution 14.3.2 Interaction between modules M16626-3 v8 A typical bay with apparatus control function consists of a combination of logical nodes or functions that are described here: Bay control REC670 2.2 ANSI Application manual...
  • Page 370 (energizing-check) is included. • The Generic Automatic Process Control function, GAPC, handles generic commands from the operator to the system. The overview of the interaction between these functions is shown in Figure below. Bay control REC670 2.2 ANSI Application manual...
  • Page 371 Close rel. (Not a LN) (Interlocking) Position Enable Enable open close Res. GAPC Open cmd granted (Generic Close cmd Automatic SXSWI SCSWI Open/Close Process (Disconnector) (Switching control) Control) Open/Close Position IEC05000120-3-EN.vsdx IEC05000120 V3 EN-US Bay control REC670 2.2 ANSI Application manual...
  • Page 372 Open cmd granted (Generic Close cmd Automatic SXSWI SCSWI Open/Close Process (Disconnector) (Switching control) Control) Open/Close Position ANSI05000120-2-en.vsd ANSI05000120 V2 EN-US Figure 129: Example overview of the interactions between functions in a typical Bay control REC670 2.2 ANSI Application manual...

  • Page 373: Setting Guidelines

    When the time has expired, the selected output signal is set to false and a cause-code is given. Bay control REC670 2.2 ANSI Application manual...

  • Page 374: Switch (Sxcbr/Sxswi)

    SuppressMidPos is set to On in the SCSWI function. If the parameter AdaptivePulse is set to Adaptive the command output pulse resets when a new correct end position is reached. If the parameter is set to Not adaptive the Bay control REC670 2.2 ANSI Application manual...

  • Page 375: Proxy For Signals From Switching Device Via Goose Xlnproxy

    In most cases, the same value can be used for both tStartMove and tIntermediate as in the source function. However, tStartMove may need to be increased to accommodate for the communication delays, mainly when representing a circuit breaker. Bay control REC670 2.2 ANSI Application manual...

  • Page 376: Bay Reserve (Qcrsv)

    (for example, < 1% of rated voltage). Paralleling of power transformers is not allowed. Grounding switches are allowed to connect and disconnect grounding of isolated points. Due to capacitive or inductive coupling there may be some voltage (for Bay control REC670 2.2 ANSI Application manual...

  • Page 377: Configuration Guidelines

    They also describe the configuration settings. The inputs for delivery specific conditions (Qx_EXy) are set to 1=TRUE if they are not used, except in the following cases: • 989_EX2 and 989_EX4 in modules BH_LINE_A and BH_LINE_B • 152_EX3 in module AB_TRAFO Bay control REC670 2.2 ANSI Application manual...

  • Page 378: Interlocking For Line Bay Abc_Line (3)

    All line disconnectors on bypass WA7 except in the own bay are open. VP_BB7_D The switch status of disconnectors on bypass busbar WA7 are valid. EXDU_BPB No transmission error from any bay containing disconnectors on bypass busbar Bay control REC670 2.2 ANSI Application manual...

  • Page 379: Signals From Bus-Coupler

    Signals from bus-coupler M13560-31 v4 If the busbar is divided by bus-section disconnectors into bus sections, the busbar- busbar connection could exist via the bus-section disconnector and bus-coupler within the other bus section. Bay control REC670 2.2 ANSI Application manual...
  • Page 380 The switch status of BC_12 is valid. VPBC17TR The switch status of BC_17 is valid. VPBC27TR The switch status of BC_27 is valid. EXDU_BC No transmission error from the bay that contains the above information. Bay control REC670 2.2 ANSI Application manual...
  • Page 381 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 line bay in section 1, these conditions are valid: Bay control REC670 2.2 ANSI Application manual...
  • Page 382 Signals to a line bay in section 1 from the bus-coupler bays in each section For a line bay in section 2, the same conditions as above are valid by changing section 1 to section 2 and vice versa. Bay control REC670 2.2 ANSI Application manual...

  • Page 383: Configuration Setting

    0 and 1 are designated 0=FALSE and 1=TRUE: • 289_OP = 1 • 289_CL = 0 • 2189G_OP = 1 • 2189G_CL = 0 • BC_12_CL = 0 • BC_27_OP = 1 • BC_27_CL = 0 • VP_BC_12 = 1 Bay control REC670 2.2 ANSI Application manual...

  • Page 384: Interlocking For Bus-Coupler Bay Abc_Bc (3)

    No transmission error from any bay connected to the WA1/WA2 busbars. These signals from each line bay (ABC_LINE), each transformer bay (AB_TRAFO), and bus-coupler bay (ABC_BC), except the own bus-coupler bay are needed: Bay control REC670 2.2 ANSI Application manual...
  • Page 385 BBTR above, add this logic: Section 1 Section 2 (WA1)A1 (WA2)B1 (WA7)C A1A2_DC(BS) ABC_BC B1B2_DC(BS) ABC_LINE ABC_BC ABC_LINE AB_TRAFO en04000482_ansi.vsd ANSI04000482 V1 EN-US Figure 136: Busbars divided by bus-section disconnectors (circuit breakers) Bay control REC670 2.2 ANSI Application manual...
  • Page 386 Signals to a bus-coupler bay in section 1 from any bays in each section For a bus-coupler bay in section 2, the same conditions as above are valid by changing section 1 to section 2 and vice versa. Bay control REC670 2.2 ANSI Application manual...

  • Page 387: Signals From Bus-Coupler

    A1A2_DC and B1B2_DC. Signal DCCLTR The bus-section disconnector is closed. VPDCTR The switch status of bus-section disconnector DC is valid. EXDU_DC No transmission error from the bay that contains the above information. Bay control REC670 2.2 ANSI Application manual...

  • Page 388: Configuration Setting

    In the functional block diagram, 0 and 1 are designated 0=FALSE and 1=TRUE: • 289_OP = 1 • 289_CL = 0 • 789_OP = 1 • 789_CL = 0 Bay control REC670 2.2 ANSI Application manual...

  • Page 389: Interlocking For Transformer Bay Ab_Trafo (3)

    The function is used when there is no disconnector between circuit breaker and transformer. Otherwise, the interlocking for line bay (ABC_LINE, 3) function can be used. This function can also be used in single busbar arrangements. Bay control REC670 2.2 ANSI Application manual...

  • Page 390: Signals From Bus-Coupler

    14.4.4.2 Signals from bus-coupler M13566-6 v4 If the busbar is divided by bus-section disconnectors into bus-sections, the busbar- busbar connection could exist via the bus-section disconnector and bus-coupler within the other bus-section. Bay control REC670 2.2 ANSI Application manual...

  • Page 391: Configuration Setting

    In the functional block diagram, 0 and 1 are designated 0=FALSE and 1=TRUE: • 289_OP = 1 • 289QB2_CL = 0 • 2189G_OP = 1 • 2189G_CL = 0 • BC_12_CL = 0 • VP_BC_12 = 1 Bay control REC670 2.2 ANSI Application manual...

  • Page 392: Interlocking For Bus-Section Breaker A1A2_Bs (3)

    Bay control REC670 2.2 ANSI Application manual...
  • Page 393 WA2. VPBC12TR The switch status of BC_12 is valid. EXDU_BC No transmission error from the bay that contains the above information. These signals from the bus-section circuit breaker bay (A1A2_BS, B1B2_BS) are needed. Bay control REC670 2.2 ANSI Application manual...
  • Page 394 EXDU_BC (sect.2) EXDU_12(bay 1/sect.1) ..EXDU_12 (bay n /sect.1) en04000490_ansi.vsd ANSI04000490 V1 EN-US Figure 144: Signals from any bays for a bus-section circuit breaker between sections A1 and A2 Bay control REC670 2.2 ANSI Application manual...

  • Page 395: Configuration Setting

    152 open circuit breaker is not used or the state for BBTR is set to open. That is, no busbar transfer is in progress in this bus-section: • BBTR_OP = 1 • VP_BBTR = 1 Bay control REC670 2.2 ANSI Application manual...

  • Page 396: Interlocking For Bus-Section Disconnector A1A2_Dc (3)

    B are used. Section 1 Section 2 (WA1)A1 (WA2)B1 (WA7)C A1A2_DC(BS) B1B2_DC(BS) ABC_BC ABC_LINE AB_TRAFO ABC_LINE AB_TRAFO en04000493_ansi.vsd ANSI04000493 V1 EN-US Figure 147: Busbars divided by bus-section disconnectors (circuit breakers) To derive the signals: Bay control REC670 2.2 ANSI Application manual...
  • Page 397 289 is open. VP189TR The switch status of 189 is valid. VP289TR The switch status of 289 is valid. EXDU_BS No transmission error from the bay BS (bus-section coupler bay) that contains the above information. Bay control REC670 2.2 ANSI Application manual...
  • Page 398 EXDU_BB (bay n/sect.A2) EXDU_DC (A2/A3) en04000495_ansi.vsd ANSI04000495 V1 EN-US Figure 149: Signals from any bays in section A2 to a bus-section disconnector For a bus-section disconnector, these conditions from the B1 busbar section are valid: Bay control REC670 2.2 ANSI Application manual...

  • Page 399: Signals In Double-Breaker Arrangement

    Signals in double-breaker arrangement M13542-80 v5 If the busbar is divided by bus-section disconnectors, the condition for the busbar disconnector bay no other disconnector connected to the bus-section must be made by a project-specific logic. Bay control REC670 2.2 ANSI Application manual...
  • Page 400 No transmission error from the bay that contains the above information. The logic is identical to the double busbar configuration “Signals in single breaker arrangement”. For a bus-section disconnector, these conditions from the A1 busbar section are valid: Bay control REC670 2.2 ANSI Application manual...
  • Page 401 EXDU_DB (bay n/sect.A2) en04000500_ansi.vsd ANSI04000500 V1 EN-US Figure 154: Signals from double-breaker bays in section A2 to a bus-section disconnector For a bus-section disconnector, these conditions from the B1 busbar section are valid: Bay control REC670 2.2 ANSI Application manual...

