Page 1 — R E L I O N ® 670 SERIES Bay control REC670 Version 2.2 IEC Application manual...
Page 4 Copyright This document and parts thereof must not be reproduced or copied without written permission from ABB, and the contents thereof must not be imparted to a third party, nor used for any unauthorized purpose. The software and hardware described in this document is furnished under a license and may be used or disclosed only in accordance with the terms of such license.
Page 5 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
Back-up protection functions............35 Control and monitoring functions............37 Communication.................45 Basic IED functions................48 Section 3 Configuration..............51 Description of configuration REC670..........51 Introduction..................51 Description of configuration A30..........51 Description of configuration B30..........52 Description of configuration C30..........54 Description of configuration D30..........57 Section 4 Analog inputs..............59...
Page 8 Short guidance for use of UDP..........101 Protocol reporting via IEEE 1344 and C37.118 PMUREPORT..103 Identification................103 Application................. 103 Operation principle..............106 Frequency reporting............. 107 Reporting filters..............109 Scaling Factors for ANALOGREPORT channels....110 Bay control REC670 2.2 IEC Application manual...
Page 9 Instantaneous residual overcurrent protection EFPIOC ....157 Identification................157 Application................. 157 Setting guidelines..............157 Directional residual overcurrent protection, four steps EF4PTOC .160 Identification................160 Application................. 160 Setting guidelines..............162 Common settings for all steps..........163 Bay control REC670 2.2 IEC Application manual...
Page 10 Pole discordance protection CCPDSC........... 201 Identification................201 Application................. 201 Setting guidelines..............202 Directional underpower protection GUPPDUP....... 202 Identification................202 Application................. 203 Setting guidelines..............205 Directional overpower protection GOPPDOP ........208 Identification................208 Application................. 208 Setting guidelines..............210 Bay control REC670 2.2 IEC Application manual...
Page 11 Equipment protection, such as for motors, generators, reactors and transformers............ 232 Equipment protection, capacitors......... 232 Power supply quality............232 High impedance earthed systems........232 The following settings can be done for the two step overvoltage protection............232 Bay control REC670 2.2 IEC Application manual...
Page 12 Setting guidelines..............248 Frequency time accumulation protection function FTAQFVR..249 Identification................249 Application................. 249 Setting guidelines..............251 Section 11 Multipurpose protection..........253 General current and voltage protection CVGAPC......253 Identification................253 Application................. 253 Bay control REC670 2.2 IEC Application manual...
Page 13 Negative sequence based............278 Zero sequence based............279 Delta U and delta I ...............279 Dead line detection...............280 Fuse failure supervision VDSPVC..........280 Identification................280 Application................. 281 Setting guidelines..............282 Section 14 Control................283 Synchrocheck, energizing check, and synchronizing SESRSYN...283 Bay control REC670 2.2 IEC Application manual...
Page 14 External selection of auto reclosing mode......309 Auto reclosing reclaim timer..........310 Pulsing of the circuit breaker closing command and counter................. 310 Transient fault...............310 Permanent fault and reclosing unsuccessful signal..... 310 Bay control REC670 2.2 IEC Application manual...
Page 15 Signals from all feeders............352 Signals from bus-coupler............354 Configuration setting............356 Interlocking for transformer bay AB_TRAFO ......357 Application................357 Signals from bus-coupler............358 Configuration setting............358 Interlocking for bus-section breaker A1A2_BS......359 Application................359 Signals from all feeders............359 Bay control REC670 2.2 IEC Application manual...
Page 16 DPGAPC..................426 Identification................426 Application................. 426 Setting guidelines..............427 Single point generic control 8 signals SPC8GAPC......427 Identification................427 Application................. 428 Setting guidelines..............428 AutomationBits, command function for DNP3.0 AUTOBITS..428 Identification................428 Bay control REC670 2.2 IEC Application manual...
Page 17 Application................. 444 Setting guidelines..............444 Scheme communication logic for residual overcurrent protection ECPSCH ...............445 Identification................445 Application................. 445 Setting guidelines..............446 Current reversal and weak-end infeed logic for residual overcurrent protection ECRWPSCH..........447 Identification................447 Bay control REC670 2.2 IEC Application manual...
Page 18 Setting guidelines..............460 Configurable logic blocks..............460 Application................. 460 Setting guidelines..............460 Configuration................ 460 Fixed signal function block FXDSIGN..........462 Identification................462 Application................. 462 Boolean 16 to Integer conversion B16I.......... 463 Identification................463 Application................. 463 Bay control REC670 2.2 IEC Application manual...
Page 19 Setting guidelines..............476 Setting examples..............479 Gas medium supervision SSIMG........... 485 Identification................485 Application................. 485 Setting guidelines..............486 Liquid medium supervision SSIML..........487 Identification................487 Application................. 487 Setting guidelines..............487 Breaker monitoring SSCBR............488 Identification................488 Bay control REC670 2.2 IEC Application manual...
Page 20 Estimation of transformer insulation life LOLSPTR ....... 506 Application................. 506 Setting guidelines..............511 Setting example.................520 Transformer Rated Data............520 Setting parameters for insulation loss of life calculation function (LOL1)..............520 Section 18 Metering............... 525 Pulse-counter logic PCFCNT............525 Identification................525 Bay control REC670 2.2 IEC Application manual...
Page 21 Loss of communication when used with LDCM....542 Setting examples for IEC/UCA 61850-9-2LE and time synchronization..............547 IEC 61850 quality expander QUALEXP........552 LON communication protocol............553 Application................. 553 MULTICMDRCV and MULTICMDSND........554 Identification................. 555 Application................555 Bay control REC670 2.2 IEC Application manual...
Page 22 IED identifiers TERMINALID............577 Application................. 577 Product information PRODINF............577 Application................. 577 Factory defined settings............577 Measured value expander block RANGE_XP........ 578 Identification................578 Application................. 579 Setting guidelines..............579 Parameter setting groups............... 579 Bay control REC670 2.2 IEC Application manual...
Page 23 Process bus IEC/UCA 61850-9-2LE synchronization..596 Section 24 Requirements............... 597 Current transformer requirements..........597 Current transformer basic classification and requirements..597 Conditions..................599 Fault current................600 Secondary wire resistance and additional load......600 General current transformer requirements........ 601 Bay control REC670 2.2 IEC Application manual...
Page 24 SNTP server requirements............. 606 PTP requirements................607 Sample specification of communication requirements for the protection and control terminals in digital telecommunication networks..................607 IEC/UCA 61850-9-2LE Merging unit requirements ....... 608 Section 25 Glossary............... 611 Bay control REC670 2.2 IEC Application manual...
Page 25: 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 IEC Application manual...
Page 26: Product Documentation
The manual provides procedures for the checking of external circuitry and energizing the IED, parameter setting and configuration as well as verifying settings by secondary injection. The manual Bay control REC670 2.2 IEC Application manual...
Page 27: 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 IEC Application manual...
Page 28: Related Documents
GUID-2945B229-DAB0-4F15-8A0E-B9CF0C2C7B15 v12 The electrical warning icon indicates the presence of a hazard which could result in electrical shock. The warning icon indicates the presence of a hazard which could result in personal injury. Bay control REC670 2.2 IEC Application manual...
Page 29: 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 IEC Application manual...
Page 30: Iec 61850 Edition 1 / Edition 2 Mapping
SECLLN0 ALMCALH ALMCALH ALMCALH ALTIM ALTIM ALTMS ALTMS ALTRK ALTRK BCZPDIF BCZPDIF BCZPDIF BCZSPDIF BCZSPDIF BCZSPDIF BCZTPDIF BCZTPDIF BCZTPDIF BDCGAPC SWSGGIO BBCSWI BDCGAPC BDZSGAPC BBS6LLN0 LLN0 BDZSGAPC BDZSGAPC Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 31 BRPTOC BRPTOC BRPTOC BTIGAPC B16IFCVI BTIGAPC BUSPTRC_B1 BUSPTRC BUSPTRC BBSPLLN0 BUSPTRC_B2 BUSPTRC BUSPTRC BUSPTRC_B3 BUSPTRC BUSPTRC BUSPTRC_B4 BUSPTRC BUSPTRC BUSPTRC_B5 BUSPTRC BUSPTRC BUSPTRC_B6 BUSPTRC BUSPTRC BUSPTRC_B7 BUSPTRC BUSPTRC Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 32 BZNPDIF BZNPDIF_Z2 BZNPDIF BZNPDIF BZNPDIF_Z3 BZNPDIF BZNPDIF BZNPDIF_Z4 BZNPDIF BZNPDIF BZNPDIF_Z5 BZNPDIF BZNPDIF BZNPDIF_Z6 BZNPDIF BZNPDIF BZNSPDIF_A BZNSPDIF BZASGAPC BZASPDIF BZNSGAPC BZNSPDIF BZNSPDIF_B BZNSPDIF BZBSGAPC BZBSPDIF BZNSGAPC BZNSPDIF Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 33 DRPRDRE DRPRDRE ECPSCH ECPSCH ECPSCH ECRWPSCH ECRWPSCH ECRWPSCH EF2PTOC EF2LLN0 EF2PTRC EF2PTRC EF2RDIR EF2RDIR GEN2PHAR GEN2PHAR PH1PTOC PH1PTOC EF4PTOC EF4LLN0 EF4PTRC EF4PTRC EF4RDIR EF4RDIR GEN4PHAR GEN4PHAR PH1PTOC PH1PTOC Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 34 L6CPTRC LAPPGAPC LAPPLLN0 LAPPPDUP LAPPPDUP LAPPPUPF LAPPPUPF LCCRPTRC LCCRPTRC LCCRPTRC LCNSPTOC LCNSPTOC LCNSPTOC LCNSPTOV LCNSPTOV LCNSPTOV LCP3PTOC LCP3PTOC LCP3PTOC LCP3PTUC LCP3PTUC LCP3PTUC LCPTTR LCPTTR LCPTTR LCZSPTOC LCZSPTOC LCZSPTOC Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 35 OEXPVPH OOSPPAM OOSPPAM OOSPPAM OOSPTRC OV2PTOV GEN2LLN0 OV2PTOV OV2PTOV PH1PTRC PH1PTRC PAPGAPC PAPGAPC PAPGAPC PCFCNT PCGGIO PCFCNT PH4SPTOC GEN4PHAR GEN4PHAR OCNDLLN0 PH1BPTOC PH1BPTOC PH1PTRC PH1PTRC PHPIOC PHPIOC PHPIOC Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 36 SPGAPC SPGGIO SPGAPC SSCBR SSCBR SSCBR SSIMG SSIMG SSIMG SSIML SSIML SSIML STBPTOC STBPTOC BBPMSS STBPTOC STEFPHIZ STEFPHIZ STEFPHIZ STTIPHIZ STTIPHIZ STTIPHIZ SXCBR SXCBR SXCBR SXSWI SXSWI SXSWI Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 37 WRNCALH WRNCALH ZC1PPSCH ZPCPSCH ZPCPSCH ZC1WPSCH ZPCWPSCH ZPCWPSCH ZCLCPSCH ZCLCPLAL ZCLCPSCH ZCPSCH ZCPSCH ZCPSCH ZCRWPSCH ZCRWPSCH ZCRWPSCH ZCVPSOF ZCVPSOF ZCVPSOF ZGVPDIS ZGVLLN0 PH1PTRC PH1PTRC ZGVPDIS ZGVPDIS ZGVPTUV ZGVPTUV Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 38 ZMFPDIS ZMFPDIS ZMFPTRC ZMFPTRC ZMMMXU ZMMMXU ZMHPDIS ZMHPDIS ZMHPDIS 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 IEC Application manual...
Page 39: Section 2 Application
Several breaker failure functions are available to provide a breaker failure function independent from the protection IEDs, also for a complete one- and a half breaker diameter. Bay control REC670 2.2 IEC Application manual...
Page 40: 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 IEC Application manual...
Page 41: Back-Up Protection Functions
LCPTTR Thermal overload 1-C51 1-C52 2-C53 1-C51 protection, one time constant, Celsius LFPTTR Thermal overload 1-C51 1-C52 2-C53 1-C51 protection, one time constant, Fahrenheit Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 42 FTAQFVR Frequency time 0-12 accumulation protection Multipurpose protection CVGAPC General current and 4-F01 4-F01 4-F01 4-F01 voltage protection General calculation SMAIHPAC Multipurpose filter 1) 67 requires voltage 2) 67N requires voltage Bay control REC670 2.2 IEC Application manual...
Page 43: Control And Monitoring Functions
Tap changer control and supervision, 32 binary inputs SLGAPC Logic rotating switch for function selection and LHMI presentation VSGAPC Selector mini switch DPGAPC Generic communication function for Double Point indication Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 44 Logic for group warning INDCALH Logic for group indication AND, GATE, INV, Basic configurable logic blocks 40-420 40-42 40-42 40-42 40-42 LLD, OR, (see Table 3) PULSETIMER, RSMEMORY, SRMEMORY, TIMERSET, XOR Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 45 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 PULSETIMER RSMEMORY Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 46 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 IEC Application manual...
Page 47 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 IEC Application manual...
Page 48 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 RSMEMORYQT SRMEMORYQT TIMERSETQT XORQT Bay control REC670 2.2 IEC Application manual...
Page 49 EVENT Event function DRPRDRE, Disturbance report A4RADR, B1RBDR- B22RBDR SPGAPC Generic communication function for Single Point indication SP16GAPC Generic communication function for Single Point indication 16 inputs Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 50 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 IEC Application manual...
Page 51: Communication
GOOSEMVRCV GOOSE function block to receive a measurand value GOOSESPRCV GOOSE function block to receive a single point value VCTRSEND Horizontal communication via GOOSE for VCTR Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 52 Synchrophasor report, 8 1-P32 1-P32 1-P32 PMUREPORT, phasors (see Table 9) PHASORREPORT1, ANALOGREPORT1 BINARYREPORT1, SMAI1 - SMAI12 3PHSUM PMUSTATUS Precision time protocol FRONTSTATUS Access point diagnostic for front Ethernet port Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 53 Local acceleration logic 1-K01 1-K01 1-K01 1-K01 ECPSCH Scheme communication 1-C51 1-C52 1-C53 1-C51 logic for residual overcurrent protection ECRWPSCH Current reversal and weak- 1-C51 1-C52 1-C53 1-C51 end infeed logic for residual overcurrent protection Bay control REC670 2.2 IEC Application manual...
Page 54: Basic Ied Functions
Signal matrix for binary outputs SMMI Signal matrix for mA inputs SMAI1 - SMAI12 Signal matrix for analog inputs 3PHSUM Summation block 3 phase ATHSTAT Authority status ATHCHCK Authority check Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 55 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 IEC Application manual...
Page 57: 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 IEC Application manual...
Page 58: Description Of Configuration B30
Section 3 1MRK 511 401-UEN 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 59 Our proposal for a full version with control is to use two binary input modules and one or two binary output modules. For systems without Substation Automation a second binary output board might be required. Bay control REC670 2.2 IEC Application manual...
Page 60: Description Of Configuration C30
Section 3 1MRK 511 401-UEN 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 61 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 IEC Application manual...
Page 62 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 IEC Application manual...
Page 63: Description Of Configuration D30
Section 3 1MRK 511 401-UEN 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 64 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 IEC Application manual...
Page 65: Section 4 Analog Inputs
The availability of VT inputs depends on the ordered transformer input module (TRM) type. Setting guidelines SEMOD55068-1 v1 SEMOD130348-4 v4 The available setting parameters related to analog inputs are depending on the actual hardware (TRM) and the logic configuration made in PCM600. Bay control REC670 2.2 IEC Application manual...
Page 66: Setting Of The Phase Reference Channel
Set parameter Set parameter CTStarPoint CTStarPoint Correct Setting is Correct Setting is "ToObject" "FromObject" en05000456.vsd IEC05000456 V1 EN-US Figure 6: Internal convention of the directionality in the IED Bay control REC670 2.2 IEC Application manual...
Page 67: Example 1
Forward. This means that the protection is looking towards the line. 4.2.2.2 Example 2 SEMOD55055-29 v7 Two IEDs used for protection of two objects and sharing a CT. Bay control REC670 2.2 IEC Application manual...
Page 68: Example 3
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. 4.2.2.3 Example 3 SEMOD55055-35 v7 One IED used to protect two objects. Bay control REC670 2.2 IEC Application manual...
Page 69 The CT direction for the current channels to the line protection is set with the line as reference object and the directional functions of the line protection shall be set to Forward to protect the line. Bay control REC670 2.2 IEC Application manual...
Page 70 CTStarPoint with CTStarPoint with Transformer as Transformer as reference object. reference object. Correct setting is Correct setting is "ToObject" "ToObject" IEC05000462 V2 EN-US Figure 10: Example how to set CTStarPoint parameters in the IED Bay control REC670 2.2 IEC Application manual...
Page 71 CT inputs marked with 1 in Figure 11, set CTStarPoint = FromObject, and for all CT inputs marked with 2 in Figure 11, set CTStarPoint = ToObject. Regardless which one of the above two options is selected, busbar differential protection will behave correctly. Bay control REC670 2.2 IEC Application manual...
Page 72: Examples On How To Connect, Configure And Set Ct Inputs For Most Commonly Used Ct Connections
CT polarity marking is correct! It shall be noted that depending on national standard and utility practices, the rated secondary current of a CT has typically one of the following values: • • Bay control REC670 2.2 IEC Application manual...
Page 73: 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 IEC Application manual...
Page 74 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 IEC Application manual...
