ABB REB670 Series Applications Manual Download

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Connect three-phase generator currents and voltages to one CVGAPC instance (for

example, GF05)

Set

CurrentInput to value MaxPh

Set

VoltageInput to value MinPh-Ph (it is assumed that minimum phase-to-phase voltage

shall be used for restraining. Alternatively, positive sequence voltage can be used for

restraining by selecting

PosSeq for this setting parameter)

4. Set base current value to the rated generator current primary amperes

5. Set base voltage value to the rated generator phase-to-phase voltage in kV

6. Enable one overcurrent step (for example, OC1)

Select

CurveType_OC1 to value ANSI Very inv

8. If required set minimum operating time for this curve by using parameter

tMin_OC1

(default value 0.05s)

9. Set

StartCurr_OC1 to value 185%

10. Set

VCntrlMode_OC1 to On

11. Set

VDepMode_OC1 to Slope

12. Set

VDepFact_OC1 to value 0.25

13. Set

UHighLimit_OC1 to value 100%

14. Set

ULowLimit_OC1 to value 25%

Proper operation of the CVGAPC function made in this way can easily be verified by secondary

injection. All other settings can be left at the default values. Furthermore the other built-in

protection elements can be used for other protection and alarming purposes.

10.1.3.6

Loss of excitation protection for a generator

M13088-182 v3

Example will be given how by using positive sequence directional overcurrent protection

element within a CVGAPC function, loss of excitation protection for a generator can be

achieved. Let us assume that from rated generator data the following values are calculated:

•

Maximum generator capability to contentiously absorb reactive power at zero active

loading 38% of the generator MVA rating

•

Generator pull-out angle 84 degrees

This functionality can be achieved by using one CVGAPC function. The following shall be done

in order to insure proper operation of the function:

Connect three-phase generator currents and three-phase generator voltages to one

CVGAPC instance (for example, GF02)

Set parameter

CurrentInput to PosSeq

Set parameter

VoltageInput to PosSeq

4. Set base current value to the rated generator current primary amperes

5. Set base voltage value to the rated generator phase-to-phase voltage in kV

6. Set parameter

RCADir to value -84 degree (that is, current lead voltage for this angle)

Set parameter

ROADir to value 90 degree

8. Set parameter

LowVolt_VM to value 5%

9. Enable one overcurrent step (for example, OC1)

10. Select parameter

CurveType_OC1 to value IEC Def. Time

11. Set parameter

StartCurr_OC1 to value 38%

12. Set parameter

tDef_OC1 to value 2.0s (typical setting)

13. Set parameter

DirMode_OC1 to Forward

14. Set parameter

DirPrinc_OC1 to IcosPhi&U

15. Set parameter

ActLowVolt1_VM to Block

Proper operation of the CVGAPC function made in this way can easily be verified by secondary

injection. All other settings can be left at the default values. However it shall be noted that set

values for RCA & ROA angles will be applicable for OC2 step if directional feature is enabled for

this step as well. Figure

118

shows overall protection characteristic

Section 10

1MRK 505 370-UEN D

Multipurpose protection

236

Busbar protection REB670

Application manual

Summary of Contents for REB670 Series

Page 1: ...Relion 670 SERIES Busbar protection REB670 Version 2 2 IEC Application manual ...

Page 2: ......

Page 4: ...erms of such license This product includes software developed by the OpenSSL Project for use in the OpenSSL Toolkit http www openssl org This product includes cryptographic software written developed by Eric Young eay cryptsoft com and Tim Hudson tjh cryptsoft com Trademarks ABB and Relion are registered trademarks of the ABB Group All other brand or product names mentioned in this document may be...

Page 5: ...product failure would create a risk for harm to property or persons including but not limited to personal injuries or death shall be the sole responsibility of the person or entity applying the equipment and those so responsible are hereby requested to ensure that all measures are taken to exclude or mitigate such risks This document has been carefully checked by ABB but deviations cannot be compl...

Page 6: ...nd 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 The product is designed in accordance with the international standards of ...

Page 7: ...ration 47 3 1 Description of configuration REB670 47 3 1 1 Available ACT configurations for pre configured REB670 47 3 1 2 Configuration X01 47 3 1 3 Configuration X02 47 3 1 4 Configuration X03 47 3 1 5 Description of 3 ph package A20 48 3 1 6 Description of 3 ph package A31 48 3 1 7 Description of 1 ph packages B20 and B21 52 3 1 8 Description of 1 ph package B31 54 Section 4 Analog inputs 59 4 ...

Page 8: ...wer systems 80 Section 5 Local HMI 83 5 1 Display 84 5 2 LEDs 85 5 3 Keypad 86 5 4 Local HMI functionality 88 5 4 1 Protection and alarm indication 88 5 4 2 Parameter management 89 5 4 3 Front communication 89 Section 6 Differential protection 91 6 1 Busbar differential protection 91 6 1 1 Identification 91 6 1 2 Basic applications 92 6 1 2 1 General 92 6 1 2 2 Meshed corner application and T conn...

Page 9: ...or end connection 141 6 1 6 7 SLCE 8 ASCT characteristics for series connection 142 Section 7 Current protection 143 7 1 Directional phase overcurrent protection four steps OC4PTOC 143 7 1 1 Identification 143 7 1 2 Application 143 7 1 3 Setting guidelines 144 7 1 3 1 Settings for each step 145 7 1 3 2 Setting example 148 7 2 Four step single phase overcurrent protection PH4SPTOC 152 7 2 1 Identif...

Page 10: ...es 198 7 10 Capacitor bank protection CBPGAPC 201 7 10 1 Identification 201 7 10 2 Application 201 7 10 2 1 SCB protection 203 7 10 3 Setting guidelines 204 7 10 3 1 Restrike detection 206 Section 8 Voltage protection 207 8 1 Two step undervoltage protection UV2PTUV 207 8 1 1 Identification 207 8 1 2 Setting guidelines 207 8 1 2 1 Equipment protection such as for motors and generators 207 8 1 2 2 ...

Page 11: ...s of voltage check LOVPTUV 219 8 5 1 Identification 219 8 5 2 Application 219 8 5 3 Setting guidelines 219 8 5 3 1 Advanced users settings 219 Section 9 Frequency protection 221 9 1 Underfrequency protection SAPTUF 221 9 1 1 Identification 221 9 1 2 Application 221 9 1 3 Setting guidelines 221 9 2 Overfrequency protection SAPTOF 222 9 2 1 Identification 222 9 2 2 Application 222 9 2 3 Setting guid...

Page 12: ...o sequence based 241 11 1 3 5 Delta U and delta I 242 11 1 3 6 Dead line detection 242 11 2 Fuse failure supervision VDSPVC 242 11 2 1 Identification 242 11 2 2 Application 242 11 2 3 Setting guidelines 243 11 3 Voltage based delta supervision DELVSPVC 244 11 3 1 Identification 244 11 3 2 Application 244 11 3 3 Setting guidelines 246 11 4 Current based delta supervision DELISPVC 246 11 4 1 Identif...

Page 13: ...the first shot 270 12 2 2 12 ARMode 1 2ph 1 3ph 1 phase 2 phase or 3 phase reclosing in the first shot 270 12 2 2 13 ARMode 1ph 1 2 3ph 1 phase 2 phase or 3 phase reclosing in the first shot 270 12 2 2 14 External selection of auto reclosing mode 271 12 2 2 15 Auto reclosing reclaim timer 271 12 2 2 16 Pulsing of the circuit breaker closing command and counter 271 12 2 2 17 Transient fault 271 12 ...

Page 14: ... 5 2 Signals from all feeders 312 12 4 5 3 Configuration setting 315 12 4 6 Interlocking for bus section disconnector A1A2_DC 315 12 4 6 1 Application 316 12 4 6 2 Signals in single breaker arrangement 316 12 4 6 3 Signals in double breaker arrangement 319 12 4 6 4 Signals in 1 1 2 breaker arrangement 321 12 4 7 Interlocking for busbar earthing switch BB_ES 322 12 4 7 1 Application 322 12 4 7 2 Si...

Page 15: ...p matrix logic TMAGAPC 337 13 1 1 Identification 337 13 1 2 Application 337 13 1 3 Setting guidelines 337 13 2 Logic for group alarm ALMCALH 337 13 2 1 Identification 337 13 2 2 Application 338 13 2 3 Setting guidelines 338 13 3 Logic for group alarm WRNCALH 338 13 3 1 Identification 338 13 3 1 1 Application 338 13 3 1 2 Setting guidelines 338 13 4 Logic for group indication INDCALH 338 13 4 1 Ide...

Page 16: ...eger inputs INTCOMP 348 13 13 1 Identification 348 13 13 2 Application 348 13 13 3 Setting guidelines 348 13 13 4 Setting example 349 13 14 Comparator for real inputs REALCOMP 349 13 14 1 Identification 349 13 14 2 Application 350 13 14 3 Setting guidelines 350 13 14 4 Setting example 350 Section 14 Monitoring 353 14 1 Measurement 353 14 1 1 Identification 353 14 1 2 Application 353 14 1 3 Zero cl...

Page 17: ...4 8 3 Setting guidelines 377 14 9 Running hour meter TEILGAPC 377 14 9 1 Identification 377 14 9 2 Application 377 14 9 3 Setting guidelines 378 14 10 Current harmonic monitoring CHMMHAI 378 14 10 1 Identification 378 14 10 2 Application 378 14 10 3 Setting guidelines 379 14 10 3 1 Setting procedure on the IED 379 14 11 Voltage harmonic monitoring VHMMHAI 380 14 11 1 Identification 380 14 11 2 App...

Page 18: ...rotocol 396 17 3 1 Introduction 396 17 3 2 Setting guidelines 398 17 3 2 1 Specific settings related to the IEC UCA 61850 9 2LE communication 399 17 3 2 2 Loss of communication when used with LDCM 399 17 3 2 3 Setting examples for IEC UCA 61850 9 2LE and time synchronization 403 17 3 3 IEC 61850 quality expander QUALEXP 407 17 4 LON communication protocol 408 17 4 1 Application 408 17 4 2 MULTICMD...

Page 19: ...on 429 19 4 2 Setting guidelines 429 Section 20 Basic IED functions 431 20 1 IED identifiers TERMINALID 431 20 1 1 Application 431 20 2 Product information PRODINF 431 20 2 1 Application 431 20 2 2 Factory defined settings 431 20 3 Measured value expander block RANGE_XP 432 20 3 1 Identification 432 20 3 2 Application 432 20 3 3 Setting guidelines 433 20 4 Parameter setting groups 433 20 4 1 Appli...

Page 20: ...1 1 2 Conditions 450 21 1 3 Fault current 451 21 1 4 Secondary wire resistance and additional load 451 21 1 5 General current transformer requirements 452 21 1 6 Rated equivalent secondary e m f requirements 452 21 1 6 1 Busbar protection 452 21 1 6 2 Breaker failure protection 453 21 1 6 3 Non directional instantaneous and definitive time phase and residual overcurrent protection 454 21 1 6 4 Non...

Page 21: ...21 6 IEC UCA 61850 9 2LE Merging unit requirements 458 Section 22 Glossary 461 Table of contents Busbar protection REB670 15 Application manual ...

Page 22: ...16 ...

Page 23: ...also provide assistance for calculating settings 1 2 Intended audience GUID C9B8127F 5748 4BEA 9E4F CC762FE28A3A v11 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 communic...

Page 24: ...for mechanical and electrical installation The chapters are organized in the chronological order in which the IED should be installed The commissioning manual contains instructions on how to commission the IED The manual can also be used by system engineers and maintenance personnel for assistance during the testing phase The manual provides procedures for the checking of external circuitry and en...

Page 25: ...cribed and sorted by function 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 v8 Document revision date History May 2017 First release A October 2017 Information updated B March 2018 2 2 Maintenance release 1 C June 2018 Added new ...

Page 26: ...1 Laser product Take adequate measures to protect the eyes and do not view directly with optical instruments The caution icon indicates important information or warning related to the concept discussed in the text It might indicate the presence of a hazard which could result in corruption of software or damage to equipment or property The information icon alerts the reader of important facts and c...

Page 27: ...o another function block in the application configuration to achieve a valid application configuration Dimensions are provided both in inches and millimeters If it is not specifically mentioned then the dimension is in millimeters 1 5 IEC 61850 edition 1 edition 2 mapping GUID C5133366 7260 4C47 A975 7DBAB3A33A96 v7 Function block names are used in ACT and PST to identify functions Respective func...

Page 28: ...BICPTRC BICPTRC BICPTRC_02 BICPTRC BICPTRC BICPTRC_03 BICPTRC BICPTRC BICPTRC_04 BICPTRC BICPTRC BICPTRC_05 BICPTRC BICPTRC BRCPTOC BRCPTOC BRCPTOC BRPTOC BRPTOC BRPTOC BTIGAPC B16IFCVI BTIGAPC BUSPTRC_B1 BUSPTRC BBSPLLN0 BUSPTRC BUSPTRC_B2 BUSPTRC BUSPTRC BUSPTRC_B3 BUSPTRC BUSPTRC BUSPTRC_B4 BUSPTRC BUSPTRC BUSPTRC_B5 BUSPTRC BUSPTRC BUSPTRC_B6 BUSPTRC BUSPTRC BUSPTRC_B7 BUSPTRC BUSPTRC BUSPTRC_...

Page 29: ...RC BUTPTRC_B8 BUTPTRC BUTPTRC BZISGGIO BZISGGIO BZISGAPC BZITGGIO BZITGGIO BZITGAPC BZNPDIF_Z1 BZNPDIF 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 BZNTPDIF_A BZNTPDIF BZATGAPC BZATPDIF BZNT...

Page 30: ...RC DPGAPC DPGGIO DPGAPC DRPRDRE DRPRDRE DRPRDRE ECPSCH ECPSCH ECPSCH ECRWPSCH ECRWPSCH ECRWPSCH EF2PTOC EF2LLN0 EF2PTRC EF2RDIR GEN2PHAR PH1PTOC EF2PTRC EF2RDIR GEN2PHAR PH1PTOC EF4PTOC EF4LLN0 EF4PTRC EF4RDIR GEN4PHAR PH1PTOC EF4PTRC EF4RDIR GEN4PHAR PH1PTOC EFPIOC EFPIOC EFPIOC EFRWPIOC EFRWPIOC EFRWPIOC ETPMMTR ETPMMTR ETPMMTR FDPSPDIS FDPSPDIS FDPSPDIS FMPSPDIS FMPSPDIS FMPSPDIS FRPSPDIS FPSRP...

Page 31: ...PDUP LAPPPUPF LAPPPDUP LAPPPUPF LCCRPTRC LCCRPTRC LCCRPTRC LCNSPTOC LCNSPTOC LCNSPTOC LCNSPTOV LCNSPTOV LCNSPTOV LCP3PTOC LCP3PTOC LCP3PTOC LCP3PTUC LCP3PTUC LCP3PTUC LCPTTR LCPTTR LCPTTR LCZSPTOC LCZSPTOC LCZSPTOC LCZSPTOV LCZSPTOV LCZSPTOV LD0LLN0 LLN0 LDLPSCH LDLPDIF LDLPSCH LDRGFC STSGGIO LDRGFC LEXPDIS LEXPDIS LEXPDIS LEXPTRC LFPTTR LFPTTR LFPTTR LMBRFLO LMBRFLO LMBRFLO LOLSPTR LOLSPTR LOLSPT...

Page 32: ...LLN0 OV2PTOV PH1PTRC OV2PTOV PH1PTRC PAPGAPC PAPGAPC PAPGAPC PCFCNT PCGGIO PCFCNT PH4SPTOC GEN4PHAR OCNDLLN0 PH1BPTOC PH1PTRC GEN4PHAR PH1BPTOC PH1PTRC PHPIOC PHPIOC PHPIOC PSLPSCH ZMRPSL PSLPSCH PSPPPAM PSPPPAM PSPPPAM PSPPTRC QCBAY QCBAY BAY LLN0 QCRSV QCRSV QCRSV RCHLCCH RCHLCCH RCHLCCH REFPDIF REFPDIF REFPDIF ROTIPHIZ ROTIPHIZ ROTIPHIZ ROTIPTRC ROV2PTOV GEN2LLN0 PH1PTRC ROV2PTOV PH1PTRC ROV2PT...

Page 33: ...PMSS STBPTOC STEFPHIZ STEFPHIZ STEFPHIZ STTIPHIZ STTIPHIZ STTIPHIZ SXCBR SXCBR SXCBR SXSWI SXSWI SXSWI T2WPDIF T2WPDIF T2WGAPC T2WPDIF T2WPHAR T2WPTRC T3WPDIF T3WPDIF T3WGAPC T3WPDIF T3WPHAR T3WPTRC TCLYLTC TCLYLTC TCLYLTC TCSLTC TCMYLTC TCMYLTC TCMYLTC TEIGAPC TEIGGIO TEIGAPC TEIGGIO TEILGAPC TEILGGIO TEILGAPC TMAGAPC TMAGGIO TMAGAPC TPPIOC TPPIOC TPPIOC TR1ATCC TR1ATCC TR1ATCC TR8ATCC TR8ATCC TR...

Page 34: ...F ZCVPSOF ZCVPSOF ZGVPDIS ZGVLLN0 PH1PTRC ZGVPDIS ZGVPTUV PH1PTRC ZGVPDIS ZGVPTUV ZMCAPDIS ZMCAPDIS ZMCAPDIS ZMCPDIS ZMCPDIS ZMCPDIS ZMFCPDIS ZMFCLLN0 PSFPDIS ZMFPDIS ZMFPTRC ZMMMXU PSFPDIS ZMFPDIS ZMFPTRC ZMMMXU ZMFPDIS ZMFLLN0 PSFPDIS ZMFPDIS ZMFPTRC ZMMMXU PSFPDIS PSFPDIS ZMFPDIS ZMFPTRC ZMMMXU ZMHPDIS ZMHPDIS ZMHPDIS ZMMAPDIS ZMMAPDIS ZMMAPDIS ZMMPDIS ZMMPDIS ZMMPDIS ZMQAPDIS ZMQAPDIS ZMQAPDIS...