  • Page 402: Signals In Breaker And A Half Arrangement

    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. Bay control REC670 2.2 ANSI Application manual...

  • Page 403: Interlocking For Busbar Grounding Switch Bb_Es (3)

    158. en04000504.vsd ANSI04000504 V1 EN-US Figure 158: Switchyard layout BB_ES (3) M15053-4 v4 The signals from other bays connected to the module BB_ES are described below. Bay control REC670 2.2 ANSI Application manual...

  • Page 404: Signals In Single Breaker Arrangement

    These signals from each bus-section disconnector bay (A1A2_DC) are also needed. For B1B2_DC, corresponding signals from busbar B are used. The same type of module (A1A2_DC) is used for different busbars, that is, for both bus-section disconnectors A1A2_DC and B1B2_DC. Bay control REC670 2.2 ANSI Application manual...
  • Page 405 ANSI04000506 V1 EN-US Figure 160: Signals from any bays in section A1 to a busbar grounding switch in the same section For a busbar grounding switch, these conditions from the A2 busbar section are valid: Bay control REC670 2.2 ANSI Application manual...
  • Page 406 ANSI04000507 V1 EN-US Figure 161: Signals from any bays in section A2 to a busbar grounding switch in the same section For a busbar grounding switch, these conditions from the B1 busbar section are valid: Bay control REC670 2.2 ANSI Application manual...
  • Page 407 ..EXDU_BB (bay n/sect.B2) EXDU_DC (B1/B2) en04000509_ansi.vsd ANSI04000509 V1 EN-US Figure 163: Signals from any bays in section B2 to a busbar grounding switch in the same section Bay control REC670 2.2 ANSI Application manual...

  • Page 408: Signals In Double-Breaker Arrangement

    The switch status of all disconnectors on this part of the busbar are valid. EXDU_BB No transmission error from any bay that contains the above information. These signals from each double-breaker bay (DB_BUS) are needed: Bay control REC670 2.2 ANSI Application manual...

  • Page 409: Signals In Breaker And A Half Arrangement

    All disconnectors on this part of the busbar are open. VP_BB_DC The switch status of all disconnectors on this part of the busbar is valid. EXDU_BB No transmission error from any bay that contains the above information. Bay control REC670 2.2 ANSI Application manual...

  • Page 410: Interlocking For Double Cb Bay Db (3)

    M13584-6 v5 For application without 989 and 989G, just set the appropriate inputs to open state and disregard the outputs. In the functional block diagram, 0 and 1 are designated 0=FALSE and 1=TRUE: Bay control REC670 2.2 ANSI Application manual...

  • Page 411: Interlocking For Breaker-And-A-Half Diameter Bh (3)

    Interlocking for breaker-and-a-half diameter BH (3) IP14173-1 v3 14.4.9.1 Application M13570-3 v6 The interlocking for breaker-and-a-half diameter (BH_CONN(3), BH_LINE_A(3), BH_LINE_B(3)) functions are used for lines connected to a breaker-and-a-half diameter according to figure 168. Bay control REC670 2.2 ANSI Application manual...

  • Page 412: Configuration Setting

    For application without 989 and 989G, just set the appropriate inputs to open state and disregard the outputs. In the functional block diagram, 0 and 1 are designated 0=FALSE and 1=TRUE: • 989_OP = 1 • 989_CL = 0 • 989G_OP = 1 • 989G_CL = 0 Bay control REC670 2.2 ANSI Application manual...

  • Page 413: Voltage Control

    0.5-1.7%. The voltage control function is intended for control of power transformers with a motor driven on-load tap-changer. The function is designed to regulate the voltage at the Bay control REC670 2.2 ANSI Application manual...
  • Page 414 A raise or lower command is generated whenever the measured voltage, for a given period of time, deviates from the set target value by more than the preset deadband value (degree of insensitivity). A Bay control REC670 2.2 ANSI Application manual...
  • Page 415 Automatic voltage control for tap changer, TR1ATCC (90) for single control and TR8ATCC (90) for parallel control function block has three inputs I3P1, I3P2 and V3P2 corresponding to HV-current, LV-current and LV-voltage respectively. These Bay control REC670 2.2 ANSI Application manual...
  • Page 416 Thus, single-phase as well as, phase-phase or three- phase feeding on the LV-side is possible but it is commonly selected for current and voltage. Bay control REC670 2.2 ANSI Application manual...
  • Page 417 The analog input signals are normally common with other functions in the IED for example, protection functions. The LV-busbar voltage is designated V , the load current I and load point voltage V Bay control REC670 2.2 ANSI Application manual...
  • Page 418 This way of working is used by TR1ATCC (90) while the busbar voltage is within the security range defined by settings Vmin and Vmax. A situation where V falls outside this range will be regarded as an abnormal situation. Bay control REC670 2.2 ANSI Application manual...
  • Page 419 Constant (definite) time delay is independent of the voltage deviation. The inverse time characteristic for the first time delay follows the formulas: VB VSet (Equation 115) ANSIEQUATION2294 V1 EN-US (Equation 116) EQUATION1846-ANSI V1 EN-US Bay control REC670 2.2 ANSI Application manual...
  • Page 420 (Constant/Inverse). Inverse time characteristic for the second time delay follows the similar formulas as for the first time delay, but the t2 setting is used instead of t1. Bay control REC670 2.2 ANSI Application manual...
  • Page 421 >V can be caused by a capacitive load condition, and if the wish is to allow for a situation like that, the limitation can be removed by setting the parameter OperCapaLDC to Enabled. Bay control REC670 2.2 ANSI Application manual...
  • Page 422 LVAConst1, LVAConst2, LVAConst3 and LVAConst4. The inputs are activated with a pulse, and the latest activation of anyone of the four inputs is valid. Activation of the input LVARESET in TR1ATCC (90) or TR8ATCC (90) block, brings the voltage setpoint back to Vset. Bay control REC670 2.2 ANSI Application manual...
  • Page 423 If they would each be in automatic voltage control for single transformer that is, each of them regulating the voltage on the LV busbar individually without any further measures taken, then the following could happen. Bay control REC670 2.2 ANSI Application manual...
  • Page 424 VRAISE/VLOWER commands individually for each follower when setting MFMode has the value Follow Tap. Selecting a master is made by activating the input FORCMAST in TR8ATCC (90) function block. Deselecting a master is made by activating the input RSTMAST. These Bay control REC670 2.2 ANSI Application manual...
  • Page 425 The very same function can also be used here to control the voltage at a load point inside the transformer, by choosing a negative value of the parameter Xline. Bay control REC670 2.2 ANSI Application manual...
  • Page 426 (highest no load voltage) will be the source of this circulating current. Figure below shows this situation with T1 being on a higher tap than T2. Bay control REC670 2.2 ANSI Application manual...
  • Page 427 Voltage control of parallel transformers with the circulating current method means minimizing of the circulating current at a given voltage target value, thereby achieving: Bay control REC670 2.2 ANSI Application manual...
  • Page 428 When the circulating current is known, it is possible to calculate a no-load voltage for each transformer in the parallel group. To do that the magnitude of the circulating current in each bay, is first converted to a voltage deviation, V , with equation 119: Bay control REC670 2.2 ANSI Application manual...
  • Page 429 USETPAR under Main menu/Test/Function status/Control/ TransformerVoltageControl(ATCC,90)/TR8ATCC:x. The use of mean VSet is recommended for parallel operation with the circulating current method, especially in cases when Load Voltage Adjustment is also used. Bay control REC670 2.2 ANSI Application manual...
  • Page 430 Homing (operation with the circulating current method) SEMOD159053-205 v3 This function can be used with parallel operation of power transformers using the circulating current method. It makes possible to keep a transformer energized from the Bay control REC670 2.2 ANSI Application manual...
  • Page 431 As the name indicates they will adapt to the manual tapping of the transformer that has been put in manual mode. Bay control REC670 2.2 ANSI Application manual...
  • Page 432 CT measuring point and the power transformer or at a tertiary winding of the power transformer, see figure 177. In a situation like this, the capacitive current will interact in opposite way in the different ATCCs with regard to Bay control REC670 2.2 ANSI Application manual...
  • Page 433 LV and the HV side. In the latter case, the part of I that goes to the HV side will divide between the two transformers and it will be measured with opposite direction Bay control REC670 2.2 ANSI Application manual...
  • Page 434 HV-side to the LV-side as shown in figure 178. The reactive power Q is forward when the total load on the LV side is inductive ( reactance) as shown in figure 178. Bay control REC670 2.2 ANSI Application manual...
  • Page 435 T3 is disconnected which will lead to T3 sending the DISC=1 signal to the other two parallel TR8ATCC (90) modules (T1 and T2) in the group. Also see table 39. Bay control REC670 2.2 ANSI Application manual...
  • Page 436 One is the data set that needs to be transmitted to other TR8ATCC (90) blocks in the same parallel group, and the other is the data set that is transferred to the Bay control REC670 2.2 ANSI Application manual...
  • Page 437 Manual configuration of VCTR GOOSE data set is required. Note that both data value attributes and quality attributes have to be mapped. The following data objects must be configured: • BusV • LodAIm • LodARe • PosRel Bay control REC670 2.2 ANSI Application manual...
  • Page 438 The purpose of blocking is to prevent the tap changer from operating under conditions that can damage it, or otherwise when the conditions are such that power system related limits would be exceeded or when, for example the conditions for automatic control are not met. Bay control REC670 2.2 ANSI Application manual...
  • Page 439 The outputs VBLK and TOTBLK or AUTOBLK will be activated depending on the actual parameter setting. Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 440 This error condition can be reset by the input RESETERR on TCMYLTC (84) function block, or alternatively by changing control mode of TR1ATCC (90) or TR8ATCC (90) function to Manual and then back to Automatic. Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 441 This error condition can be reset by the input RESETERR on TCMYLTC (84) function block, or alternatively by changing control mode of TR1ATCC (90) or TR8ATCC (90) function to Manual and then back to Automatic. Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 442 Usually this can be achieved by manual control of the tap changers. TR1ATCC (90) or TR8ATCC (90) outputs ICIRC and TOTBLK or AUTOBLK will be activated depending on the actual parameter setting. Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 443 The voltage control function can input) be blocked for automatic control via the binary input EAUTOBLK on TR1ATCC (90) or TR8ATCC (90) function block. The output AUTOBLK will be activated. Deblocking is made via the input DEBLKAUT. Bay control REC670 2.2 ANSI Application manual...
  • Page 444 TR8ATCCs (90) working in parallel with that module, shall block their operation as well. To achieve this, the affected TR8ATCC (90) function broadcasts a mutual block to the other group members via the horizontal communication. When mutual Bay control REC670 2.2 ANSI Application manual...
  • Page 445 It should be noted that partial blocking will not cause mutual blocking. TR8ATCC (90), which is the “source” of the mutual blocking will set its AUTOBLK output as well as the output which corresponds to the actual blocking condition for Bay control REC670 2.2 ANSI Application manual...
  • Page 446 ( set by setting tTCTimeout ) (settable in PST/local HMI) is also started, and the idea is then that this timer shall have a setting that covers, with some margin, a normal tap changer operation. Bay control REC670 2.2 ANSI Application manual...
  • Page 447 The advantage with monitoring the TCINPROG signal in this case is thus that resetting of TR1ATCC (90) or TR8ATCC (90) can sometimes be made faster, which in turn makes the system ready for consecutive commands in a shorter time. Bay control REC670 2.2 ANSI Application manual...
  • Page 448 NoOpWindow within the time sliding window specified via the setting parameter tWindowHunt. Only active in automatic mode. Hunting can be the result of a narrow deadband setting or some other abnormalities in the control system. Bay control REC670 2.2 ANSI Application manual...