Page 75 GRPL1, GRPL2 and GRPL3. If GRP2N is connected, the data reflects the measured value of GRP2N. Another alternative is to have the star point of the three-phase CT set as shown in Figure 14: Bay control REC670 2.2 IEC Application manual...
Page 76 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 IEC Application manual...
Page 77 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 IEC Application manual...
Page 78: 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 IEC Application manual...
Page 79 Section 4 1MRK 511 401-UEN A Analog inputs IL1-IL2 SMAI2 IL2-IL3 BLOCK AI3P REVROT ^GRP2L1 IL3-IL1 ^GRP2L2 ^GRP2L3 ^GRP2N IEC11000027-3-en.vsdx Protected Object IEC11000027 V3 EN-US Figure 16: Delta DAB connected three-phase CT set Bay control REC670 2.2 IEC Application manual...
Page 80 If frequency tracking and compensation is required (this feature is typically required only DFTReference for IEDs installed in the generating stations) then the setting parameters shall be set accordingly. Another alternative is to have the delta connected CT set as shown in figure 17: Bay control REC670 2.2 IEC Application manual...
Page 81: 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 IEC Application manual...
Page 82 IED, which are connected to this preprocessing function block. If frequency tracking and compensation is required (this feature is typically required DFTReference only for IEDs installed in the power plants) then the setting parameters shall be set accordingly. Bay control REC670 2.2 IEC Application manual...
Page 83: 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-earth voltage from the VT. 4.2.4.1 Example SEMOD55055-47 v3 Consider a VT with the following data: Bay control REC670 2.2 IEC Application manual...
Page 84: Examples How To Connect, Configure And Set Vt Inputs For Most Commonly Used Vt Connections
100 V • 110 V • 115 V • 120 V • 230 V The IED fully supports all of these values and most of them will be shown in the following examples. Bay control REC670 2.2 IEC Application manual...
Page 85: Examples On How To Connect A Three Phase-To-Earth Connected Vt To The Ied
For correct terminal designations, see the connection diagrams valid for the delivered IED. SMAI2 BLOCK AI3P REVROT ^GRP2L1 ^GRP2L2 ^GRP2L3 ^GRP2N #Not used IEC06000599-4-en.vsdx IEC06000599 V4 EN-US Figure 20: A Three phase-to-earth connected VT Bay control REC670 2.2 IEC Application manual...
Page 86 Inside the IED, only the ratio of these two parameters is used. It shall be noted that the ratio of the entered values exactly corresponds to ratio of one individual VT. (Equation 2) EQUATION1903 V1 EN-US Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 87: 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 IEC Application manual...
Page 88 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 IEC Application manual...
Page 89: Example On How To Connect An Open Delta Vt To The Ied For High Impedance Earthed Or Unearthed 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 IEC Application manual...
Page 90 BLOCK AI3P REVROT ^GRP2L1 # Not Used ^GRP2L2 # Not Used ^GRP2L3 # Not Used ^GRP2N +3Uo IEC06000601-4-en.vsdx IEC06000601 V4 EN-US Figure 23: Open delta connected VT in high impedance earthed power system Bay control REC670 2.2 IEC Application manual...
Page 91 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 IEC Application manual...
Page 92: For Low Impedance Earthed Or Solidly Earthed 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 IEC Application manual...
Page 93 REVROT # Not Used ^GRP2L1 # Not Used ^GRP2L2 # Not Used ^GRP2L3 ^GRP2N +3Uo IEC06000602-4-en.vsdx IEC06000602 V4 EN-US Figure 24: Open delta connected VT in low impedance or solidly earthed power system Bay control REC670 2.2 IEC Application manual...
Page 94 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 IEC Application manual...
Page 95: Section 5 Local Hmi
AMU0600442 v14 IEC13000239-3-en.vsd IEC13000239 V3 EN-US Figure 25: Local human-machine interface The LHMI of the IED contains the following elements: • Keypad • Display (LCD) • LED indicators • Communication port for PCM600 Bay control REC670 2.2 IEC Application manual...
Page 96: Display
4 Scroll bar (appears when needed) The function key button panel shows on request what actions are possible with the function buttons. Each function button has a LED indication that can be used as a Bay control REC670 2.2 IEC Application manual...
Page 97 Each panel is shown by pressing one of the function buttons or the 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 IEC Application manual...
Page 98: 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 IEC Application manual...
Page 99: 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 IEC Application manual...
Page 100 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 Menu Bay control REC670 2.2 IEC Application manual...
Page 101: 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 IEC Application manual...
Page 102: Parameter Management
Numerical values are presented either in integer or in decimal format with minimum and maximum values. Character strings can be edited character by character. Enumerated values have a predefined set of selectable values. Bay control REC670 2.2 IEC Application manual...
Page 103: 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 IEC Application manual...
Page 105: C37.118 Phasor Measurement Data Streaming Protocol Configuration Pmuconf
Whereas, for UDP clients, the PMUREPORT instance for each UDP channel is defined by the user in the PMU and the client has to know the PMU ID corresponding to that instance in order to be able to communicate. More Bay control REC670 2.2 IEC Application manual...
Page 106: Short Guidance For Use Of Tcp
C37.118 protocol (C37.118 TCPport). Client can communicate with the IED over IEEE1344 protocol using the selected TCP port defined in 1344TCPport, and can communicate with the IED over IEEE C37.118 protocol using the selected TCP port number in C37.118TCPport. Bay control REC670 2.2 IEC Application manual...
Page 107: Short Guidance For Use Of Udp
PMUReportUDP[x] – Instance number of PMUREPORT function block that must send data on this UDP stream (UDP client group[x]) UDPDestAddres[x] – UDP destination address for UDP client group[x] (unicast / multicast address range) Bay control REC670 2.2 IEC Application manual...
Page 108 UDP data will be only sent to that specific unicast IP address. In addition to UDPDestAddress[x] parameter, UDPDestPort[x] parameter is used to define the UDP destination port number for UDP client group[x]. Bay control REC670 2.2 IEC Application manual...
Page 109: Protocol Reporting Via Ieee 1344 And C37.118 Pmureport
The message generated by the PMUREPORT function block is set in accordance with the IEEE C37.118 and/or IEEE 1344 standards. Bay control REC670 2.2 IEC Application manual...
Page 110 PHASORREPORT blocks including 32 configurable phasor channels (8 phasor channels in each PHASORREPORT block). Each phasor channel can be configured as a 3-phase (symmetrical components positive/ negative/zero) or single-phase phasor (L1/L2/L3). Bay control REC670 2.2 IEC Application manual...
Page 111 BINARYREPORT blocks capable of reporting up to 24 Binary signals (8 Binary signals in each BINARYREPORT block). These binary signals can be for example dis-connector or breaker position indications or internal/ external protection alarm signals. Bay control REC670 2.2 IEC Application manual...
Page 112: Operation Principle
The IEEE C37.118 standard also imposes a variety of steady state and dynamic requirements which are fulfilled in the IED with the help of high accuracy measurements and advanced filtering techniques. Bay control REC670 2.2 IEC Application manual...
Page 113: Frequency Reporting
9 Hz to 95 Hz. In order to do that, the three-phase voltage signal shall be connected to the IED. Then IED can adapt its filtering algorithm in order to properly measure phasors of all current and voltage signals connected to the Bay control REC670 2.2 IEC Application manual...
Page 114 FREQREFCHERR output states if the reference frequency is good, or if there is an error or if the reference channel is unavailable. For more information refer to the table PMUREPORT monitored data. Bay control REC670 2.2 IEC Application manual...
Page 115: Reporting Filters
This has to be considered in connection with 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, Bay control REC670 2.2 IEC Application manual...
Page 116: 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. Bay control REC670 2.2 IEC Application manual...
Page 117 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 IEC Application manual...
Page 118: Pcm600 Application Configuration Tool (Act)
3 ms while the PHASORREPORT block is expecting input every 0.9 ms. The PHASORREPORT filtering window is designed to receive updated input every 0.9 ms and therefore the application will fail. Bay control REC670 2.2 IEC Application manual...
Page 119 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 IEC Application manual...
Page 120 In this example, 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 IEC Application manual...
Page 121 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 IEC Application manual...
Page 122 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 IEC Application manual...
Page 123 PHASORREPORT function block. On the other hand, when 3PHSUM uses external DFT reference, it also adapts its filtering according to the SMAI reference block. Therefore, in order to avoid two Bay control REC670 2.2 IEC Application manual...
Page 124: 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: PMUREPORT PHASORREPORT ANALOGREPORT BINARYREPORT Bay control REC670 2.2 IEC Application manual...
Page 125 1, 2 and 3 organization defined in IEEE C37.118.2 message format. Here the user can select the data type of the calculated synchrophasors. The options are Integer or Float data. The Bay control REC670 2.2 IEC Application manual...
Page 126 IEEE floating-point format. The data sent via the DFREQ field is Rate Of Change Of Frequency (ROCOF), in Hertz per second times 100. It is ranged from –327.67 to Bay control REC670 2.2 IEC Application manual...
Page 127 PHASORREPORT is the function block responsible for reporting the synchrophasors. Each instance of PMUREPORT function block has 32 phasor channels with the following setting parameters; where X is a number from 1 to Bay control REC670 2.2 IEC Application manual...
Page 128 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 IEC Application manual...
Page 129: High Impedance Differential Protection, Single Phase Hzpdif
Restricted earth fault protection for transformer, generator and shunt reactor windings • Restricted earth fault protection The application is dependent on the primary system arrangements and location of breakers, available CT cores and so on. Bay control REC670 2.2 IEC Application manual...
Page 130 Section 7 1MRK 511 401-UEN A Differential protection 3·Id 3·Id 3·Id 3·Id 3·Id IEC05000163-4-en.vsd IEC05000163 V4 EN-US Bay control REC670 2.2 IEC Application manual...
Page 131: The Basics Of The High Impedance Principle
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 IEC Application manual...
Page 132 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 IEC Application manual...
Page 133 Normally the voltage can be increased to higher values than the calculated minimum U>Trip 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 IEC Application manual...
Page 134 ΣImag is the sum of the magnetizing currents from all CTs in the circuit (for example, 4 for restricted earth fault protection, 2 for reactor differential protection, 3-5 for autotransformer differential protection). Bay control REC670 2.2 IEC Application manual...
Page 135 The series resistor is dimensioned for 200 W. Preferable the U>Trip SeriesResistor should always be lower than 200 W to allow continuous activation during testing. If this value is exceeded, testing should be done with a transient faults. Bay control REC670 2.2 IEC Application manual...
Page 136 Rres I> Protected Object a) Through load situation b) Through fault situation c) Internal faults IEC05000427-2-en.vsd IEC05000427 V2 EN-US Figure 49: The high impedance principle for one phase with two current transformer inputs Bay control REC670 2.2 IEC Application manual...
Page 137: Connection Examples For High Impedance Differential Protection
3-Ph Plate with Metrosils and Resistors IEC07000193-5-en.vsdx IEC07000193 V5 EN-US Figure 50: CT connections for high impedance differential protection Description Scheme earthing point It is important to insure that only one earthing point exist in this scheme. Bay control REC670 2.2 IEC Application manual...
Page 138: Connections For 1Ph High Impedance Differential Protection Hzpdif
G2AI2 ^GRP2L2 G2AI3 AI04 (I) ^GRP2L3 G2AI4 ^GRP2N AI05 (I) Protected Object AI06 (I) 1-Ph Plate with Metrosil and Resistor =IEC07000194=5=en=Original.vsdx IEC07000194 V5 EN-US Figure 51: CT connections for restricted earth fault protection Bay control REC670 2.2 IEC Application manual...
Page 139: Setting Guidelines
Measure the value achieved and set this value for this parameter. The value shall always be high impedance. This means for example, for 1A circuits say bigger than 400 ohms (400 VA) and Bay control REC670 2.2 IEC Application manual...
Page 140: T-Feeder Protection
T-zone is protected with a separate differential protection scheme. The 1Ph high impedance differential HZPDIF function in the IED allows this to be done efficiently, see Figure 52. Bay control REC670 2.2 IEC Application manual...
Page 141 Section 7 1MRK 511 401-UEN A Differential protection 3·Id IEC05000165-2-en.vsd IEC05000165 V2 EN-US 3·Id IEC05000739-2-en.vsd IEC05000739 V2 EN-US Figure 52: The protection scheme utilizing the high impedance function for the T-feeder Bay control REC670 2.2 IEC Application manual...
Page 142 As this application requires to be so sensitive select SeriesResistor= 2000 ohm, which gives an IED operating current of 100 mA. Calculate the primary sensitivity at operating voltage using the following equation. Bay control REC670 2.2 IEC Application manual...
Page 143: Tertiary Reactor Protection
HZPDIF can be used to protect the tertiary reactor for phase faults as well as earth faults if the power system of the tertiary winding is direct or low impedance earthed. Bay control REC670 2.2 IEC Application manual...
Page 144 Bay control REC670 2.2 IEC Application manual...
Page 145 For the voltage dependent resistor current the peak value of voltage 30 ˣ √2 is used. Then the RMS current is calculated by dividing obtained current value from the metrosil curve with √2. Use the maximum value from the metrosil curve given in Figure 54. Bay control REC670 2.2 IEC Application manual...
Page 146: Alarm Level Operation
The metrosil operating characteristic is given in the following figure. 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 IEC Application manual...
Page 147: Instantaneous Phase Overcurrent Protection Phpioc
(and relay) point, for which very high fault currents are characteristic. The instantaneous phase overcurrent protection PHPIOC can operate in 10 ms for faults characterized by very high currents. Bay control REC670 2.2 IEC Application manual...
Page 148: Setting Guidelines
The following fault calculations have to be done for three-phase, single-phase-to- earth and two-phase-to-earth faults. With reference to Figure 55, apply a fault in B and then calculate the current through-fault phase current I . The calculation Bay control REC670 2.2 IEC Application manual...
Page 149 5% for the maximum possible transient overreach have to be introduced. An additional 20% is suggested due to the inaccuracy of the instrument transformers under transient conditions and inaccuracy in the system data. Bay control REC670 2.2 IEC Application manual...
Page 150: 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 ) on the healthy line (this applies for single-phase-to-earth and two-phase-to- earth faults) is calculated. Bay control REC670 2.2 IEC Application manual...
Page 151 The IED setting value IP>> is given in percentage of the primary base current value, IBase. The value for IP>> is given from this formula: >>= × IBase (Equation 26) EQUATION1147 V3 EN-US Bay control REC670 2.2 IEC Application manual...
Page 152: Directional Phase Overcurrent Protection, Four Steps Oc4Ptoc
The selectivity between different overcurrent protections is normally enabled by co-ordination between the function time delays of the different protections. To enable optimal co-ordination between all overcurrent Bay control REC670 2.2 IEC Application manual...
Page 153: Setting Guidelines
The parameters for the directional phase overcurrent protection, four steps OC4PTOC are set via the local HMI or PCM600. The following settings can be done for OC4PTOC. Bay control REC670 2.2 IEC Application manual...
Page 154 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 IEC Application manual...
Page 155: Settings For Each Step
DirModex: The directional mode of step x. Possible settings are Off/Non- directional/Forward/Reverse. Characteristx: Selection of time characteristic for step x. Definite time delay and different types of inverse time characteristics are available according to Table 19. Bay control REC670 2.2 IEC Application manual...
Page 156 ANSI reset characteristic according to standard. If IMinx is set above Ix> for any step the ANSI reset works as if current is zero when current drops below IMinx. Bay control REC670 2.2 IEC Application manual...
Page 157 The delay characteristics are described in Technical manual. There are some restrictions regarding the choice of the reset delay. For the definite time delay characteristics, the possible delay time setting instantaneous (1) and IEC (2 = set constant time reset). Bay control REC670 2.2 IEC Application manual...
Page 158: Setting Example
The protection reset current must also be considered so that a short peak of overcurrent does not cause the operation of a protection even when the overcurrent has ceased. This phenomenon is described in Figure 61. Bay control REC670 2.2 IEC Application manual...
Page 159 The maximum load current on the line has to be estimated. There is also a demand that all faults within the zone that the protection shall cover must be detected by the phase overcurrent protection. The minimum fault current Iscmin to be detected by Bay control REC670 2.2 IEC Application manual...
Page 160 This is mostly used in the case of inverse time overcurrent protection. Figure shows how the time-versus-current curves are plotted in a diagram. The time setting is chosen to get the shortest fault time with maintained selectivity. Bay control REC670 2.2 IEC Application manual...
Page 161 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 IEC Application manual...
Page 162 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 IEC Application manual...
Page 163: Instantaneous Residual Overcurrent Protection Efpioc
Some guidelines for the choice of setting parameter for EFPIOC is given. M12762-6 v8 Common base IED values for primary current (IBase), primary voltage (UBase) and primary power (SBase) are set in the global base values for settings function GBASVAL. Bay control REC670 2.2 IEC Application manual...
Page 164 The function shall not operate for any of the calculated currents to the protection. The minimum theoretical current setting (Imin) will be:    in MAX I (Equation 33) EQUATION284 V2 EN-US Bay control REC670 2.2 IEC Application manual...
Page 165 = 1.3 × I (Equation 36) EQUATION288 V3 EN-US The IED setting value IN>> is given in percent of the primary base current value, IBase. The value for IN>> is given by the formula: Bay control REC670 2.2 IEC Application manual...