Page 35: ... achieved numerically by a parameter setting The numerical low impedance differential protection function is designed for fast and selective protection for faults within protected zone All connected CT inputs are provided with a restraint feature The minimum pick up value for the differential current is set to give a suitable sensitivity for all internal faults The pick up setting for the fault cu...

Page 36: ...ures Dynamic linking of measured CT currents to the appropriate differential protection zone as required by substation topology Efficient merging of the two or more differential zones when required by substation topology that is load transfer Easy zone merging initiated by closing of bus sectionalizing disconnectors Selective operation of busbar differential protection ensures tripping only of cir...

Page 37: ... values Central Account Management is an authentication infrastructure that offers a secure solution for enforcing access control to IEDs and other systems within a substation This incorporates management of user accounts roles and certificates and the distribution of such a procedure completely transparent to the user The Flexible Product Naming allows the customer to use an IED vendor independen...

Page 38: ...n 2 zones three phase 4 bays 1 BUTPTRC BCZTPDIF BZNTPDIF BZITGGIO BUTSM8 87B Busbar differential protection 2 zones three phase 8 bays 1 1 BUSPTRC BCZSPDIF BZNSPDIF BZISGGIO BUSSM12 87B Busbar differential protection 2 zones single phase 12 bays 1 1 BUSPTRC BCZSPDIF BZNSPDIF BZISGGIO BUSSM24 87B Busbar differential protection 2 zones single phase 24 bays 1 1 BDZSGAPC BFPTRC BICPTRC BZNPDIF BCZPDIF...

Page 39: ...protection 0 8 TRPTTR 49 Thermal overload protection two time constants 0 2 CCRBRF 50BF Breaker failure protection 0 8 4 C10 8 C11 CCSRBRF 50BF Breaker failure protection single phase version 0 24 12 C12 12 C12 24 C13 GUPPDUP 37 Directional underpower protection 0 4 GOPPDOP 32 Directional overpower protection 0 4 CBPGAPC Capacitor bank protection 0 2 Voltage protection UV2PTUV 27 Two step undervol...

Page 40: ...E3777F16 0B76 4157 A3BF 0B6B978863DE v17 IEC 61850 or function name ANSI Function description Busbar REB670 Customized REB670 A20 REB670 A31 REB670 B20 REB670 B21 REB670 B31 Control SESRSYN 25 Synchroch eck energizing check and synchroni zing 0 3 SMBRREC 79 Autoreclo ser 0 2 2 H05 2 H05 2 H05 2 H05 2 H05 APC30 3 Control functional ity for up to 6 bays max 30 objects 6CBs including interlocki ng se...

Page 41: ...30 30 30 30 30 30 DPGAPC Generic communic ation function for Double Point indication 32 32 32 32 32 32 SPC8GAPC Single point generic control function 8 signals 5 5 5 5 5 5 AUTOBITS Automati on bits command function for DNP3 0 3 3 3 3 3 3 SINGLECMD Single command 16 signals 8 8 8 8 8 8 I103CMD Function command s for IEC 60870 5 1 03 1 1 1 1 1 1 I103GENCMD Function command s generic for IEC 60870 5 ...

Page 42: ...1 1 1 1 I103USRCMD Function command s user defined for IEC 60870 5 1 03 4 4 4 4 4 4 Secondary system supervision FUFSPVC Fuse failure supervisio n 0 2 VDSPVC 60 Fuse failure supervisio n based on voltage difference 0 2 DELVSPVC 7V_78 V Voltage delta supervisio n 2 phase 4 4 4 4 4 4 DELISPVC 71 Current delta supervisio n 2 phase 4 4 4 4 4 4 DELSPVC 78 Real delta supervisio n real 4 4 4 4 4 4 Logic ...

Page 43: ...PQT INDEXTSPQT INVALIDQT INVERTERQT ORQT PULSETIMERQT RSMEMORYQT SRMEMORYQT TIMERSETQT XORQT Configura ble logic blocks Q T see Table 5 0 1 AND GATE INV LLD OR PULSETIMER RSMEMORY SLGAPC SRMEMORY TIMERSET VSGAPC XOR Extension logic package see Table 6 0 1 FXDSIGN Fixed signal function block 1 1 1 1 1 1 B16I Boolean to integer conversio n 16 bit 18 18 18 18 18 18 BTIGAPC Boolean to integer conversi...

Page 44: ...ime integrator with limit transgres sion and overflow supervisio n 12 12 12 12 12 12 INTCOMP Comparat or for integer inputs 30 30 30 30 30 30 REALCOMP Comparat or for real inputs 30 30 30 30 30 30 Table 3 Total number of instances for basic configurable logic blocks Basic configurable logic block Total number of instances AND 328 GATE 64 INV 492 LLD 40 OR 496 PULSETIMER 40 RSMEMORY 40 SRMEMORY 40 ...

Page 45: ... of position indication 30 QCBAY Bay control 5 LOCREM Handling of LR switch positions 5 XLNPROXY Proxy for signals from switching device via GOOSE 42 GOOSEXLNRCV GOOSE function block to receive a switching device 42 Table 5 Total number of instances for configurable logic blocks Q T Configurable logic blocks Q T Total number of instances ANDQT 120 INDCOMBSPQT 20 INDEXTSPQT 20 INVALIDQT 22 INVERTER...

Page 46: ...B670 A31 REB670 B20 REB670 B21 REB670 B31 Monitoring CVMMXN Power system measurem ent 6 6 6 6 6 6 CMMXU Current measurem ent 10 10 10 10 10 10 VMMXU Voltage measurem ent phase phase 6 6 6 6 6 6 CMSQI Current sequence measurem ent 6 6 6 6 6 6 VMSQI Voltage sequence measurem ent 6 6 6 6 6 6 VNMMXU Voltage measurem ent phase earth 6 6 6 6 6 6 AISVBAS General service value presentati on of analog inpu...

Page 47: ...ation 16 inputs 16 16 16 16 16 16 MVGAPC Generic communic ation function for measured values 24 24 24 24 24 24 BINSTATREP Logical signal status report 3 3 3 3 3 3 RANGE_XP Measured value expander block 28 28 28 28 28 28 SSIMG 63 Insulation supervisio n for gas medium 21 21 21 21 21 21 SSIML 71 Insulation supervisio n for liquid medium 3 3 3 3 3 3 SSCBR Circuit breaker condition monitorin g 0 24 12...

Page 48: ...OT Function status fault protection for IEC 60870 5 1 03 1 1 1 1 1 1 I103IED IED status for IEC 60870 5 1 03 1 1 1 1 1 1 I103SUPERV Superviso n status for IEC 60870 5 1 03 1 1 1 1 1 1 I103USRDEF Status for user defined signals for IEC 60870 5 1 03 20 20 20 20 20 20 L4UFCNT Event counter with limit supervisio n 30 30 30 30 30 30 TEILGAPC Running hour meter 6 6 6 6 6 6 CHMMHAI ITHD Current harmonic ...

Page 49: ...0 B31 Station communication ADE LON communication protocol 1 1 1 1 1 1 HORZCOMM Network variables via LON 1 1 1 1 1 1 IEC 61850 8 1 IEC 61850 1 1 1 1 1 1 GOOSEINTLKRCV Horizontal communication via GOOSE for interlocking 59 59 59 59 59 59 GOOSEBINRCV GOOSE binary receive 16 16 16 16 16 16 GOOSEDPRCV GOOSE function block to receive a double point value 64 64 64 64 64 64 GOOSEINTRCV GOOSE function bl...

Page 50: ...ts 0 1 1 P30 1 P30 1 P30 1 P30 1 P30 ACTIVLOG Activity logging 1 1 1 1 1 1 ALTRK Service tracking 1 1 1 1 1 1 PRP IEC 62439 3 Parallel redundancy protocol 0 1 1 P23 1 P23 1 P23 1 P23 1 P23 HSR IEC 62439 3 High availability seamless redundancy 0 1 1 P24 1 P24 1 P24 1 P24 1 P24 PTP Precision time protocol 1 1 1 1 1 1 SCHLCCH Access point diagnostic for non redundant Ethernet port 6 6 6 6 6 6 RCHLCCH...

Page 51: ...ignal 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 AUTHMAN Authority management FTPACCS FTP access with password GBASVAL Global base values for settings ALTMS Time master supervision ALTIM Time management COMSTATUS Protocol diagnostic Table 8 Local HMI function...

Page 52: ...ndication part for LHMI OPENCLOSE_LED LHMI LEDs for open and close keys GRP1_LED1 GRP1_LED15 GRP2_LED1 GRP2_LED15 GRP3_LED1 GRP3_LED15 Basic part for CP HW LED indication module Section 2 1MRK 505 370 UEN D Application 46 Busbar protection REB670 Application manual ...

Page 53: ... this configuration by the signal matrix tool to be used as direct replacement of RED521 terminals This configuration is available for all five REB670 variants that is A20 A31 B20 B21 B31 It shall be noted that optional functions breaker failure protection CCRBRF end fault protection and overcurrent protection PH4SPTOC can be ordered together with this configuration but they will not be pre config...

Page 54: ... OC4 PTOC 51_67 4 3I CC RBRF 50BF 3I BF SMB RREC 79 5 0 1 BZIT GGIO 87B 3Id I BCZT PDIF 87B 3Id I Other Functions available from the function library BDC GAPC 87B QB1 DRP RDRE DFR SER DR C MMXU MET I C MMXU MET I Q CBAY Control C MSQI MET Isqi VN MMXU MET UN S SIML 71 S SIMG 63 S XCBR 3 Control S SCBR Control V MMXU MET U V MSQI MET Usqi ETP MMTR MET W Varh IEC16000254 2 en vsd CV MMXN MET P Q DEL...

Page 55: ...SQI MET Isqi C MMXU MET I C MMXU MET I Optional Functions OC4 PTOC 51_67 4 3I CC RBRF 50BF 3I BF SMB RREC 79 5 0 1 Other Functions available from the function library BDC GAPC 87B Q CBAY Control C MSQI MET Isqi VN MMXU MET UN S SIML 71 S SIMG 63 S XCBR 3 Control S SCBR Control V MMXU MET U V MSQI MET Usqi ETP MMTR MET W Varh CV MMXN MET P Q IEC16000255 2 en vsd DELI SPVC 7I DELTAI DELV SPVC 7V_78V...

Page 56: ...9 5 0 1 Other Functions available from the function library BDC GAPC 87B With Just one CT in the Bus Section Bay QB1 QB2 QA1 BCZT PDIF 87B 3Id I BZIT GGIO 87B 3Id I DRP RDRE DFR SER DR C MMXU MET I C MSQI MET Isqi C MMXU MET I C MSQI MET Isqi C MMXU MET I C MSQI MET Isqi DELI SPVC 7I DELTAI DELV SPVC 7V_78V DELTAU DEL SPVC 7 DELTA CHM MHAI ITHD ITHD VHM MHAI VTHD UTHD GUID 1264BCF9 F245 423C B620 ...

Page 57: ...1_67 4 3I CC RBRF 50BF 3I BF SMB RREC 79 5 0 1 Other Functions available from the function library BDC GAPC 87B BUT PTRC 87B 3Id I With Just one CT in the Bus Section Bay DRP RDRE DFR SER DR C MMXU MET I C MMXU MET I C MMXU MET I Q CBAY Control C MSQI MET Isqi VN MMXU MET UN S SIML 71 S SIMG 63 S XCBR 3 Control S SCBR Control V MMXU MET U V MSQI MET Usqi ETP MMTR MET W Varh CV MMXN MET P Q IEC1600...

Page 58: ...MSQI MET Usqi ETP MMTR MET W Varh CV MMXN MET P Q DELI SPVC 7I DELTAI DELV SPVC 7V_78V DELTAU DEL SPVC 7 DELTA CHM MHAI ITHD ITHD VHM MHAI VTHD UTHD 1EC16000257 IEC16000257 2 en us Original vsd IEC16000257 V2 EN US Figure 7 Configuration diagram for A31 configuration X03 3 1 7 Description of 1 ph packages B20 and B21 SEMOD129275 40 v8 One phase version of the IED with two low impedance differentia...

Page 59: ...nction library BDC GAPC 87B VERSION OF REB670 NUMBER OF FEDERS IN BOTH BUSBAR SECTIONS REB670 B20 X01 1 Phase 12 Bays 2 Zones for Simple Station Layout 12 AI 12 REB670 B21 X01 1 Phase 12 Bays 2 Zones for Simple Station Layout 12 AI 12 NUMBER OF REB670 REQUIRED BY THE SCHEME 3 3 REB670 B31 X01 1 Phase 24 Bays 2 Zones for Simple Station Layout 24 AI 24 3 QB1 C MMXU MET I DRP RDRE DFR SER DR IEC13000...

Page 60: ... RBRF 50BF I BF SMB RREC 79 5 0 1 Other Functions available from the function library BDC GAPC 87B Q CBAY Control C MSQI MET Isqi VN MMXU MET UN S SIML 71 S SIMG 63 S XCBR 3 Control S SCBR Control V MMXU MET U V MSQI MET Usqi ETP MMTR MET W Varh CV MMXN MET P Q DELI SPVC 7I DELTAI DELV SPVC 7V_78V DELTAU DEL SPVC 7 DELTA CHM MHAI ITHD ITHD VHM MHAI VTHD UTHD IEC13000224 V3 EN US Figure 9 Configura...

Page 61: ...2 Zones for Simple Station Layout 12 AI 22 With Just one CT in the Bus Section Bay NUMBER OF REB670 REQUIRED BY THE SCHEME 6 6 REB670 B31 X01 1 Phase 24 Bays 2 Zones for Simple Station Layout 24 AI 46 6 QB1 QB2 QA1 BCZS PDIF 87B Id I BZIS GGIO 87B Id I C MMXU MET I DRP RDRE DFR SER DR BCZS PDIF 87B Id I BZIS GGIO 87B Id I C MMXU MET I DRP RDRE DFR SER DR BUS PTRC 87B Id I BUS PTRC 87B Id I IEC1300...

Page 62: ...nes for Double Busbar Station 24AI 23 3 BUS PTRC 87B Id I BUS PTRC 87B Id I C MMXU MET I DRP RDRE DFR SER DR C MMXU MET I C MMXU MET I IEC13000226 3 en vsd Optional Functions PH4S PTOC 51 I CCS RBRF 50BF I BF SMB RREC 79 5 0 1 Other Functions available from the function library BDC GAPC 87B Q CBAY Control C MSQI MET Isqi S SIML 71 S SIMG 63 S XCBR 3 Control S SCBR Control V MMXU MET U V MSQI MET U...

Page 63: ...tection 12AI 11 With Just one CT in the Bus Section Bay NUMBER OF REB670 REQUIRED BY THE SCHEME 3 REB670 B31 X03 1 Phase 24 Bays 2 Zones for Double Busbar Station with Breaker Failure and End Fault Protection 24AI 23 3 DRP RDRE DFR SER DR C MMXU MET I C MMXU MET I C MMXU MET I IEC13000227 3 en vsd NUMBER OF FEEDERS IN THE STATION EXCLUDING BUS COUPLER BAY Optional Functions SMB RREC 79 5 0 1 Other...

Page 64: ...58 ...

Page 65: ... commissioning of the IED the reference channel can be changed to facilitate testing and service values reading The IED has the ability to receive analog values from primary equipment that are sampled by Merging units MU connected to a process bus via the IEC 61850 9 2 LE protocol The availability of VT inputs depends on the ordered transformer input module TRM type 4 2 Setting guidelines SEMOD550...

Page 66: ...e direction out from the object is defined as Reverse See Figure 13 A positive value of current power and so on forward means that the quantity flows towards the object A negative value of current power and so on reverse means that the quantity flows away from the object See Figure 13 Protected Object Line transformer etc Forward Reverse Definition of direction for directional functions Measured q...

Page 67: ...g is FromObject IEC05000753 IEC05 000753 1 en Origin al 1 vsd Is Is Ip Ip Ip IED IED IEC05000753 V2 EN US Figure 14 Example how to set CTStarPoint parameters in the IED Figure 14 shows the normal case where the objects have their own CTs The settings for CT direction shall be done according to the figure To protect the line direction of the directional functions of the line protection shall be set...

Page 68: ...IEC05000460 V2 EN US Figure 15 Example how to set CTStarPoint parameters in the IED This example is similar to example 1 but here the transformer is feeding just one line and the line protection uses the same CT as the transformer protection does The CT direction is set with different reference objects for the two IEDs though it is the same current from the same CT that is feeding the two IEDs Wit...

Page 69: ...et to Reverse The direction Forward Reverse is related to the reference object that is the transformer in this case When a function is set to Reverse and shall protect an object in reverse direction it shall be noted that some directional functions are not symmetrical regarding the reach in forward and reverse direction It is in first hand the reach of the directional criteria that can differ Norm...

Page 70: ...ctions Setting of current input for transformer functions Set parameter CTStarPoint with Transformer as reference object Correct setting is ToObject Setting of current input for line functions Set parameter CTStarPoint with Line as reference object Correct setting is FromObject IED IEC05000462 V2 EN US Figure 17 Example how to set CTStarPoint parameters in the IED Section 4 1MRK 505 370 UEN D Anal...

Page 71: ...second solution will be to use all connected bays as reference objects In that case for all CT inputs marked with 1 in Figure 18 set CTStarPoint FromObject and for all CT inputs marked with 2 in Figure 18 set CTStarPoint ToObject Regardless which one of the above two options is selected busbar differential protection will behave correctly The main CT ratios must also be set This is done by setting...

Page 72: ...ked with a square indicates the primary and secondary winding terminals with the same that is positive polarity b and c are equivalent symbols and terminal marking used by IEC ANSI standard for CTs Note that for these two cases the CT polarity marking is correct It shall be noted that depending on national standard and utility practices the rated secondary current of a CT has typically one of the ...

Page 73: ...000002 V4 EN US Figure 20 Star connected three phase CT set with star point towards the protected object Where 1 The drawing shows how to connect three individual phase currents from a star connected three phase CT set to the three CT inputs of the IED 2 The current inputs are located in the TRM It shall be noted that for all these current inputs the following setting values shall be entered for t...