  • Page 449: Setting Guidelines

    Thus, transformers that can be part of the same parallel group must have unique identities. Moreover, all transformers that communicate over the same horizontal communication (GOOSE) must have unique identities. Xr2: The reactance of the transformer in primary ohms referred to the LV side. Bay control REC670 2.2 ANSI Application manual...

  • Page 450: Tr1Atcc (90) Or Tr8Atcc (90) Setting Group

    UVblock and Vmin. 14.5.3.2 TR1ATCC (90) or TR8ATCC (90) Setting group SEMOD171501-22 v8 General Operation: Switching automatic voltage control for tap changer, TR1ATCC (90) for single control and TR8ATCC (90) for parallel control function Enabled/Disabled. Bay control REC670 2.2 ANSI Application manual...
  • Page 451 VDeadbandInner: Setting value for one half of the inner deadband, to be set in percent of VBase. The inner deadband is symmetrical around VSet, see section "Automatic voltage control for a single transformer",figure 170. In that figure VDeadbandInner is Bay control REC670 2.2 ANSI Application manual...
  • Page 452 That situation can be caused by a capacitive load. When the line voltage drop compensation function is used for parallel control with the reverse reactance method, then OperCapaLDC must always be set Enabled. Bay control REC670 2.2 ANSI Application manual...
  • Page 453 The automatic tap change control regulates the voltage towards a set target value, representing a voltage magnitude, without considering the phase angle. Thus, V as well as V and also the dashed line could all be said to be on the target value. Bay control REC670 2.2 ANSI Application manual...
  • Page 454 Rline/Xline is not adjusted. shows an example of this where the settings of Rline and Xline for j = 11° Figure has been applied with a different value of j (j = 30°). from figure Bay control REC670 2.2 ANSI Application manual...
  • Page 455 This kind of response is easily achieved by setting a high Xline value, as was discussed above, and the disadvantage is then a high susceptibility to changing power factor. Bay control REC670 2.2 ANSI Application manual...
  • Page 456 DayHuntDetect: Setting of the number of tap changer operations required during the last 24 hours (sliding window) to activate the signal DAYHUNT HourHuntDetect: Setting of the number of tap changer operations required during the last hour (sliding window) to activate the signal HOURHUNT Bay control REC670 2.2 ANSI Application manual...
  • Page 457 P< means pickup for all values to the left of the setting. Reference is made to figure for definition of forward and reverse direction of power through the transformer. P< en06000635_2_en.vsd IEC06000635 V2 EN-US Figure 184: Setting of a positive value for P< Bay control REC670 2.2 ANSI Application manual...
  • Page 458 V which corresponds to the dead-band setting. • p is the tap step (in percent of transformer nominal voltage). Bay control REC670 2.2 ANSI Application manual...
  • Page 459 OUTOFPOS in the Automatic voltage control for tap changer, parallel control TR8ATCC (90) function block of the follower will be activated after the time delay tMFPosDiff. tMFPosDiff: Time delay for activation of the output OUTOFPOS. Bay control REC670 2.2 ANSI Application manual...

  • Page 460: Tcmyltc And Tclyltc (84) General Settings

    Length of the command pulse (VRAISE/VLOWER) to the tap changer. It shall be noticed that this pulse has a fixed extension of 4 seconds that adds to the setting value of tPulseDur. Bay control REC670 2.2 ANSI Application manual...

  • Page 461: Logic Rotating Switch For Function Selection And Lhmi Presentation Slgapc

    14.6.3 Setting guidelines SEMOD115063-294 v6 The following settings are available for the Logic rotating switch for function selection and LHMI presentation (SLGAPC) function: Operation: Sets the operation of the function Enabled or Disabled. Bay control REC670 2.2 ANSI Application manual...

  • Page 462: Selector Mini Switch Vsgapc

    An example where VSGAPC is configured to switch Autorecloser enabled–disabled from a button symbol on the local HMI is shown in figure185. The Close and Open buttons on the local HMI are normally used for enable–disable operations of the circuit breaker. Bay control REC670 2.2 ANSI Application manual...

  • Page 463: Setting Guidelines

    Generic communication function for Double Point indication (DPGAPC) function block is used to send double point position indication to other systems, equipment or functions in the substation through IEC 61850-8-1 or other communication protocols. Bay control REC670 2.2 ANSI Application manual...

  • Page 464: Setting Guidelines

    Open Closed Bad State 14.8.3 Setting guidelines SEMOD55398-5 v4 The function does not have any parameters available in the local HMI or PCM600. 14.9 Single point generic control 8 signals SPC8GAPC SEMOD176448-1 v3 Bay control REC670 2.2 ANSI Application manual...

  • Page 465: Identification

    PulseModex: decides if the command signal for output x is Latched (steady) or Pulsed. tPulsex: if PulseModex is set to Pulsed, then tPulsex will set the length of the pulse (in seconds). 14.10 AutomationBits, command function for DNP3.0 AUTOBITS SEMOD158589-1 v3 Bay control REC670 2.2 ANSI Application manual...

  • Page 466: Identification

    PCM600. 14.11 Single command, 16 signals SINGLECMD SEMOD119849-1 v2 14.11.1 Identification GUID-2217CCC2-5581-407F-A4BC-266CD6808984 v1 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Single command, 16 signals SINGLECMD Bay control REC670 2.2 ANSI Application manual...

  • Page 467: Application

    Application example showing a logic diagram for control of a circuit breaker via configuration logic circuits Figure and figure show other ways to control functions, which require steady Enabled/Disabled signals. Here, the output is used to control built-in functions or external devices. Bay control REC670 2.2 ANSI Application manual...

  • Page 468: Setting Guidelines

    Application example showing a logic diagram for control of external devices via configuration logic circuits 14.11.3 Setting guidelines M12448-3 v2 The parameters for Single command, 16 signals (SINGLECMD) are set via the local HMI or PCM600. Bay control REC670 2.2 ANSI Application manual...
  • Page 469 Pulse, gives a pulse with 100 ms duration, if a value sent from the station level is changed from 0 to 1. That means the configured logic connected to the command function block may not have a cycle time longer than the cycle time for the command function block. Bay control REC670 2.2 ANSI Application manual...

  • Page 471: Protection Zcpsch(85)

    The logic supports the following communications schemes: • blocking schemes (blocking and delta blocking) • permissive schemes (overreaching and underreaching) • unblocking scheme and direct intertrip Bay control REC670 2.2 ANSI Application manual...

  • Page 472: Blocking Schemes

    A security margin of at least 10 ms should be considered. The timer tSendMin for prolonging the send signal is proposed to set to zero. Bay control REC670 2.2 ANSI Application manual...

  • Page 473: Delta Blocking Scheme

    Inadequate speed or dependability can cause spurious tripping for external faults. Inadequate security can cause delayed tripping for internal faults. Bay control REC670 2.2 ANSI Application manual...

  • Page 474: Permissive Schemes

    A general requirement on permissive schemes is that it shall be fast and secure. If the sending signal(s) is issued by underreaching or overreaching zone, it is divided into a permissive underreach or permissive overreach scheme. Bay control REC670 2.2 ANSI Application manual...
  • Page 475 Therefore set the timer tCoord to zero. Failure of the communication channel does not affect the selectivity, but delays tripping at one end(s) for certain fault locations. Bay control REC670 2.2 ANSI Application manual...
  • Page 476 Communication media that uses metallic paths are particularly subjected to this type of interference, therefore they must be properly shielded or otherwise designed to provide an adequate communication signal during power system faults. Bay control REC670 2.2 ANSI Application manual...
  • Page 477 CR signal is received. The absence of the CR_GUARD signal during the security time is used as a CR signal. This also enables a permissive scheme to operate when the line fault blocks the signal transmission. Set the tSecurity to 35 ms. Bay control REC670 2.2 ANSI Application manual...