Page 166: Directional Residual Overcurrent Protection, Four Steps Ef4Ptoc
EF4PTOC 51N_67N 4(IN>) protection, four steps TEF-REVA V2 EN-US 8.4.2 Application M12509-12 v10 The directional residual overcurrent protection, four steps EF4PTOC is used in several applications in the power system. Some applications are: Bay control REC670 2.2 IEC Application manual...
Page 167 Time characteristics Curve name ANSI Extremely Inverse ANSI Very Inverse ANSI Normal Inverse ANSI Moderately Inverse ANSI/IEEE Definite time ANSI Long Time Extremely Inverse ANSI Long Time Very Inverse Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 168: 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 IEC Application manual...
Page 169: Common Settings For All Steps
IN>Dir IEC05000135-5-en.vsdx IEC05000135 V5 EN-US Figure 67: Relay characteristic angle given in degree In a normal transmission network a normal value of RCA is about 65°. The setting range is -180° to +180°. Bay control REC670 2.2 IEC Application manual...
Page 170: Nd Harmonic Restrain
This will give a declining residual current in the network, as the inrush current is deviating between the phases. There is a risk that the residual overcurrent function will give an unwanted trip. The inrush current has a relatively large ratio of 2nd Bay control REC670 2.2 IEC Application manual...
Page 171: Parallel Transformer Inrush Current Logic
Also the same current setting as this step is chosen for the blocking at parallel transformer energizing. The settings for the parallel transformer logic are described below. BlkParTransf: This is used to On blocking at energising of parallel transformers. Bay control REC670 2.2 IEC Application manual...
Page 172: Switch Onto Fault Logic
The function can be activated by Circuit breaker position (change) or Circuit breaker command. tUnderTime: Time delay for operation of the sensitive undertime function. The setting range is 0.000 - 60.000 s in step of 0.001 s. The default setting is 0.300 s Bay control REC670 2.2 IEC Application manual...
Page 173: Settings For Each Step (X = 1, 2, 3 And 4)
IMinx: Minimum operate current for step x in % of IB. Set IMinx below INx> for every step to achieve ANSI reset characteristic according to standard. If IMinx is set above INx> for any step, signal will reset at current equals to zero. Bay control REC670 2.2 IEC Application manual...
Page 174 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 IEC Application manual...
Page 175: Line Application Example
The polarizing voltage and current can be internally generated when a three-phase set of voltage transformers and current transformers are used. IN> IEC05000149-2-en.vsdx IEC05000149 V2 EN-US Figure 70: Connection of polarizing voltage from an open delta Bay control REC670 2.2 IEC Application manual...
Page 176 As a consequence of the distribution of zero sequence current in the power system, the current to the protection might be larger if one line out from the remote busbar is taken out of service, see Figure 72. Bay control REC670 2.2 IEC Application manual...
Page 177 IEC05000152 V2 EN-US Figure 73: Step 1, third calculation In this case the residual current out on the line can be larger than in the case of earth fault on the remote busbar. Bay control REC670 2.2 IEC Application manual...
Page 178 To assure selectivity the current setting must be chosen so that step 2 does not operate at step 2 for faults on the next line from the remote substation. Consider a fault as shown in Figure 75. Bay control REC670 2.2 IEC Application manual...
Page 179 IEC05000156 V3 EN-US Figure 76: Step 3, Selectivity calculation ³ × × step3 step2 (Equation 44) EQUATION1204 V4 EN-US where: is the chosen current setting for step 2 on the faulted line. step2 Bay control REC670 2.2 IEC Application manual...
Page 180: Four Step Directional Negative Phase Sequence Overcurrent Protection Ns4Ptoc
Four step negative sequence NS4PTOC 46I2 overcurrent protection IEC10000053 V1 EN-US 8.5.2 Application GUID-343023F8-AFE3-41C2-8440-1779DD7F5621 v2 Four step negative sequence overcurrent protection NS4PTOC is used in several applications in the power system. Some applications are: Bay control REC670 2.2 IEC Application manual...
Page 181 ANSI. Table 22: Inverse time characteristics Curve name ANSI Extremely Inverse ANSI Very Inverse ANSI Normal Inverse ANSI Moderately Inverse ANSI/IEEE Definite time ANSI Long Time Extremely Inverse Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 182: Setting Guidelines
When inverse time overcurrent characteristic is selected, the operate time of the stage will be the sum of the inverse time delay and the set definite time delay. Thus, if only the inverse time delay Bay control REC670 2.2 IEC Application manual...
Page 183: Settings For Each Step
IEC Definite Time User Programmable ASEA RI RXIDG (logarithmic) The different characteristics are described in the Technical Reference Manual (TRM). Ix>: Operation negative sequence current level for step x given in % of IBase. Bay control REC670 2.2 IEC Application manual...
Page 184 Curve name Instantaneous IEC Reset (constant time) ANSI Reset (inverse time) The different reset characteristics are described in the Technical Reference Manual (TRM). There are some restrictions regarding the choice of reset delay. Bay control REC670 2.2 IEC Application manual...
Page 185: 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 (Upol = -U2) Bay control REC670 2.2 IEC Application manual...
Page 186: Sensitive Directional Residual Overcurrent And Power Protection Sdepsde
% of IBase. The start forward or start 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 SEMOD171436-1 v4 Bay control REC670 2.2 IEC Application manual...
Page 187: Identification
When should the sensitive directional residual overcurrent protection be used and when should the sensitive directional residual power protection be used? Consider the following: Bay control REC670 2.2 IEC Application manual...
Page 188: Setting Guidelines
Bay control REC670 2.2 IEC Application manual...
Page 189 In a system with a neutral point resistor (resistance earthed system) the impedance can be calculated as: Bay control REC670 2.2 IEC Application manual...
Page 190 The series impedances in the system can no longer be neglected. The system with a single phase to earth fault can be described as in Figure 80. Bay control REC670 2.2 IEC Application manual...
Page 191 The residual voltages in stations A and B can be written: × T ,0 (Equation 52) EQUATION1949 V1 EN-US × 3I (Z T ,0 lineAB,0 (Equation 53) EQUATION1950 V1 EN-US Bay control REC670 2.2 IEC Application manual...
Page 192 ) to calculate the reference voltage (-3U ). Since the reference voltage is used as the polarizing quantity for directionality, it is important to set this parameter correctly. With the setting OpMode the principle of directional function is chosen. Bay control REC670 2.2 IEC Application manual...
Page 193 When OpMode is set to 3I0 and fi the function will operate if the residual current is larger than the setting INDir> and the residual current angle is within the sector RCADir ± ROADir. Bay control REC670 2.2 IEC Application manual...
Page 194 The characteristic angle of the directional functions RCADir is set in degrees. RCADir is normally set equal to 0° in a high impedance earthed network with a neutral point resistor as the active current component is appearing out on the Bay control REC670 2.2 IEC Application manual...
Page 195 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 IEC Application manual...
Page 196 OpUN> is set On to activate the trip function of the residual over voltage protection. tUN is the definite time delay for the trip function of the residual voltage protection, given in s. Bay control REC670 2.2 IEC Application manual...
Page 197: Thermal Overload Protection, One Time Constant, Celsius Fahrenheit Lcpttr/Lfpttr
The thermal overload protection provides information and makes temporary overloading of transformers possible. The permissible load level of a power transformer is highly dependent on the cooling system of the transformer. There are two main principles: Bay control REC670 2.2 IEC Application manual...
Page 198: Setting Guideline
IRefMult: If a binary input ENMULT is activated the reference current value can be multiplied by the factor IRefMult. The activation could be used in case of deviating ambient temperature from the reference value. In the standard for loading of a Bay control REC670 2.2 IEC Application manual...
Page 199 Tau1High: Multiplication factor to adjust the time constant Tau1 if the current is higher than the set value IHighTau1. IHighTau1 is set in % of IBase1. Bay control REC670 2.2 IEC Application manual...
Page 200: Breaker Failure Protection Ccrbrf
ThetaInit: is set in % of the trip heat content level. Warning: If the calculated time to trip factor is below the setting Warning a warning signal is activated. The setting is given in minutes. Breaker failure protection CCRBRF IP14514-1 v6 Bay control REC670 2.2 IEC Application manual...
Page 201: Identification
The mode Current/Contact means that both ways of detections are activated. Contact mode can be usable in applications where the fault current through the circuit breaker is Bay control REC670 2.2 IEC Application manual...
Page 202 Typical setting is 10% of IBase. I>BlkCont: If any contact based detection of breaker failure is used, this function can be blocked if any phase current is larger than this setting level. If the Bay control REC670 2.2 IEC Application manual...
Page 203 It is often required that the total fault clearance time shall be less than a given critical time. This time is often dependent of the ability to maintain transient stability in case of a fault close to a power plant. Bay control REC670 2.2 IEC Application manual...
Page 204 CBFLT is active. Typical setting is 2.0 seconds. tPulse: Trip pulse duration. This setting must be larger than the critical impulse time of circuit breakers to be tripped from the breaker failure protection. Typical setting is 200 ms. Bay control REC670 2.2 IEC Application manual...
Page 205: Stub Protection Stbptoc
The stub protection is only activated when the disconnector of the object is open. STBPTOCenables fast fault clearance of faults at the section between the CTs and the open disconnector. Bay control REC670 2.2 IEC Application manual...
Page 206: Setting Guidelines
This signal is normally taken from an auxiliary contact (normally closed) of the line disconnector and connected to a binary input RELEASE of the IED. With the settingContinuous the function is activated independent of presence of any external release signal. Bay control REC670 2.2 IEC Application manual...
Page 207: Pole Discordance Protection Ccpdsc
Each phase current through the circuit breaker is measured. If the difference between the phase currents is larger than a CurrUnsymLevel this is an indication of pole discordance, and the protection will operate. Bay control REC670 2.2 IEC Application manual...
Page 208: Setting Guidelines
CurrRelLevel: Current magnitude for release of the function in % of IBase. 8.12 Directional underpower protection GUPPDUP SEMOD156693-1 v4 8.12.1 Identification SEMOD158941-2 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Directional underpower protection GUPPDUP P < SYMBOL-LL V2 EN-US Bay control REC670 2.2 IEC Application manual...
Page 209: Application
Power to the power plant auxiliaries may come from a station service transformer connected to the secondary side of the step-up transformer. Power may also come from a start-up service transformer connected to the external network. One has to Bay control REC670 2.2 IEC Application manual...
Page 210 Underpower protection Overpower protection Operate Operate Line Line Margin Margin Operating point Operating point without without turbine torque turbine torque IEC09000019-2-en.vsd IEC09000019 V2 EN-US Figure 86: Reverse power protection with underpower or overpower protection Bay control REC670 2.2 IEC Application manual...
Page 211: Setting Guidelines
With the parameter OpMode1(2) the function can be set On/Off. 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 IEC Application manual...
Page 212 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 IEC Application manual...
Page 213 Calculated is settable parameter Bay control REC670 2.2 IEC Application manual...
Page 214: Directional Overpower Protection Goppdop
Often, the motoring condition may imply that the turbine is in a very dangerous state. The task of the reverse power protection is to protect the turbine and not to protect the generator itself. Bay control REC670 2.2 IEC Application manual...
Page 215 This power will be about 10% of the rated power. If there is only air in the hydro turbine, the power demand will fall to about 3%. Bay control REC670 2.2 IEC Application manual...
Page 216: Setting Guidelines
IBase, UBase and SBase as applicable. Operation: With the parameter Operation the function can be set On/Off. Mode: The voltage and current used for the power measurement. The setting possibilities are shown in table 27. Bay control REC670 2.2 IEC Application manual...
Page 217 With the parameter OpMode1(2) the function can be set On/Off. 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 IEC Application manual...
Page 218 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 IEC Application manual...
Page 219 Calculated is settable parameter Bay control REC670 2.2 IEC Application manual...
Page 220: Broken Conductor Check Brcptoc
All settings are in primary values or percentage. Set IBase (given in GlobalBaseSel) to power line rated current or CT rated current. Set minimum operating level per phase IP> to typically 10-20% of rated current. Bay control REC670 2.2 IEC Application manual...
Page 221: Capacitor Bank Protection Cbpgapc
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 IEC Application manual...
Page 222 SCB, still without any fuses Which type of fusing is used may depend on can manufacturer or utility preference and previous experience. Bay control REC670 2.2 IEC Application manual...
Page 223: Scb Protection
In addition, to fault conditions SCB can be exposed to different types of abnormal operating conditions. In accordance with IEC and ANSI standards capacitors shall be capable of continuous operation under contingency system and bank conditions, provided the following limitations are not exceeded: Bay control REC670 2.2 IEC Application manual...
Page 224 Current or Voltage based unbalance protection for SCB (can be provided by using EF4PTOC, OC4PTOC, CVGAPC or VDCPTOV functions) Overload protection for SCB Undercurrent protection for SCB Reconnection inhibit protection for SCB Restrike condition detection Bay control REC670 2.2 IEC Application manual...
Page 225: Setting Guidelines
Note that the SCB rated current on the secondary CT side is important for secondary injection of the function. The parameters for the Capacitor bank protection function CBPGAPC are set via the local HMI or PCM600. The following settings are done for this function: Bay control REC670 2.2 IEC Application manual...
Page 226 Selected value gives pickup recommended by international standards. tQOL =60s; Time delay for reactive power overload trip Harmonic voltage overload feature: OperationHOL =On; to enable this feature Settings for definite time delay step Bay control REC670 2.2 IEC Application manual...
Page 227: Restrike Detection
IED. 8.16 Voltage-restrained time overcurrent protection VRPVOC GUID-613620B1-4092-4FB6-901D-6810CDD5C615 v4 8.16.1 Identification GUID-7835D582-3FF4-4587-81CE-3B40D543E287 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Voltage-restrained time overcurrent VRPVOC I>/U< protection Bay control REC670 2.2 IEC Application manual...
Page 228: Application
GlobalBaseSel defines the particular Global Base Values Group where the base quantities of the function are set. In that Global Base Values Group: IBase shall be entered as rated phase current of the protected object in primary amperes. Bay control REC670 2.2 IEC Application manual...
Page 229: Application Possibilities
VRPVOC Trip output I3P* TRIP U3P* TROC BLOCK TRUV BLKOC START BLKUV STOC STUV IEC12000183-1-en.vsd IEC12000183 V1 EN-US Figure 94: Undervoltage seal-in of current start Bay control REC670 2.2 IEC Application manual...
Page 230: Setting Guidelines
StartCurr when the voltage is lower than 25% of UBase; so it defines the first point of the characteristic (VDepFact*StartCurr/100*IBase ; 0.25*UBase). Step mode: it is the start level of the overcurrent stage given in % of StartCurr when the voltage is lower than UHighLimit/100*UBase. Bay control REC670 2.2 IEC Application manual...
Page 231: 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 IEC Application manual...
Page 232 Set tDef_UV to 3.0 s. 10. Set EnBlkLowV to Off (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 IEC Application manual...
Page 233: Two Step Undervoltage Protection Uv2Ptuv
Disconnect apparatuses, like electric motors, which will be damaged when subject to service under low voltage conditions. The function has a high measuring accuracy and a settable hysteresis to allow applications to control reactive load. Bay control REC670 2.2 IEC Application manual...
Page 234: Setting Guidelines
9.1.3.5 Backup protection for power system faults M13851-62 v3 The setting must be below the lowest occurring "normal" voltage and above the highest occurring voltage during the fault conditions under consideration. Bay control REC670 2.2 IEC Application manual...
Page 235: Settings For Two Step Undervoltage Protection
When using inverse time characteristic for the undervoltage function during very low voltages can give a short operation time. This might lead to unselective tripping. By setting t1Min longer than the operation time for other protections, such unselective tripping can be avoided. Bay control REC670 2.2 IEC Application manual...
Page 236: Two Step Overvoltage Protection Ov2Ptov
Two step overvoltage protection OV2PTOV IP14545-1 v3 9.2.1 Identification M17002-1 v8 Function description IEC 61850 IEC 60617 identification ANSI/IEEE C37.2 identification device number Two step overvoltage protection OV2PTOV 3U> SYMBOL-C-2U-SMALLER-THAN V2 EN-US Bay control REC670 2.2 IEC Application manual...
Page 237: Application
The same also applies to the associated equipment, its voltage and time characteristic. There are wide applications where general overvoltage functions are used. All voltage related settings are made as a percentage of a settable base primary voltage, Bay control REC670 2.2 IEC Application manual...
Page 238: Equipment Protection, Such As For Motors, Generators Reactors And Transformers
The following settings can be done for the two step overvoltage protection M13852-22 v10 ConnType: Sets whether the measurement shall be phase-to-earth fundamental value, phase-to-phase fundamental value, phase-to-earth RMS value or phase-to- phase RMS value. Bay control REC670 2.2 IEC Application manual...
Page 239 The speed might be important for example in case of protection of transformer that might be overexcited. The time delay must be co- ordinated with other automated actions in the system. Bay control REC670 2.2 IEC Application manual...
Page 240 If the function is used as control for automatic switching of reactive compensation devices the hysteresis must be set smaller than the voltage change after switching of the compensation device. Bay control REC670 2.2 IEC Application manual...
Page 241: Two Step Residual Overvoltage Protection Rov2Ptov
The time delay for ROV2PTOV is seldom critical, since residual voltage is related to earth faults in a high-impedance earthed system, and enough time must normally be given for the primary protection to clear the fault. In some more specific Bay control REC670 2.2 IEC Application manual...
Page 242: Reactors And Transformersequipment Protection For Transformers
The two healthy phases will measure full phase-to- phase voltage, as the faulty phase will be connected to earth. The residual overvoltage will be three times the phase-to-earth voltage. See figure 95. Bay control REC670 2.2 IEC Application manual...