Page 74: ... block is a grouped signal which contains all the data about the phases L1 L2 L3 and neutral quantity in particular the data about fundamental frequency phasors harmonic content and positive sequence negative and zero sequence quantities are available AI1 AI2 AI3 AI4 are the output signals from the SMAI function block which contain the fundamental frequency phasors and the harmonic content of the ...

Page 75: ...ED Where 1 Shows how to connect three individual phase currents from a star connected three phase CT set to the three CT inputs of the IED 2 Shows how to connect residual neutral current from the three phase CT set to the fourth input in the IED It shall be noted that if this connection is not made the IED will still calculate this current internally by vectorial summation of the three individual ...

Page 76: ...sing the fundamental frequency phasors of the first three input channels channel one taken as reference for sequence quantities These calculated values are then available for all built in protection and control functions within the IED which are connected to this preprocessing function block in the configuration tool For this application most of the preprocessing settings can be left to the defaul...

Page 77: ...eed this current information more then one preprocessing block might be connected in parallel to these three CT inputs 4 is a Preprocessing block that has the task to digitally filter the connected analog inputs and calculate fundamental frequency phasors for all three input channels harmonic content for all three input channels positive negative and zero sequence quantities by using the fundament...

Page 78: ...ntered CTprim 800A CTsec 1A CTStarPoint ToObject ConnectionType Ph Ph It is important to notice the references in SMAI As inputs at Ph Ph are expected to be L1L2 L2L3 respectively L3L1 we need to tilt 180º by setting ToObject 4 2 2 7 Example how to connect single phase CT to the IED SEMOD55055 431 v8 Figure 25 gives an example how to connect the single phase CT to the IED It gives an overview of t...

Page 79: ...d this feature is typically required only for IEDs installed in the power plants then the setting parameters DFTReference shall be set accordingly 4 2 3 Relationships between setting parameter Base Current CT rated primary current and minimum pickup of a protection IED GUID 8EB19363 9178 4F04 A6AC AF0C2F99C5AB v1 Note that for all line protection applications e g distance protection or line differ...

Page 80: ...ll be individually verified for all current inputs involved in the protection scheme Note that exceptions from the above 4 rule may be acceptable for very special applications e g when Multipurpose filter SMAIHPAC is involved in the protection scheme 4 2 4 Setting of voltage channels SEMOD55055 44 v4 As the IED uses primary system quantities the main VT ratios must be known to the IED This is done...

Page 81: ...utility practices the rated secondary voltage of a VT has typically one of the following values 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 4 2 4 3 Examples on how to connect a three phase to earth connected VT to the IED SEMOD55055 87 v9 Figure 27 gives an example on how to connect a three phase to earth connect...

Page 82: ...4 AIN IEC06000599 V4 EN US Figure 27 A Three phase to earth connected VT L1 IED L2 132 2 110 2 kV V 1 3 2 132 2 110 2 kV V IEC16000140 1 en vsdx 4 SMAI2 BLOCK GRP2L1 GRP2L2 GRP2L1L2 GRP2N AI2P AI1 AI2 AI3 AI4 AIN 5 IEC16000140 V1 EN US Figure 28 A two phase to earth connected VT Section 4 1MRK 505 370 UEN D Analog inputs 76 Busbar protection REB670 Application manual ...

Page 83: ...task to digitally filter the connected analog inputs and calculate fundamental frequency phasors for all input channels harmonic content for all input channels positive negative and zero sequence quantities by using the fundamental frequency phasors for the first three input channels channel one taken as reference for sequence quantities These calculated values are then available for all built in ...

Page 84: ...input channel of the preprocessing block is not connected in SMT Note If the parameters UL1 UL2 UL3 UN should be used the open delta must be connected here 5 Preprocessing block has a task to digitally filter the connected analog inputs and calculate fundamental frequency phasors for all four input channels harmonic content for all four input channels positive negative and zero sequence quantities...

Page 85: ...gs gives a secondary voltage equal to three times the individual VT secondary winding rating Thus the secondary windings of open delta VTs quite often have a secondary rated voltage equal to one third of the rated phase to phase VT secondary voltage 110 3V in this particular example Figure 30 gives overview of required actions by the user in order to make this measurement available to the built in...

Page 86: ...annels harmonic content for all four input channels positive negative and zero sequence quantities by using the fundamental frequency phasors for the first three input channels channel one taken as reference for sequence quantities These calculated values are then available for all built in protection and control functions within the IED which are connected to this preprocessing function block in ...

Page 87: ...e that is 115V or 115 3V as in this particular example Figure 31 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 1 L1 IED L2 L3 138 3 115 3 kV V 3Uo 138 3 115 3 kV V 138 3 115 3 kV V IEC06000602 4 en vsdx Not Used Not Used Not Used SMAI2 BLOCK REVROT GRP2L1 GRP2L2 GRP2L3 GRP2N AI3P AI1 AI2 AI3 AI4 ...

Page 88: ...e fourth input channel of the preprocessing function block 4 5 preprocessing block has a task to digitally filter the connected analog inputs and calculate fundamental frequency phasors for all four input channels harmonic content for all four input channels positive negative and zero sequence quantities by using the fundamental frequency phasors for the first three input channels channel one take...

Page 89: ... Local human machine interface The LHMI of the IED contains the following elements Keypad Display LCD LED indicators Communication port for PCM600 The LHMI is used for setting monitoring and controlling 1MRK 505 370 UEN D Section 5 Local HMI Busbar protection REB670 83 Application manual ...

Page 90: ...is divided into four basic areas IEC15000270 1 en vsdx IEC15000270 V1 EN US Figure 33 Display layout 1 Path 2 Content 3 Status 4 Scroll bar appears when needed The function key button panel shows on request what actions are possible with the function buttons Each function button has a LED indication that can be used as a feedback signal for the function button control action The LED is connected t...

Page 91: ...ng the ESC button clears the panel from the display Both panels have a dynamic width that depends on the label string length 5 2 LEDs AMU0600427 v14 The LHMI includes three status LEDs above the display Ready Start and Trip There are 15 programmable indication LEDs on the front of the LHMI Each LED can indicate three states with the colors green yellow and red The texts related to each three color...

Page 92: ...s lit whenever any LED on any panel is lit If there are un acknowledged indication LEDs then the Multipage LED blinks To acknowledge LEDs press the Clear button to enter the Reset menu refer to description of this menu for details There are two additional LEDs which are next to the control buttons and These LEDs can indicate the status of two arbitrary binary signals by configuring the OPENCLOSE_L...

Page 93: ...ject control navigation and command push buttons and RJ 45 communication port 1 5 Function button 6 Close 7 Open 8 Escape 9 Left 10 Down 11 Up 12 Right 13 Key 14 Enter 15 Remote Local 16 Uplink LED 17 Not in use 18 Multipage 19 Menu 20 Clear 21 Help 1MRK 505 370 UEN D Section 5 Local HMI Busbar protection REB670 87 Application manual ...

Page 94: ...played The start indication is latching and must be reset via communication LHMI or binary input on the LEDGEN component To open the reset menu on the LHMI press Flashing The IED is in test mode and protection functions are blocked or the IEC61850 protocol is blocking one or more functions The indication disappears when the IED is no longer in test mode and blocking is removed The blocking of func...

Page 95: ...sequence The activation signal is on LatchedAck F S sequence The activation signal is on or it is off but the indication has not been acknowledged LatchedAck S F sequence The indication has been acknowledged but the activation signal is still on 5 4 2 Parameter management GUID 5EE466E3 932B 4311 9FE1 76ECD8D6E245 v9 The LHMI is used to access the relay parameters Three types of parameters can be r...

Page 96: ...work mask is 255 255 254 0 It can be set through the local HMI path Main menu Configuration Communication Ethernet configuration FRONT port AP_FRONT Ensure not to change the default IP address of the IED 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 Section 5 1MRK 505 3...

Page 97: ... 3Ph 4 8CT zone interconnection function BZITGGIO 3Id I SYMBOL JJ V1 EN US 87B GUID F771BD7B 53F1 437A A41C 7266323DC02F v1 Two zone busbar differential protections twelve or twenty four single phase CTs Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Busbar protection 2Z 1Ph 12 24CT differential protection function BZNSPDIF_x x A B Id I IEC1600...

Page 98: ...1 EN US 87B 6 1 2 Basic applications SEMOD127448 1 v1 6 1 2 1 General M12097 3 v3 Basic types of applications for REB670 IED are shown and described in this chapter For these applications usually three phase version of the IED with two differential zones and four or even eight 3 phase CT inputs is used 6 1 2 2 Meshed corner application and T connection application M12098 3 v4 The REB670 general di...

Page 99: ...lts can be equal to the stations maximum short circuit capacity Heavy CT saturation due to high DC components and or remanence at external faults must not lead to maloperation of the busbar differential protection The security against misoperation must be extremely high due to the heavy impact on the overall network service 2 Must have as short tripping time as possible in order to minimize the da...

Page 100: ...t cause the unwanted operation of the differential IED In order to obtain the required secondary CT current distribution the resistive burden in the individual CT secondary circuits must be kept below the pre calculated value in order to guaranty the stability of the IED In new numerical protection IEDs all CT and VT inputs are galvanically separated from each other All analog input quantities are...

Page 101: ...tivity is required Operation and operating characteristic of the sensitive differential protection can be set independently from the operating characteristic of the main differential protection The sensitive differential level is blocked as soon as the total incoming current exceeds the pre set level By appropriate setting then it can be insured that this sensitive level is blocked for external ph...

Page 102: ...high cost as separate CT cores are required but also a need for extra cabling and a separate check zone differential relay In REB670 an internal built in check zone in the IED is provided therefore there is no need for such costly external check zone This is possible mainly due to the following facts the CT switching is made only in software and CT secondary current circuits do not include any aux...

Page 103: ...Off nor it is out of service And the check zone supervises differential protection zones Exactly which differential protection zones shall be supervised by the operation of the check zone also varies depending on the version of the IED used In two zone busbar differential protections freely settable by using a setting CheckZoneSup at each zone function block In six zone busbar differential protect...

Page 104: ...iary contact indicates that primary device is open In protection literature it is called by different names as stated below Normally closed auxiliary contact b contact that is 52b open Typically both contacts are used to provide position indication and supervision for busbar protection SEMOD127523 18 v2 Minimum contact requirements The minimum requirement for the busbar replica is the record of th...

Page 105: ...above two schemes The maximum time allowed before an alarm is given can be set according to the disconnector timing Table 13 and the following two figures summarize the properties of these two schemes Table 13 Treatment of primary object auxiliary contact status within BBP in REB670 Primary equipment Status in busbar protection Alarm facility Normally Open auxiliary contact status closed or a cont...

Page 106: ...e again the CT current to the busbar protection zones in time It is as strongly recommended to always use Scheme1_RADSS for all CBs positions connected to the IED in order to minimize any risk of possible problems due to late inclusion of CT current to the relevant differential zones Line disconnector replica SEMOD127523 82 v4 The line disconnector position from a feeder bay might be required for ...

Page 107: ...based on operational status of related disconnectors In addition in two zone busbar differential protections a setting parameter is also introduced to determine together with the binary inputs how the bay CT current shall be connected to the differential zones The philosophy is to allow every CT input to be individually controlled by a setting parameter This parameter called ZoneSel can be individ...

Page 108: ...ue one and it will be included to the differential zone B when input signal CTRLZB on corresponding bay block is given logical value zero This setting is typically used for feeder bays in double busbar single breaker stations in order to form proper busbar disconnector replica It is especially suitable when only normally closed that is b contact auxiliary contact from the busbar disconnector s is ...

Page 109: ...mple application in Figure 46 showed for an internal fault in the blind spot the differential zone ZA will unnecessarily operate and open the bus section breaker and all other feeder breakers associated with it Nevertheless the fault will still exists on other busbar section but it is outside the current transformer in the bus section bay and hence outside the zone ZB that is it is external fault ...

Page 110: ...ckup OC Trip QB1 QB2 b BI1 2400 1 QA1 ZEROCUR BIM CB Closing Signal 1 t t 1s IEC06000155 V1 EN US Figure 47 Bus coupler bay with one CT and b aux contact only from CB This scheme will disconnect the section coupler CTs after a pre set time length 80 ms recommended defined by the parameter setting tZeroCurrent in the relevant bay function block from the moment of opening of the section coupler CB t...

Page 111: ...ll be closed Example of such logic is shown in Figure 49 for a two zone differential protection application en06000137 vsd QA1 Zone A Zone B ZI ACTIVE BOM BIM REB 670 Bus coupler EXTSTART ALARM Indication that Zone interconnection is active BC CB closing switch QB1 QB2 t tOFF 1 0s 1 IEC06000137 V1 EN US Figure 49 Configuration logic for bus coupler without main CTs 6 1 3 7 End fault protection SEM...

Page 112: ...lt between CT and CB will cause certain problems Typically such fault will be detected and tripped by busbar protection However to completely clear such fault the remote feeder end CB must be tripped as well It shall be noted that for the feeder protection such fault will be either a reverse fault that is distance protection used for feeder protection or external fault that is line transformer dif...

Page 113: ...ime delay either by operation of local backup protection that is feeder circuit breaker failure protection or by operation of remote backup protection that is remote ends zone 2 distance protection However the overall busbar protection behavior can be improved for primary faults within end fault regions when feeder breaker is open Under such circumstances the following actions can be taken For fee...

Page 114: ...he feeder bay busbar disconnector originally closed The load is now transferred from one to other bus opening of bus coupler or bus section bay CB The zone interconnection has to be taken into consideration for the busbar differential protection scheme as each two busbar zones are interconnected together via two disconnectors The primary current split between busbars is then not known and the two ...

Page 115: ... for all feeders bay in double busbar stations With this setting all feeder bays which were not connected to any of the two zones before the zone interconnection activation that is out for scheduled maintenance will not either be included during zone interconnection This practically means that for double busbar station when zone switching feature is active all feeder bays will be connected to both...

Page 116: ... failure function will be started in the same phase only In order to secure internal breaker failure starting in all three phases it is advisable to do the following Connect a zone say Zone A trip signal from one IED to the external trip input of the Zone A in the other two IEDs Thus all three IEDs will then issue trip in Zone A and start internally circuit breaker failure protection in all three ...

Page 117: ...cts are sufficient M12118 4 v4 Decentralized trip arrangement Tripping is performed directly from the IED contacts which then activate dedicated auxiliary trip unit per bay This individual auxiliary trip unit can be mounted either in the busbar protection cubicle or in the individual bay cubicles This tripping setup is suitable when individual circuit breaker failure relays exist in all bays A sui...

Page 118: ...cularly occur during site testing In this case it is recommended to use COMBIFLEX RXMH 2 or RXMVB 2 heavy duty relays 6 1 3 12 Trip circuit supervision M12121 3 v3 M12121 4 v3 Trip circuit supervision is mostly required to supervise the trip circuit from the individual bay IED panel to the circuit breaker It can be arranged also for the tripping circuits from the busbar protection However it can b...

Page 119: ... to split the station into two separate buses However switching of the sectionalizing disconnector has to be done without any load This means that one of the two busbars has to be de energized before any opening or closing of the sectionalizer For this case the protection scheme must have two differential zones which can be either split to work independently from each other or switched to one over...

Page 120: ...the operator to split the station into two separate buses under full load The requirement for busbar protection scheme is that the scheme must have two independent differential zones one for each busbar section If there is an internal fault on one of the two sections bus section circuit breaker and all feeder circuit breakers associated with this section have to be tripped leaving the other busbar...

Page 121: ...e 56 These arrangements are very similar to the single busbar station with sectionalizer or bus section breaker but are characterized by very limited number of feeder bays connected to the station normally only two OHL and two transformers 01 02 04 BS 03 ZA ZB xx06000121 vsd IEC06000121 V1 EN US Figure 56 Example of H type station The requirement for the busbar protection scheme for this type of s...

Page 122: ...I1 BI2 QA2 QA1 BI1 BI2 QA2 QA1 BI1 BI2 QA2 ZA ZB xx06000018 vsd IEC06000018 V1 EN US Figure 57 Example of double breaker station This is an extremely flexible solution In normal service all breakers are closed The requirement for busbar protection scheme is that the scheme must have two independent differential zones one for each busbar If there is an internal fault on one of the two buses all cir...

Page 123: ... BI2 1500 1 Zone B Other Equipment Other Equipment CT Input Zone A A D A D QA2 Internal BFP Backup Trip Command BBP BFP TRIP QA1 BBP BFP TRIP QA2 OR BFP Remote Feeder End Inter Trip Feeder Parameter ZoneSel must be set to FixedToZB Parameter ZoneSel must be set to FixedToZA IEC06000148 V1 EN US Figure 58 Feeder bay in double bus double breaker station 6 1 4 7 One and half circuit breaker M6646 3 v...

Page 124: ... very easily protected The most common setups for this type of station are described in the following table Table 19 Typical solutions for one and half circuit breaker stations when CBF for middle breaker is not required Version of REB670 IED Number of diameters in the station Number of REB670 IEDs required for the scheme 3PH 2 zones 4 bays BBP A20 2 4 1 2 3PH 2 zones 8 bays BBP A31 4 8 1 2 1Ph 2 ...

Page 125: ...n one and half breaker station with breaker failure protection for all three breakers inside REB670 6 1 4 8 Double busbar single breaker arrangement M6647 3 v5 This type of arrangement is shown in Figure 61 BI1 QA1 QB1 QB2 BI1 QA1 QB1 QB2 BI1 QA1 QB1 QB2 BI1 QA1 QB1 QB2 BI1 QA1 QB1 QB2 BI1 QA1 BI1 QB1 QB2 QA1 ZA ZB IEC11000239 1 en vsd IEC11000239 V1 EN US Figure 61 Example of double busbar statio...

Page 126: ...s BBP B20 NA NA 1Ph 2 zones 12 bays BBP B21 11 3 1Ph 2 zones 24 bays BBP B31 23 3 with just one CT input from bus coupler bay Please note that Table 20 is given for the preconfigured versions of REB670 which do not contain any VT inputs For station with just one CT in the bus coupler bay it might be required depending on the client requirements to provide the special scheme for disconnection of bu...