  • Page 478: Intertrip Scheme

    NoRestart if Unblocking scheme with no alarm for loss of guard is to be (Set to used. Set to Restart if Unblocking scheme with alarm for loss of guard is to be used) tSecurity 0.035 s Bay control REC670 2.2 ANSI Application manual...

  • Page 479: Delta Blocking Scheme

    Disabled tSecurity = 0.035 s 15.1.3.5 Unblocking scheme M13869-43 v4 Unblock Restart (Loss of guard signal will give both trip and alarm NoRestart if only trip is required) Choose tSecurity = 0.035 s Bay control REC670 2.2 ANSI Application manual...

  • Page 480: Intertrip Scheme

    Figure 194. Initially the protection A2 at A side will detect a fault in forward direction and send a communication signal to the protection B2 at remote end, which is measuring a fault in reverse direction. Bay control REC670 2.2 ANSI Application manual...

  • Page 481: Weak-End Infeed Logic

    Here, the fault current increases when the breaker opens at the strong terminal, and a sequential tripping is achieved. This requires a detection of the fault by an independent tripping zone 1. To avoid sequential tripping as described, and Bay control REC670 2.2 ANSI Application manual...

  • Page 482: Setting Guidelines

    (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. 15.2.3.1 Current reversal logic M13856-6 v6 Set CurrRev to Enabled to activate the function. Bay control REC670 2.2 ANSI Application manual...

  • Page 483: Weak-End Infeed Logic

    The local acceleration logic (ZCLCPSCH) is used in those applications where conventional teleprotection scheme is not available (no communication channel), but the user still require fast clearance for faults on the whole line. Bay control REC670 2.2 ANSI Application manual...

  • Page 484: Setting Guidelines

    The drop-out timer tLoadOff is used to determine the window for the current release conditions for Loss-of-load. The timer is by default set to 300ms, which is judged to be enough to secure the current release. Bay control REC670 2.2 ANSI Application manual...

  • Page 485: Scheme Communication Logic For Residual Overcurrent Protection Ecpsch (85)

    This short operate time enables rapid autoreclosing function after the fault clearance. During a single-phase reclosing cycle, the autoreclosing device must block the directional comparison ground-fault communication scheme. Bay control REC670 2.2 ANSI Application manual...

  • Page 486: Setting Guidelines

    Restart if unblocking scheme with alarm for loss of guard is used. tSendMin: Time duration, the carrier send signal is prolonged. tSecurity: The absence of CRG signal for a time duration of tSecurity is considered as CR signal. Bay control REC670 2.2 ANSI Application manual...

  • Page 487: Current Reversal And Weak-End Infeed Logic For Residual Overcurrent Protection Ecrwpsch (85)

    CLOSED CLOSED FAULT LINE 1 Weak Strong source source CLOSED CLOSED LINE 2 en99000043_ansi.vsd ANSI99000043 V1 EN-US Figure 195: Current distribution for a fault close to B side when all breakers are closed Bay control REC670 2.2 ANSI Application manual...

  • Page 488: Weak-End Infeed Logic

    Initial condition for weak-end infeed 15.5.3 Setting guidelines IP15042-1 v1 M13933-4 v5 The parameters for the current reversal and weak-end infeed logic for residual overcurrent protection function are set via the local HMI or PCM600. Bay control REC670 2.2 ANSI Application manual...

  • Page 489: Current Reversal

    2 – 10 ms. If the teleprotection equipment is integrated in the protection IED the decision time can be slightly reduced. The principle time sequence of signaling at current reversal is shown. Bay control REC670 2.2 ANSI Application manual...

  • Page 490: Weak-End Infeed

    (3V0) higher than the maximum false network frequency residual voltage that can occur during normal service conditions. The recommended minimum setting is two times the false zero-sequence voltage during normal service conditions. Bay control REC670 2.2 ANSI Application manual...

  • Page 491: Tripping Logic Smpptrc (94)

    IED. In such installation, use one instance of SMPPTRC function per circuit breaker. If the OHL is connected to the substation via more than one breaker, one SMPPTRC (94) function block should be used for each breaker. For example when single-pole Bay control REC670 2.2 ANSI Application manual...

  • Page 492: Three-Pole Tripping

    PS_A TR3P PS_B CLLKOU T PS_C BFI_3P 1PTRZ BFI_A 1PTRGF BFI_B P3PTR BFI_C SETLKOUT RSTLKOUT ANSI05000707-4-en.vsdx ANSI05000544 V4 EN-US Figure 199: Tripping logic SMPPTRC (94) is used for a simple three-pole tripping application Bay control REC670 2.2 ANSI Application manual...

  • Page 493: Single- And/Or Three-Pole Tripping

    SMBRREC will use single-pole dead time. If a second line protection is utilizing the same SMBRREC (79), the three-pole trip signal must be generated as OR conditions from both line protections. Bay control REC670 2.2 ANSI Application manual...

  • Page 494: Single-, Two- Or Three-Pole Tripping

    SMBRREC (79) must also be informed that the trip is two phases by connecting the output TR2P to the input TR2P in the SMBRREC (79) function. Bay control REC670 2.2 ANSI Application manual...

  • Page 495: Lock-Out

    SETLKOUT. 16.1.2.5 Example of directional data GUID-08AC09AB-2B2F-4095-B06E-1171CF225869 v2 An example how to connect the directional data from different application functions to the trip function is given below, see Figure 201: Bay control REC670 2.2 ANSI Application manual...
  • Page 496 Trip function (SMPPTRC). Protection functions connect their directional data via the STARTCOMB function to SMAGAPC and then to the SMPPTRC, or directly to SMAGAPC and then to the SMPPTRC. Bay control REC670 2.2 ANSI Application manual...

  • Page 497: Blocking Of The Function Block

    If no pole selection has been achieved, a three-pole trip will be issued after this time has elapsed. tEvolvingFault: Secures two- or three-pole tripping depending on Program selection during evolving faults. 16.2 Trip matrix logic TMAGAPC IP15121-1 v4 Bay control REC670 2.2 ANSI Application manual...

  • Page 498: Identification

    ModeOutputx: Defines if output signal OUTPUTx (where x=1-3) is Steady or Pulsed. 16.3 Logic for group alarm ALMCALH GUID-64EA392C-950F-486C-8D96-6E7736B592BF v1 16.3.1 Identification GUID-64EA392C-950F-486C-8D96-6E7736B592BF v1 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Logic for group alarm ALMCALH Bay control REC670 2.2 ANSI Application manual...

  • Page 499: Application

    Setting guidelines GUID-B08F2636-33DA-4937-92EB-1A8AC0909AB4 v2 OperationEnabled or Disabled 16.5 Logic for group indication INDCALH 16.5.1 Identification GUID-3B5D4371-420D-4249-B6A4-5A168920D635 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Logic for group indication INDCALH Bay control REC670 2.2 ANSI Application manual...

  • Page 500: Application

    HMI or via the PST tool. Both timers in the same logic block (the one delayed on pick-up and the one delayed on drop-out) always have a common setting value. Bay control REC670 2.2 ANSI Application manual...

  • Page 501: Configuration

    The execution of different function blocks within the same cycle is determined by the order of their serial execution numbers. Always remember this when connecting two or more logical function blocks in series. Bay control REC670 2.2 ANSI Application manual...

  • Page 502: Fixed Signal Function Block Fxdsign

    When used for auto-transformers, information from both windings parts, together with the neutral point current, needs to be available to the function. This means that three inputs are needed. Bay control REC670 2.2 ANSI Application manual...

  • Page 503: Boolean 16 To Integer Conversion B16I

    REFPDIF (87N) function inputs for normal transformer application 16.8 Boolean 16 to Integer conversion B16I SEMOD175715-1 v1 16.8.1 Identification SEMOD175721-2 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Boolean 16 to integer conversion B16I Bay control REC670 2.2 ANSI Application manual...

  • Page 504: Application

    BOOLEAN Input 10 IN11 BOOLEAN Input 11 1024 IN12 BOOLEAN Input 12 2048 IN13 BOOLEAN Input 13 4096 IN14 BOOLEAN Input 14 8192 IN15 BOOLEAN Input 15 16384 IN16 BOOLEAN Input 16 32768 Bay control REC670 2.2 ANSI Application manual...

  • Page 505: Boolean To Integer Conversion With Logical Node Representation

    The sum of the value on each INx corresponds to the integer presented on the output OUT on the function block BTIGAPC. Name of input Type Default Description Value when Value when activated deactivated BOOLEAN Input 1 BOOLEAN Input 2 BOOLEAN Input 3 Table continues on next page Bay control REC670 2.2 ANSI Application manual...

  • Page 506: Integer To Boolean 16 Conversion Ib16

    The Boolean 16 to integer conversion function (IB16) will transfer a combination of up to 16 binary inputs INx where 1≤x≤16 to an integer. Each INx represents a value Bay control REC670 2.2 ANSI Application manual...

  • Page 507: Integer To Boolean 16 Conversion With Logic Node Representation Itbgapc

    1≤x≤16) are active that is=1; is 65535. 65535 is the highest boolean value that can be converted to an integer by the IB16 function block. 16.11 Integer to Boolean 16 conversion with logic node representation ITBGAPC SEMOD158419-1 v3 Bay control REC670 2.2 ANSI Application manual...

  • Page 508: Identification

    Output 7 OUT8 BOOLEAN Output 8 OUT9 BOOLEAN Output 9 OUT10 BOOLEAN Output 10 OUT11 BOOLEAN Output 11 1024 OUT12 BOOLEAN Output 12 2048 OUT13 BOOLEAN Output 13 4096 Table continues on next page Bay control REC670 2.2 ANSI Application manual...