Page 243: Direct Earthed System
The other healthy phase will still have normal phase-to-earth voltage. The residual sum will have the same value as the remaining phase-to-earth voltage, which is shown in Figure 96. IEC07000189-2-en.vsd IEC07000189 V2 EN-US Figure 96: Earth fault in Direct earthed system Bay control REC670 2.2 IEC Application manual...
Page 244: Settings For Two Step Residual Overvoltage Protection
The setting is highly dependent on the protection application. In many applications, the protection function has the task to prevent damage to the protected object. The speed might be important, for Bay control REC670 2.2 IEC Application manual...
Page 245 Make sure that the set value for parameter HystABSn is somewhat smaller than the set pickup value. Otherwise there is a risk that step n will not reset properly. Bay control REC670 2.2 IEC Application manual...
Page 246: Voltage Differential Protection Vdcptov
The function requires voltage transformers in all phases of the capacitor bank. Figure shows some different alternative connections of this function. Bay control REC670 2.2 IEC Application manual...
Page 247 It will be an alternative for example, generator units where often two voltage transformers are supplied for measurement and excitation equipment. The application to supervise the voltage on two voltage transformers in the generator circuit is shown in figure 98. Bay control REC670 2.2 IEC Application manual...
Page 248: Setting Guidelines
The factor is defined as U2 · RFLx and shall be equal to the U1 voltage. Each phase has its own ratio factor. Bay control REC670 2.2 IEC Application manual...
Page 249: Loss Of Voltage Check Lovptuv
(SDDRFUF) the alarm delay can be set to zero. Loss of voltage check LOVPTUV SEMOD171868-1 v2 9.5.1 Identification SEMOD171954-2 v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Loss of voltage check LOVPTUV Bay control REC670 2.2 IEC Application manual...
Page 250: Application
(LOVPTUV), 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 IEC Application manual...
Page 251: Underfrequency Protection Saptuf
M13355-3 v8 All the frequency and voltage magnitude conditions in the system where SAPTUF performs its functions should be considered. The same also applies to the associated equipment, its frequency and time characteristic. Bay control REC670 2.2 IEC Application manual...
Page 252: Overfrequency Protection Saptof
10.2 Overfrequency protection SAPTOF IP15747-1 v3 10.2.1 Identification M14866-1 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Overfrequency protection SAPTOF f > SYMBOL-O V1 EN-US Bay control REC670 2.2 IEC Application manual...
Page 253: Application
In smaller systems the frequency START level has to be set at a higher value, and the time delay must be rather short. Bay control REC670 2.2 IEC Application manual...
Page 254: Rate-Of-Change Of Frequency Protection Sapfrc
SAPFRC is normally used together with an overfrequency or underfrequency function, in small power systems, where a single event can cause a large imbalance Bay control REC670 2.2 IEC Application manual...
Page 255: Frequency Time Accumulation Protection Function Ftaqfvr
This design avoids the mechanical resonant condition, which can lead to an increased mechanical stress on turbine blade. If the ratio between the turbine resonant frequencies to the system Bay control REC670 2.2 IEC Application manual...
Page 256 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 IEC Application manual...
Page 257: 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 IEC Application manual...
Page 258 FreqHighLimit and FreqLowLimit setting is derived from the generator manufacturer's operating requirements. Bay control REC670 2.2 IEC Application manual...
Page 259: 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 IEC Application manual...
Page 260: Current And Voltage Selection For Cvgapc Function
(selected current quantity and selected voltage quantity). The user can select, by a setting parameter CurrentInput, to measure one of the following current quantities shown in table 28. Bay control REC670 2.2 IEC Application manual...
Page 261 CVGAPC function will measure the phase L1 voltage phasor phase2 CVGAPC function will measure the phase L2 voltage phasor phase3 CVGAPC function will measure the phase L3 voltage phasor Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 262 & U VAB, VBC and VCA. L1L2 L2L3 L3L1 This information about actual VT connection is entered as a setting parameter for the pre-processing block, which will then take automatically care about it. Bay control REC670 2.2 IEC Application manual...
Page 263: Base Quantities For Cvgapc Function
• Underimpedance protection • Voltage Controlled/Restrained Overcurrent protection • Turn-to-Turn & Differential Backup protection (directional Negative Sequence. Overcurrent protection connected to generator HV terminal CTs looking into generator) • Stator Overload protection Bay control REC670 2.2 IEC Application manual...
Page 264: Inadvertent Generator Energization
For big and important machines, fast protection against inadvertent energizing should, therefore, be included in the protective scheme. The protection against inadvertent energization can be made by a combination of undervoltage, overvoltage and overcurrent protection functions. The undervoltage Bay control REC670 2.2 IEC Application manual...
Page 265: Setting Guidelines
CVGAPC function. This functionality can be achieved by using one CVGAPC function. The following shall be done to ensure proper operation of the function: Bay control REC670 2.2 IEC Application manual...
Page 266 OC1 stage can be used to detect faults in forward direction. The built-in OC2 stage can be used to detect faults in reverse direction. However the following shall be noted for such application: Bay control REC670 2.2 IEC Application manual...
Page 267: Negative Sequence Overcurrent Protection
By defining parameter x equal to maximum continuous negative sequence rating of the generator in accordance with the following formula 0, 07 (Equation 97) EQUATION1373 V1 EN-US Bay control REC670 2.2 IEC Application manual...
Page 268 OC1 step of the CVGAPC function can be used for generator negative sequence inverse overcurrent protection. For this particular example the following settings shall be entered to insure proper function operation: Bay control REC670 2.2 IEC Application manual...
Page 269: Generator Stator Overload Protection In Accordance With Iec Or Ansi Standards
This formula is applicable only when measured current (for example, positive sequence current) exceeds a pre-set value (typically in the range from 105 to 125% of the generator rated current). Bay control REC670 2.2 IEC Application manual...
Page 270 A, B, C and P are user settable coefficients which determine the curve used for Inverse Time Overcurrent TOC/IDMT calculation When the equation is compared with the equation for the inverse time characteristic of the OC1 step in it is obvious that if the following rules are followed: Bay control REC670 2.2 IEC Application manual...
Page 271: Generators And Circuit Breaker Head Flashover Protection For Generators
Connect three-phase currents from the protected object to one CVGAPC instance (for example, GF03) Set CurrentInput to value UnbalancePh Set EnRestrainCurr to On Set RestrCurrInput to MaxPh Set RestrCurrCoeff to value 0.97 Bay control REC670 2.2 IEC Application manual...
Page 272: Voltage Restrained Overcurrent Protection For Generator And Step-Up Transformer
Select CurveType_OC1 to value ANSI Very inv If required set minimum operating time for this curve by using parameter tMin_OC1 (default value 0.05s) Set StartCurr_OC1 to value 185% 10. Set VCntrlMode_OC1 to On 11. Set VDepMode_OC1 to Slope Bay control REC670 2.2 IEC Application manual...
Page 273: Loss Of Excitation Protection For A Generator
RCA & ROA angles will be applicable for OC2 step if directional feature is enabled for this step as well. Figure shows overall protection characteristic Bay control REC670 2.2 IEC Application manual...
Page 274 Furthermore the other build-in protection elements can be used for other protection and alarming purposes. Q [pu] Operating region ILowSet [pu] -rca -0.2 -0.4 ILowSet Operating Region -0.6 -0.8 en05000535.vsd IEC05000535 V2 EN-US Figure 101: Loss of excitation Bay control REC670 2.2 IEC Application manual...
Page 275: Multipurpose Filter Smaihpac
Sub-synchronous resonance protection for turbo generators • Sub-synchronous protection for wind turbines/wind farms • Detection of sub-synchronous oscillation between HVDC links and synchronous generators • Super-synchronous protection • Detection of presence of the geo-magnetic induced currents Bay control REC670 2.2 IEC Application manual...
Page 276: Setting Guidelines
GUID-5A3F67BD-7D48-4734-948C-01DAF9470EF8 v2 A relay type used for generator subsynchronous resonance overcurrent protection shall be replaced. The relay had inverse time operating characteristic as given with the following formula: (Equation 104) EQUATION13000029 V1 EN-US Bay control REC670 2.2 IEC Application manual...
Page 277 To achieve exactly the same inverse time characteristic the programmable IDMT characteristic is used which for multi-purpose overcurrent stage one, which has the following equation (for more information see Section “Inverse time characteristics” in the TRM). Bay control REC670 2.2 IEC Application manual...
Page 278 Setting Group1 Operation CurrentInput MaxPh IBase 1000 VoltageInput MaxPh UBase 20.50 OPerHarmRestr I_2ndI_fund 20.0 BlkLevel2nd 5000 EnRestrainCurr RestrCurrInput PosSeq RestrCurrCoeff 0.00 Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 279 System protection and control 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 IEC Application manual...
Page 281: Current Circuit Supervision Ccsspvc
13.1.3 Setting guidelines M12397-17 v8 GlobalBaseSel: Selects the global base value group used by the function to define IBase, UBase and SBase as applicable. Bay control REC670 2.2 IEC Application manual...
Page 282: Fuse Failure Supervision Fufspvc
These solutions are combined to get the best possible effect in the fuse failure supervision function (FUFSPVC). FUFSPVC function built into the IED products can operate on the basis of external binary signals from the miniature circuit breaker or from the line disconnector. The Bay control REC670 2.2 IEC Application manual...
Page 283: Setting Guidelines
We propose a setting of approximately 70% of UBase. The drop off time of 200 ms for dead phase detection makes it recommended to always set SealIn to On since this will secure a fuse failure indication at persistent Bay control REC670 2.2 IEC Application manual...
Page 284: Negative Sequence Based
The setting of the current limit 3I2< is in percentage of parameter IBase. The setting of 3I2< must be higher than the normal unbalance current that might exist in the system and can be calculated according to equation 109. Bay control REC670 2.2 IEC Application manual...
Page 285: Zero Sequence Based
13.2.3.5 Delta U and delta I GUID-02336F26-98C0-419D-8759-45F5F12580DE v7 Set the operation mode selector OpDUDI to On if the delta function shall be in operation. Bay control REC670 2.2 IEC Application manual...
Page 286: Dead Line Detection
A safety margin of at least 15% is recommended. 13.3 Fuse failure supervision VDSPVC GUID-9C5BA1A7-DF2F-49D4-A13A-C6B483DDFCDC v2 13.3.1 Identification GUID-109434B0-23E5-4053-9E6E-418530A07F9C v2 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Fuse failure supervision VDSPVC Bay control REC670 2.2 IEC Application manual...
Page 287: Application
VDSPVC output can be configured to block voltage dependent protection functions such as high-speed distance protection, undervoltage relays, underimpedance relays and so on. Main Vt circuit FuseFailSupvn IEC12000143-1-en.vsd IEC12000143 V1 EN-US Figure 103: Application of VDSPVC Bay control REC670 2.2 IEC Application manual...
Page 288: Setting Guidelines
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 USealIn setting. The fuse failure outputs are deactivated when the normal voltage conditions are restored. Bay control REC670 2.2 IEC Application manual...
Page 289: Synchrocheck, Energizing Check, And Synchronizing Sesrsyn
FreqDiffMin. If the frequency is less than FreqDiffMin the synchrocheck is used and the value of FreqDiffMin must thus be identical to the value FreqDiffM resp FreqDiffA for synchrocheck function. Bay control REC670 2.2 IEC Application manual...
Page 290 If needed an additional phase angle adjustment can be done for selected line voltage with the PhaseShift setting. Bay control REC670 2.2 IEC Application manual...
Page 291: Synchrocheck
In steady conditions a bigger phase angle difference can be allowed as this is sometimes the case in a long and loaded parallel power line. For this application we accept a synchrocheck Bay control REC670 2.2 IEC Application manual...
Page 292: Energizing Check
The output is given only when the actual measured conditions match the set conditions. Figure shows two substations, where one (1) is energized and the other (2) is not energized. The line Bay control REC670 2.2 IEC Application manual...
Page 293: Voltage Selection
The voltage selection function is used for the connection of appropriate voltages to the synchrocheck, synchronizing and energizing check functions. For example, when the IED is used in a double bus arrangement, the voltage that should be Bay control REC670 2.2 IEC Application manual...
Page 294: 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. The connection example for selection of the manual energizing mode is shown in figure 107.
Page 295: 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 IEC Application manual...
Page 296: Single Circuit Breaker With Single Busbar
The voltage from busbar VT is connected to U3PBB1 and the voltage from the line VT is connected to U3PLN1. 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 IEC Application manual...
Page 297: Single Circuit Breaker With Double Busbar, External Voltage Selection
UB1FF LINE_MCB UB2OK WA2_MCB UB2FF ULN1OK LINE_MCB ULN1FF LINE_VT LINE IEC10000095-6-en.vsd IEC10000095 V4 EN-US Figure 110: Connection of the SESRSYN function block in a single breaker, double busbar arrangement with internal voltage selection Bay control REC670 2.2 IEC Application manual...
Page 298: Double Circuit Breaker
U3PBB1 on all three function blocks and the voltage from busbar 2 VT is connected to U3PBB2 on all three function blocks. The voltage from line1 VT is connected to U3PLN1 on all three function blocks and the voltage from line2 VT is Bay control REC670 2.2 IEC Application manual...
Page 299 Section 14 1MRK 511 401-UEN A Control connected to U3PLN2 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 IEC Application manual...
Page 300 UB1OK UB1FF WA2_MCB UB2OK UB2FF LINE1_MCB ULN1OK ULN1FF LINE2_MCB ULN2OK ULN2FF IEC10000097-4-en.vsd IEC10000097 V4 EN-US Figure 112: Connections of the SESRSYN function block in a 1 ½ breaker arrangement with internal voltage selection Bay control REC670 2.2 IEC Application manual...
Page 301 UB1OK/FF = Supervision of WA1_MCB fuse • UB2OK/FF = Supervision of WA2_MCB fuse • ULN1OK/FF = Supervision of LINE1_MCB fuse • ULN2OK/FF = Supervision of LINE2_MCB fuse • Setting CBConfig = 1 1/2 bus alt. CB Bay control REC670 2.2 IEC Application manual...
Page 302: Setting Guidelines
1 and 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 IEC Application manual...
Page 303 A typical value for FreqDiffMin is 10 mHz. Generally, the value should be low if both synchronizing and synchrocheck functions are provided, and it is better to let the synchronizing function close, as it Bay control REC670 2.2 IEC Application manual...
Page 304 100 seconds. If the network frequencies are expected to be outside the limits from the start, a margin needs to be added. A typical setting is 600 seconds. Bay control REC670 2.2 IEC Application manual...
Page 305 PhaseDiffA setting. tSCM and tSCA The purpose of the timer delay settings, tSCM and tSCA, is to ensure that the synchrocheck conditions remains constant and that the situation is not due to a Bay control REC670 2.2 IEC Application manual...
Page 306 This voltage can be as high as 30% or more of the base line voltage. Because the setting ranges of the threshold voltages UHighBusEnerg/ UHighLineEnerg and ULowBusEnerg/ULowLineEnerg partly overlap each other, Bay control REC670 2.2 IEC Application manual...
Page 307: Smbrrec
“dead time” setting value. When simultaneous tripping and reclosing at the two line ends occurs, line dead time is approximately equal to the auto recloser “dead time”. If the auto reclosing dead time and line Bay control REC670 2.2 IEC Application manual...
Page 308 During the single-phase dead time there is an equivalent "series"-fault in the system resulting in a flow of zero sequence current. It is therefore necessary to Bay control REC670 2.2 IEC Application manual...
Page 309 The auto recloser can be inhibited (blocked) when certain protection functions detecting permanent faults, such as shunt reactor, cable or busbar protection are in operation. Back-up protection zones Bay control REC670 2.2 IEC Application manual...
Page 310 A permanent fault will cause the line protection to trip again when it recloses in an attempt to energize the line. The auto reclosing function allows a number of parameters to be adjusted. Examples: Bay control REC670 2.2 IEC Application manual...
Page 311: Auto Reclosing Operation Off And On
No signal at INHIBIT input that is, no blocking or inhibit signal present. After the start has been accepted, it is latched in and an internal signal “start” is set. It can be interrupted by certain events, like an “inhibit” signal. Bay control REC670 2.2 IEC Application manual...
Page 312: Start Auto Reclosing From Circuit Breaker Open Information
This time extension is controlled by the setting Extended t1 = On and the PLCLOST input. If this functionality is used the auto recloser start must also be allowed from distance protection zone 2 time delayed trip. Time Bay control REC670 2.2 IEC Application manual...
Page 313: Long Trip Signal
If TR2P and TR3P inputs are low (i.e. single-phase trip): The timer for single- phase auto reclosing dead time is started and the 1PT1 output (single-phase reclosing in progress) is activated. It can be used to suppress pole Bay control REC670 2.2 IEC Application manual...
Page 314: First Shot
1/2/3ph. If the first reclosing shot fails, a three-phase trip will be issued and three-phase reclosing will follow, if selected. At three-phase trip, a failure of a three-phase auto reclosing attempt will inhibit the auto recloser. No Bay control REC670 2.2 IEC Application manual...
Page 315: Armode = 1Ph + 1*2/3Ph, 1-Phase, 2-Phase Or 3-Phase Reclosing In The First Shot
External selection of auto reclosing mode M12391-241 v5 The auto reclosing mode can be selected by use of available logic function blocks. Below is an example where the choice of mode, ARMode=3ph or Bay control REC670 2.2 IEC Application manual...