Page 127: ...NC CLOSED OPEN ALARM FORCED SSxx DISABLE BBP BFP trip command to feeder breaker BIM BOM Set Parameter ZoneSel CtrlIncludes TRM External or Internal Feeder BFP Backup Trip Command Feeder Backup OC Trip Disconnector aux contact timing Aux contact a timing is only crucial when Scheme2_INX is used QB2 QB1 QB9 QA1 IEC06000151 V1 EN US Figure 62 Feeder bay where a b aux contacts are used 1MRK 505 370 UE...

Page 128: ... BOM Main contact Open Closed Set Parameter ZoneSel CtrlExcludes Feeder Bay Other Equipment A D TRM Feeder Backup OC Trip Disconnector aux contact timing QB9 QB1 QB2 QA1 External or Internal Feeder BFP Backup Trip Command IEC06000152 V1 EN US Figure 63 Feeder bay where b aux contacts are used Section 6 1MRK 505 370 UEN D Differential protection 122 Busbar protection REB670 Application manual ...

Page 129: ...A CONNZB Bxxx I3PB1 BLKTR TRZONE TRBAY Parameter ZoneSel must be set to FixedToZA OR Other Equipment Other Equipment CT Input TRM Bus Coupler Backup OC Trip QB2 QA1 External or Internal Bus Coupler BFP Backup Trip Command Parameter ZoneSel must be set to FixedToZB IEC06000153 V1 EN US Figure 64 Bus coupler bay with two sets of CTs 1MRK 505 370 UEN D Section 6 Differential protection Busbar protect...

Page 130: ...EN US Figure 65 Bus coupler bay with one CT and a b aux contact from CB en06000155 vsd Zone A Zone B Bus Coupler Bay REB 670 CTRLZA CTRLZB TRIP CONNZA CONNZB Bxxx I3PB1 BLKTR TRZONE TRBAY BBP BFP trip command to Bus Coupler breaker BOM A D Parameter ZoneSel must be set to FixedToZA ZB tZeroCurrent 150ms Other Equipment CT Input TRM External or Internal Bus Coupler BFP Backup Trip Command Bus Coupl...

Page 131: ...heme 3PH 2 zones 4 bays BBP A20 NA NA 3PH 2 zones 8 bays BBP A31 5 2 1Ph 2 zones 12 bays BBP B20 NA NA 1Ph 2 zones 12 bays BBP B21 9 6 1Ph 2 zones 24 bays BBP B31 21 6 with just one CT input from bus coupler bay Please note that Table 21 is given for the preconfigured versions of REB670 which do not contain any VT inputs Provision for zone selection disconnector replica and zone interconnection ha...

Page 132: ...QB2 ZA ZB QA1 BI1 BI2 QA2 IEC06000124 V1 EN US Figure 69 Combination between double breaker and double busbar station layouts In this type of arrangement the double breaker bay has in the same time the role of the bus coupler bay for normal double busbar single breaker stations Therefore zone interconnection zone selection and disconnector replica facilities have to be provided for all double busb...

Page 133: ... QA1 QB1 QB2 IEC06000125 V1 EN US Figure 70 Combination between one and half breaker and double busbar station layouts For this type of busbar arrangement the double busbar bay is usually connected to the reactive power compensation equipment that is shunt reactor or shunt capacitor The diameters in the one and half breaker part of the station have at the same time the role of the bus coupler bay ...

Page 134: ...l zones are presented in Figure 71 Figure 75 In the next section the engineering procedure is described for the example application shown in Figure 74 to illustrate the engineering principles Z1 Z2 Z5 Z6 QB1 Z3 Z4 QA1 B11 B11 QA1 B12 B14 B13 B11 QA1 QA1 QA1 Feeder 01 08 Bus Interconnector 1 with two CTs Bus Interconnector 2 with one CT Bus Interconnector 3 with one CT Feeder 09 15 QB11 QB21 QB2 QB...

Page 135: ...CT1 QB2 QB3 QB7 BU1 Z1 Z2 Z3 Z4 Feeder 01 07 Feeder 08 20 IEC16000146 1 en vsdx IEC16000146 V1 EN US Figure 75 Triple busbar station with transfer bus and four protection zones 6 1 5 3 Example engineering procedure GUID 8E5A800E F88D 4C93 B837 78D257774D3B v1 The procedure for how to engineer the triple busbar station with two sections and six protection zones see Figure 74 will be presented here ...

Page 136: ...utput from BFPTRC_Fxx function block to the binary output contact alternatively the tripping can also be arranged using GOOSE communication This will ensure proper tripping of this feeder bay for any relevant operation of the BBP including BFP tripping ACT configuration example for Feeder 01 located at Section 1 is given in Figure 76 Any other feeders located at Section 1 shall be engineered in th...

Page 137: ...erconnector function block BICPTRC_xx This will ensure proper dynamic inclusion of the CT measurements from the two CTs located within the bus section bay towards the differential protection zones 4 Connect the two currents from the TRM via pre processing blocks to the bus interconnector function block BICPTRC_xx Ensure overlapping of the two CTs In case that only one CT is available connect this ...

Page 138: ...ctor primary contacts 3 Connect the close status output from BDCGAPC function block to the respective zone control input on the bus interconnector function block BICPTRC_xx This will ensure proper dynamic inclusion of the CT measurements from the two CTs located within the bus section bay towards the differential protection zones 4 Connect the two currents from the TRM via pre processing blocks to...

Page 139: ...wing steps need to be done 1 Connect the two auxiliary contacts i e normally open and normally closed auxiliary contacts or also sometimes called a b contacts from each of the three sectionalizing disconnectors to the IED This can be done by wiring using binary inputs or via communication e g via GOOSE or via LDCM 2 Use three BDCGAPC function blocks i e one per busbar disconnector to derive open o...

Page 140: ...e are shown in Figure 81 Auxiliary Summation CT type SLCE 8 1 1A 2 1A or 5 1A Three one phase REB670 Single one phase REB670 Up to 18 pcs auxiliary CTs One SLCE 8 per main CT REB670 with 1A CT inputs REB670 REB670 REB670 IEC06000126_2_en vsd IEC06000126 V2 EN US Figure 81 Difference between phase segregated summation type differential protection In the full phase segregated design three one phase ...

Page 141: ...s differential protection still has the same main CT requirements as outlined in section Rated equivalent secondary e m f requirements Some of these are main CT ratio differences can be tolerated up to 10 1 for example 3000 5A CT can be balanced against CT s as low as 300 5 different main CT ratios are compensated numerically by a parameter setting main CT shall not saturate quicker than 2 ms refe...

Page 142: ...indings and one secondary winding In further text turn numbers of these windings will be marked with N1 N2 N3 N4 respectively see Figure 83 for more information There are three types of ASCT for REB670 1 ASCT type with ratio 1 1A for balanced 3 Ph current input shall be used with all main current transformers with 1A rated secondary current that is 2000 1A 2 ASCT type with ratio 5 1A for balanced ...

Page 143: ...in the same protection cubicle 6 1 6 3 Possible ASCT connections for REB670 M12137 3 v4 It is possible to connect the ASCTs for summated bus differential protection with REB670 at the end of the main CT circuit for example beyond the other protective relays as shown in Figure 84 in series with other secondary equipment when some other relay must be located at the end of the main CT circuit as show...

Page 144: ...e rated secondary current of the main CT Refer to section SLCE 8 ASCT characteristics for end connection for detailed ASCT current calculations for end connection Typical series connection with ASCT is shown in Figure 85 Other relays IL1 IL2 IL3 en06000129 vsd IL3 Auxiliary Summation CT type SLCE 8 1 1 or 5 1A or 2 1A N4 S1 S2 A103 X401 5 6 REB 670 with 1A CTs L3 L2 L1 N IL1 IN IN Main CT 2000 1A ...

Page 145: ...he actual primary start value Table 24 Start coefficients for Summated Differential Protection Type of fault L1 Gnd L2 Gnd L3 Gnd L1 L2 L2 L3 L3 L1 L1L2L3 ASCT end connected 0 434 0 578 0 867 1 732 1 732 0 867 1 0 ASCT series connected 1 732 0 867 0 578 1 732 1 732 0 867 1 0 The coefficients in Table 24 are only relevant for ideal internal faults that is load currents do not exist in the healthy p...

Page 146: ... different start level depending on the type of fault and involved phase s See Table 24 for more info Thus it will be very difficult to insure proper start and time grading with downstream overcurrent protection relays Hence it will be quite difficult to use OC4PTOC PHS4PTOC as backup feeder protection with summation design OC4PTOC PHS4PTOC function End Fault Protection feature will be connected t...

Page 147: ...ro sequence current components and individual phase current quantities is shown in Equation 16 IL1 IL2 IL3 1 1 1 a 2 a 1 a a 2 1 I1 I2 I0 EQUATION1111 V1 EN US Equation 16 where a complex constant that is a 0 5 j0 866 By including Equation 13 Equation 14 Equation 15 and Equation 16 into the Equation 12 the equation for the end connected ASCT secondary current that is summated current can be derive...

Page 148: ...o sequence current components and individual phase current quantities is shown in Equation 22 IL1 IL2 IL3 1 1 1 a 2 a 1 a a 2 1 I1 I2 I0 EQUATION1111 V1 EN US Equation 22 where a is complex constant that is a 0 5 j0 866 By including Equation 19 Equation 20 Equation 21 and Equation 22 into the Equation 18 the equation for the series connected ASCT secondary current that is summated current can be d...

Page 149: ...p to four different individually settable steps The following options are possible Non directional Directional function In most applications the non directional functionality is used This is mostly the case when no fault current can be fed from the protected object itself In order to achieve both selectivity and fast fault clearance the directional function can be necessary If VT inputs are not av...

Page 150: ...sible to make a choice how many phases at minimum that have to have current above the pick up level to enable operation If set 1 of 3 it is sufficient to have high current in one phase only If set 2 of 3 or 3 of 3 single phase earth faults are not detected 7 1 3 Setting guidelines IP14982 1 v1 M12982 4 v14 When inverse time overcurrent characteristic is selected the operate time of the stage will ...

Page 151: ... 4 IEC09000636 V2 EN US Figure 86 Directional function characteristic 1 RCA Relay characteristic angle 2 ROA Relay operating angle 3 Reverse 4 Forward 7 1 3 1 Settings for each step M12982 19 v10 x means step 1 2 3 and 4 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...

Page 152: ...inverse time characteristic is selected Note that the value set is the time between activation of the start and the trip outputs kx Time multiplier for inverse time delay for step x IMinx Minimum operate current in of IB for all inverse time characteristics below which no operation takes place IMinx Minimum operate current for step x in of IBase Set IMinx below Ix for every step to achieve ANSI re...

Page 153: ...elay time setting instantaneous 1 and IEC 2 set constant time reset For ANSI inverse time characteristics all three types of reset time characteristics are available instantaneous 1 IEC 2 set constant time reset and ANSI 3 current dependent reset time For IEC inverse time characteristics the possible delay time settings are instantaneous 1 and IEC 2 set constant time reset For the customer tailor ...

Page 154: ...ation where the protection is used A general description is given below The operating current setting of the inverse time protection or the lowest current step of the definite time protection must be defined so that the highest possible load current does not cause protection operation The protection reset current must also be considered so that a short peak of overcurrent does not cause the operat...

Page 155: ...se the highest pickup current setting can be written according to Equation 26 Ipu 0 7 Iscmin EQUATION1263 V2 EN US Equation 26 where 0 7 is a safety factor Iscmin is the smallest fault current to be detected by the overcurrent protection As a summary the operating current shall be chosen within the interval stated in Equation 27 Imax 1 2 Ipu 0 7 Iscmin k EQUATION1264 V2 EN US Equation 27 The high ...

Page 156: ...s 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 Selectivity is assured if the time difference between the curves is larger than a critical time difference Time current curves Fault Current 10 10 0 01 10000 en05000204 ai Str tfunc1 n n tfunc2 Trip time n IEC05000204 V2 EN US Figure 89 Fault time with...

Page 157: ...000205 2 en Original vsd Fault t t4 Protection A1 resets t t1 B1 and A1 start IEC05000205 V2 EN US Figure 90 Sequence of events during fault where t 0 is when the fault occurs t t1 is when protection IED B1 and protection IED A1 start t t2 is when the trip signal from the overcurrent protection at IED B1 is sent to the circuit breaker t t3 is when the circuit breaker at IED B1 opens The circuit br...

Page 158: ...of equipment connected to the power system such as shunt capacitor banks shunt reactors motors and others Back up short circuit protection of power generators The single phase overcurrent protection is used in IEDs having only input from one phase for example busbar protection for large busbars with many bays In many applications several steps with different current pick up levels and time delays ...

Page 159: ... harmonic current reaches a value above a set percentage of the fundamental current 7 2 3 Setting guidelines SEMOD127939 1 v1 SEMOD127941 4 v4 A typical starting time delay of 24ms is subtracted from the set trip time delay so that the resulting trip time will take the internal IED start time into consideration The parameters for the four step phase overcurrent protection function OC are set via t...

Page 160: ... of the start and the trip outputs kx Time multiplier for the dependent inverse characteristic InxMult Multiplier for scaling of the current setting value If a binary input signal enableMultiplier is activated the current operation level is increase by this setting constant Setting range 1 0 10 0 txMin Minimum operation time for IEC inverse time characteristics At high currents the inverse time ch...

Page 161: ...N1261 V2 EN US Equation 30 For more information please refer to the Technical reference manual tPRCrvx tTRCrvx tCRCrvx Parameters for customer creation of inverse reset time characteristic curve Reset Curve type 3 Further description can be found in the Technical reference manual 7 2 3 2 Second harmonic restrain SEMOD127941 90 v1 If a power transformer is energized there is a risk that the transfo...

Page 162: ...he resetting ratio of the protection and Imax is the maximum load current The maximum load current on the line has to be estimated From operation statistics the load current up to the present situation can be found The current setting must be valid also for some years ahead It is in most cases realistic that the setting values are updated not more often than once every five years In many cases thi...

Page 163: ...C component of the short circuit current The lowest current setting of the most rapid stage of the phase overcurrent protection can be written according to max 1 2 t sc high I k I EQUATION1265 V1 EN US Equation 34 where 1 2 is a safety factor kt is a factor that takes care of the transient overreach due to the DC component of the fault current and can be considered to be less than 1 1 Iscmax is th...

Page 164: ...ing time and protection resetting time These time delays can vary significantly between different pieces of equipment The following time delays can be estimated protection operation time 15 60 ms protection resetting time 15 60 ms Breaker opening time 20 120 ms Example Assume two substations A and B directly connected to each other via one line as shown in the figure below We study a fault located...

Page 165: ...at IED A1 is selective to the overcurrent protection at IED B1 the minimum time difference must be larger that the time t3 There are uncertainties in the values of protection operation time breaker opening time and protection resetting time Therefor a safety margin has to be included With normal values the needed time difference can be calculated according to equation 35 40 100 40 40 220 t ms ms m...

Page 166: ...se primary voltage UBase and primary power SBase are set in global base values for settings function GBASVAL GlobalBaseSel Selects the global base value group used by the function to define IBase UBase and SBase Note that this function will only use IBase value SeqTypeUPol This is used to select the type of voltage polarising quantity i e Zero seq or Neg seq for direction detection SeqTypeIPol Thi...

Page 167: ...s definitely higher than 1 minimum 3U0 UPolMin setting as a verification RNPol XNPol The zero sequence source is set in primary ohms as base for the current polarizing The polarizing voltage is then achieved as 3I0 ZNpol The ZNpol can be defined as ZS1 ZS0 3 that is the earth return impedance of the source behind the protection The maximum earth fault current at the local source can be used to cal...

Page 168: ...sformers is in operation and the parallel transformer is switched in the asymmetric inrush current of the switched in transformer will cause partial saturation of the transformer already in service This is called transferred saturation The 2nd harmonic of the inrush currents of the two transformers will be in phase opposition The summation of the two currents will thus give a small 2nd harmonic cu...

Page 169: ... Time ActivationSOTF This setting will select the signal to activate SOTF function CB position open CB position closed CB close command StepForSOTF If this parameter is set on step 3 the step 3 start signal will be used as current set level If set on step 2 the step 2 start signal will be used as current set level HarmBlkSOTF This is used to On Off harmonic restrain during SOTF conditions tSOTF Ti...

Page 170: ... be changed if remote setting of operation current level INx is used The limits are used for decreasing the used range of the INx setting If INx is set outside INx Max and INx Min the closest of the limits to INx is used by the function If INx Max is smaller than INx Min the limits are swapped kx Time multiplier for the dependent inverse characteristic for step x IMinx Minimum operate current for ...

Page 171: ... è ø è ø p A t s B k i C in EQUATION1189 V1 EN US Equation 36 Further description can be found in the technical reference manual tPRCrvx tTRCrvx tCRCrvx Parameters for user programmable of inverse reset time characteristic curve Further description can be found in the technical reference manual 7 4 Four step directional negative phase sequence overcurrent protection NS4PTOC GUID E8CF8AA2 AF54 4FD1...

Page 172: ...ault protection in meshed and effectively earthed transmission systems The directional negative sequence overcurrent protection is also well suited to operate in teleprotection communication schemes which enables fast clearance of unsymmetrical faults on transmission lines The directional function uses the voltage polarizing quantity Choice of time characteristics There are several types of time c...

Page 173: ...SBase are set in global base values for settings function GBASVAL GlobalBaseSel Selects the global base value group used by the function to define IBase UBase and SBase Note that this function will only use IBase value GUID F7AA2194 4D1C 4475 8853 C7D064912614 v4 When inverse time overcurrent characteristic is selected the operate time of the stage will be the sum of the inverse time delay and the...

Page 174: ...eristic 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 IxMult Multiplier for scaling of the current setting value If a binary input signal ENMULTx is activated the current operation level is multiplied by this setting constant txMin Minimum operation time for inverse time characteristics At high currents the inv...