  • Page 509: Elapsed Time Integrator With Limit Transgression And Overflow Supervision Teigapc

    A resolution of 10 ms can be achieved when the settings are defined within the range 1.00 second ≤ tAlarm ≤ 99 999.99 seconds 1.00 second ≤ tWarning ≤ 99 999.99 seconds. Bay control REC670 2.2 ANSI Application manual...

  • Page 510: Comparator For Integer Inputs - Intcomp

    EnaAbs: This setting is used to select the comparison type between signed and absolute values. • Absolute: Comparison is performed on absolute values of input and reference values • Signed: Comparison is performed on signed values of input and reference values. Bay control REC670 2.2 ANSI Application manual...

  • Page 511: Setting Example

    SetValue shall be set between -2000000000 to 2000000000 Similarly for signed comparison between input and setting Set the EnaAbs = Signed Set the RefSource = Set Value SetValue shall be set between -2000000000 to 2000000000 Bay control REC670 2.2 ANSI Application manual...

  • Page 512: Comparator For Real Inputs - Realcomp

    Milli, Unity, Kilo, Mega and Giga. EqualBandHigh: This setting is used to set the equal condition high band limit in % of reference value. This high band limit will act as reset limit for INHIGH output when INHIGH. Bay control REC670 2.2 ANSI Application manual...

  • Page 513: Setting Example

    INPUT and REF. Then the settings should be adjusted as below, EnaAbs = Absolute RefSource = Input REF EqualBandHigh = 5.0 % of reference value EqualBandLow = 5.0 % of reference value. Bay control REC670 2.2 ANSI Application manual...

  • Page 515: Measurement

    VMMXU SYMBOL-UU V1 EN-US Current sequence component CMSQI measurement I1, I2, I0 SYMBOL-VV V1 EN-US Voltage sequence component VMSQI measurement U1, U2, U0 SYMBOL-TT V1 EN-US Phase-neutral voltage measurement VNMMXU SYMBOL-UU V1 EN-US Bay control REC670 2.2 ANSI Application manual...

  • Page 516: Application

    P, Q and S: three phase active, reactive and apparent power • PF: power factor • V: phase-to-phase voltage magnitude • I: phase current magnitude • F: power system frequency The measuring functions CMMXU, VMMXU and VNMMXU provide physical quantities: Bay control REC670 2.2 ANSI Application manual...

  • Page 517: Zero Clamping

    Outputs seen on the local HMI under Main menu/Measurements/Monitoring/ Servicevalues(P_Q)/CVMMXN(P_Q): Apparent three-phase power Active three-phase power Reactive three-phase power Power factor ILAG I lagging U ILEAD I leading U Table continues on next page Bay control REC670 2.2 ANSI Application manual...

  • Page 518: Setting Guidelines

    Mode: Selection of measured current and voltage. There are 9 different ways of calculating monitored three-phase values depending on the available VT inputs connected to the IED. See parameter group setting table. k: Low pass filter coefficient for power measurement, V and I. Bay control REC670 2.2 ANSI Application manual...
  • Page 519 This forms the minimum limit of the range. Xmax: Maximum value for analog signal X. This forms the maximum limit of the range. XZeroDb: Zero point clamping. A signal value less than XZeroDb is forced to zero. Bay control REC670 2.2 ANSI Application manual...
  • Page 520 (example). The first phase will be used as reference channel and compared with the curve for calculation of factors. The factors will then be used for all related channels. Bay control REC670 2.2 ANSI Application manual...

  • Page 521: Setting Examples

    For each of them detail explanation and final list of selected setting parameters values will be provided. The available measured values of an IED are depending on the actual hardware (TRM) and the logic configuration made in PCM600. Bay control REC670 2.2 ANSI Application manual...
  • Page 522 Set under General settings parameters for the Measurement function: • general settings as shown in table 46. • level supervision of active power as shown in table 47. • calibration parameters as shown in table 48. Bay control REC670 2.2 ANSI Application manual...
  • Page 523 Cycl: Report interval (s), Db: In 2000 Set ±Δdb=40 MW that is, 2% (larger 0.001% of range, Int Db: In changes than 40 MW will be reported) 0.001%s Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 524 30% of In IAngComp100 Angle pre-calibration for current 0.00 at 100% of In Measurement function application for a power transformer SEMOD54481-61 v9 Single line diagram for this application is given in figure 208. Bay control REC670 2.2 ANSI Application manual...
  • Page 525 PCM600 for analog input channels Connect, in PCM600, measurement function to LV side CT & VT inputs Set the setting parameters for relevant Measurement function as shown in the following table 49: Bay control REC670 2.2 ANSI Application manual...
  • Page 526 Base setting for power in MVA 31.5 Set based on rated power Global base) Measurement function application for a generator SEMOD54481-110 v8 Single line diagram for this application is given in figure 209. Bay control REC670 2.2 ANSI Application manual...
  • Page 527 PCM600 for analog input channels Connect, in PCM600, measurement function to the generator CT & VT inputs Set the setting parameters for relevant Measurement function as shown in the following table: Bay control REC670 2.2 ANSI Application manual...

  • Page 528: Gas Medium Supervision Ssimg (63)

    Binary information based on the gas pressure in the circuit breaker is used as an input signal to the function. The function generates alarms based on the received information. Bay control REC670 2.2 ANSI Application manual...

  • Page 529: Setting Guidelines

    This is used for the temperature lockout indication to reset after a set time delay in s. tResetTempAlm: This is used for the temperature alarm indication to reset after a set time delay in s. Bay control REC670 2.2 ANSI Application manual...

  • Page 530: Liquid Medium Supervision Ssiml (71)

    This is used to set the time delay for a level alarm indication, given in s. tLevelLockOut: This is used to set the time delay for a level lockout indication, given in s. Bay control REC670 2.2 ANSI Application manual...

  • Page 531: Breaker Monitoring Sscbr

    Detecting an excessive traveling time is essential to indicate the need for maintenance of the circuit breaker mechanism. The excessive travel time can be due to problems in the driving mechanism or failures of the contacts. Bay control REC670 2.2 ANSI Application manual...
  • Page 532 Circuit breaker manufacturers provide the number of make-break operations possible at various interrupted currents. An example is shown in figure 210. Bay control REC670 2.2 ANSI Application manual...
  • Page 533 • Breaker interrupts between rated operating current and rated fault current, that is, 10 kA, one operation at 10kA is equivalent to 10000/900 = 11 operations at the Bay control REC670 2.2 ANSI Application manual...
  • Page 534 Binary input available from the pressure sensor is based on the pressure levels inside the arc chamber. When the pressure becomes too low compared to the required value, the circuit breaker operation is blocked. Bay control REC670 2.2 ANSI Application manual...

  • Page 535: Setting Guidelines

    It is given as a percentage of IBase. ContTrCorr: Correction factor for time difference in auxiliary and main contacts' opening time. AlmAccCurrPwr: Setting of alarm level for accumulated energy. LOAccCurrPwr: Lockout limit setting for accumulated energy. Bay control REC670 2.2 ANSI Application manual...

  • Page 536: Event Function Event

    These events are created from any available signal in the IED that is connected to the Event function (EVENT). The EVENT function block is used for remote communication. Analog, integer and double indication values are also transferred through the EVENT function. Bay control REC670 2.2 ANSI Application manual...

  • Page 537: Setting Guidelines

    M12811-34 v1 It is important to set the time interval for cyclic events in an optimized way to minimize the load on the station bus. 17.6 Disturbance report DRPRDRE IP14584-1 v2 Bay control REC670 2.2 ANSI Application manual...

  • Page 538: Identification

    Every disturbance report recording is saved in the IED. The same applies to all events, which are continuously saved in a ring-buffer. Local HMI can be used to get information about the recordings, and the disturbance report files may be uploaded in Bay control REC670 2.2 ANSI Application manual...

  • Page 539: Setting Guidelines

    (TVR) uses analog information from the analog input function blocks (AxRADR), which is used by Fault locator (FL) after estimation by Trip Value Recorder (TVR). Disturbance report function acquires information from both AxRADR and BxRBDR. Bay control REC670 2.2 ANSI Application manual...
  • Page 540 No power supply Yellow LED: Steady light Triggered on binary signal N with SetLEDx = Start (or Start and Trip) Flashing light The IED is in test mode Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 541 Long recording time will reduce the number of recordings to less than 100. The IED flash disk should NOT be used to store any user files. This might cause disturbance recordings to be deleted due to lack of disk space. Bay control REC670 2.2 ANSI Application manual...

  • Page 542: Recording Times

    Disturbance report function can handle a maximum of 3 simultaneous disturbance recordings. 17.6.3.2 Binary input signals M12179-90 v9 Up to 352 binary signals can be selected among internal logical and binary input signals. The configuration tool is used to configure the signals. Bay control REC670 2.2 ANSI Application manual...

  • Page 543: Analog Input Signals

    M (Enabled) or not (Disabled). OverTrigLeM, UnderTrigLeM: Over or under trig level, Trig high/low level relative nominal value for analog input M in percent of nominal value. Bay control REC670 2.2 ANSI Application manual...

  • Page 544: Sub-Function Parameters

    The density of recording equipment in power systems is increasing, since the number of modern IEDs, where recorders are included, is increasing. This leads to a vast number of recordings at every single disturbance and a lot of information has to be Bay control REC670 2.2 ANSI Application manual...

  • Page 545: Logical Signal Status Report Binstatrep

    Such parameters are, for example, station and object identifiers, CT and VT ratios. 17.7 Logical signal status report BINSTATREP GUID-E7A2DB38-DD96-4296-B3D5-EB7FBE77CE07 v2 17.7.1 Identification GUID-E0247779-27A2-4E6C-A6DD-D4C31516CA5C v3 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Logical signal status report BINSTATREP Bay control REC670 2.2 ANSI Application manual...