Page 316: Auto Reclosing Reclaim Timer
If a new start occurs, and the number of auto reclosing shots is set to 1, and a new 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 Bay control REC670 2.2 IEC Application manual...
Page 317: Lock-Out Initiation
An example of lock-out logic. Bay control REC670 2.2 IEC Application manual...
Page 318: Evolving Fault
The sequence will continue as a three-phase auto reclosing sequence, if it is a selected alternative reclosing mode. The second fault which can be single-phase is tripped three-phase because the trip function Bay control REC670 2.2 IEC Application manual...
Page 319: Automatic Continuation Of The Auto Reclosing Sequence
BLKON input or by an unsuccessful auto reclosing attempt if the BlockByUnsucCl setting is set to On. BLKON Used to block the auto recloser, for example, when certain special service conditions arise. When used, blocking must be reset with BLKOFF. Bay control REC670 2.2 IEC Application manual...
Page 320 Used to reset the auto recloser to start conditions. Possible hold by thermal overload protection will be reset. Circuit breaker position will be checked and time settings will be restarted with their set times. Bay control REC670 2.2 IEC Application manual...
Page 321 Signals for two-phase and three-phase trip. They are usually connected to the corresponding output of the trip function block. They control the choice of dead time and the auto reclosing cycle according to the selected program. Signal TR2P Bay control REC670 2.2 IEC Application manual...
Page 322 • wait: an auto recloser, acting as slave, is waiting for a release from the master to proceed with its own reclosing sequence Bay control REC670 2.2 IEC Application manual...
Page 323 Indicates that the auto recloser is ready for a new and complete auto reclosing sequence. It can be connected to the zone extension if a line protection should have extended zone reach before auto reclosing. Bay control REC670 2.2 IEC Application manual...
Page 324 Figure is showing an example of how to connect the auto recloser when used for single-phase, two-phase or three-phase auto reclosing. Bay control REC670 2.2 IEC Application manual...
Page 325 SKIPHS 3PT1 ZCVPSOF-TRIP TRSOTF 3PT2 3PT3 THOLHOLD 3PT4 TR2P 3PT5 TRUE TR3P SESRSYN-AUTOOK SYNC WAIT RSTCOUNT WFMASTER =IEC04000135=5=en=Original.vsd IEC04000135 V5 EN-US Figure 117: Example of I/O-signal connections at a three-phase auto reclosing sequence Bay control REC670 2.2 IEC Application manual...
Page 326 WAIT input resets. The mimimum settable time for tSlaveDeadTime is 0.1sec because both master and slave should not send the breaker closing command at the same time. The slave Bay control REC670 2.2 IEC Application manual...
Page 327 If the High priority circuit breaker is not closed the High priority moves to the low priority circuit breaker. Bay control REC670 2.2 IEC Application manual...
Page 328 IEC04000137-4-en.vsd IEC04000137 V4 EN-US Figure 119: Additional input and output signals at multi-breaker arrangement. The connections can be made "symmetrical" to make it possible to control the priority by the settings, Priority: High/Low Bay control REC670 2.2 IEC Application manual...
Page 329: Auto Recloser Settings
INHIBIT input. tLongStartInh: The user can set a maximum start pulse duration time tLongStartInh. At a set time somewhat longer than the auto reclosing dead time, Bay control REC670 2.2 IEC Application manual...
Page 330 BlockByUnsucCl: Setting of whether an unsuccessful auto reclosing attempt shall set the auto recloser in blocked status. If used the BLKOFF input must be configured to unblock the function after an unsuccessful auto reclosing attempt. Normal setting is Off. Bay control REC670 2.2 IEC Application manual...
Page 331 NoOfShots: In power transmission one shot is mostly used. In most cases one auto reclosing shot is sufficient as the majority of arcing faults will cease after the first auto reclosing shot. In power systems with many other types of faults caused by Bay control REC670 2.2 IEC Application manual...
Page 332 The maximum wait time, tWaitForMaster for the second circuit breaker is set longer than the auto reclosing dead time plus a margin for synchrocheck conditions to be fulfilled for the first circuit breaker. Typical setting is 2sec. Bay control REC670 2.2 IEC Application manual...
Page 333: 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 IEC Application manual...
Page 334 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 IEC Application manual...
Page 335 The extension of the signal flow and the usage of the GOOSE communication are shown in Figure 122. IEC 61850 en05000116.vsd IEC05000116 V2 EN-US Figure 121: Signal flow between apparatus control function blocks when all functions are situated within the IED Bay control REC670 2.2 IEC Application manual...
Page 336 IED, then the local/remote switch is under authority control, otherwise the default user can perform control operations from the local IED HMI without logging in. The default position of the local/remote switch is on remote. Bay control REC670 2.2 IEC Application manual...
Page 337: Bay Control Qcbay
The Bay control (QCBAY) is used to handle the selection of the operator place per bay. The function gives permission to operate from two main types of locations either from Remote (for example, control centre or station HMI) or from Local Bay control REC670 2.2 IEC Application manual...
Page 338: Switch Controller Scswi
SCSWI may handle and operate on one three-phase device or three one-phase switching devices. After the selection of an apparatus and before the execution, the switch controller performs the following checks and actions: Bay control REC670 2.2 IEC Application manual...
Page 339: Switches Sxcbr/Sxswi
Substitution of position indication • Supervision timer that the primary device starts moving after a command • Supervision of allowed time for intermediate position • Definition of pulse duration for open/close command respectively Bay control REC670 2.2 IEC Application manual...
Page 340: Xlnproxy
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 IEC Application manual...
Page 341 Section 14 1MRK 511 401-UEN 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 IEC Application manual...
Page 342 SCSWI function. This cause is also shown on the output L_CAUSE as indicated in the following table: Bay control REC670 2.2 IEC Application manual...
Page 343: Reservation Function (Qcrsv And Resin)
IEDs. With this reservation method, the bay that wants the reservation sends a reservation request to other bays and then waits for a reservation granted signal from the other bays. Actual position Bay control REC670 2.2 IEC Application manual...
Page 344 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 IEC Application manual...
Page 345: 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 IEC Application manual...
Page 346 (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 IEC Application manual...
Page 347: Setting Guidelines
Figure 129: Example overview of the interactions between functions in a typical 14.3.3 Setting guidelines M16669-3 v4 The setting parameters for the apparatus control function are set via the local HMI or PCM600. Bay control REC670 2.2 IEC Application manual...
Page 348: Bay Control (Qcbay)
When the time has expired, the control function is reset, and a cause-code is given. tSynchrocheck is the allowed time for the synchrocheck function to fulfill the close conditions. When the time has expired, the function tries to start the synchronizing Bay control REC670 2.2 IEC Application manual...
Page 349: Switch (Sxcbr/Sxswi)
The default length is set to 200 ms for a circuit breaker (SXCBR) and 500 ms for a disconnector (SXSWI). tClosePulse is the output pulse length for a close command. If AdaptivePulse is set to Adaptive, it is the maximum length of the output pulse for an open command. Bay control REC670 2.2 IEC Application manual...
Page 350: Xlnproxy
(x) in the bay, only the own bay is reserved, that is, the output for reservation request of other bays (RES_BAYS) will not be activated at selection of apparatus x. Bay control REC670 2.2 IEC Application manual...
Page 351: Reservation Input (Resin)
As an option, a voltage indication can be used for interlocking. Take care to avoid a dangerous enable condition at the loss of a VT secondary voltage, for example, because of a blown fuse. Bay control REC670 2.2 IEC Application manual...
Page 352: Configuration Guidelines
130. The function can also be used for a double busbar arrangement without transfer busbar or a single busbar arrangement with/without transfer busbar. Bay control REC670 2.2 IEC Application manual...
Page 353: Signals From Bypass Busbar
Signal QB7OPTR Q7 is open VPQB7TR The switch status for QB7 is valid. EXDU_BPB No transmission error from the bay that contains the above information. For bay n, these conditions are valid: Bay control REC670 2.2 IEC Application manual...
Page 354: Signals From Bus-Coupler
VP_BC_12 The switch status of BC_12 is valid. VP_BC_17 The switch status of BC_17 is valid. VP_BC_27 The switch status of BC_27 is valid. EXDU_BC No transmission error from any bus-coupler bay (BC). Bay control REC670 2.2 IEC Application manual...
Page 355 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 IEC Application manual...
Page 356: Configuration Setting
1 to section 2 and vice versa. 14.4.2.4 Configuration setting M13560-108 v4 If there is no bypass busbar and therefore no QB7 disconnector, then the interlocking for QB7 is not used. The states for QB7, QC71, BB7_D, BC_17, Bay control REC670 2.2 IEC Application manual...
Page 357: Interlocking For Bus-Coupler Bay Abc_Bc
QB2_CL = 0 • QC21_OP = 1 • QC21_CL = 0 • BC_12_CL = 0 • BC_27_OP = 1 • BC_27_CL = 0 • VP_BC_12 = 1 14.4.3 Interlocking for bus-coupler bay ABC_BC IP14144-1 v2 Bay control REC670 2.2 IEC Application manual...
Page 358: Application
Signal QQB12OPTR QB1 or QB2 or both are open. VPQB12TR The switch status of QB1 and QB2 are valid. EXDU_12 No transmission error from the bay that contains the above information. Bay control REC670 2.2 IEC Application manual...
Page 359 If the busbar is divided by bus-section circuit breakers, the signals from the bus- section coupler bay (A1A2_BS), rather than the bus-section disconnector bay (A1A2_DC), have to be used. For B1B2_BS, corresponding signals from busbar B Bay control REC670 2.2 IEC Application manual...
Page 360: Signals From Bus-Coupler
Section 1 Section 2 (WA1)A1 (WA2)B1 (WA7)C A1A2_DC(BS) B1B2_DC(BS) ABC_BC ABC_BC en04000484.vsd IEC04000484 V1 EN-US Figure 138: Busbars divided by bus-section disconnectors (circuit breakers) To derive the signals: Bay control REC670 2.2 IEC Application manual...
Page 361 A bus-section coupler connection exists between bus sections 1 and 2. VPS1S2TR The switch status of bus-section coupler BS is valid. EXDU_BS No transmission error from the bay containing the above information. For a bus-coupler bay in section 1, these conditions are valid: Bay control REC670 2.2 IEC Application manual...
Page 362: Configuration Setting
In the functional block diagram, 0 and 1 are designated 0=FALSE and 1=TRUE: • QB2_OP = 1 • QB2_CL = 0 • QB20_OP = 1 • QB20_CL = 0 • QC21_OP = 1 • QC21_CL = 0 Bay control REC670 2.2 IEC Application manual...
Page 363: Interlocking For Transformer Bay Ab_Trafo
QA2 and QC4 are not used in this interlocking en04000515.vsd IEC04000515 V1 EN-US Figure 140: Switchyard layout AB_TRAFO M13566-4 v4 The signals from other bays connected to the module AB_TRAFO are described below. Bay control REC670 2.2 IEC Application manual...
Page 364: Signals From Bus-Coupler
0 and 1 are designated 0=FALSE and 1=TRUE: • QB2_OP = 1 • QB2QB2_CL = 0 • QC21_OP = 1 • QC21_CL = 0 • BC_12_CL = 0 • VP_BC_12 = 1 Bay control REC670 2.2 IEC Application manual...
Page 365: Interlocking For Bus-Section Breaker A1A2_Bs
Bay control REC670 2.2 IEC Application manual...
Page 366 The switch status of bus-section coupler BS is valid. EXDU_BS No transmission error from the bay that contains the above information. For a bus-section circuit breaker between A1 and A2 section busbars, these conditions are valid: Bay control REC670 2.2 IEC Application manual...
Page 367 IEC04000490 V1 EN-US Figure 144: Signals from any bays for a bus-section circuit breaker between sections A1 and A2 For a bus-section circuit breaker between B1 and B2 section busbars, these conditions are valid: Bay control REC670 2.2 IEC Application manual...
Page 368: Configuration Setting
QA1 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 IEC Application manual...
Page 369: Interlocking For Bus-Section Disconnector A1A2_Dc
B are used. Section 1 Section 2 (WA1)A1 (WA2)B1 (WA7)C A1A2_DC(BS) B1B2_DC(BS) ABC_BC AB_TRAFO ABC_LINE ABC_LINE AB_TRAFO en04000493.vsd IEC04000493 V1 EN-US Figure 147: Busbars divided by bus-section disconnectors (circuit breakers) To derive the signals: Bay control REC670 2.2 IEC Application manual...
Page 370 The switch status of QB2 is valid. EXDU_BS No transmission error from the bay BS (bus-section coupler bay) that contains the above information. For a bus-section disconnector, these conditions from the A1 busbar section are valid: Bay control REC670 2.2 IEC Application manual...
Page 371 EXDU_BB (bay n/sect.A2) EXDU_DC (A2/A3) en04000495.vsd IEC04000495 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 IEC Application manual...
Page 372: Signals In Double-Breaker 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 IEC Application manual...
Page 373 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 IEC Application manual...
Page 374 EXDU_DB (bay n/sect.A2) en04000500.vsd IEC04000500 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 IEC Application manual...
Page 375: Signals In 1 1/2 Breaker 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 IEC Application manual...
Page 376: Interlocking For Busbar Earthing Switch Bb_Es
The signals from other bays connected to the module BB_ES are described below. 14.4.7.2 Signals in single breaker arrangement M15053-6 v5 The busbar earthing switch is only allowed to operate if all disconnectors of the bus-section are open. Bay control REC670 2.2 IEC Application manual...
Page 377 The switch status of bus-section disconnector DC is valid. EXDU_DC No transmission error from the bay that contains the above information. If no bus-section disconnector exists, the signal DCOPTR, VPDCTR and EXDU_DC are set to 1 (TRUE). Bay control REC670 2.2 IEC Application manual...
Page 378 IEC04000506 V1 EN-US Figure 160: Signals from any bays in section A1 to a busbar earthing switch in the same section For a busbar earthing switch, these conditions from the A2 busbar section are valid: Bay control REC670 2.2 IEC Application manual...
Page 379 IEC04000508 V1 EN-US Figure 162: Signals from any bays in section B1 to a busbar earthing switch in the same section For a busbar earthing switch, these conditions from the B2 busbar section are valid: Bay control REC670 2.2 IEC Application manual...
Page 380: Signals In Double-Breaker Arrangement
Signals from bypass busbar to busbar earthing switch 14.4.7.3 Signals in double-breaker arrangement M15053-83 v4 The busbar earthing switch is only allowed to operate if all disconnectors of the bus section are open. Bay control REC670 2.2 IEC Application manual...
Page 381: Signals In 1 1/2 Breaker Arrangement
The logic is identical to the double busbar configuration described in section “Signals in single breaker arrangement”. 14.4.7.4 Signals in 1 1/2 breaker arrangement M15053-123 v4 The busbar earthing switch is only allowed to operate if all disconnectors of the bus-section are open. Bay control REC670 2.2 IEC Application manual...
Page 382: Interlocking For Double Cb Bay Db
M13585-3 v10 The interlocking for a double busbar double circuit breaker bay including DB_BUS_A, DB_BUS_B and DB_LINE functions are used for a line connected to a double busbar arrangement according to figure 167. Bay control REC670 2.2 IEC Application manual...
Page 383: Configuration Setting
• QB9_OP = VOLT_OFF • QB9_CL = VOLT_ON If there is no voltage supervision, then set the corresponding inputs as follows: • VOLT_OFF = 1 • VOLT_ON = 0 Bay control REC670 2.2 IEC Application manual...
Page 384: Interlocking For 1 1/2 Cb Bh
M13569-6 v5 For application without QB9 and QC9, 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 IEC Application manual...
Page 385: Voltage Control
This alters the power transformer ratio in a number of predefined steps and in that way changes the voltage. Each step usually represents a change in voltage of approximately 0.5-1.7%. Bay control REC670 2.2 IEC Application manual...
Page 386 (degree of insensitivity). A time delay (inverse or definite time) is set to avoid unnecessary Bay control REC670 2.2 IEC Application manual...
Page 387 Digital Converter and thereafter a Pre-Processing Block. In the Pre-Processing Block, a great number of quantities for example, phase-to-phase analog values, sequence values, max value in a three phase group etc., are derived. The different Bay control REC670 2.2 IEC Application manual...
Page 388 The voltage measurement on the LV-side can be made single phase-earth. However, it shall be remembered that this can only be used in solidly earthed Bay control REC670 2.2 IEC Application manual...
Page 389 URAISE command will be sent from TCMYLTC or TCLYLTC function block to the transformer tap changer. If necessary, the procedure will be repeated until the magnitude of the busbar voltage again falls within the inner deadband. One half of Bay control REC670 2.2 IEC Application manual...
Page 390 Constant (definite) time delay is independent of the voltage deviation. The inverse time characteristic for the first time delay follows the formulas: (Equation 115) IECEQUATION2294 V2 EN-US Bay control REC670 2.2 IEC Application manual...
Page 391 (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 IEC Application manual...
Page 392 OperCapaLDC to IEC06000487-2-en.vsd IEC06000487 V2 EN-US Figure 172: Vector diagram for line voltage drop compensation Bay control REC670 2.2 IEC Application manual...
Page 393 Original set voltage: Base quality is U Automatic load voltage adjustment factor, setting VRAuto Load current I2Base Rated current, LV winding Constant load voltage adjust. factor for active input i (corresponding to LVAConst1, LVAConst2, LVAConst3 and LVAConst4 ) Bay control REC670 2.2 IEC Application manual...