Page 175: ...us 1 IEC 2 set constant time reset and ANSI 3 current dependent reset time If the current dependent type is used settings pr tr and cr must be given tPCrvx tACrvx tBCrvx tCCrvx Parameters for programmable inverse time characteristic curve The time characteristic equation is according to equation 37 æ ö ç ç ç æ ö ç ç è ø è ø p A t s B k i C in EQUATION1189 V1 EN US Equation 37 Further description c...

Page 176: ...iven in 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 7 5 Thermal overload protection two time constants TRPTTR IP14513 1 v4 7 5 1 Identification M14877 1 v2 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Thermal overload prot...

Page 177: ...ated by the binary input signal COOLING This can be used for transformers where forced cooling can be taken out of operation for example at fan or pump faults The thermal overload protection estimates the internal heat content of the transformer temperature continuously This estimation is made by using a thermal model of the transformer which is based on current measurement If the heat content of ...

Page 178: ...rmal time constants for medium and large transformers according to IEC 60076 7 are about 2 5 hours for naturally cooled transformers and 1 5 hours for forced cooled transformers The time constant can be estimated from measurements of the oil temperature during a cooling sequence described in IEC 60076 7 It is assumed that the transformer is operated at a certain load level with a constant oil temp...

Page 179: ...rotected circuit transformer as long as the transformer temperature is high The signal is released when the estimated heat content is below the set value This temperature value should be chosen below the alarm temperature ResLo is set in of the trip heat content level ThetaInit Heat content before activation of the function This setting can be set a little below the alarm level If the transformer ...

Page 180: ...1 110 of IB1 Tau1High 125 of tC1 ILowTau1 90 of IB1 Tau1Low 75 of tC1 IHighTau2 110 of IB2 Tau2High 115 of tC2 ILowTau2 90 of IB2 Tau2Low 85 of tC2 ITrip 120 of IBx ThetaInit 50 ResLo 60 of Itr As the cooling system is ON IBase2 is selected as the base current and Tau2 setting is selected as the time constant For example the largest phase load current is taken as 1800 A then 2 1800 1 2677685 95 1 ...

Page 181: ...1850 identification IEC 60617 identification ANSI IEEE C37 2 device number Breaker failure protection 3 phase activation and output CCRBRF 3I BF SYMBOL U V1 EN US 50BF 7 6 2 Application M13916 3 v8 In the design of the fault clearance system the N 1 criterion is often used This means that a fault needs to be cleared even if any component in the fault clearance system is faulty One necessary compon...

Page 182: ... command shall be given out from the function Timers cannot be stopped by removing the external START signal Function can be started again only when all of the following three timers t1 t2 and fixed timer of 150ms in function internal design has expired and the measurement criterion defined by parameter FunctionMode has deactivated see Figure 99 Note that this option corresponds to the function be...

Page 183: ... Current Check CB Position Check AND t t1 t t1 t t2 t t2 TRRET TRBU OR OR OR AND IEC18001003 1 en vsdx IEC18001003 V1 EN US Figure 100 Simplified overall logic for FollowStart OR START Current Check CB Position Check AND t t1 t t2 TRRET TRBU IEC18001004 1 en vsdx IEC18001004 V1 EN US Figure 101 Simplified overall logic for FollowStart Mode RetripMode This setting defines how the re trip function s...

Page 184: ...er 1A or 5A depending on the ordered IED I BlkCBPos If the FunctionMode is set to Current or CB pos breaker failure for high current faults are safely detected by the current measurement function To increase security for low currents the contact based function will be enabled only if the current at the moment of starting is below this set level The setting can be given within the range 5 200 of IB...

Page 185: ...ing is 90 150 ms Note that for a protected object which are always tripped three phase e g transformers generators reactors cables etc this timer shall always be set to the same value as t2 timer t3 Additional time delay to t2 for a second backup trip TRBU2 In some applications there might be a requirement to have separated backup trip functions tripping different backup circuit breakers tCBAlarm ...

Page 186: ... set level t1 and t2 or t2MPh and 150ms expires and current is below set level 3 LatchedStart Always external START always be given current is above set level t1 and t2 or t2MPh and 150ms expires and current is below set level 4 FollowStart Off external START never be given current is above set level external START disappears 5 FollowStart UseFunction Mode external START be given if current is abo...

Page 187: ...has logical value one CBCLDLx input has logical value one external START disappears 15 FollowStart Always external START if external START is present CBCLDLx input has logical value one external START disappears 16 FollowStart Mode Off external START and CBCLDLx input has logical value one never be given be given if CBCLDLx input has logical value one and external START is present CBCLDLx input ha...

Page 188: ...lways be given current is above set level and higher than I BlkCBPos or CBCLDLx input has logical value one when current is smaller than I BlkCBPos t1 and t2 or t2MPh and 150ms expires and current is below set level or CBCLDLx input has logical value zero 22 FollowStart Off external START never be given current is above set level and higher than I BlkCBPos or CBCLDLx input has logical value one wh...

Page 189: ...ler than I BlkCBPos current is below set level or external START disappears Set level depends on selected BuTripMode that is set level can be either IPh or IN or both 7 7 Breaker failure protection single phase version CCSRBRF SEMOD127864 1 v2 7 7 1 Identification SEMOD127866 2 v2 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Breaker failure p...

Page 190: ...terion defined by parameter FunctionMode will be always checked in order to verify if the appropriate command shall be given out from the function Timers cannot be stopped by removing the external START signal Function can be started again only when all of the following three timers t1 t2 and fixed timer of 150ms in function internal design has expired and the measurement criterion defined by para...

Page 191: ...ied overall logic for LatchedStart OR OR START Current Check CB Position Check AND t t1 t t1 t t2 t t2 TRRET TRBU OR OR OR AND IEC18001003 1 en vsdx IEC18001003 V1 EN US Figure 104 Simplified overall logic for FollowStart OR START Current Check CB Position Check AND t t1 t t2 TRRET TRBU IEC18001004 1 en vsdx IEC18001004 V1 EN US Figure 105 Simplified overall logic for FollowStart Mode RetripMode T...

Page 192: ...y the current measurement function To increase security for low currents the contact based function will be enabled only if the current at the moment of starting is below this set level The setting can be given within the range 5 200 of IBase It is strongly recommended to set this level above IPh set level t1 Time delay of the retrip The setting can be given within the range 0 60s in steps of 0 00...

Page 193: ...air the circuit breaker The time delay for backup trip is bypassed when the 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 tStartTimeout When one of the two Follow Modes is used there is a settable timer tStartTimeout ...

Page 194: ...RT disappears 7 FollowStart Mode Off external START and current above set level never be given current is above set level of IPh and external START present current is below set level of IPh or external START disappears 8 FollowStart Mode UseFunction Mode external START and current above set level be given if current is above set level of IPh and external START is present current is above set level...

Page 195: ...CBCLD input has logical value zero or external START disappears 18 FollowStart Mode Always external START and CBCLD input has logical value one be given if external START is present be given if CBCLD input has logical value one and external START is present CBCLD input has logical value zero or external START disappears No StartMode RetripMode t1 and t2 initiated with When t1 has elapsed TRRET wil...

Page 196: ...ART is present current is above set level of IPh and higher than I BlkCBPos or CBCLD input has logical value one when current is smaller than I BlkCBPos external START disappears 25 FollowStart Mode Off external START and current above set level never be given current is above set level of IPh and higher than I BlkCBPos or CBCLD input has logical value one when current is smaller than I BlkCBPos c...

Page 197: ...team pipe damage to one or more blades in the steam turbine or inadvertent closing of the main stop valves In the last case it is highly desirable to have a reliable reverse power protection It may prevent damage to an otherwise undamaged plant During the routine shutdown of many thermal power units the reverse power protection gives the tripping impulse to the generator breaker the unit breaker B...

Page 198: ...ystem A stiff engine may require perhaps 25 of the rated power to motor it An engine that is good run in might need no more than 5 It is necessary to obtain information from the engine manufacturer and to measure the reverse power during commissioning Gas turbines usually do not require reverse power protection Figure 107 illustrates the reverse power protection with underpower protection and with...

Page 199: ...EN US Equation 47 L2L3 2 3 2 3 L L L L S U I I EQUATION1701 V1 EN US Equation 48 L3L1 3 1 3 1 L L L L S U I I EQUATION1702 V1 EN US Equation 49 L1 1 1 3 L L S U I EQUATION1703 V1 EN US Equation 50 L2 2 2 3 L L S U I EQUATION1704 V1 EN US Equation 51 L3 3 3 3 L L S U I EQUATION1705 V1 EN US Equation 52 The function has two stages that can be set independently With the parameter OpMode1 2 the functi...

Page 200: ...ting is 0 2 of SN when metering class CT inputs into the IED are used 3 N S UBase IBase EQUATION1708 V1 EN US Equation 53 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 Section 7 1MRK 50...

Page 201: ...red power can be made as shown in the formula 1 Old Calculated S k S k S EQUATION1893 V1 EN US Equation 55 Where S is a new measured value to be used for the protection function Sold is the measured value given from the function in previous execution cycle SCalculated is the new calculated value in the present execution cycle k is settable parameter The value of k 0 92 is recommended in generator ...

Page 202: ... 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 Steam turbines easily become overheated if the steam flow becomes too low or if the steam ceases to flow through the turbine Therefore turbo generators should have reverse power protection There are several contingencies that may cause reve...

Page 203: ...ages to hydro turbines can justify reverse power protection in unattended plants A hydro turbine that rotates in water with closed wicket gates will draw electric power from the rest of the power system 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 Diesel engines should have reverse power protection The generator will...

Page 204: ...698 V1 EN US Equation 58 PosSeq 3 PosSeq PosSeq S U I EQUATION1699 V1 EN US Equation 59 L1L2 1 2 1 2 L L L L S U I I EQUATION1700 V1 EN US Equation 60 L2L3 2 3 2 3 L L L L S U I I EQUATION1701 V1 EN US Equation 61 L3L1 3 1 3 1 L L L L S U I I EQUATION1702 V1 EN US Equation 62 L1 1 1 3 L L S U I EQUATION1703 V1 EN US Equation 63 L2 2 2 3 L L S U I EQUATION1704 V1 EN US Equation 64 L3 3 3 3 L L S U ...

Page 205: ... setting is 0 2 of SN when metering class CT inputs into the IED are used 3 N S UBase IBase EQUATION1708 V1 EN US Equation 66 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 1MRK 505 370 UEN D Sec...

Page 206: ...iltering of the measured power can be made as shown in the formula 1 Old Calculated S k S k S EQUATION1893 V1 EN US Equation 68 Where S is a new measured value to be used for the protection function Sold is the measured value given from the function in previous execution cycle SCalculated is the new calculated value in the present execution cycle k is settable parameter The value of k 0 92 is reco...

Page 207: ...he building block used for SCB construction The capacitor unit is made up of individual capacitor elements arranged in parallel or series connections Capacitor elements normally consist of aluminum foil paper or film insulated cells immersed in a biodegradable insulating fluid and are sealed in a metallic container The internal discharge resistor is also integrated within the capacitor unit in ord...

Page 208: ...and without any fuses Unfused where in contrary to the fuseless configuration a series or parallel connection of the capacitor units is used to form SCB still without any fuses Which type of fusing is used may depend on can manufacturer or utility preference and previous experience Because the SCBs are built from the individual capacitor units the overall connections may vary Typically used SCB co...

Page 209: ...ce or a landing site When the animal touches the HV live parts this can result in a flash over can rapture or a cascading failures that might cause extensive damages fire or even total destruction of the whole SCB unless the bank is sufficiently fitted with protection IEDs In addition to fault conditions SCB can be exposed to different types of abnormal operating conditions In accordance with IEC ...

Page 210: ...connecting leads can be provided by using EFPIOC EF4PTOC CVGAPC T2WPDIF T3WPDIF or HZPDIF functions 3 Current or Voltage based unbalance protection for SCB can be provided by using EF4PTOC OC4PTOC CVGAPC or VDCPTOV functions 4 Overload protection for SCB 5 Undercurrent protection for SCB 6 Reconnection inhibit protection for SCB 7 Restrike condition detection CBPGAPC function can be used to provid...

Page 211: ...perationRecIn On to enable this feature IRecnInhibit 10 of IBase Current level under which function will detect that SCB is disconnected from the power system tReconnInhibit 300s Time period under which SCB shall discharge remaining residual voltage to less than 5 Overcurrent feature OperationOC On to enable this feature IOC 135 of IBase Current level for overcurrent pickup Selected value gives pi...

Page 212: ...ional standards 7 10 3 1 Restrike detection GUID 114747A5 0F7C 4F48 A32D 0C13BFF6ADCE v1 Opening of SCBs can be quite problematic for certain types of circuit breakers CBs Typically such problems are manifested as CB restrikes In simple words this means that the CB is not breaking the current at the first zero crossing after separation of the CB contacts Instead current is re ignited and only brak...

Page 213: ...nder consideration The trip time setting for UV2PTUV is normally not critical since there must be enough time available for the main protection to clear short circuits and earth faults Some applications and related setting guidelines for the voltage level are described in the following sections 8 1 2 1 Equipment protection such as for motors and generators M13851 50 v3 The setting must be below th...

Page 214: ...e measured voltages should be below the set level to give operation for step n The setting can be 1 out of 3 2 out of 3 or 3 out of 3 In most applications it is sufficient that one phase voltage is low to give operation If UV2PTUV shall be insensitive for single phase to earth faults 2 out of 3 can be chosen In subtransmission and transmission networks the undervoltage function is mainly a system ...

Page 215: ...Valn given in s It is important that this delay is shorter than the operate time delay of the undervoltage protection step 8 2 Two step overvoltage protection OV2PTOV IP14545 1 v3 8 2 1 Identification M17002 1 v8 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Two step overvoltage protection OV2PTOV 3U SYMBOL C 2U SMALLER THAN V2 EN US 59 8 2 2 ...

Page 216: ...e 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 which is normally set to the nominal voltage level phase to phase of the power system or the high voltage equipment under consideration The time delay for...

Page 217: ...y phase to phase voltage of the protected object If phase to neutral PhN measurement is selected as setting the operation of phase to earth over voltage is automatically divided by sqrt3 This means operation for phase to earth voltage over 3 U UBase kV and operation for phase to phase voltage over U UBase kV EQUATION1993 V1 EN US Equation 72 The below described setting parameters are identical for...

Page 218: ...ent inverse time delayed undervoltage protections ACrvn BCrvn CCrvn DCrvn PCrvn Parameters to set to create programmable under voltage inverse time characteristic Description of this can be found in the technical reference manual CrvSatn When the denominator in the expression of the programmable curve is equal to zero the time delay will be infinity There will be an undesired discontinuity Therefo...

Page 219: ...oltage phase phase level of the power system or the high voltage equipment under consideration 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 situations where the residual overvoltage protection is used to pr...

Page 220: ... voltage transformers measuring the phase to earth voltages measure zero voltage in the faulty phase 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 115 3U 0 UL1 IEC07000190 2 en vsd IEC07000190 V2 EN US Figure 115 Earth fault in Non effectively earthed ...

Page 221: ...wer transformer in the power system In this connection the protection is fed by the voltage UN U0 single input Section Analog inputs in the Application manual explains how the analog input needs to be set ROV2PTOV will measure the residual voltage corresponding to the nominal phase to earth voltage for a high impedance earthed system The measurement will be based on the neutral voltage displacemen...

Page 222: ...Instantaneous Frozen time Linearly decreased The default setting is Instantaneous tIResetn Reset time for step n if inverse time delay is used given in s The default value is 25 ms kn Time multiplier for inverse time characteristic This parameter is used for co ordination between different inverse time delayed undervoltage protections ACrvn BCrvn CCrvn DCrvn PCrvn Parameters for step n to set to c...

Page 223: ...en element in the capacitor bank It is mainly used on elements with external fuses but can also be used on elements with internal fuses instead of a current unbalance protection measuring the current between the neutrals of two half s of the capacitor bank The function requires voltage transformers in all phases of the capacitor bank Figure 117 shows some different alternative connections of this ...

Page 224: ...epend of the capacitor bank voltage and the number of elements per phase in series and parallel Capacitor banks must be tripped before excessive voltage occurs on the healthy capacitor elements The setting values required are normally given by the capacitor bank supplier For other applications it has to be decided case by case For fuse supervision normally only the alarm level is used tTrip The ti...

Page 225: ...V is used for signallization only through an output contact or through the event recording function 8 5 3 Setting guidelines SEMOD171929 4 v5 Loss of voltage check LOVPTUV is in principle independent of the protection functions It requires to be set to open the circuit breaker in order to allow a simple system restoration following a main voltage loss of a big part of the network and only when the...

Page 226: ...220 ...

Page 227: ...ge and hence also reduce the voltage dependent part of the load SAPTUF is very sensitive and accurate and is used to alert operators that frequency has slightly deviated from the set point and that manual actions might be enough The underfrequency signal is also used for overexcitation detection This is especially important for generator step up transformers which might be connected to the generat...

Page 228: ...voltage related time delay is used for load shedding The settings of SAPTUF could be the same all over the power system The load shedding is then performed firstly in areas with low voltage magnitude which normally are the most problematic areas where the load shedding also is most efficient 9 2 Overfrequency protection SAPTOF IP15747 1 v3 9 2 1 Identification M14866 1 v4 Function description IEC ...

Page 229: ...ensitive loads The setting level the number of levels and the distance between two levels in time and or in frequency depend very much on the characteristics of the power system under consideration The size of the largest loss of load compared to the size of the power system is a critical parameter In large systems the generator shedding can be set at a fairly low frequency level and the time dela...

Page 230: ...r generation shedding has to take place very quickly and there might not be enough time to wait until the frequency signal has reached an abnormal value Actions are therefore taken at a frequency level closer to the primary nominal level if the rate of change frequency is large with respect to sign The start value for SAPFRC is set in Hz s All voltage magnitude related settings are made as a perce...

Page 231: ...ncident The IED can be provided with multiple General current and voltage protection CVGAPC protection modules The function is always connected to three phase current and three phase voltage input in the configuration tool but it will always measure only one current and one voltage quantity selected by the end user in the setting tool Each CVGAPC function module has got four independent protection...