  • Page 546: Application

    Fault locator LMBRFLO 17.8.2 Application M13752-3 v6 The main objective of line protection and monitoring IEDs is fast, selective and reliable operation for faults on a protected line section. Besides this, information on Bay control REC670 2.2 ANSI Application manual...

  • Page 547: Setting Guidelines

    After allocation of analog inputs to the Disturbance report function, the user has to point out which analog inputs to be used by the Fault locator. According to the default settings the first four analog inputs are currents and next three are voltages Bay control REC670 2.2 ANSI Application manual...

  • Page 548: Connection Of Analog Currents

    85° give satisfactory results. 17.8.3.1 Connection of analog currents M13769-16 v5 Connection diagram for analog currents included IN from parallel line shown in figure 214. Bay control REC670 2.2 ANSI Application manual...

  • Page 549: Limit Counter L4Ufcnt

    Example of connection of parallel line IN for Fault locator LMBRFLO 17.9 Limit counter L4UFCNT GUID-22E141DB-38B3-462C-B031-73F7466DD135 v1 17.9.1 Identification GUID-F3FB7B33-B189-4819-A1F0-8AC7762E9B7E v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Limit counter L4UFCNT Bay control REC670 2.2 ANSI Application manual...

  • Page 550: Application

    Settable time limits for warning and alarm are provided. The time limit for overflow indication is fixed to 99999.9 hours. At overflow the accumulated time resets and the accumulation starts from zero again. Bay control REC670 2.2 ANSI Application manual...

  • Page 551: Setting Guidelines

    A transformer is rated at the power output. It can continuously deliver at rated voltage and frequency without exceeding the specified temperature limit. This temperature rise is based on thermal limitations of the core, winding and insulation. Therefore, Bay control REC670 2.2 ANSI Application manual...
  • Page 552 However, measurements have shown that the hottest spot might be moved to conductors in the lower part of the winding. Therefore, direct hot spot temperature measurement is difficult. Hence, it should be calculated using the Bay control REC670 2.2 ANSI Application manual...
  • Page 553 In addition to loading of the transformer, oil temperature rise depends also on reduced oil flow inside the winding and malfunctioning/failure of the cooling system (water or air circulation). Therefore, hot spot temperature can be measured by sensing top oil Bay control REC670 2.2 ANSI Application manual...
  • Page 554 This is not a normal operating condition, but may persist for some time. • Short time emergency loading: Unusually heavy loading for short time due to occurrence of one or more unwanted events that disturb the normal system loading seriously. Bay control REC670 2.2 ANSI Application manual...
  • Page 555 Deterioration of insulation reduces mechanical strength and dielectric strength. Heating from heavy overload or large electromagnetic force resulting from short circuit causes expansion and unusual movement of conductors and it leads to turn-to-turn fault. Bay control REC670 2.2 ANSI Application manual...

  • Page 556: Setting Guidelines

    GUID-FED52BFB-66A9-46E9-BD11-3FA18DD0FB50 v1 Operation: Disabled or Enabled. TrafoRating: Rated transformer power in MVA. TrafoType: This setting is used to set the number of phases in the transformer. The options are: Bay control REC670 2.2 ANSI Application manual...
  • Page 557 Based on the setting NoOfWindings, hot spot temperature of the winding 3 is either calculated or assigned as zero. ConstSelection: This setting is used to select the transformer parameters taken either from IEC 60076-7 standard or IEEE C57.96-1995 standard. The options are: Bay control REC670 2.2 ANSI Application manual...
  • Page 558 Winding 2: Only winding 2 CT is available. This option can be selected when two winding transformer is considered. • Winding 1&2: Only winding 1 and winding 2 CTs are available. This option can be selected when three winding transformer is considered. Bay control REC670 2.2 ANSI Application manual...
  • Page 559 This mass consists of all winding mass, core mass and paper mass of the transformer. OilMass: This setting is used to set the transformer oil mass. This mass consists of free oil mass and oil insulation mass of the transformer. Bay control REC670 2.2 ANSI Application manual...
  • Page 560 This setting is useful when setting WdgTmConstMode is selected for calculation. This setting has two options: • Copper: Winding material is selected as copper. • Aluminum: Winding material is selected as aluminum. Bay control REC670 2.2 ANSI Application manual...
  • Page 561 RatedVoltTap: This setting is used to set the position number of tap changer at rated voltage. HighVoltTap: This setting is used to set the position number of tap changer at possible maximum voltage. Bay control REC670 2.2 ANSI Application manual...
  • Page 562 HPTmpRiseW1: This setting is used to set the hot spot temperature rise of winding 1 above ambient temperature in K (Kelvin). HPTmpRiseW2: This setting is used to set the hot spot temperature rise of winding 2 above ambient temperature in K (Kelvin). Bay control REC670 2.2 ANSI Application manual...
  • Page 563 If the transformer insulation loss of life value will start from this value and at any time the insulation loss of life value can be reset with this value by activating LOLRST from local HMI reset menu. Bay control REC670 2.2 ANSI Application manual...
  • Page 564 °C Top oil temperature in °C IEEE standard has also suggested the limits of temperature and load for loads higher than transformer nameplate. • For distribution transformers with 65°C hot spot temperature rise: Bay control REC670 2.2 ANSI Application manual...

  • Page 565: Setting Example

    Winding 1 rated current 696 A Winding 2 rated current 1255 A Winding 3 rated current 577 A Connection Type YNyn0d1 Cooling ONAF p.u. Impedance 0.120 At Base 500 MVA Table continues on next page Bay control REC670 2.2 ANSI Application manual...

  • Page 566: Setting Parameters For Insulation Loss Of Life Calculation Function (Lol1)

    Select the transformer oil time constant mode of input to the function OilTimeConst 9000.0 sec Set the transformer oil time constant when the oil time constant mode is selected as User defined Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 567 Calculated selected as WdgToOilGrad2 Set the transformer winding to oil 20° C temperature gradient for the winding 2 when the winding time constant mode is Calculated selected as Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 568 FebAmbTmp Set the February month average ambient 30° C temperature for the calculation of top oil temperature when ambient temperature sensor failure/absence Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 569 2 for the calculation of hot spot to top oil temperature gradient HPTmpRiseW3 Set the hot spot temperature rise of 65° C winding 3 for the calculation of hot spot to top oil temperature gradient Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 570 Set the hot spot temperature value for the level 2 warning tDelayToAlarm1 1800 sec Set the time delay for the alarm level 1 tDelayToAlarm2 Set the time delay for the alarm level 2 900 sec Bay control REC670 2.2 ANSI Application manual...

  • Page 571: Pulse-Counter Logic Pcfcnt

    PCFCNT can also be used as a general purpose counter. 18.1.3 Setting guidelines M13396-4 v9 Parameters that can be set individually for each pulse counter from PCM600: • Operation: Disabled/Enabled • tReporting: 0-3600s • EventMask: NoEvents/ReportEvents Bay control REC670 2.2 ANSI Application manual...

  • Page 572: Function For Energy Calculation And Demand Handling Etpmmtr

    (CVMMXN). This function has a site calibration possibility to further increase the total accuracy. The function is connected to the instantaneous outputs of (CVMMXN) as shown in figure 217. Bay control REC670 2.2 ANSI Application manual...

  • Page 573: Setting Guidelines

    The following settings can be done for the energy calculation and demand handling function ETPMMTR: GlobalBaseSel: Selects the global base value group used by the function to define IBase, VBase and SBase as applicable. Bay control REC670 2.2 ANSI Application manual...
  • Page 574 Pulse counter (PCGGIO) settings to give the correct total pulse value. For the advanced user there are a number of settings for direction, zero clamping, max limit, and so on. Normally, the default values are suitable for these parameters. Bay control REC670 2.2 ANSI Application manual...

  • Page 575: Access Point

    Subnetwork shows the SCL subnetwork to which the access point is connected. This column shows the SCL subnetworks available in the PCM600 project. SCL subnetworks can be created/deleted in the Subnetworks tab of IEC 61850 Configuration tool in PCM600. Bay control REC670 2.2 ANSI Application manual...
  • Page 576 For more information on routes, see the Routes chapter in the Technical manual and the Application manual. DHCP can be activated for the front port from the LHMI in Main menu/ Configuration/Communication/Ethernet configuration/Front port/DHCP:1 Bay control REC670 2.2 ANSI Application manual...

  • Page 577: Redundant Communication

    Parallel Redundancy Protocol (PRP) and High-availability Seamless Redundancy (HSR) provides redundant communication over station bus running the available communication protocols. The redundant communication uses two Ethernet ports. Bay control REC670 2.2 ANSI Application manual...
  • Page 578 1MRK 511 401-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 218: Parallel Redundancy Protocol (PRP) Bay control REC670 2.2 ANSI Application manual...

  • Page 579: Setting Guidelines

    PRP-1 and HSR can be combined in a mixed network. If the access point is not taken into operation, the write option in Ethernet Configuration Tool can be used to activate the access point. Bay control REC670 2.2 ANSI Application manual...

  • Page 580: Merging Unit

    (or subscribers) in the system. Some merging units are able to get data from classical measuring transformers, others from non-conventional measuring transducers and yet others can pick up data from both types. Bay control REC670 2.2 ANSI Application manual...

  • Page 581: Setting Guidelines

    Routes are configured using the Ethernet configuration tool in PCM600. Operation for the route can be set to On/Off by checking and unchecking the check- box in the operation column. Gateway specifies the address of the gateway. Bay control REC670 2.2 ANSI Application manual...
  • Page 582 Section 19 1MRK 511 401-UUS A Ethernet-based communication Destination specifies the destination. Destination subnet mask specifies the subnetwork mask of the destination. Bay control REC670 2.2 ANSI Application manual...