Page 394 USet ± DU, but at the same time it will drive the two tap changers to their opposite end positions. High circulating currents and loss of control would be the result of this runaway tap situation. Bay control REC670 2.2 IEC Application manual...
Page 395 When the selection of master or follower in parallel control, or automatic control in single mode, is made with a three position switch in the substation, an arrangement as in figure below is arranged with application configuration. Bay control REC670 2.2 IEC Application manual...
Page 396 The tap positions will diverge and finally end up in a runaway tap situation if no measures to avoid this are taken. Bay control REC670 2.2 IEC Application manual...
Page 397 Vector diagram for two transformers regulated exactly on target voltage. A comparison with figure gives that the line voltage drop compensation for the purpose of reverse reactance control is made with a value with opposite sign on X Bay control REC670 2.2 IEC Application manual...
Page 398 T1 will be the one to tap down, and when the busbar voltage decreases, T2 will be the one to tap up. The overall performance will then be that the runaway tap situation will be avoided and that the circulating current will be minimized. Bay control REC670 2.2 IEC Application manual...
Page 399 HMI as a service Bmean value BusVolt under Main menu/Test/Function status/Control/ TransformerVoltageControl(ATCC,90)/TR8ATCC:x. Measured current values for the individual transformers must be communicated between the participating TR8ATCC functions, in order to calculate the circulating current. Bay control REC670 2.2 IEC Application manual...
Page 400 This is set On/Off by setting parameter OperUsetPar. The calculated mean USet value is shown on the local HMI as a service value USETPAR under Main menu/Test/Function status/ Control/TransformerVoltageControl(ATCC,90)/TR8ATCC:x. Bay control REC670 2.2 IEC Application manual...
Page 401 (with or without an offset) of the master. The setting parameter tAutoMSF then introduces a time delay on UVRAISE/ULOWER commands individually for each follower, and effectively this can be used to avoid simultaneous tapping. Homing SEMOD159053-200 v2 Bay control REC670 2.2 IEC Application manual...
Page 402 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 IEC Application manual...
Page 403 ATCCs with regard to the calculation of circulating currents. The capacitive current is part of the imaginary load current and therefore essential in the calculation. The calculated circulating current and the real circulating currents Bay control REC670 2.2 IEC Application manual...
Page 404 ATCC this is made numerically. The reactive power of the capacitor bank is given as a setting Q1, which makes it possible to calculate the reactive capacitance: Bay control REC670 2.2 IEC Application manual...
Page 405 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 IEC Application manual...
Page 406 T3 is disconnected which will lead to T3 sending the DISC=1 signal to the other two parallel TR8ATCC modules (T1 and T2) in the group. Also see table 39. Bay control REC670 2.2 IEC Application manual...
Page 407 One is the data set that needs to be transmitted to other TR8ATCC blocks in the same parallel group, and the other is the data set that is transferred to the TCMYLTC or TCLYLTC function block for the same transformer as TR8ATCC block belongs to. Bay control REC670 2.2 IEC Application manual...
Page 408 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 • SetV • VCTRStatus • Bay control REC670 2.2 IEC Application manual...
Page 409 Partial Block: Prevents operation of the tap changer only in one direction (only URAISE or ULOWER command is blocked) in manual and automatic control mode. Auto Block: Prevents automatic voltage regulation, but the tap changer can still be controlled manually. Bay control REC670 2.2 IEC Application manual...
Page 410 The outputs UBLK and TOTBLK or AUTOBLK will be activated depending on the actual parameter setting. Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 411 This error condition can be reset by the input RESETERR on TCMYLTC function block, or alternatively by changing control mode of TR1ATCC or TR8ATCC function to Manual and then back to Automatic. Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 412 OUTOFPOS and AUTOBLK (alternatively an alarm) will be set. Setting parameters for blocking that can be set in TR1ATCC or TR8ATCC under setting group Nx in PST/ local HMI are listed in table 41. Bay control REC670 2.2 IEC Application manual...
Page 413 The output AUTOBLK will be activated. Deblocking is made via the input DEBLKAUT. Blockings activated by the operating conditions, without setting or separate external activation possibilities, are listed in table 43. Bay control REC670 2.2 IEC Application manual...
Page 414 TR8ATCCs that is, all units of the parallel group. The following conditions in any one of TR8ATCCs in the group will cause mutual blocking when the circulating current method is used: Bay control REC670 2.2 IEC Application manual...
Page 415 OperationPAR to Off from the built-in local HMI or PST. TR8ATCC function can be forced to single mode at any time. It will then behave exactly the same way as described in section "Automatic voltage control for a Bay control REC670 2.2 IEC Application manual...
Page 416 BIM module to TCMYLTC or TCLYLTC input TCINPROG, and it can then be used by TCMYLTC or TCLYLTC function in three ways, which is explained below with the help of figure 180. Bay control REC670 2.2 IEC Application manual...
Page 417 CMDERRAL is set high and TR1ATCC or TR8ATCC function is blocked. The fixed extension (g) 2 sec. of TCINPROG, is made to prevent a situation where this could happen despite no real malfunction. Bay control REC670 2.2 IEC Application manual...
Page 418 (Equation 123) EQUATION1873 V2 EN-US where n is the number of operations and α is an adjustable setting parameter, CLFactor, with default value is set to 2. With this default setting an operation at Bay control REC670 2.2 IEC Application manual...
Page 419: Setting Guidelines
CircCurrBk: Selection of action to be taken in case the circulating current exceeds CircCurrLimit. CmdErrBk: Selection of action to be taken in case the feedback from the tap changer has resulted in command error. Bay control REC670 2.2 IEC Application manual...
Page 420: Tr1Atcc Or Tr8Atcc Setting Group
(reactor) needs to be compensated for in the calculation of circulating currents. There are three independent settings Q1, Q2 and Q3 in order to make possible switching of three steps in a capacitor bank in one bay. Bay control REC670 2.2 IEC Application manual...
Page 421 Ublock: Voltages below Ublock normally correspond to a disconnected transformer and therefore it is recommended to block automatic control for this condition (setting UVBk). Ublock is set in percent of UBase. Bay control REC670 2.2 IEC Application manual...
Page 422 (for example, assume two equal transformers on the same tap position). The load current lags the busbar voltage U with the power factor j and the argument of the impedance Rline and Xline is designated j1. Bay control REC670 2.2 IEC Application manual...
Page 423 If for example cosj = 0.8 then j = arcos 0.8 = 37°. With the references in figure 181, j will be negative (inductive load) and we get: j = - - ( 37 ) 90 (Equation 125) EQUATION1939 V1 EN-US Bay control REC670 2.2 IEC Application manual...
Page 424 There is no rule for the setting of Xline such that an optimal balance between control response and susceptibility to changing power factor is achieved. One way of determining the setting is by trial and error. This can be done by setting e.g. Bay control REC670 2.2 IEC Application manual...
Page 425 The tap changer operations shall be temporarily blocked. This function typically monitors the three phase currents on the HV side of the transformer. Bay control REC670 2.2 IEC Application manual...
Page 426 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. Bay control REC670 2.2 IEC Application manual...
Page 427 ´ D = ´ ´ Comp a 100% ´ (Equation 126) EQUATION1941 V1 EN-US where: Bay control REC670 2.2 IEC Application manual...
Page 428 TapPosOffs) between a follower and the master reaches the value in this setting, then the output OUTOFPOS in the Automatic voltage control for tap changer, parallel control TR8ATCC function block of the follower will be activated after the time delay tMFPosDiff. Bay control REC670 2.2 IEC Application manual...
Page 429: Tcmyltc And Tclyltc General Settings
Length of the command pulse (URAISE/ULOWER) 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 IEC Application manual...
Page 430: Logic Rotating Switch For Function Selection And Lhmi Presentation Slgapc
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 On or Off. NrPos: Sets the number of positions in the switch (max. 32). Bay control REC670 2.2 IEC Application manual...
Page 431: Selector Mini Switch Vsgapc
An example where VSGAPC is configured to switch Autorecloser on–off from a button symbol on the local HMI is shown in figure185. The I and O buttons on the local HMI are normally used for on–off operations of the circuit breaker. Bay control REC670 2.2 IEC Application manual...
Page 432: Setting Guidelines
It is especially intended to be used in the interlocking station-wide logics. To be able to get the signals into other systems, equipment or functions, one must use other tools, described in the Engineering manual, and define which Bay control REC670 2.2 IEC Application manual...
Page 433: Setting Guidelines
14.9 Single point generic control 8 signals SPC8GAPC SEMOD176448-1 v3 14.9.1 Identification SEMOD176456-2 v3 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Single point generic control 8 signals SPC8GAPC Bay control REC670 2.2 IEC Application manual...
Page 434: Application
(in seconds). 14.10 AutomationBits, command function for DNP3.0 AUTOBITS SEMOD158589-1 v3 14.10.1 Identification GUID-C3BB63F5-F0E7-4B00-AF0F-917ECF87B016 v4 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number AutomationBits, command function for AUTOBITS DNP3 Bay control REC670 2.2 IEC Application manual...
Page 435: Application
For local control functions, the local HMI can also be used. Together with the configuration logic circuits, the user can govern pulses or steady output signals for control purposes within the IED or via binary outputs. Bay control REC670 2.2 IEC Application manual...
Page 436 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 On/Off signals. Here, the output is used to control built-in functions or external devices. Bay control REC670 2.2 IEC Application manual...
Page 437: 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 IEC Application manual...
Page 438 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 IEC Application manual...
Page 439: Scheme Communication Logic For Distance Or Overcurrent Protection Zcpsch
(overreaching and underreaching) • unblocking scheme and direct intertrip A permissive scheme is inherently faster and has better security against false tripping than a blocking scheme. On the other hand, a permissive scheme depend Bay control REC670 2.2 IEC Application manual...
Page 440: Blocking Schemes
The timer tSendMin for prolonging the send signal is proposed to set to zero. Z rev TRIP = OR + tCoord+ CR Z rev IEC09000015_2_en.vsd IEC09000015 V2 EN-US Figure 189: Principle of blocking scheme Overreaching Communication signal received Communication signal send Z rev : Reverse zone Bay control REC670 2.2 IEC Application manual...
Page 441: Delta Blocking Scheme
IEC11000252-1-en.vsd IEC11000252 V1 EN-US Figure 190: Principle of delta blocking scheme Overreaching Communication signal received Communication signal send deltaA: Delta based fault inception detection on A side that gets inhibited for forward faults Bay control REC670 2.2 IEC Application manual...
Page 442: Permissive Schemes
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 IEC Application manual...
Page 443 The send signal (CS) might be issued in parallel both from an overreaching zone and an underreaching, independent tripping zone. The CS signal from the overreaching zone must not be prolonged while the CS signal from zone 1 can be prolonged. Bay control REC670 2.2 IEC Application manual...
Page 444: Intertrip Scheme
In some power system applications, there is a need to trip the remote end breaker immediately from local protections. This applies for instance when transformers or reactors are connected to the system without circuit-breakers or for remote tripping following operation of breaker failure protection. Bay control REC670 2.2 IEC Application manual...
Page 445: Setting Guidelines
Restart if Unblocking scheme with alarm for loss of guard is to be used) Set to tSecurity 0.035 s 15.1.3.2 Delta blocking scheme GUID-F4359690-F433-46CB-A173-8C14559E3FCF v1 Operation SchemeType DeltaBlocking tCoord = 0 s tSendMin = 0 s Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 446: Permissive Underreaching Scheme
NoRestart if only trip is required) tSecurity = 0.035 s 15.1.3.6 Intertrip scheme M13869-62 v5 Operation SchemeType Intertrip tCoord = 50 ms (10 ms + maximal transmission time) Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 447: Current Reversal And Weak-End Infeed Logic For Distance Protection 3-Phase Zcrwpsch
If the communication signal has not reset at the same time as the distance protection function used in the teleprotection scheme has switched on to forward direction, we will have an unwanted operation of breaker B2 at B side. Bay control REC670 2.2 IEC Application manual...
Page 448: Weak-End Infeed Logic
Only the trip part of the function can be used together with the blocking scheme. It is not possible to use the echo function to send the echo signal to the remote line IED. The echo signal would block the operation of the distance Bay control REC670 2.2 IEC Application manual...
Page 449: Setting Guidelines
Set WEI to Echo&Trip to obtain echo with trip. Set tPickUpWEI to 10 ms, a short delay is recommended to avoid that spurious carrier received signals will activate WEI and cause unwanted carrier send (ECHO) signals. Bay control REC670 2.2 IEC Application manual...
Page 450: Local Acceleration Logic Zclcpsch
LoadCurr must be set below the current that will flow on the healthy phase when one or two of the other phases are faulty and the breaker has opened at remote end (three-phase). Calculate the setting according to equation 127. Bay control REC670 2.2 IEC Application manual...
Page 451: Scheme Communication Logic For Residual Overcurrent Protection Ecpsch
15.4.2 Application M13919-3 v6 To achieve fast fault clearance of earth faults on the part of the line not covered by the instantaneous step of the residual overcurrent protection, the directional Bay control REC670 2.2 IEC Application manual...
Page 452: Setting Guidelines
The following settings can be done for the scheme communication logic for residual overcurrent protection function: Operation: Off or On. SchemeType: This parameter can be set to Off , Intertrip, Permissive UR, Permissive OR or Blocking. Bay control REC670 2.2 IEC Application manual...
Page 453: Current Reversal And Weak-End Infeed Logic For Residual Overcurrent Protection Ecrwpsch
Note that the fault current is reversed in line L2 after the breaker B1 opening. It can cause an unselective trip on line L2 if the current reversal logic does not block the permissive overreaching scheme in the IED at B2. Bay control REC670 2.2 IEC Application manual...
Page 454: Weak-End Infeed Logic
Note that there is no fault current from node B. This causes that the IED at B cannot detect the fault and trip the breaker in B. To cope with this situation, a selectable weak-end infeed logic is provided for the permissive overreaching scheme. Bay control REC670 2.2 IEC Application manual...
Page 455: Setting Guidelines
This equipment makes a decision and gives a binary signal to the protection device. In case of analog teleprotection equipment typical decision time is in the range 10 – 30 ms. For digital teleprotection equipment this time is in the range 2 – 10 ms. Bay control REC670 2.2 IEC Application manual...
Page 456: Weak-End Infeed
(3U0) 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 IEC Application manual...
Page 457: Tripping Logic Smpptrc
1/3-phase tripping and 1/3-phase autoreclosing. Alternatively, the breaker chosen as master can have single-phase tripping, while the slave Bay control REC670 2.2 IEC Application manual...
Page 458: Three-Phase Tripping
TR2P PSL1 TR3P PSL2 CLLKOUT PSL3 START 1PTRZ STL1 1PTREF STL2 P3PTR STL3 SETLKOUT RSTLKOUT STDIR IEC05000544-4-en.vsdx IEC05000544 V4 EN-US Figure 199: Tripping logic SMPPTRC is used for a simple three-phase tripping application Bay control REC670 2.2 IEC Application manual...
Page 459: Single- And/Or Three-Phase Tripping
OR conditions from both line protections. Other back-up functions are connected to the input TRIN as described above for three-phase tripping. A typical connection for a single-phase tripping scheme is shown in figure 200. Bay control REC670 2.2 IEC Application manual...
Page 460: Single-, Two- Or Three-Phase Tripping
The SMPPTRC function block is provided with possibilities to initiate lock-out. The lock-out can be set to only activate the block closing output CLLKOUT or initiate the block closing output and also maintain the trip signal output TR3P (latched trip). Bay control REC670 2.2 IEC Application manual...
Page 461: Example Of Directional Data
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 IEC Application manual...
Page 462 SMPPTRC, or directly to SMAGAPC and then to the SMPPTRC. The trip function (SMPPTRC) splits up the directional data as general output data for START, STL1, STL2, STL3, STN, FW and REV. Bay control REC670 2.2 IEC Application manual...
Page 463: Blocking Of The Function Block
Secures two- or three-pole tripping depending on Program selection during evolving faults. 16.2 Trip matrix logic TMAGAPC IP15121-1 v4 16.2.1 Identification SEMOD167882-2 v3 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Trip matrix logic TMAGAPC Bay control REC670 2.2 IEC Application manual...
Page 464: Application
Group alarm logic function ALMCALH is used to route alarm signals to different LEDs and/or output contacts on the IED. ALMCALH output signal and the physical outputs allows the user to adapt the alarm signal to physical tripping outputs according to the specific application needs. Bay control REC670 2.2 IEC Application manual...
Page 465: Setting Guidelines
LEDs and/or output contacts on the IED. INDCALH output signal IND and the physical outputs allows the user to adapt the indication signal to physical outputs according to the specific application needs. Bay control REC670 2.2 IEC Application manual...
Page 466: Setting Guidelines
Configuration GUID-D93E383C-1655-46A3-A540-657141F77CF0 v4 Logic is configured using the ACT configuration tool in PCM600. Execution of functions as defined by the configurable logic blocks runs according to a fixed sequence with different cycle times. Bay control REC670 2.2 IEC Application manual...
Page 467 Remember to design the logic circuits carefully and always check the execution sequence for different functions. In other cases, additional time delays must be introduced into the logic schemes to prevent errors, for example, race between functions. Bay control REC670 2.2 IEC Application manual...
Page 468: Fixed Signal Function Block Fxdsign
Since all group connections are mandatory to be connected, the third input needs to be connected to something, which is the GRP_OFF signal in FXDSIGN function block. Bay control REC670 2.2 IEC Application manual...