Page 232: ...Input Comment 1 phase1 CVGAPC function will measure the phase L1 current phasor 2 phase2 CVGAPC function will measure the phase L2 current phasor 3 phase3 CVGAPC function will measure the phase L3 current phasor 4 PosSeq CVGAPC function will measure internally calculated positive sequence current phasor 5 NegSeq CVGAPC function will measure internally calculated negative sequence current phasor 6 ...

Page 233: ... enable easier settings for the directional feature when used 7 MaxPh CVGAPC function will measure voltage phasor of the phase with maximum magnitude 8 MinPh CVGAPC function will measure voltage phasor of the phase with minimum magnitude 9 UnbalancePh CVGAPC function will measure magnitude of unbalance voltage which is internally calculated as the algebraic magnitude difference between the voltage...

Page 234: ...ntity is selected from 10 to 15 as shown in table 39 10 1 2 3 Application possibilities SEMOD53443 136 v3 Due to its flexibility the general current and voltage protection CVGAPC function can be used with appropriate settings and configuration in many different applications Some of possible examples are given below 1 Transformer and line applications Underimpedance protection circular non directio...

Page 235: ...f a few seconds Of more critical concern however is the bearing which can be damaged in a fraction of a second due to low oil pressure Therefore it is essential that high speed tripping is provided This tripping should be almost instantaneous 100 ms There is a risk that the current into the generator at inadvertent energization will be limited so that the normal overcurrent or underimpedance prote...

Page 236: ... overcurrent protection elements within a CVGAPC function This functionality can be achieved by using one CVGAPC function The following shall be done to ensure proper operation of the function 1 Connect three phase power line currents and three phase power line voltages to one CVGAPC instance for example GF04 2 Set CurrentInput to NegSeq please note that CVGAPC function measures I2 current and NOT...

Page 237: ...forward and reverse signals to the remote end of the power line the available scheme communications function block within IED shall be used between multipurpose protection function and the communication equipment in order to insure proper conditioning of the above two start signals Furthermore the other built in UC OV and UV protection elements can be used for other protection and alarming purpose...

Page 238: ...g M is ratio between measured current magnitude and set pickup current level A B C and P are user settable coefficients which determine the curve used for Inverse Time Overcurrent TOC IDMT calculation When the equation 76 is compared with the equation 78 for the inverse time characteristic of the OC1 it is obvious that if the following rules are followed 1 set k equal to the generator negative seq...

Page 239: ...r rating The generator stator overload protection is defined by IEC or ANSI standard for turbo generators in accordance with the following formula 2 1 op m r k t I I æ ö ç è ø EQUATION1376 V1 EN US Equation 80 where top is the operating time of the generator stator overload IED k is the generator capability constant in accordance with the relevant standard k 37 5 for the IEC standard or k 41 4 for...

Page 240: ...C1 step in it is obvious that if the following rules are followed 1 set k equal to the IEC or ANSI standard generator capability value 2 set parameter A_OC1 equal to the value 1 x2 3 set parameter C_OC1 equal to the value 1 x2 4 set parameters B_OC1 0 0 and P_OC1 2 0 5 set StartCurr_OC1 equal to the value x then the OC1 step of the CVGAPC function can be used for generator negative sequence invers...

Page 241: ...C1 8 Select parameter CurveType_OC1 to value IEC Def Time 9 Set parameter StartCurr_OC1 to value 5 10 Set parameter tDef_OC1 to desired time delay for example 2 0s Proper operation of CVGAPC function made in this way can easily be verified by secondary injection All other settings can be left at the default values However it shall be noted that set values for restrain current and its coefficient w...

Page 242: ...enerator data the following values are calculated Maximum generator capability to contentiously absorb reactive power at zero active loading 38 of the generator MVA rating Generator pull out angle 84 degrees This functionality can be achieved by using one CVGAPC function The following shall be done in order to insure proper operation of the function 1 Connect three phase generator currents and thr...

Page 243: ...2 0 4 0 6 0 2 0 6 0 8 0 8 1 D ILowSet B A C 0 4 0 2 0 1 2 1 4 0 4 0 6 0 8 rca Operating Region Q pu P pu rca UPS IPS ILowSet Operating region en05000535 vsd IEC05000535 V2 EN US Figure 118 Loss of excitation 1MRK 505 370 UEN D Section 10 Multipurpose protection Busbar protection REB670 237 Application manual ...

Page 244: ...238 ...

Page 245: ...ailure 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 first case influences the operation of all voltage dependent functions while the second one does not affect the impedance measuring functions The negative sequence detection algorithm based on the n...

Page 246: ...ndication will persist in the phase with the blown fuse When the local breaker closes the current will start to flow and the function detects the fuse failure situation But due to the 200 ms drop off timer the output BLKZ will not be activated until after 200 ms This means that distance functions are not blocked and due to the no voltage but current situation might issue a trip The operation mode ...

Page 247: ...e 3U0 is given in percentage of the base voltage UBase The setting of 3U0 should not be set lower than the value that is calculated according to equation 86 100 3 0 3 0 3 UBase U U EQUATION1521 V4 EN US Equation 86 where 3U0 is the maximal zero sequence voltage during normal operation conditions plus a margin of 10 20 UBase is the base voltage for the function according to the setting GlobalBaseSe...

Page 248: ...nce protection function A 5 10 lower value is recommended 11 1 3 6 Dead line detection M13683 78 v4 The condition for operation of the dead line detection is set by the parameters IDLD for the current threshold and UDLD for the voltage threshold Set the IDLD with a sufficient margin below the minimum expected load current A safety margin of at least 15 20 is recommended The operate value must howe...

Page 249: ...ircuit IEC12000143 V1 EN US Figure 119 Application of VDSPVC 11 2 3 Setting guidelines GUID 0D5A517C 1F92 46B9 AC2D F41ED4E7C39E v1 GUID 52BF4E8E 0B0C 4F75 99C4 0BCB22CDD166 v2 The parameters for Fuse failure supervision VDSPVC are set via the local HMI or PCM600 GUID 0B298162 C939 47E4 A89B 7E6BD7BEBB2C v2 The voltage input type phase to phase or phase to neutral is selected using ConTypeMain and...

Page 250: ...11 3 1 Identification GUID C7108931 DECA 4397 BCAF 8BFF3B57B4EF v2 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Voltage based delta supervision DELVSPVC 7V_78V 11 3 2 Application GUID D179DBA4 B068 4A1E A53E 477BD3B6ACFC v2 In a weak grid networks fault detection and operation of other protection functions is reliably done by delta supervisio...

Page 251: ...machines Islanding can occur as a consequence of a fault in the network circuit breaker maloperation circuit breaker opening during maintenance If the distributed generator continues its operation after the utility supply is disconnected faults do not clear under certain conditions as the arc is charged by the distributed generators Moreover the distributed generators are incompatible with the cur...

Page 252: ...etting enables the function to start detecting delta Typical setting is 10 of UBase If the MeasMode setting is set as phase to ground this setting is taken as 50 of the set value MeasMode This setting is used to detect the mode of measurement phase to phase or phase to ground OpMode This setting is used to select the mode of operation For protection applications this should be set to Instantaneous...

Page 253: ...n can be used for load supervision also in DFT Mag based delta mode 11 4 3 Setting guidelines GUID 69D28046 FAC4 4EF3 9886 F7B0F6341196 v2 Operation This setting is used to enable disable the delta supervision function Imin The minimum start level setting should be set as of IBase This setting enables the function to start detecting delta Typical setting is 10 of IBase MeasMode This setting is use...

Page 254: ... S Active power P Reactive power P Thermal heat content ɸ Energy The change over time of these quantities with respect to the old value can be supervised with this function 11 5 3 Setting guidelines GUID 0D420893 4266 4EED 8790 1FFA0F41C962 v1 Operation This setting is used to enable disable the delta supervision function MinStVal The minimum start level of the function If the input is below this ...

Page 255: ...angle is equal to the measured phase angle and the following conditions are simultaneously fulfilled The voltages U Line and U Bus are higher than the set values for UHighBusSynch and UHighLineSynch of the respective base voltages GblBaseSelBus and GblBaseSelLine The difference in the voltage is smaller than the set value of UDiffSynch The difference in frequency is less than the set value of Freq...

Page 256: ...or phase phase L1 L2 L2 L3 L3 L1 or positive sequence Require a three phase voltage that is UL1 UL2 and UL3 By setting the phases used for SESRSYN with the settings SelPhaseBus1 SelPhaseBus2 SelPhaseLine2 and SelPhaseLine2 a compensation is made automatically for the voltage amplitude difference and the phase angle difference caused if different setting values are selected for the two sides of the...

Page 257: ...se in a long and loaded parallel power line For this application we accept a synchrocheck with a long operation time and high sensitivity regarding the frequency difference The phase angle difference setting can be set for steady state conditions Another example is the operation of a power network that is disturbed by a fault event after the fault clearance a highspeed auto reclosing takes place T...

Page 258: ...substations where one 1 is energized and the other 2 is not energized The line between CB A and CB B is energized DLLB from substation 1 via the circuit breaker A and energization of station 2 is done by CB B energization check device for that breaker DBLL or Both 1 2 A EnergizingCheck UHighBusEnerg 50 120 of GblBaseSelBus UHighLineEnerg 50 120 of GblBaseSelLine ULowBusEnerg 10 80 of GblBaseSelBus...

Page 259: ...it breaker with double busbars and the 1 circuit breaker arrangement A double circuit breaker arrangement and single circuit breaker with a single busbar do not need any voltage selection function Neither does a single circuit breaker with double busbars using external voltage selection need any internal voltage selection Manual energization of a completely open diameter in 1 circuit breaker switc...

Page 260: ...I symbol through a selector switch function block 12 1 3 Application examples M12323 3 v7 The synchronizing function block can also be used in some switchyard arrangements but with different parameter settings Below are some examples of how different arrangements are connected to the IED analogue inputs and to the function block SESRSYN One function block is used per circuit breaker The input used...

Page 261: ...o No voltage sel 12 1 3 2 Single circuit breaker with double busbar external voltage selection M12325 3 v8 WA1 WA2 QB1 QB2 LINE QA1 IEC10000094 4 en vsd WA2_MCB WA1_MCB LINE_VT LINE_MCB SESRSYN U3PBB1 U3PBB2 U3PLN1 U3PLN2 GRP_OFF UB1OK UB1FF ULN1OK ULN1FF WA1_VT WA2_VT LINE_VT LINE_MCB WA1_MCB WA2_MCB WA1_MCB WA2_MCB WA1_VT WA2_VT IEC10000094 V4 EN US Figure 126 Connection of SESRSYN function bloc...

Page 262: ...N1 The positions of the disconnectors and VT fuses shall be connected as shown in figure 127 The voltage selection parameter CBConfig is set to Double bus 12 1 3 4 Double circuit breaker M12329 3 v7 WA1 WA2 WA1_QA1 WA2_QA1 LINE WA1_MCB WA2_ MCB LINE_MCB LINE_MCB WA1_VT WA1_QA1 GRP_OFF SESRSYN U3PBB1 U3PBB2 U3PLN1 U3PLN2 WA1_VT LINE_VT UB1OK UB1FF ULN1OK ULN1FF WA1_MCB LINE_MCB WA2_QA1 GRP_OFF SESR...

Page 263: ...e same IED each of them handling voltage selection for WA1_QA1 TIE_QA1 and WA2_QA1 breakers respectively The voltage from busbar 1 VT is connected to 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 connected to U3PLN...

Page 264: ...MCB LINE1_MCB LINE2_MCB SESRSYN U3PBB1 B1 QOPEN B1 QCLD B2 QOPEN B2 QCLD LN1 QOPEN LN1 QCLD LN2 QOPEN LN2 QCLD UB1OK UB1FF UB2OK UB2FF ULN1OK ULN1FF ULN2OK ULN2FF U3PLN2 U3PLN1 U3PBB2 LINE1_MCB TIE_QA1 LINE2 LINE2_MCB LINE2_VT LINE1_VT LINE2_QB9 WA1_QA1 WA2_QA1 WA2_VT WA2_MCB WA1_MCB WA1_VT WA1_QB6 WA2_QB6 LINE1_QB9 WA1_QA1 TIE_QA1 WA2_QA1 LINE2_QB9 IEC10000097 V4 EN US Figure 129 Connections of t...

Page 265: ...pervision of LINE1_MCB fuse ULN2OK FF Supervision of LINE2_MCB fuse Setting CBConfig 1 1 2 bus alt CB If only two SESRSYN functions are provided in the same IED the connections and settings are according to the SESRSYN functions for WA1_QA1 and TIE_QA1 12 1 4 Setting guidelines M12550 3 v14 The setting parameters for the Synchronizing synchrocheck and energizing check function SESRSYN are set via ...

Page 266: ...reaker connected to busbar 1 1 1 2 bus CB 1 1 2 circuit breaker arrangement with the breaker connected to busbar 2 1 1 2 bus alt CB 1 1 2 circuit breaker arrangement with the breaker connected to line 1 and 2 Tie CB PhaseShift This setting is used to compensate the phase shift between the measured bus voltage and line voltage when different phase neutral voltages are selected for example UL1 for b...

Page 267: ...lated to nominal frequency independent of each other so the frequency difference shall be small FreqRateChange The maximum allowed rate of change for the frequency CloseAngleMax The setting CloseAngleMax is the maximum closing angle between bus and line at which synchronizing is accepted To minimize the moment stress when synchronizing near a power station a narrower limit should be used A typical...

Page 268: ...n be10 mHz and a typical value for FreqDiffA can be 100 200 mHz PhaseDiffM and PhaseDiffA The phase angle difference level settings PhaseDiffM and PhaseDiffA shall also be chosen depending on conditions in the network The phase angle setting must be chosen to allow closing under maximum load condition A typical maximum value in heavy loaded networks can be 45 degrees whereas in most networks the m...

Page 269: ...iderable potential due to for instance induction from a line running in parallel or by being fed via the extinguishing capacitors in the circuit breakers This voltage can be as high as 30 or more of the base line voltage Because the setting ranges of the threshold voltages UHighBusEnerg UHighLineEnerg and ULowBusEnerg ULowLineEnerg partly overlap each other the setting conditions may be such that ...

Page 270: ...ration logic can be implemented by using optionally available auto reclosers and built in logical gates Two auto reclosers are available Automatic reclosing is a well established method for the restoration of service in a power system after a transient line fault The majority of line faults are flashovers which are transient by nature When the power line is switched off by the operation of line pr...

Page 271: ...lted phases To maximize the availability of the power system it is possible to choose single phase tripping and automatic reclosing during single phase faults and three phase tripping and automatic reclosing during multi phase faults Three phase automatic reclosing can be performed with or without the use of synchrocheck During the single phase dead time there is an equivalent series fault in the ...

Page 272: ...ser 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 indicating faults outside the own line are typically connected to inhibit the auto recloser Automatic reclosing should not be attempted when closing a CB and energizing a line onto a fault SOTF except when multiple shot...

Page 273: ... is ready to accept a start 12 2 2 2 Start auto reclosing and conditions for start of a reclosing cycle M12391 94 v5 The usual way to start an auto reclosing cycle or sequence is to start it at selective tripping by line protection by applying a signal to the START input Starting signals can be either general trip signals or only the conditions for differential distance protection zone 1 and dista...

Page 274: ...te settings for single two and three phase auto reclosing dead time t1 1Ph t1 2Ph t1 3Ph If no particular input signal is applied and an auto reclosing program with single phase auto reclosing is selected the auto reclosing dead time t1 1Ph will be used If one of the TR2P or TR3P inputs is activated in connection with the start the auto reclosing dead time for two phase or three phase auto reclosi...

Page 275: ...le 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 disagreement and earth fault protection trip during the single phase dead time interval If TR2P input is high and TR3P input is low i e two phase trip The timer for two phase auto reclosing dead time is started and the 2PT1 output two phase reclosing in p...

Page 276: ...t will inhibit the auto recloser No more shots are attempted The expression 1 3ph should be understood as Only one shot at three phase auto reclosing 12 2 2 13 ARMode 1ph 1 2 3ph 1 phase 2 phase or 3 phase reclosing in the first shot M12391 146 v5 At single phase or two phase tripping the operation is as in the above described example program mode 1 2 3ph If the first reclosing shot fails a three ...

Page 277: ...s a pulse with a duration set by the tPulse setting For circuit breakers without an anti pumping function close pulse cutting can be used It is selected by the CutPulse setting In case of a new start pulse trip the breaker closing command pulse is then cut interrupted The minimum breaker closing command pulse length is always 50ms At the issue of the breaker closing command the appropriate auto re...

Page 278: ... connected to binary I O as required Many alternative ways of performing the logic exist depending on whether manual circuit breaker closing is interlocked in the IED whether an external physical lock out relay exists and whether the reset is hardwired or carried out by means of communication There are also different alternatives regarding what shall generate lock out Examples of questions are sha...

Page 279: ...er which ensures that the second fault is always tripped three phase For other types of relays where the relays do not include this function the PREP3PH output or the inverted PERMIT1PH output is used to prepare the other sub system for three phase tripping This signal will for evolving fault situations be activated a short time after the first trip has reset and will thus ensure that new starts t...

Page 280: ...f the CBREADY input INHIBIT To this input shall be connected signals that interrupt an auto reclosing cycle or prevent a start from being accepted Such signals can come from protection for a line connected shunt reactor from transfer trip receive from back up protection functions busbar protection trip or from breaker failure protection When the circuit breaker open position is set to start the au...

Page 281: ...n different protection trip operations This input starts the dead time t1 3PhHS High speed reclosing shot 1 started by this input is without a synchronization check SYNC This input is connected to the internal synchrocheck function when required or to an external device for synchronism If neither internal nor external synchronism or energizing check is required it can be connected to a permanently...

Page 282: ... 136 and default factory configuration for examples 1PT1 and 2PT1 Indicates that single phase or two phase auto reclosing is in progress It is used to temporarily block an earth fault and or pole disagreement function during the single phase or two phase open interval 3PT1 3PT2 3PT3 3PT4 and 3PT5 Indicates that three phase auto reclosing shots one to five are in progress The signals can be used as...