  • Page 583: Communication Protocols

    M13913-3 v6 Figure shows the topology of an IEC 61850–8–1 configuration. IEC 61850–8–1 specifies only the interface to the substation LAN. The LAN itself is left to the system integrator. Bay control REC670 2.2 ANSI Application manual...
  • Page 584 Engineering Station HSI Workstation Gateway Base System Printer KIOSK 3 KIOSK 1 KIOSK 2 IEC09000135_en.v IEC09000135 V1 EN-US Figure 222: SA system with IEC 61850–8–1 M16925-3 v4 Figure223 shows the GOOSE peer-to-peer communication. Bay control REC670 2.2 ANSI Application manual...

  • Page 585: Sending Data

    GOOSE Control Block to other subscriber IEDs. There are different function blocks for different type of sending data. Generic communication function for Single Point indication SPGAPC, SP16GAPC SEMOD55999-1 v4 Bay control REC670 2.2 ANSI Application manual...

  • Page 586: Receiving Data

    Engineering manual for more information about how to configure GOOSE. Function block type Data Type GOOSEBINRCV 16 single point GOOSEINTLKRCV 2 single points 16 double points GOOSEDPRCV Double point GOOSEINTRCV Integer GOOSEMVRCV Analog value Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 587 Input1 Input1 DataValid Input2 Noput Input2 Noput Ext_Res_OK_To_Operate CommValid Input3 Input3 Test Input4 Input4 IEC16000082=1=en.vsd IEC16000082 V1 EN-US Figure 224: GOOSESPRCV and AND function blocks - checking the validity of the received data Bay control REC670 2.2 ANSI Application manual...

  • Page 588: Lon Communication Protocol

    Specification of the fibre optic connectors Glass fibre Plastic fibre Cable connector ST-connector snap-in connector Cable diameter 62.5/125 m 1 mm Max. cable length 1000 m 10 m Table continues on next page Bay control REC670 2.2 ANSI Application manual...
  • Page 589 LON bus. To communicate via LON, the IEDs need to know • The node addresses of the other connected IEDs. • The network variable selectors to be used. This is organized by LNT. Bay control REC670 2.2 ANSI Application manual...

  • Page 590: Multicmdrcv And Multicmdsnd

    The Mode setting sets the outputs to either a Steady or Pulsed mode. 20.4 SPA communication protocol IP14614-1 v1 20.4.1 Application IP14785-1 v1 SEMOD115767-5 v6 SPA communication protocol is an alternative to IEC 60870-5-103, and they use the same rear communication port. Bay control REC670 2.2 ANSI Application manual...
  • Page 591 SPA-bus codes and for translation of the data that should be sent to the IED. For the specification of the SPA protocol V2.5, refer to SPA-bus Communication Protocol V2.5. Bay control REC670 2.2 ANSI Application manual...

  • Page 592: Setting Guidelines

    Refer to technical data to determine the rated communication speed for the selected communication interfaces. The IED does not adapt its speed to the actual communication conditions because the communication speed is set on the local HMI. Bay control REC670 2.2 ANSI Application manual...

  • Page 593: Iec 60870-5-103 Communication Protocol

    In IEC terminology a primary station is a master and a secondary station is a slave. The communication is based on a point-to-point principle. The master must have software that can interpret Bay control REC670 2.2 ANSI Application manual...

  • Page 594: Design

    Function block with defined IED functions in control direction, I103IEDCMD. This block use PARAMETR as FUNCTION TYPE, and INFORMATION NUMBER parameter is defined for each output signal. • Function commands in control direction Bay control REC670 2.2 ANSI Application manual...
  • Page 595 For more information on the description of the Disturbance report in the Technical reference manual. The analog channels, that are reported, are those Bay control REC670 2.2 ANSI Application manual...

  • Page 596: Settings

    The protocol to activate on a physical port is selected under: Main menu/Configuration/Communication/Station Communication/Port configuration/ • RS485 port • RS485PROT:1 (off, DNP, IEC103) • SLM optical serial port • PROTOCOL:1 (off, DNP, IEC103, SPA) Bay control REC670 2.2 ANSI Application manual...

  • Page 597: Settings From Pcm600

    0 and 255. To get proper operation of the sequence of events the event masks in the event function is to be set to ON_CHANGE. For single-command signals, the event mask is to be set to ON_SET. Bay control REC670 2.2 ANSI Application manual...
  • Page 598 Table 56. Table 56: Channels on disturbance recorder sent with a given ACC DRA#-Input IEC103 meaning Private range Private range Private range Private range Private range Private range Table continues on next page Bay control REC670 2.2 ANSI Application manual...

  • Page 599: Function And Information Types

    Private range Private range 20.5.3 Function and information types M17109-145 v6 Product type IEC103mainFunType value Comment: REL 128 Compatible range REC 242 Private range, use default RED 192 Compatible range RET 176 Compatible range Bay control REC670 2.2 ANSI Application manual...

  • Page 600: Dnp3 Communication Protocol

    For more information, refer to IEC standard IEC 60870-5-103. 20.6 DNP3 Communication protocol 20.6.1 Application GUID-EF1F0C38-9FF6-4683-8B10-AAA372D42185 v1 For more information on the application and setting guidelines for the DNP3 communication protocol refer to the DNP3 Communication protocol manual. Bay control REC670 2.2 ANSI Application manual...

  • Page 601: Binary Signal Transfer

    If it is not possible to have a communication link between each station, the solution has been to set the protection up in a slave-master-slave configuration. This means that in Figure 229, only IED-B has access to all currents and, therefore, this is the only place Bay control REC670 2.2 ANSI Application manual...

  • Page 602: Communication Hardware Solutions

    The LDCM (Line Data Communication Module) has an optical connection such that two IEDs can be connected over a direct fibre (multimode), as shown in figure 230. The protocol used is IEEE/ANSI C37.94. The distance with this solution is typical 110 km/68 miles. Bay control REC670 2.2 ANSI Application manual...

  • Page 603: Setting Guidelines

    3 km/2 mile length. The IEEE/ANSI C37.94 protocol is always used between LDCM and the modem. 21.1.3 Setting guidelines M12454-3 v6 64 kbit and 2 Mbit mode common settings Bay control REC670 2.2 ANSI Application manual...
  • Page 604 LDCM for slot 306: set TerminalNo to 4 and RemoteTermNo to 3 The redundant channel is always configured to the lower position, for example: • Slot 305: main channel • Slot 306: redundant channel Bay control REC670 2.2 ANSI Application manual...
  • Page 605 If fixed asymmetry is known, Echo synchronization method can be used, provided that AsymDelay is properly set. From the definition follows that asymmetry is always positive at one end and negative at the other end. Bay control REC670 2.2 ANSI Application manual...
  • Page 606 RedundantCh is used to set the channel as a redundant backup channel. The redundant channel takes the CT group setting of the main channel, and ignores the CT group configured in its own transmit block. Bay control REC670 2.2 ANSI Application manual...
  • Page 607 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. Bay control REC670 2.2 ANSI Application manual...

  • Page 609: Authority Status Athstat

    Similarly, when the failure is corrected, a corresponding event is generated. Apart from the built-in supervision of the various modules, events are also generated when the status changes for the: Bay control REC670 2.2 ANSI Application manual...

  • Page 610: Change Lock Chnglck

    Clear disturbances • Reset LEDs • Reset counters and other runtime component states • Control operations • Set system time • Enter and exit from test mode • Change of active setting group Bay control REC670 2.2 ANSI Application manual...

  • Page 611: 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. 22.4 Denial of service SCHLCCH/RCHLCCH 22.4.1...

  • Page 612: Setting Guidelines

    A and B (redundant communication) • LinkStatus indicates the Ethernet link status for the front port 22.4.2 Setting guidelines GUID-CE3344E8-539B-47E0-9C19-8239988BDBCF v2 The function does not have any parameters available in the local HMI or PCM600. Bay control REC670 2.2 ANSI Application manual...

  • Page 613: 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). Bay control REC670 2.2 ANSI Application manual...

  • Page 614: Factory Defined Settings

    • IEDMainFunType • Main function type code according to IEC 60870-5-103. Example: 128 (meaning line protection). • SerialNo • OrderingNo • ProductionDate 23.3 Measured value expander block RANGE_XP SEMOD52451-1 v2 Bay control REC670 2.2 ANSI Application manual...

  • Page 615: Identification

    Operational departments can plan for different operating conditions in the primary equipment. The protection engineer can prepare the necessary optimized and pre-tested settings in advance for different protection functions. Six different groups of setting Bay control REC670 2.2 ANSI Application manual...

  • Page 616: Setting Guidelines

    Configuration/ Power system/ Primary Values in the local HMI and PCM600 parameter setting tree. 23.5.3 Setting guidelines M15292-3 v2 Set the system rated frequency. Refer to section "Signal matrix for analog inputs SMAI" for description on frequency tracking. Bay control REC670 2.2 ANSI Application manual...

  • Page 617: Summation Block 3 Phase 3Phsum

    GlobalBaseSel: Selects the global base value group used by the function to define (IBase), (VBase) and (SBase). 23.7 Global base values GBASVAL GUID-2FDB0A2C-10FE-4954-B6E4-9DA2EEEF1668 v1 23.7.1 Identification GUID-0D5405BE-E669-44C8-A208-3A4C86D39115 v3 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Global base values GBASVAL Bay control REC670 2.2 ANSI Application manual...

  • Page 618: Application

    SMBI inputs, directly in the Application Configuration tool. These names will define SMBI function in the Signal Matrix tool. The user defined name for the input or output signal will also appear on the respective output or input signal. Bay control REC670 2.2 ANSI Application manual...

  • Page 619: Signal Matrix For Binary Outputs Smbo

    Parameter Setting tool. However, the user must give a name to SMMI instance and SMMI inputs, directly in the Application Configuration tool. 23.11 Signal matrix for analog inputs SMAI SEMOD55751-1 v2 Bay control REC670 2.2 ANSI Application manual...