Page 469: Boolean 16 To Integer Conversion B16I
Values of each of the different OUTx from function block B16I for 1≤x≤16. The sum of the value on each INx corresponds to the integer presented on the output OUT on the function block B16I. Bay control REC670 2.2 IEC Application manual...
Page 470: Representation, 16 Bit Btigapc
Boolean to integer conversion with logical node representation, 16 bit (BTIGAPC) is used to transform a set of 16 binary (logical) signals into an integer. BTIGAPC has a logical node mapping in IEC 61850. Bay control REC670 2.2 IEC Application manual...
Page 471: Integer To Boolean 16 Conversion Ib16
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 BTIGAPC function block. 16.10 Integer to Boolean 16 conversion IB16 SEMOD158367-1 v2 Bay control REC670 2.2 IEC Application manual...
Page 472: Identification
BOOLEAN Input 7 BOOLEAN Input 8 BOOLEAN Input 9 IN10 BOOLEAN Input 10 IN11 BOOLEAN Input 11 1024 IN12 BOOLEAN Input 12 2048 IN13 BOOLEAN Input 13 4096 Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 473: Representation Itbgapc
OUTx where 1≤x≤16. The values of the different OUTx are according to the Table 45. If the BLOCK input is activated, it freezes the logical outputs at the last value. Bay control REC670 2.2 IEC Application manual...
Page 474: Elapsed Time Integrator With Limit Transgression And Overflow Supervision Teigapc
The function TEIGAPC is used for user-defined logics and it can also be used for different purposes internally in the IED. An application example is the integration of elapsed time during the measurement of neutral point voltage or neutral current at earth-fault conditions. Bay control REC670 2.2 IEC Application manual...
Page 475: Setting Guidelines
The function gives the possibility to monitor the level of integer values in the system relative to each other or to a fixed value. It is a basic arithmetic function that can be used for monitoring, supervision, interlocking and other logics. Bay control REC670 2.2 IEC Application manual...
Page 476: Setting Guidelines
For absolute comparison between input and setting Set the EnaAbs = Absolute Set the RefSource = Set Value SetValue shall be set between -2000000000 to 2000000000 Similarly for signed comparison between input and setting Bay control REC670 2.2 IEC Application manual...
Page 477: Comparator For Real Inputs - Realcomp
RefPrefix: This setting is used to set the unit of the reference value for comparison when setting RefSource is selected as SetValue. It has 5 unit selections and they are Milli, Unity, Kilo, Mega and Giga. Bay control REC670 2.2 IEC Application manual...
Page 478: 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 IEC Application manual...
Page 479: Measurement
IEC 61850. The possibility to continuously monitor measured values of active power, reactive power, currents, voltages, frequency, power factor etc. is vital for efficient production, transmission and distribution of electrical energy. It Bay control REC670 2.2 IEC Application manual...
Page 480 (DFT values) of the measured current and voltage signals. The measured power quantities are available either, as instantaneously calculated quantities or, averaged values over a period of time (low pass filtered) depending on the selected settings. Bay control REC670 2.2 IEC Application manual...
Page 481: Zero Clamping
I leading U System mean voltage, calculated according to selected mode System mean current, calculated according to selected mode Frequency Relevant settings and their values on the local HMI under Main menu/ Settings/IED settings/Monitoring/Servicevalues(P_Q)/CVMMXN(P_Q): Bay control REC670 2.2 IEC Application manual...
Page 482: Setting Guidelines
UAmpCompY: Amplitude compensation to calibrate voltage measurements at Y% of Ur, where Y is equal to 5, 30 or 100. IAmpCompY: Amplitude compensation to calibrate current measurements at Y% of Ir, where Y is equal to 5, 30 or 100. Bay control REC670 2.2 IEC Application manual...
Page 483 Integral deadband setting is the integral area, that is, measured value in m% of measuring range multiplied by the time between two measured values. XHiHiLim: High-high limit. Set as % of YBase (Y is SBase for S,P,Q UBase for Voltage measurement and IBase for current measurement). Bay control REC670 2.2 IEC Application manual...
Page 484 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. IEC05000652 V2 EN-US Figure 206: Calibration curves Bay control REC670 2.2 IEC Application manual...
Page 485: Setting Examples
PhaseAngleRef (see Section “Setting of the phase reference channel”) using PCM600 for analog input channels Connect, in PCM600, measurement function to three-phase CT and VT inputs Set under General settings parameters for the Measurement function: Bay control REC670 2.2 IEC Application manual...
Page 486 Cycl: Report interval (s), Db: In 2000 Set ±Δdb=40 MW that is, 2% 0.001% of range, Int Db: In (larger changes than 40 MW will 0.001%s be reported) Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 487 30% of Ir IAngComp100 Angle pre-calibration for current 0.00 at 100% of Ir 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 IEC Application manual...
Page 488 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 IEC Application manual...
Page 489 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 IEC Application manual...
Page 490 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 IEC Application manual...
Page 491: Gas Medium Supervision Ssimg
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 IEC Application manual...
Page 492: 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 IEC Application manual...
Page 493: Liquid Medium Supervision Ssiml
This is used to set the time delay for a level lockout indication, given in s. tTempAlarm: This is used to set the time delay for a temperature alarm indication, given in s. Bay control REC670 2.2 IEC Application manual...
Page 494: Breaker Monitoring Sscbr
The breaker status is monitored using breaker auxiliary contacts. The breaker status is indicated by the binary outputs. These signals indicate whether the circuit breaker is in an open, closed or error state. Bay control REC670 2.2 IEC Application manual...
Page 495 10000/900 = 11 operations at the rated current. It is assumed that prior to tripping, the remaining life of a breaker is 10000 operations. Remaining life calculation for three different interrupted current conditions is explained below. Bay control REC670 2.2 IEC Application manual...
Page 496 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 IEC Application manual...
Page 497: Setting Guidelines
ContTrCorr: Correction factor for time difference in auxiliary and main contacts' opening time. AlmAccCurrPwr: Setting of alarm level for accumulated energy. LOAccCurrPwr: Lockout limit setting for accumulated energy. SpChAlmTime: Time delay for spring charging time alarm. Bay control REC670 2.2 IEC Application manual...
Page 498: 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 LON and SPA communication. Analog, integer and double indication values are also transferred through the EVENT function. Bay control REC670 2.2 IEC Application manual...
Page 499: Setting Guidelines
Disturbance report DRPRDRE IP14584-1 v2 17.6.1 Identification M16055-1 v8 Function description IEC 61850 identification IEC 60617 ANSI/IEEE C37.2 identification device number Disturbance report DRPRDRE Disturbance report A1RADR - A4RADR Disturbance report B1RBDR - B22RBDR Bay control REC670 2.2 IEC Application manual...
Page 500: Application
IEC 60870-5-103 is used. 17.6.3 Setting guidelines IP14874-1 v1 M12179-64 v8 The setting parameters for the Disturbance report function DRPRDRE are set via the local HMI or PCM600. Bay control REC670 2.2 IEC Application manual...
Page 501 For Disturbance report function there are a number of settings which also influences the sub-functions. Three LED indications placed above the LCD screen makes it possible to get quick status information about the IED. Bay control REC670 2.2 IEC Application manual...
Page 502 To be able to delete disturbance records, Operation parameter has to be On. The maximum number of recordings depend on each recordings total recording time. Long recording time will reduce the number of recordings to less than 100. Bay control REC670 2.2 IEC Application manual...
Page 503: Recording Times
(PostFaultrecT or TimeLimit) period is terminated. If a new trig occurs during the post-fault period and lasts longer than the proceeding recording a new complete recording will be started. Disturbance report function can handle a maximum of 3 simultaneous disturbance recordings. Bay control REC670 2.2 IEC Application manual...
Page 504: Binary Input Signals
M (On) or not (Off). 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 IEC Application manual...
Page 505: Sub-Function Parameters
The goal is to optimize the settings in each IED to be able to capture just valuable disturbances and to maximize the number that is possible to save in the IED. Bay control REC670 2.2 IEC Application manual...
Page 506: Logical Signal Status Report Binstatrep
The Logical signal status report (BINSTATREP) function makes it possible to poll signals from various other function blocks. BINSTATREP has 16 inputs and 16 outputs. The output status follows the inputs and can be read from the local HMI or via SPA communication. Bay control REC670 2.2 IEC Application manual...
Page 507: Setting Guidelines
(TVR). Beside this information the function must be informed about faulted phases for correct loop selection (phase selective outputs from differential protection, distance Bay control REC670 2.2 IEC Application manual...
Page 508: Setting Guidelines
The list of parameters explains the meaning of the abbreviations. Figure also presents these system parameters graphically. Note, that all impedance values relate to their primary values and to the total length of the protected line. Bay control REC670 2.2 IEC Application manual...
Page 509: Connection Of Analog Currents
If the actual values are not known, the values that correspond to the source impedance characteristic angle of 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 IEC Application manual...
Page 510: Limit Counter L4Ufcnt
The limit counter provides four independent limits to be checked against the accumulated counted value. The four limit reach indication outputs can be utilized Bay control REC670 2.2 IEC Application manual...
Page 511: Setting Guidelines
0.1 hours (6 minutes). tAlarm and tWarning are independent settings, that is, there is no check if tAlarm > tWarning. The limit for the overflow supervision is fixed at 99999.9 hours. Bay control REC670 2.2 IEC Application manual...
Page 512: Estimation Of Transformer Insulation Life Lolsptr
The permissible transformer load level is highly depends on the transformer cooling system. Both IEEE and IEC standards have established transformer thermal model for all cooling system types and described formulae for transformer temperature calculation. Bay control REC670 2.2 IEC Application manual...
Page 513 The hot spot temperature shall be monitored continuously so that it will not exceed the transformer oil flashover value. Figure shows the complex transformer temperature distribution. The assumptions made are: Bay control REC670 2.2 IEC Application manual...
Page 514 Consequences of excessive transformer loading leads to unacceptable temperature rise in windings, leads, insulation and oil. When temperature changes, moisture and gas content in the insulation and oil will change. Bay control REC670 2.2 IEC Application manual...
Page 515 • 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 IEC Application manual...
Page 516 Insulation aging or deterioration is a time function of temperature, moisture content, and oxygen content. With modern oil preservation systems, the moisture Bay control REC670 2.2 IEC Application manual...
Page 517: Setting Guidelines
TrafoType: This setting is used to set the number of phases in the transformer. The options are: • Three Phase Trafo: The function considers the given transformer as three phase transformer. • Single Phase Trafo: The function considers the given transformer as single phase transformer. Bay control REC670 2.2 IEC Application manual...
Page 518 The function takes phase currents of each winding as input. From each winding, only one phase current is considered for load factor calculation. The options are: Bay control REC670 2.2 IEC Application manual...
Page 519 Time required for the top oil temperature in relation to ambient temperature to reach its ultimate value is a function of the thermal oil time constant. The function has the following settings related to oil time constant. Bay control REC670 2.2 IEC Application manual...
Page 520 The function has the following settings related to winding time constant. WdgTmConstMode: This setting is used to select the winding time constant mode of input to the function. It has three options: Bay control REC670 2.2 IEC Application manual...
Page 521 CuLossW2: This setting is used to set the winding loss at rated load for the winding CuLossW3: This setting is used to set the winding loss at rated load for the winding MassW1: This setting is used to set the mass of the winding 1. Bay control REC670 2.2 IEC Application manual...
Page 522 AprilAmbTmp: This setting is used to set the April month average ambient temperature. MayAmbTmp: This setting is used to set the May month average ambient temperature. JuneAmbTmp: This setting is used to set the June month average ambient temperature. Bay control REC670 2.2 IEC Application manual...
Page 523 RatedCurrW3: This setting is used to set the rated RMS current of winding 3 in A. CurrTypeTestW1: This setting is used to set the RMS value of the current which is applied during the type test in A for winding 1. Bay control REC670 2.2 IEC Application manual...
Page 524 LOLINYRS. It can be selected as 1 hour/ 2 hour/ 4 hour/ 8 hour/ 12 hour/ 24 hour depending on user requirement. GUID-B170CF21-839E-4246-A607-55A8999FAD07 v1 Two settable warning levels are available for hot spot temperature with separate outputs. If warning level exceeds for the set time, an alarm is generated. Bay control REC670 2.2 IEC Application manual...
Page 525 For example if the winding time constant is 420 sec, this setting can be 400 sec. tDelayToAlarm2: This setting is used to set the time delay for the level 2 hot spot temperature alarm. This should be less than time setting in tDelayToAlarm1. Bay control REC670 2.2 IEC Application manual...
Page 526: Setting Example
Select the unit of temperature should be °C used in the function AvailableCT Select the available CT connections on All windings the windings RatedVoltageW1 Set the winding 1 rated nominal voltage 415.0 kV Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 527 WdgTimeConst3 420.0 sec Set the transformer winding time constant for the winding 3 when the winding time User constant mode is selected as defined Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 528 Set the rated voltage tap position number HighVoltTap Set the tap position number where maximum voltage is possible LowVoltTap Set the tap position number where minimum voltage is possible Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 529 1 for the calculation of hot spot to top oil temperature gradient HPTmpRiseW2 65° C Set the hot spot temperature rise of winding 2 for the calculation of hot spot to top oil temperature gradient Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 530 Set the hot spot temperature value for the level 2 warning tDelayToAlarm1 1800 sec Set the time delay for the alarm level 1 tDelayToAlarm2 900 sec Set the time delay for the alarm level 2 Bay control REC670 2.2 IEC Application manual...
Page 531: Pulse-Counter Logic Pcfcnt
M13396-4 v9 Parameters that can be set individually for each pulse counter from PCM600: • Operation: Off/On • tReporting: 0-3600s • EventMask: NoEvents/ReportEvents Configuration of inputs and outputs of PCFCNT is made via PCM600. Bay control REC670 2.2 IEC Application manual...
Page 532: 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 IEC Application manual...
Page 533: 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, UBase and SBase as applicable. Operation: Off/On Bay control REC670 2.2 IEC Application manual...
Page 534 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 IEC Application manual...
Page 535: Access Point
When saving the ECT configuration after selecting a subnetwork, ECT creates the access point in the SCL model. Unselecting the subnetwork removes the access point from the SCL model. This column is editable for IEC61850 Ed2 IEDs and not editable for Bay control REC670 2.2 IEC Application manual...
Page 536: Redundant Communication
Identification GUID-B7AE0374-0336-42B8-90AF-3AE1C79A4116 v1 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number IEC 62439-3 Parallel redundancy protocol IEC 62439-3 High-availability seamless redundancy Access point diagnostic for redundant RCHLCCH Ethernet ports Bay control REC670 2.2 IEC Application manual...
Page 537: Application
The redundant communication uses two Ethernet ports. 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 IEC Application manual...
Page 538: 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 IEC Application manual...
Page 539: 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 IEC Application manual...
Page 540: Setting Guidelines
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. Destination specifies the destination. Destination subnet mask specifies the subnetwork mask of the destination. Bay control REC670 2.2 IEC Application manual...
Page 541: 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 IEC Application manual...
Page 542 SA system with IEC 61850–8–1 M16925-3 v4 Figure223 shows the GOOSE peer-to-peer communication. Station HSI MicroSCADA Gateway GOOSE Control Protection Control and protection Control Protection en05000734.vsd IEC05000734 V1 EN-US Figure 223: Example of a broadcasted GOOSE message Bay control REC670 2.2 IEC Application manual...
Page 543: Sending Data
The settings available for Generic communication function for Measured Value (MVGAPC) function allows the user to choose a deadband and a zero deadband for the monitored signal. Values within the zero deadband are considered as zero. Bay control REC670 2.2 IEC Application manual...
Page 544: Receiving Data
Input1 Input1 Ext_Res_OK_To_Operate DataValid Input2 Noput Input2 Noput 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 IEC Application manual...
Page 545: Iec/Uca 61850-9-2Le Communication Protocol
The process bus physical layout can be arranged in several ways, described in Annex B of the standard, depending on what are the needs for sampled data in a substation. Bay control REC670 2.2 IEC Application manual...
Page 546 The electronic part of a non-conventional measuring transducer (like a Rogowski coil or a capacitive divider) can represent a MU by itself as long as it can send sampled data over process bus. Bay control REC670 2.2 IEC Application manual...
Page 547: Setting Guidelines
Example of a station configuration with the IED receiving analog values from both classical measuring transformers and merging units. 20.3.2 Setting guidelines GUID-29B296B3-6185-459F-B06F-8E7F0C6C9460 v4 Merging Units (MUs) have several settings on local HMI under: Bay control REC670 2.2 IEC Application manual...
Page 548: Specific Settings Related To The Iec/Uca 61850-9-2Le Communication
Loss of communication when used with LDCM GUID-29EFBCB7-2B4F-4AA1-B593-8E89838722E0 v3 If IEC/UCA 61850-9-2LE communication is lost, see examples in figures 227, and 229, the protection functions in table are blocked as per graceful degradation. Case 1: Bay control REC670 2.2 IEC Application manual...
Page 549 IEC13000299 V2 EN-US Figure 228: MU failed, mixed system Case 3: Failure of one MU (sample lost) blocks the sending and receiving of binary signals through LDCM. →DTT from the remote end is not working. Bay control REC670 2.2 IEC Application manual...