Page 283: ... the auto recloser cannot make a single phase or two phase auto reclosing the tripping should be three phase READY 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 SETON Indicates that auto recloser is switched on and operative SUCCL If the ci...

Page 284: ...L SUCCL CLOSECB CBREADY CBCLOSED PLCLOST 1PT1 WFMASTER RESET START THOLHOLD READY TRSOTF SYNC INPUT xx xx xx xx xx xx xx xx xx xx OR OUTPUT xx xx xx xx xx xx xx xx xx xx PROTECTION xxxx TRIP ZCVPSOF TRIP SESRSYN AUTOOK BIM BOM SMBRREC IEC04000135 5 en Original vsd PERMIT1P PREP3P STARTHS SKIPHS TR2P TR3P TRUE WAIT RSTCOUNT 3PT1 2PT1 3PT2 3PT3 3PT4 3PT5 IEC04000135 V5 EN US Figure 134 Example of I ...

Page 285: ...utput After an unsuccessful reclosing the WFMASTER output is also maintained by the UNSUCCL signal When activating the WAIT input in the auto recloser set as slave every dead timer is changed to the value of setting tSlaveDeadTime and holds back the auto reclosing operation When the WAIT input is reset at the time of a successful reclosing of the first circuit breaker the slave is released to cont...

Page 286: ...YNC INHIBIT Terminal Master Priority High SMBRREC CLOSECB WAIT Terminal Slave Priority Low CB1 CB2 WFMASTER WFMASTER Other input output signals as in previous single breaker arrangements PLCLOST SUCCL SKIPHS STARTHS RSTCOUNT THOLHOLD PERMIT1P PREP3P 3PT1 2PT1 1PT1 3PT5 RESET BLKOFF BLKON OFF ON INHIBIT PLCLOST START SKIPHS STARTHS CBCLOSED CBREADY SYNC THOLHOLD TRSOTF 3PT2 3PT3 3PT4 PERMIT1P PREP3...

Page 287: ...he function is started by protection trip signals If set On the start of the auto recloser is controlled by an circuit breaker auxiliary contact LongStartInhib Usually the protection trip command used as an auto reclosing start signal resets quickly as the fault is cleared A prolonged trip command may depend on a circuit breaker failing to clear the fault A protection trip signal present when the ...

Page 288: ...ing relays the setting CutPulse On can be used to avoid repeated closing operation when reclosing onto a fault A new start will then cut the ongoing pulse tPulse The circuit breaker closing command should be long enough to ensure reliable operation of the circuit breaker The circuit breaker closing command pulse has a duration set by the tPulse setting A typical setting may be tPulse 200 ms A long...

Page 289: ...to use if the communication channel for permissive line protection is lost The communication link in a permissive not strict line protection scheme for instance a power line carrier PLC link may not always be available If lost it can result in delayed tripping at one end of a line There is a possibility to extend the auto reclosing dead time in such a case by use of the PLCLOST input and the tExte...

Page 290: ...f circuit breakers disconnectors and earthing switches within a bay Permission to operate is given after evaluation of conditions from other functions such as interlocking synchrocheck operator place selection and external or internal blockings The complete apparatus control function is not included in this product and the information below is included for understanding of the principle for the us...

Page 291: ...Y Bay reserve QCRSV Reservation input RESIN Local remote LOCREM Local remote control LOCREMCTRL The signal flow between the function blocks is shown in Figure 138 To realize the reservation function the function blocks Reservation input RESIN and Bay reserve QCRSV also are included in the apparatus control function The application description for all these functions can be found below The function...

Page 292: ...850 IEC05000116 V2 EN US Figure 138 Signal flow between apparatus control function blocks when all functions are situated within the IED Section 12 1MRK 505 370 UEN D Control 286 Busbar protection REB670 Application manual ...

Page 293: ...fined in the IED then the local remote switch is under authority control otherwise the default user can perform control operations from the local IED HMI without logging in The default position of the local remote switch is on remote Accepted originator categories for PSTO If the requested command is accepted by the authority control the value will change Otherwise the attribute blocked by switchi...

Page 294: ...v10 The Bay control QCBAY is used to handle the selection of the operator place per bay The function gives permission to operate from two main types of locations either from Remote for example control centre or station HMI or from Local local HMI on the IED or from all Local and Remote The Local Remote switch position can also be set to Off which means no operator place selected that is operation ...

Page 295: ...n are read and evaluated if the operation is permitted The synchrocheck synchronizing conditions are read and checked and performs operation upon positive response The blocking conditions are evaluated The position indications are evaluated according to given command and its requested direction open or closed The command sequence is supervised regarding the time between Select and execute Select a...

Page 296: ...time for intermediate position Definition of pulse duration for open close command respectively The realizations of these functions are done with SXCBR representing a circuit breaker and with SXSWI representing a circuit switch that is a disconnector or an earthing switch Circuit breaker SXCBR can be realized either as three one phase switches or as one three phase switch The content of this funct...

Page 297: ...Configuration with XLNPROXY and GOOSEXLNRCV where only the mandatory data in the IEC 61850 modelling is used All the information from the XLNPROXY to the SCSWI about command following status causes for failed command and selection status is transferred in the output XPOS The other outputs 1MRK 505 370 UEN D Section 12 Control Busbar protection REB670 291 Application manual ...

Page 298: ... close commands 9 Blocked by process If the Blk input is connected and active indicating that the switch is dynamically blocked Or if the OPCAP input is connected it indicates that the operation capability of the switch is not enough to perform the command 5 Position reached Switch is already in the intended position 31 Switch not start moving Switch did not start moving within tStartMove 32 Persi...

Page 299: ... the bay has received a request from another bay The other function block RESIN receives the reservation information from other bays The number of instances is the same as the number of involved bays up to 60 instances are available The received signals are either the request for reservation from another bay or the acknowledgment from each bay respectively which have received a request from this b...

Page 300: ...pical bay with apparatus control function consists of a combination of logical nodes or functions that are described here The Switch controller SCSWI initializes all operations for one apparatus It is the command interface of the apparatus It includes the position reporting as well as the control of the position The Circuit breaker SXCBR is the process interface to the circuit breaker for the appa...

Page 301: ...ted to SCILO The Synchrocheck energizing check and synchronizing SESRSYN calculates and compares the voltage phasor difference from both sides of an open breaker with predefined switching conditions synchrocheck Also the case that one side is dead energizing check is included The Generic Automatic Process Control function GAPC handles generic commands from the operator to the system The overview o...

Page 302: ...TRC Trip logic Position Pos from other bays I O Open cmd Close cmd Synchronizing OK Synchrocheck OK Start Synchronizing Synchronizing in progress SCILO Interlocking Enable open Enable close IEC05000120 3 EN vsdx IEC05000120 V3 EN US Figure 146 Example overview of the interactions between functions in a typical bay 12 3 8 Setting guidelines M16669 3 v5 The setting parameters for the apparatus contr...

Page 303: ...ct and the execute command signal that is the time the operator has to perform the command execution after the selection of the object to operate When the time has expired the selected output signal is set to false and a cause code is given The time parameter tResResponse is the allowed time from reservation request to the feedback reservation granted from all bays involved in the reservation func...

Page 304: ...se is the output pulse length for a close command If AdaptivePulse is set to Adaptive it is the maximum length of the output pulse for an open command The default length is set to 200 ms for a circuit breaker SXCBR and 500 ms for a disconnector SXSWI 12 3 8 4 Proxy for signals from switching device via GOOSE XLNPROXY GUID 7C253FE7 6E02 4F94 96C7 81C9129D925D v1 The SwitchType setting controls the ...

Page 305: ...e controlled This means that switch interlock because of device alarms is not included in this section Disconnectors and earthing switches have a limited switching capacity Disconnectors may therefore only operate With basically zero current The circuit is open on one side and has a small extension The capacitive current is small for example 5A and power transformers with inrush current are not al...

Page 306: ...eration is not permitted For switches with an individual operation gear per phase the evaluation must consider possible phase discrepancies This is done with the aid of an AND function for all three phases in each apparatus for both open and close indications Phase discrepancies will result in an unknown double indication state 12 4 1 Configuration guidelines M13529 4 v4 The following sections des...

Page 307: ...ept in the own bay are open VP_BB7_D The switch status of disconnectors on bypass busbar WA7 are valid EXDU_BPB No transmission error from any bay containing disconnectors on bypass busbar WA7 These signals from each line bay ABC_LINE except that of the own bay are needed Signal QB7OPTR Q7 is open VPQB7TR The switch status for QB7 is valid EXDU_BPB No transmission error from the bay that contains ...

Page 308: ...00479 vsd IEC04000479 V1 EN US Figure 149 Busbars divided by bus section disconnectors circuit breakers To derive the signals Signal BC_12_CL A bus coupler connection exists between busbar WA1 and WA2 BC_17_OP No bus coupler connection between busbar WA1 and WA7 BC_17_CL A bus coupler connection exists between busbar WA1and WA7 BC_27_OP No bus coupler connection between busbar WA2 and WA7 BC_27_CL...

Page 309: ...for both bus section disconnector A1A2_DC and B1B2_DC Signal DCOPTR The bus section disconnector is open DCCLTR The bus section disconnector is closed VPDCTR The switch status of bus section disconnector DC is valid EXDU_DC No transmission error from the bay that contains the above information If the busbar is divided by bus section circuit breakers the signals from the bus section coupler bay A1A...

Page 310: ...27_CL VP_BC_27 EXDU_BC en04000480 vsd IEC04000480 V1 EN US Figure 150 Signals to a line bay in section 1 from the bus coupler bays in each section For a line bay in section 2 the same conditions as above are valid by changing section 1 to section 2 and vice versa 12 4 2 4 Configuration setting M13560 108 v4 If there is no bypass busbar and therefore no QB7 disconnector then the interlocking for QB...

Page 311: ...e designated 0 FALSE and 1 TRUE QB2_OP 1 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 12 4 3 Interlocking for bus coupler bay ABC_BC IP14144 1 v2 12 4 3 1 Application M13555 3 v8 The interlocking for bus coupler bay ABC_BC function is used for a bus coupler bay connected to a double busbar arrangement according to figure 151 The function can also be used for a single bu...

Page 312: ...The switch status is valid for all apparatuses involved in the busbar transfer EXDU_12 No transmission error from any bay connected to the WA1 WA2 busbars These signals from each line bay ABC_LINE each transformer bay AB_TRAFO and bus coupler bay ABC_BC except the own bus coupler bay are needed Signal QQB12OPTR QB1 or QB2 or both are open VPQB12TR The switch status of QB1 and QB2 are valid EXDU_12...

Page 313: ...ls from busbar B are used The same type of module A1A2_DC is used for different busbars that is for both bus section disconnector A1A2_DC and B1B2_DC Signal DCOPTR The bus section disconnector is open VPDCTR The switch status of bus section disconnector DC is valid EXDU_DC No transmission error from the bay that contains the above information If the busbar is divided by bus section circuit breaker...

Page 314: ... section must be transmitted to the own busbar coupler if both disconnectors are closed Section 1 Section 2 A1A2_DC BS B1B2_DC BS ABC_BC ABC_BC WA1 A1 WA2 B1 WA7 C C B2 A2 en04000484 vsd IEC04000484 V1 EN US Figure 155 Busbars divided by bus section disconnectors circuit breakers To derive the signals Signal BC_12_CL Another bus coupler connection exists between busbar WA1 and WA2 VP_BC_12 The swi...

Page 315: ...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 DCCLTR A1A2 DCCLTR B1B2 BC12CLTR sect 2 VPDCTR A1A2 VPDCTR B1B2 VPBC12TR sect 2 EXDU_DC A1A2 EXDU_DC B1B2 EXDU_BC sect 2 BC_12_CL VP_BC_12 EXDU_BC en04000485 vsd IEC04000485 V1 EN...

Page 316: ..._12_CL 0 VP_BC_12 1 BBTR_OP 1 VP_BBTR 1 12 4 4 Interlocking for transformer bay AB_TRAFO IP14149 1 v2 12 4 4 1 Application M13567 3 v7 The interlocking for transformer bay AB_TRAFO function is used for a transformer bay connected to a double busbar arrangement according to figure 157 The function is used when there is no disconnector between circuit breaker and transformer Otherwise the interlocki...

Page 317: ...her bus section Section 1 Section 2 A1A2_DC BS B1B2_DC BS AB_TRAFO ABC_BC AB_TRAFO ABC_BC WA1 A1 WA2 B1 WA7 C C B2 A2 en04000487 vsd IEC04000487 V1 EN US Figure 158 Busbars divided by bus section disconnectors circuit breakers The project specific logic for input signals concerning bus coupler are the same as the specific logic for the line bay ABC_LINE Signal BC_12_CL A bus coupler connection exi...

Page 318: ...n breaker A1A2_BS IP14154 1 v2 12 4 5 1 Application M15110 3 v7 The interlocking for bus section breaker A1A2_BS function is used for one bus section circuit breaker between section 1 and 2 according to figure 159 The function can be used for different busbars which includes a bus section circuit breaker QA1 WA1 A1 QB2 QC4 QB1 QC3 WA2 A2 en04000516 vsd QC2 QC1 A1A2_BS IEC04000516 V1 EN US Figure 1...

Page 319: ...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 These signals from each bus coupler bay ABC_BC are needed Signal BC12OPTR No bus coupler connection through the own bus coupler between busbar WA1 and WA2 VPBC12TR The switch status of BC_12 is valid EXDU_BC No transmission error from the bay that contains the...

Page 320: ... sect 2 VPQB12TR bay 1 sect 1 VPQB12TR bay n sect 1 EXDU_12 bay 1 sect 2 EXDU_12 bay n sect 2 EXDU_12 bay 1 sect 1 EXDU_12 bay n sect 1 EXDU_BS B1B2 EXDU_BC sect 1 EXDU_BC sect 2 IEC04000490 V1 EN US Figure 161 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 Section 12 ...

Page 321: ...U_BS A1A2 EXDU_BC sect 1 EXDU_BC sect 2 IEC04000491 V1 EN US Figure 162 Signals from any bays for a bus section circuit breaker between sections B1 and B2 12 4 5 3 Configuration setting M15111 57 v3 If there is no other busbar via the busbar loops that are possible then either the interlocking for the QA1 open circuit breaker is not used or the state for BBTR is set to open That is no busbar trans...

Page 322: ...s used for different busbars that is for both bus section disconnector A1A2_DC and B1B2_DC But for B1B2_DC corresponding signals from busbar B are used Section 1 Section 2 A1A2_DC BS B1B2_DC BS ABC_LINE ABC_BC ABC_LINE WA1 A1 WA2 B1 WA7 C C B3 A3 en04000493 vsd AB_TRAFO AB_TRAFO A2 B2 IEC04000493 V1 EN US Figure 164 Busbars divided by bus section disconnectors circuit breakers To derive the signal...

Page 323: ...l bus section disconnector the signals from the bus section circuit breaker bay A1A2_BS rather than the bus section disconnector bay A1A2_DC must be used Signal QB1OPTR QB1 is open QB2OPTR QB2 is open VPQB1TR The switch status of QB1 is valid VPQB2TR The switch status of QB2 is valid EXDU_BS No transmission error from the bay BS bus section coupler bay that contains the above information For a bus...

Page 324: ...ector these conditions from the B1 busbar section are valid QB2OPTR QB220OTR bay 1 sect B1 S1DC_OP VPS1_DC EXDU_BB en04000496 vsd QB2OPTR QB220OTR bay n sect B1 VPQB2TR VQB220TR bay 1 sect B1 VPQB2TR VQB220TR bay n sect B1 EXDU_BB bay 1 sect B1 EXDU_BB bay n sect B1 IEC04000496 V1 EN US Figure 167 Signals from any bays in section B1 to a bus section disconnector For a bus section disconnector thes...

Page 325: ...t busbars that is for both bus section disconnector A1A2_DC and B1B2_DC But for B1B2_DC corresponding signals from busbar B are used Section 1 Section 2 A1A2_DC BS B1B2_DC BS DB_BUS DB_BUS DB_BUS DB_BUS WA1 A1 WA2 B1 B2 A2 en04000498 vsd IEC04000498 V1 EN US Figure 169 Busbars divided by bus section disconnectors circuit breakers To derive the signals Signal S1DC_OP All disconnectors on bus sectio...

Page 326: ...R bay n sect A1 EXDU_DB bay 1 sect A1 EXDU_DB bay n sect A1 IEC04000499 V1 EN US Figure 170 Signals from double breaker bays in section A1 to a bus section disconnector For a bus section disconnector these conditions from the A2 busbar section are valid QB1OPTR bay 1 sect A2 S2DC_OP VPS2_DC EXDU_BB en04000500 vsd QB1OPTR bay n sect A2 VPQB1TR bay 1 sect A2 VPQB1TR bay n sect A2 EXDU_DB bay 1 sect ...

Page 327: ...ble breaker bays in section B2 to a bus section disconnector 12 4 6 4 Signals in 1 1 2 breaker arrangement M13542 127 v5 If the busbar is divided by bus section disconnectors the condition for the busbar disconnector bay no other disconnector connected to the bus section must be made by a project specific logic The same type of module A1A2_DC is used for different busbars that is for both bus sect...

Page 328: ...04000504 vsd IEC04000504 V1 EN US Figure 175 Switchyard layout BB_ES M15053 4 v4 The signals from other bays connected to the module BB_ES are described below 12 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 Section 1 Section 2 A1A2_DC BS B1B2_DC BS AB_TRAFO ABC_LINE BB_ES ABC_LINE WA1 ...

Page 329: ... VPDCTR The switch status of bus section disconnector DC is valid EXDU_DC No transmission error from the bay that contains the above information If no bus section disconnector exists the signal DCOPTR VPDCTR and EXDU_DC are set to 1 TRUE 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...