  • Page 620: Application

    SAPTOF G1AI3P DFTSPFC V3P* TRIP SAPTOF(1)_TRIP PICK UP BLOCK REVROT G1AI1 BLKTRIP BLKDMAGN PHASEA G1AI2 FREQ ^GRP1_A G1AI4 TRM_40.CH7(U) PHASEB ^GRP1_B PHASEC ^GRP1_C NEUTRAL ^GRP1_N ANSI10000060-1-en.vsdx ANSI10000060 V1 EN-US Figure 232: Connection example Bay control REC670 2.2 ANSI Application manual...

  • Page 621: Setting Guidelines

    DFTRefGrp(n) will use DFT reference from the selected group block, when own group is selected, an adaptive DFT reference will be used based on calculated signal frequency from own group. The setting ExternalDFTRef will use reference based on what is connected to input DFTSPFC. Bay control REC670 2.2 ANSI Application manual...
  • Page 622 When two or more preprocessing blocks are used to feed one protection function (e.g. over-power function GOPPDOP), it is of outmost importance that parameter setting DFTReference has the same set value for all of the preprocessing blocks involved Bay control REC670 2.2 ANSI Application manual...
  • Page 623 In practice each instance can be adapted to the needs of the actual application. The adaptive frequency tracking is needed in IEDs that belong to the protection system of synchronous machines and that are active during run-up and Bay control REC670 2.2 ANSI Application manual...
  • Page 624 SMAI1:13 – SMAI12:24: DFTReference = ExternalDFTRef to use DFTSPFC input of SMAI1:13 as reference (SMAI7:7) For task time group 3 this gives the following settings: SMAI1:25 – SMAI12:36: DFTReference = ExternalDFTRef to use DFTSPFC input as reference (SMAI7:7) Bay control REC670 2.2 ANSI Application manual...
  • Page 625 (see Figure 235) SMAI2:14 – SMAI12:24: DFTReference = DFTRefGrp4 to use SMAI4:16 as reference. For task time group 3 this gives the following settings: SMAI1:25 – SMAI12:36: DFTReference = ExternalDFTRef to use DFTSPFC input as reference (SMAI4:16) Bay control REC670 2.2 ANSI Application manual...

  • Page 626: Test Mode Functionality Testmode

    Function test modes/Communication/Station Communication It is possible that the behavior is also influenced by other sources as well, independent of the mode, such as the insertion of the test handle, loss of SV, and IED configuration Bay control REC670 2.2 ANSI Application manual...

  • Page 627: Setting Guidelines

    INPUT on the TESTMODE function block might be activated in the configuration. Forcing of binary input and output signals is only possible when the IED is in IED test mode. Bay control REC670 2.2 ANSI Application manual...

  • Page 628: Time Synchronization Timesynchgen

    MU supply a PPS signal to the IED or by supplying a PPS signal from the IED to the MU, by using a GTM. Out of these, LON and SPA contains two types of synchronization messages: Bay control REC670 2.2 ANSI Application manual...

  • Page 629: Setting Guidelines

    The time is set with years, month, day, hour, minute, second and millisecond. 23.13.2.2 Synchronization M11348-143 v4 The setting parameters for the real-time clock with external time synchronization are set via local HMI or PCM600. The path for Time Synchronization parameters on local Bay control REC670 2.2 ANSI Application manual...
  • Page 630 The parameter SyncMaster defines if the IED is a master, or not a master for time synchronization within a Substation Automation System, for IEDs connected in a communication network (IEC 61850-8-1). The SyncMaster can have the following values: Bay control REC670 2.2 ANSI Application manual...
  • Page 631 The PTP VLAN tag does not need to be the same on all access points in one IED. It is possible to mix as long as they are the same for all devices on each subnet. Bay control REC670 2.2 ANSI Application manual...
  • Page 632 On the REL, the parameter FineSyncSource (under Configuration/Time/ Synchronization/TIMESYNCHGEN:1/General) is set to “GPS” if there is a GPS antenna attached. If the GTM is used as a PPS output only, the FineSynchSource is not set. Bay control REC670 2.2 ANSI Application manual...

  • Page 633: Current Transformer Requirements

    Since approximately year 2000 some CT manufactures have introduced new core materials that gradually have increased the possible maximum levels of remanent flux even up to 95 % related to the hysteresis curve. Corresponding level of actual remanent Bay control REC670 2.2 ANSI Application manual...
  • Page 634 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 635: 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 636: Fault Current

    The conclusion is that the loop resistance, twice the resistance of the single secondary wire, must be used in the calculation for phase-to-ground faults and the phase Bay control REC670 2.2 ANSI Application manual...

  • Page 637: 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 638: Breaker Failure Protection

    Non-directional instantaneous and definitive time, phase and residual overcurrent protection M11622-3 v5 The CTs must have a rated equivalent limiting secondary e.m.f. E that is larger than or equal to the required rated equivalent limiting secondary e.m.f. E below: alreq Bay control REC670 2.2 ANSI Application manual...

  • Page 639: Non-Directional Inverse Time Delayed Phase And Residual Overcurrent Protection

    The primary current set value of the inverse time function (A) The rated primary CT current (A) The rated secondary CT current (A) The nominal current of the protection IED (A) Table continues on next page Bay control REC670 2.2 ANSI Application manual...

  • Page 640: Directional Phase And Residual Overcurrent Protection

    The burden of an IED current input channel (VA). S =0.020 VA/channel for I =1 A and S =0.150 VA/channel for I =5 A Bay control REC670 2.2 ANSI Application manual...

  • Page 641: Current Transformer Requirements For Cts According To Other Standards

    CTs according to class PX, PXR, X and TPS must have a rated knee point e.m.f. that fulfills the following: knee × × TD S TD S Calculated (Equation 134) EQUATION1893.ANSI V1 EN-US Bay control REC670 2.2 ANSI Application manual...

  • Page 642: Current Transformers According To Ansi/Ieee

    EQUATION2101 V2 EN-US The following guide may also be referred for some more application aspects of ANSI class CTs: IEEE C37.110 (2007), IEEE Guide for the Application of Current Transformers Used for Protective Relaying Purposes. Bay control REC670 2.2 ANSI Application manual...

  • Page 643: Voltage Transformer Requirements

    IEEE1588. The clocks used must follow the IEEE1588 standard BMC (Best Master Algorithm) and shall, for instance, not claim class 7 for a longer time than it can guarantee 1us absolute accuracy. Bay control REC670 2.2 ANSI Application manual...

  • Page 644: Protection And Control Terminals In Digital Telecommunication Networks

    PDH-system via the SDH-system in transparent mode. • Maximum clock deviation <±50 ppm nominal, <±100 ppm operational • Jitter and Wander according to ITU-T G.823 and G.825 • Buffer memory <100 μs Bay control REC670 2.2 ANSI Application manual...
  • Page 645 • A fixed asymmetry can be compensated (setting of asymmetric delay in built in HMI or the parameter setting tool PST). IED with GPS clock • Independent of asymmetry. Bay control REC670 2.2 ANSI Application manual...

  • Page 647: Section 25 Glossary

    British Standards Binary signal transfer function, receiver blocks Binary signal transfer function, transmit blocks C37.94 IEEE/ANSI protocol used when sending binary signals between IEDs Controller Area Network. ISO standard (ISO 11898) for serial communication Bay control REC670 2.2 ANSI Application manual...
  • Page 648 Carrier send Current transformer Communication unit CVT or CCVT Capacitive voltage transformer Delayed autoreclosing DARPA Defense Advanced Research Projects Agency (The US developer of the TCP/IP protocol etc.) DBDL Dead bus dead line Bay control REC670 2.2 ANSI Application manual...
  • Page 649 Modular 20 channel telecommunication system for speech, data and protection signals FOX 512/515 Access multiplexer FOX 6Plus Compact time-division multiplexer for the transmission of up to seven duplex channels of digital data over optical fibers Flexible product naming Bay control REC670 2.2 ANSI Application manual...
  • Page 650 IEC 61850 Substation automation communication standard IEC 61850–8–1 Communication protocol standard IEEE Institute of Electrical and Electronics Engineers IEEE 802.12 A network technology standard that provides 100 Mbits/s on twisted-pair or optical fiber cable Bay control REC670 2.2 ANSI Application manual...
  • Page 651 IP 54 Ingression protection, according to IEC 60529, level IP54-Dust-protected, protected against splashing water. Internal failure signal IRIG-B: InterRange Instrumentation Group Time code format B, standard 200 International Telecommunications Union Local area network Bay control REC670 2.2 ANSI Application manual...
  • Page 652 The relay “sees” the fault but perhaps it should not have seen it. Peripheral component interconnect, a local data bus Pulse code modulation PCM600 Protection and control IED manager PC-MIP Mezzanine card standard Bay control REC670 2.2 ANSI Application manual...
  • Page 653 Short circuit location Station control system SCADA Supervision, control and data acquisition System configuration tool according to standard IEC 61850 Service data unit Small form-factor pluggable (abbreviation) Optical Ethernet port (explanation) Serial communication module. Bay control REC670 2.2 ANSI Application manual...
  • Page 654 Time delayed gound-fault protection function Transport Layer Security Transmit (disturbance data) TNC connector Threaded Neill-Concelman, a threaded constant impedance version of a BNC connector Trip (recorded fault) TPZ, TPY, TPX, TPS Current transformer class according to IEC Bay control REC670 2.2 ANSI Application manual...
  • Page 655 A digital signalling interface primarily used for telecom equipment Three times zero-sequence current.Often referred to as the residual or the ground-fault current Three times the zero sequence voltage. Often referred to as the residual voltage or the neutral point voltage Bay control REC670 2.2 ANSI Application manual...
  • Page 658 — 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.

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