Page 550 Four step residual EF4PTOC Sudden change in SCCVPTOC overcurrent protection current variation Instantaneous residual EFPIOC Sensitive Directional SDEPSDE overcurrent protection residual over current and power protetcion Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 551 Negative sequence LCNSPTOV Scheme ZCPSCH overvoltage protection communication logic for distance or overcurrent protection Three phase LCP3PTOC Current reversal and ZCRWPSCH overcurrent weak-end infeed logic for distance protection Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 552 Four step phase OC4PTOC Power swing detection ZMRPSB overcurrent protection Overexcitation OEXPVPH Mho Impedance ZSMGAPC protection supervision logic Out-of-step protection OOSPPAM Transformer tank TPPIOC overcurrent protection Bay control REC670 2.2 IEC Application manual...
Page 553: Setting Examples For Iec/Uca 61850-9-2Le And Time Synchronization
When using an external clock, it is possible to set the IED to be synchronized via PPS,IRIG-B or PTP. It is also possible to use an internal GPS receiver in the IED (if the external clock is using GPS). Bay control REC670 2.2 IEC Application manual...
Page 554 SyncAccLevel: can be set to 1μs since this corresponds to a maximum phase angle error of 0.018 degrees at 50Hz Settings on the local HMI under Main menu/Configuration/Communication/ Ethernet configuration/Access point/AP_X: • Operation: On • PTP: On Bay control REC670 2.2 IEC Application manual...
Page 555 Setting example when MU is the synchronizing source Settings on the local HMI under Main menu/Configuration/Time/ Synchronization/TIMESYNCHGEN:1/IEC61850-9-2: • HwSyncSrc: set to PPS as generated by the MU (ABB MU) • SyncLostMode : set to Block to block protection functions if time synchronization is lost •...
Page 556 HWSyncSrc , “full-time” has to be acquired from another source. If station clock is on the local area network (LAN) and has an sntp-server, this is one option. Two status monitoring signals can be: Bay control REC670 2.2 IEC Application manual...
Page 557 Synchronization/TIMESYNCHGEN:1/IEC61850-9-2: • HwSyncSrc: set to Off • SyncLostMode: set to No block to indicate that protection functions are not blocked • SyncAccLevel: set to unspecified Two status monitoring signals with no time synchronization: Bay control REC670 2.2 IEC Application manual...
Page 558: Iec 61850 Quality Expander Qualexp
IED. The function outputs are updated once every second and, therefore, do not reflect the quality bits in real time. Bay control REC670 2.2 IEC Application manual...
Page 559: Lon Communication Protocol
Cable diameter 62.5/125 m 1 mm Max. cable length 1000 m 10 m Wavelength 820-900 nm 660 nm Transmitted power -13 dBm (HFBR-1414) -13 dBm (HFBR-1521) Receiver sensitivity -24 dBm (HFBR-2412) -20 dBm (HFBR-2521) Bay control REC670 2.2 IEC Application manual...
Page 560: Multicmdrcv And Multicmdsnd
The communication speed of the LON bus is set to the default of 1.25 Mbit/s. This can be changed by LNT. 20.4.2 MULTICMDRCV and MULTICMDSND SEMOD119881-1 v3 Bay control REC670 2.2 IEC Application manual...
Page 561: Identification
LAN (see Figure 236), and when using the rear optical Ethernet port, the only hardware required for a station monitoring system is: • Optical fibres from the IED to the utility substation LAN • PC connected to the utility office LAN Bay control REC670 2.2 IEC Application manual...
Page 562: Setting Guidelines
When the communication protocol is selected, the IED is automatically restarted, and the port then operates as a SPA port. The SPA communication setting parameters are set on the local HMI under Main menu/Configuration/Communication/Station communication/SPA/SPA:1. Bay control REC670 2.2 IEC Application manual...
Page 563 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 IEC Application manual...
Page 564: Iec 60870-5-103 Communication Protocol
The master must have software that can interpret the IEC 60870-5-103 communication messages. For detailed information about IEC 60870-5-103, refer to IEC 60870 standard part 5: Transmission Bay control REC670 2.2 IEC Application manual...
Page 565: Design
Function block with pre-defined functions in control direction, I103CMD. This block includes the FUNCTION TYPE parameter, and the INFORMATION NUMBER parameter is defined for each output signal. • Function commands in control direction Bay control REC670 2.2 IEC Application manual...
Page 566: Settings
A1RADR to A4RADR. The eight first ones belong to the public range and the remaining ones to the private range. 20.6.2 Settings M17109-116 v1 Bay control REC670 2.2 IEC Application manual...
Page 567: Settings For Rs485 And Optical Serial Communication
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 IEC Application manual...
Page 568: Settings From Pcm600
ON_SET. In addition there is a setting on each event block for function type. Refer to description of the Main Function type set on the local HMI. Bay control REC670 2.2 IEC Application manual...
Page 569 DRA#-Input IEC 60870-5-103 meaning Private range Private range Private range Private range Private range Private range Private range Private range Private range Private range Private range Private range Table continues on next page Bay control REC670 2.2 IEC Application manual...
Page 570: Function And Information Types
REC 242 Private range, use default RED 192 Compatible range RET 176 Compatible range REB 207 Private range REG 150 Private range REQ 245 Private range RER 152 Private range RES 118 Private range Bay control REC670 2.2 IEC Application manual...
Page 571: Dnp3 Communication Protocol
For more information, refer to IEC standard IEC 60870-5-103. 20.7 DNP3 Communication protocol 20.7.1 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 IEC Application manual...
Page 573: Binary Signal Transfer
Figure 239, only IED-B has access to all currents and, therefore, this is the only place where the differential current is evaluated. If the evaluation results in a trip, the trip signal will be sent over the two communication links. Bay control REC670 2.2 IEC Application manual...
Page 574: 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 240. The protocol used is IEEE/ANSI C37.94. The distance with this solution is typical 110 km. Bay control REC670 2.2 IEC Application manual...
Page 575: Setting Guidelines
IEDs in the system is out of service: it can either be done on the IED out of service by setting all local LDCMs to channel mode OutOfService or at the remote Bay control REC670 2.2 IEC Application manual...
Page 576 Slot 305: main channel • Slot 306: redundant channel The same is applicable for slot 312-313 and slot 322-323. DiffSync defines the method of time synchronization for the line differential function: Echo or GPS. Bay control REC670 2.2 IEC Application manual...
Page 577 If data arrive in wrong order, the oldest data is disregarded. MaxtDiffLevel indicates the maximum time difference allowed between internal clocks in respective line ends. 64 kbit mode specific settings TransmCurr is used to select among the following: Bay control REC670 2.2 IEC Application manual...
Page 578 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 IEC Application manual...
Page 579: Authority Status Athstat
Apart from the built-in supervision of the various modules, events are also generated when the status changes for the: • built-in real time clock (in operation/out of order). • external time synchronization (in operation/out of order). Bay control REC670 2.2 IEC Application manual...
Page 580: Change Lock Chnglck
The binary input controlling the function is defined in ACT or SMT. The CHNGLCK function is configured using ACT. LOCK Binary input signal that will activate/deactivate the function, defined in ACT or SMT. Bay control REC670 2.2 IEC Application manual...
Page 581: 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 583: Ied Identifiers Terminalid
OrderingNo • ProductionDate • IEDProdType This information is very helpful when interacting with ABB product support (for example during repair and maintenance). 23.2.2 Factory defined settings M11789-39 v10 The factory defined settings are very useful for identifying a specific version and very helpful in the case of maintenance, repair, interchanging IEDs between different Substation Automation Systems and upgrading.
Page 584: Measured Value Expander Block Range_Xp
• OrderingNo • ProductionDate 23.3 Measured value expander block RANGE_XP SEMOD52451-1 v2 23.3.1 Identification SEMOD113212-2 v3 Function description IEC 61850 IEC 60617 ANSI/IEEE C37.2 identification identification device number Measured value expander block RANGE_XP Bay control REC670 2.2 IEC Application manual...
Page 585: Application
MAXSETGR and shall be set to the required value for each IED. Only the number of setting groups set will be available in the Parameter Setting tool for activation with the ActiveGroup function block. Bay control REC670 2.2 IEC Application manual...
Page 586: Setting Guidelines
The analog summation block 3PHSUM function block is used in order to get the sum of two sets of 3 phase analog signals (of the same type) for those IED functions that might need it. Bay control REC670 2.2 IEC Application manual...
Page 587: Setting Guidelines
Each applicable function in the IED has a parameter, GlobalBaseSel, defining one out of the twelve sets of GBASVAL functions. 23.7.3 Setting guidelines GUID-E3F5D754-BD17-4729-895B-957A09C2AC75 v4 UBase: Phase-to-phase voltage value to be used as a base value for applicable functions throughout the IED. Bay control REC670 2.2 IEC Application manual...
Page 588: Signal Matrix For Binary Inputs Smbi
Parameter Setting tool. However, the user must give a name to SMBO instance and SMBO outputs, directly in the Application Configuration tool. These names will define SMBO function in the Signal Matrix tool. Bay control REC670 2.2 IEC Application manual...
Page 589: Signal Matrix For Ma Inputs Smmi
L1-L2 to GRPxL1, L2-L3 to GRPxL2, L3-L1 to GRPxL3. If SMAI setting ConnectionType is Ph-N, all three inputs GRPxL1, GRPxL2 and GRPxL3 must be connected in order to calculate the positive sequence voltage. Bay control REC670 2.2 IEC Application manual...
Page 590: Setting Guidelines
– 244 values in total). Besides the block “group name”, the analog inputs type (voltage or current) and the analog input names that can be set directly in ACT. Bay control REC670 2.2 IEC Application manual...
Page 591 Examples of adaptive frequency tracking Preprocessing block shall only be used to feed functions within the same execution cycles (e.g. use preprocessing block with cycle 1 to feed transformer differential protection). The only exceptions are Bay control REC670 2.2 IEC Application manual...
Page 592 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 IEC Application manual...
Page 593 In other application the usual setting of the parameter DFTReference of SMAI is InternalDFTRef. Example 1 Bay control REC670 2.2 IEC Application manual...
Page 594 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) Example 2 Bay control REC670 2.2 IEC Application manual...
Page 595 (see Figure 245) 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 IEC Application manual...
Page 596: Test Mode Functionality Testmode
SV, and IED configuration or LHMI. If a function of an IED is set to Off, the related Beh is set to Off as well. The related mod keeps its current state. Bay control REC670 2.2 IEC Application manual...
Page 597: Setting Guidelines
IEDs in the system. If a global common source (i.e. GPS) is used in different substations for the time synchronization, also comparisons and analysis between recordings made at different locations can be Bay control REC670 2.2 IEC Application manual...
Page 598 IRIG-B with IEEE1344 will be automatically selected as the time synchronization source. Or if GPS and SNTP are selected, when the GPS signal quality is bad, the IED will automatically choose SNTP as the time-source. Bay control REC670 2.2 IEC Application manual...
Page 599: Setting Guidelines
TimeSynch. The time synchronization source can also be set from PCM600. The setting alternatives are: FineSyncSource which can have the following values: • • • • BIN (Binary Minute Pulse) • • GPS+SPA • GPS+LON • GPS+BIN Bay control REC670 2.2 IEC Application manual...
Page 600 A PTP-group is set up by connecting the IEDs to a network and enabling PTP. To set one IED as the grandmaster change Priority2 to 127 instead of the default 128. Bay control REC670 2.2 IEC Application manual...
Page 601 PTP compliant. As a side effect, the GTM contains a GPS receiver and the REL acts as a backup of the GPS on the station bus. On all access points, the PTP parameter is “ON”. Bay control REC670 2.2 IEC Application manual...
Page 602: Process Bus Iec/Uca 61850-9-2Le Synchronization
If the PPS output from the GTM module is used to synchronize the merging unit and PTP is not used, the IED does not know how the merging unit is synchronized and the parameter LostSyncMode must be set to NoBlock. Bay control REC670 2.2 IEC Application manual...
Page 603: Current Transformer Requirements
). As the present CT standards have no limitation of the level of remanent flux, these CTs are also classified as for example, class TPX, P and PX according to IEC. The IEC TR 61869-100, Edition Bay control REC670 2.2 IEC Application manual...
Page 604 So far remanence factors of maximum 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 605: 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 606: Fault Current
Even in a case where the phase- to-earth fault current is smaller than the three-phase fault current the phase-to-earth fault can be dimensioning for the CT depending on the higher burden. Bay control REC670 2.2 IEC Application manual...
Page 607: General Current Transformer Requirements
CT (TPZ) is not well defined as far as the phase angle error is concerned. If no explicit recommendation is given for a specific function we therefore recommend contacting ABB to confirm that the non remanence type can be used.
Page 608: Non-Directional Instantaneous And Definitive Time, Phase And Residual Overcurrent Protection
The resistance of a single secondary wire should be used for faults in high impedance earthed systems. The burden of an IED current input channel (VA). S =0.020 VA/channel for I =1 A and =0.150 VA/channel for I =5 A Bay control REC670 2.2 IEC Application manual...
Page 609: Non-Directional Inverse Time Delayed Phase And Residual Overcurrent Protection
æ ö ³ × × ç ÷ alreq max k max è ø (Equation 131) EQUATION1077 V2 EN-US where Maximum primary fundamental frequency current for close-in faults (A) kmax Bay control REC670 2.2 IEC Application manual...
Page 610: Directional Phase And Residual Overcurrent Protection
The value of the E is approximately equal to the corresponding E . Therefore, the CTs according to class P and PR must have a secondary limiting e.m.f. E that fulfills the following: Bay control REC670 2.2 IEC Application manual...
Page 611: Px, Pxr (And Old Iec 60044-6, Class Tps And Old British Standard, Class X)
ANSI The CTs according to class C must have a calculated rated equivalent limiting secondary e.m.f. E that fulfils the following: alANSI > maximum of E alANSI alreq (Equation 136) EQUATION1384 V2 EN-US Bay control REC670 2.2 IEC Application manual...
Page 612: Voltage Transformer Requirements
SNTP server software. The SNTP server should be stable, that is, either synchronized from a stable source like GPS, or local without synchronization. Using a local SNTP server without synchronization as primary or secondary server in a redundant configuration is not recommended. Bay control REC670 2.2 IEC Application manual...
Page 613: Ptp Requirements
Jitter and Wander according to ITU-T G.823 and G.825 • Buffer memory <250 μs, <100 μs asymmetric difference • Format.G 704 frame, structured etc.Format. • No CRC-check Synchronization in PDH systems connected to SDH systems Bay control REC670 2.2 IEC Application manual...
Page 614: Iec/Uca 61850-9-2Le Merging Unit Requirements
Thus, the accuracy of the current and voltage inputs to the merging unit and the inaccuracy added by the merging unit must be coordinated with the requirement for actual type of protection function. Bay control REC670 2.2 IEC Application manual...
Page 615: Application Manual
In principle the accuracy of the current and voltage transformers, together with the merging unit, shall have the same quality as direct input of currents and voltages. Bay control REC670 2.2 IEC Application manual...
Page 617: Section 25 Glossary
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 Circuit breaker Combined backplane module Bay control REC670 2.2 IEC Application manual...
Page 618 Delayed autoreclosing DARPA Defense Advanced Research Projects Agency (The US developer of the TCP/IP protocol etc.) DBDL Dead bus dead line DBLL Dead bus live line Direct current Data flow control Discrete Fourier transform Bay control REC670 2.2 IEC Application manual...
Page 619 File Transfer Protocol Function type G.703 Electrical and functional description for digital lines used by local telephone companies. Can be transported over balanced and unbalanced lines Communication interface module with carrier of GPS receiver module Bay control REC670 2.2 IEC Application manual...
Page 620 PCI specifications from the PCI SIG (Special Interest Group) for the electrical EMF (Electromotive force). IEEE 1686 Standard for Substation Intelligent Electronic Devices (IEDs) Cyber Security Capabilities Intelligent electronic device IET600 Integrated engineering tool Bay control REC670 2.2 IEC Application manual...
Page 621 LON network tool Local operating network Miniature circuit breaker Mezzanine carrier module Milli-ampere module Main processing module MVAL Value of measurement Multifunction vehicle bus. Standardized serial bus originally developed for use in trains. Bay control REC670 2.2 IEC Application manual...
Page 622 Permissive underreach transfer trip RASC Synchrocheck relay, COMBIFLEX Relay characteristic angle RISC Reduced instruction set computer RMS value Root mean square value RS422 A balanced serial interface for the transmission of digital data in point-to-point connections Bay control REC670 2.2 IEC Application manual...
Page 623 Switch or push button to trip Starpoint Neutral point of transformer or generator Static VAr compensation Trip coil Trip circuit supervision Transmission control protocol. The most common transport layer protocol used on Ethernet and the Internet. Bay control REC670 2.2 IEC Application manual...
Page 624 Gregorian calendar. It is used for aeroplane and ship navigation, where it is also sometimes known by the military name, "Zulu time." "Zulu" in the phonetic alphabet stands for "Z", which stands for longitude zero. Bay control REC670 2.2 IEC Application manual...
Page 625 A digital signalling interface primarily used for telecom equipment Three times zero-sequence current.Often referred to as the residual or the earth-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 IEC Application manual...
Page 628 — ABB AB Grid Automation Products 721 59 Västerås, Sweden Phone: +46 (0) 21 32 50 00 abb.com/protection-control © Copyright 2017 ABB. All rights reserved. Specifications subject to change without notice.

ABB REC670 Applications Manual

Section 1 Introduction

Section 2 Application

Section 3 Configuration

Section 4 Analog Inputs

Section 5 Local HMI

Quick Links

Related Manuals for ABB REC670

Summary of Contents for ABB REC670