Page 330: ...tch these conditions from the A2 busbar section are valid QB1OPTR bay 1 sect A2 BB_DC_OP VP_BB_DC EXDU_BB en04000507 vsd QB1OPTR bay n sect A2 VPQB1TR bay 1 sect A2 VPQB1TR bay n sect A2 VPDCTR A1 A2 EXDU_BB bay n sect A2 DCOPTR A1 A2 EXDU_BB bay 1 sect A2 EXDU_DC A1 A2 IEC04000507 V1 EN US Figure 178 Signals from any bays in section A2 to a busbar earthing switch in the same section For a busbar ...

Page 331: ... switch these conditions from the B2 busbar section are valid QB2OPTR QB220OTR bay 1 sect B2 BB_DC_OP VP_BB_DC EXDU_BB en04000509 vsd QB2OPTR QB220OTR bay n sect B2 VPQB2TR VQB220TR bay 1 sect B2 VPQB2TR VQB220TR bay n sect B2 VPDCTR B1 B2 EXDU_BB bay n sect B2 DCOPTR B1 B2 EXDU_BB bay 1 sect B2 EXDU_DC B1 B2 IEC04000509 V1 EN US Figure 180 Signals from any bays in section B2 to a busbar earthing ...

Page 332: ...derive the signals Signal BB_DC_OP All disconnectors of this part of the busbar are open VP_BB_DC The switch status of all disconnectors on this part of the busbar are valid EXDU_BB No transmission error from any bay that contains the above information These signals from each double breaker bay DB_BUS are needed Signal QB1OPTR QB1 is open QB2OPTR QB2 is open VPQB1TR The switch status of QB1 is val...

Page 333: ...vsd BH_LINE IEC04000512 V1 EN US Figure 183 Busbars divided by bus section disconnectors circuit breakers The project specific logic are the same as for the logic for the double busbar configuration described in section Signals in single breaker arrangement Signal BB_DC_OP All disconnectors on this part of the busbar are open VP_BB_DC The switch status of all disconnectors on this part of the busb...

Page 334: ...appropriate inputs to open state and disregard the outputs In the functional block diagram 0 and 1 are designated 0 FALSE and 1 TRUE QB9_OP 1 QB9_CL 0 QC9_OP 1 QC9_CL 0 If in this case line voltage supervision is added then rather than setting QB9 to open state specify the state of the voltage supervision QB9_OP VOLT_OFF QB9_CL VOLT_ON If there is no voltage supervision then set the corresponding ...

Page 335: ...to a busbar BH_CONN is the connection between the two lines of the diameter in the 1 1 2 breaker switchyard layout M13569 4 v4 For a 1 1 2 breaker arrangement the modules BH_LINE_A BH_CONN and BH_LINE_B must be used 12 4 9 2 Configuration setting 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...

Page 336: ... UP and DOWN one blocking input BLOCK and one operator position input PSTO SLGAPC can be activated both from the local HMI and from external sources switches via the IED binary inputs It also allows the operation from remote like the station computer SWPOSN is an integer value output giving the actual output number Since the number of positions of the switch can be established by settings see belo...

Page 337: ... it in the configuration through the outputs POS1 and POS2 as well as a command function controlled by the PSTO input giving switching commands through the CMDPOS12 and CMDPOS21 outputs The output POSITION is an integer output showing the actual position as an integer number 0 3 where 0 MidPos 1 Open 2 Closed and 3 Error An example where VSGAPC is configured to switch Autorecloser on off from a bu...

Page 338: ... function block in which systems equipment or functions should receive this information More specifically DPGAPC function reports a combined double point position indication output POSITION by evaluating the value and the timestamp attributes of the inputs OPEN and CLOSE together with the logical input signal VALID When the input signal VALID is active the values of the OPEN and CLOSE inputs deter...

Page 339: ...of the result of the commands is supposed to be achieved by other means such as binary inputs and SPGAPC function blocks PSTO is the universal operator place selector for all control functions Even if PSTO can be configured to allow LOCAL or ALL operator positions the only functional position usable with the SPC8GAPC function block is REMOTE 12 8 3 Setting guidelines SEMOD176518 4 v7 The parameter...

Page 340: ...ction block has one setting Operation On Off enabling or disabling the function These names will be seen in the DNP3 communication management tool in PCM600 12 10 Single command 16 signals SINGLECMD SEMOD119849 1 v2 12 10 1 Identification GUID 2217CCC2 5581 407F A4BC 266CD6808984 v1 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Single command ...

Page 341: ...gram for control of a circuit breaker via configuration logic circuits Figure 188 and figure 189 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 Single command function SINGLECMD CMDOUTy OUTy Function n en04000207 vsd Function n IEC04000207 V2 EN US Figure 188 Application example showing a logic diag...

Page 342: ...efined name for each output signal The MODE input sets the outputs to be one of the types Off Steady or Pulse Off sets all outputs to 0 independent of the values sent from the station level that is the operator station or remote control gateway Steady sets the outputs to a steady signal 0 or 1 depending on the values sent from the station level Pulse gives a pulse with 100 ms duration if a value s...

Page 343: ...roximately 0 150 seconds in order to obtain satisfactory minimum duration of the trip pulse to the circuit breaker trip coils OnDelay Used to prevent output signals to be given for spurious inputs Normally set to 0 or a low value OffDelay Defines a delay of the reset of the outputs after the activation conditions no longer are fulfilled It is only used in Steady mode When used for direct tripping ...

Page 344: ...g signals to LEDs and or output contacts on the IED WRNCALH output signal WARNING and the physical outputs allows the user to adapt the warning signal to physical tripping outputs according to the specific application needs 13 3 1 2 Setting guidelines GUID B08F2636 33DA 4937 92EB 1A8AC0909AB4 v2 OperationOn or Off 13 4 Logic for group indication INDCALH 13 4 1 Identification GUID 3B5D4371 420D 424...

Page 345: ... blocks have a designation including the letters QT like ANDQT ORQT etc 13 5 2 Setting guidelines GUID E6BD982D 9E47 4CC2 9666 6E5CABA414C0 v4 There are no settings for AND gates OR gates inverters or XOR gates as well as for ANDQT gates ORQT gates or XORQT gates For normal On Off delay and pulse timers the time delays and pulse lengths are set from the local HMI or via the PST tool Both timers in...

Page 346: ...re logical function blocks in series Always be careful when connecting function blocks with a fast cycle time to function blocks with a slow cycle time Remember to design the logic circuits carefully and always check the execution sequence for different functions In other cases additional time delays must be introduced into the logic schemes to prevent errors for example race between functions 13 ...

Page 347: ...indings parts together with the neutral point current needs to be available to the function This means that three inputs are needed I3PW1CT1 I3PW2CT1 I3P REFPDIF IEC09000619_3_en vsd IEC09000619 V3 EN US Figure 192 REFPDIF function inputs for autotransformer application For normal transformers only one winding and the neutral point is available This means that only two inputs are used Since all gr...

Page 348: ...sum of the values of all the inputs INx that are activated OUT is an integer When all INx where 1 x 16 are activated that is Boolean 1 it corresponds to that integer 65535 is available on the output OUT B16I function is designed for receiving up to 16 booleans input locally If the BLOCK input is activated it will freeze the output at the last value Values of each of the different OUTx from functio...

Page 349: ... 1 where 1 x 16 The sum of all the values on the activated INx will be available on the output OUT as a sum of the values of all the inputs INx that are activated OUT is an integer When all INx where 1 x 16 are activated that is Boolean 1 it corresponds to that integer 65535 is available on the output OUT BTIGAPC function is designed for receiving up to 16 booleans input locally If the BLOCK input...

Page 350: ...onversion function IB16 will transfer a combination of up to 16 binary inputs INx where 1 x 16 to an integer Each INx represents a value according to the table below from 0 to 32768 This follows the general formula INx 2x 1 where 1 x 16 The sum of all the values on the activated INx will be available on the output OUT as a sum of the values of all the inputs INx that are activated OUT is an intege...

Page 351: ...conversion for six zone busbar BCTZCONN 13 10 2 Application GUID 221AFC68 C31C 459F 8301 2A8048CB93CE v1 Integer to Boolean conversion for six zone busbar BCTZCONN is used to transform the zone connection integer signal of each CT from one bay function block into 7 binary logical signals in the six zone busbar differential protection It is intended to facilitate the recording of zone connection in...

Page 352: ...LEAN Bay is connected to Z6 0 32 CZ BOOLEAN Supervision status of the check zone on differential zones Valid only for feeder bays 0 64 Figure 194 shows an example how to use BCTZCONN to facilitate the recording of the zone connection information from one bay say feeder 01 to a disturbance recorder in ACT for any six zone busbar differential protection application IEC16000075 1 en vsdx IEC16000075 ...

Page 353: ...le 48 Output signals Name of OUTx Type Description Value when activated Value when deactivated OUT1 BOOLEAN Output 1 1 0 OUT2 BOOLEAN Output 2 2 0 OUT3 BOOLEAN Output 3 4 0 OUT4 BOOLEAN Output 4 8 0 OUT5 BOOLEAN Output 5 16 0 OUT6 BOOLEAN Output 6 32 0 OUT7 BOOLEAN Output 7 64 0 OUT8 BOOLEAN Output 8 128 0 OUT9 BOOLEAN Output 9 256 0 OUT10 BOOLEAN Output 10 512 0 OUT11 BOOLEAN Output 11 1024 0 OUT...

Page 354: ...e to the 32 bit float representation 99 999 99 seconds tAlarm 999 999 0 seconds 99 999 99 seconds tWarning 999 999 0 seconds Note that tAlarm and tWarning are independent settings that is there is no check if tAlarm tWarning The limit for the overflow supervision is fixed at 999999 9 seconds 13 13 Comparator for integer inputs INTCOMP 13 13 1 Identification GUID 5992B0F2 FC1B 4838 9BAB 2D2542BB264...

Page 355: ...6D 44F231982C59 v2 For absolute comparison between inputs Set the EnaAbs Absolute Set the RefSource Input REF Similarly for Signed comparison between inputs Set the EnaAbs Signed Set the RefSource Input REF 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 betw...

Page 356: ...elected as Set Value If this setting value is less than 0 2 of the set unit then the output INLOW will never pickup 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 EqualBandHigh This setting is used to set the equal condition high band limit in of...

Page 357: ... INPUT crosses below 95 kA If the comparison should be done between two current magnitudes then those current signals need to be connected to function inputs 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 1MRK 505 370 UEN D Section 13 Logic Busbar protection REB670 351 Applicat...

Page 358: ...352 ...

Page 359: ... tool within PCM600 or to station level for example via IEC 61850 The possibility to continuously monitor measured values of active power reactive power currents voltages frequency power factor etc is vital for efficient production transmission and distribution of electrical energy It provides to the system operator fast and easy overview of the present status of the power system Additionally it c...

Page 360: ...XU The CVMMXN function calculates three phase power quantities by using fundamental frequency phasors DFT values of the measured current and voltage signals The measured power quantities are available either as instantaneously calculated quantities or averaged values over a period of time low pass filtered depending on the selected settings It is possible to calibrate the measuring function above ...

Page 361: ...CMSQI VMSQI VNMMXU are depending on the actual hardware TRM and the logic configuration made in PCM600 The parameters for the Measurement functions CVMMXN CMMXU VMMXU CMSQI VMSQI VNMMXU are set via the local HMI or PCM600 GlobalBaseSel Selects the global base value group used by the function to define IBase UBase and SBase Note that this function will only use IBase value Operation Off On Every fu...

Page 362: ... 3U0 Xmin Minimum value for analog signal X set directly in applicable measuring unit This forms the minimum limit of the range Xmax Maximum value for analog signal X This forms the maximum limit of the range XZeroDb Zero point clamping A signal value less than XZeroDb is forced to zero Observe the related zero point clamping settings in Setting group N for CVMMXN UGenZeroDb and IGenZeroDb If meas...

Page 363: ...ed current and voltage The compensation curve will have the characteristic for amplitude and angle compensation of currents as shown in figure 195 example The first phase will be used as reference channel and compared with the curve for calculation of factors The factors will then be used for all related channels IEC05000652 V2 EN US Figure 195 Calibration curves 14 1 4 1 Setting examples SEMOD544...

Page 364: ...ision of active power as shown in table 50 calibration parameters as shown in table 51 Table 49 General settings parameters for the Measurement function Setting Short Description Selected value Comments Operation Operation Off On On Function must be On PowAmpFact Amplitude factor to scale power calculations 1 000 It can be used during commissioning to achieve higher measurement accuracy Typically ...

Page 365: ...range Int Db In 0 001 s 2000 Set Δdb 40 MW that is 2 larger changes than 40 MW will be reported PHiHiLim High High limit physical value of SBase 60 High alarm limit that is extreme overload alarm hence it will be 415 MW PHiLim High limit physical value in of SBase 50 High warning limit that is overload warning hence it will be 371 MW PLowLim Low limit physical value in of SBase 50 Low warning limi...

Page 366: ...mer SEMOD54481 61 v9 Single line diagram for this application is given in figure 197 110kV Busbar 200 1 35 0 1kV 35kV Busbar 500 5 P Q 31 5 MVA 110 36 75 10 5 kV Yy0 d5 UL1L2 IEC09000040 1 en vsd IED IEC09000040 1 EN V1 EN US Figure 197 Single line diagram for transformer application In order to measure the active and reactive power as indicated in figure 197 it is necessary to do the following Se...

Page 367: ...angle compensation have to be used in order to get measurements in aliment with the required direction Mode Selection of measured current and voltage L1L2 Only UL1L2 phase to phase voltage is available k Low pass filter coefficient for power measurement U and I 0 00 Typically no additional filtering is required UGenZeroDb Zero point clamping in of Ubase 25 Set minimum voltage level to 25 IGenZeroD...

Page 368: ... power as indicated in figure 198 it is necessary to do the following 1 Set correctly all CT and VT data and phase angle reference channel PhaseAngleRef using PCM600 for analog input channels 2 Connect in PCM600 measurement function to the generator CT VT inputs 3 Set the setting parameters for relevant Measurement function as shown in the following table Section 14 1MRK 505 370 UEN D Monitoring 3...

Page 369: ...9D5B4B v3 14 2 1 Identification GUID AD96C26E C3E5 4B21 9ED6 12E540954AC3 v4 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Insulation gas monitoring function SSIMG 63 14 2 2 Application GUID A840E38C CC42 4995 A569 A6092DDB81B2 v5 Gas medium supervision SSIMG is used for monitoring the circuit breaker condition Proper arc extinction by the com...

Page 370: ... 4C96 8A67 09600F847F23 v3 14 3 1 Identification GUID 4CE96EF6 42C6 4F2E A190 D288ABF766F6 v3 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Insulation liquid monitoring function SSIML 71 14 3 2 Application GUID 140AA10C 4E93 4C23 AD57 895FADB0DB29 v7 Liquid medium supervision SSIML is used for monitoring the oil insulated device condition For ...

Page 371: ...dentification IEC 60617 identification ANSI IEEE C37 2 device number Breaker monitoring SSCBR 14 4 2 Application GUID 45572680 3A39 4B3C 8639 4E4C5A95AA26 v10 The circuit breaker maintenance is usually based on regular time intervals or the number of operations performed This has some disadvantages because there could be a number of abnormal operations or few operations with high level currents wi...

Page 372: ...e of a circuit breaker Calculation for estimating the remaining life The graph shows that there are 10000 possible operations at the rated operating current and 900 operations at 10 kA and 50 operations at rated fault current Therefore if the interrupted current is 10 kA one operation is equivalent to 10000 900 11 operations at the rated current It is assumed that prior to tripping the remaining l...

Page 373: ...sting in case of an oil circuit breaker Circuit breaker operation monitoring By monitoring the activity of the number of operations it is possible to calculate the number of days the breaker has been inactive Long periods of inactivity degrade the reliability for the protection system Circuit breaker spring charge monitoring For normal circuit breaker operation the circuit breaker spring should be...

Page 374: ...circuit breaker opening travel time CloseTimeCorr Correction factor for circuit breaker closing travel time tTrOpenAlm Setting of alarm level for opening travel time tTrCloseAlm Setting of alarm level for closing travel time OperAlmLevel Alarm limit for number of mechanical operations OperLOLevel Lockout limit for number of mechanical operations CurrExponent Current exponent setting for energy cal...

Page 375: ...ents 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 14 5 3 Setting guidelines IP14841 1 v1 M12811 3 v3 The input parameters for the Event function EVENT can be set individually via the local HMI Ma...

Page 376: ...lished by the disturbance report function DRPRDRE and facilitate a better understanding of the power system behavior and related primary and secondary equipment during and after a disturbance An analysis of the recorded data provides valuable information that can be used to explain a disturbance basis for change of IED setting plan improve existing equipment and so on This information can also be ...

Page 377: ...nes IP14874 1 v1 M12179 64 v9 The setting parameters for the Disturbance report function DRPRDRE are set via the local HMI or PCM600 It is possible to handle up to 40 analog and 352 binary signals either internal signals or signals coming from external inputs The binary signals are identical in all functions that is Disturbance recorder DR Event recorder ER Indication IND Trip value recorder TVR a...

Page 378: ...ED Steady light In Service Flashing light Internal failure Dark No power supply Yellow LED Steady light Triggered on binary signal N with SetLEDx Start or Start and Trip Flashing light The IED is in test mode Red LED Steady light Triggered on binary signal N with SetLEDx Trip or Start and Trip Flashing The IED is in configuration mode Operation M12179 82 v7 The operation of Disturbance report func...

Page 379: ... 6 3 1 Recording times M12179 88 v6 The different recording times for Disturbance report are set the pre fault time post fault time and limit time These recording times affect all sub functions more or less but not the Event list EL function Prefault recording time PreFaultRecT is the recording time before the starting point of the disturbance The setting should be at least 0 1 s to ensure enough ...

Page 380: ...d be activated on positive 1 or negative 0 slope OperationN Disturbance report may trig for binary input N On or not Off TrigLevelN Trig on positive Trig on 1 or negative Trig on 0 slope for binary input N Func103N Function type number 0 255 for binary input N according to IEC 60870 5 103 that is 128 Distance protection 160 overcurrent protection 176 transformer differential protection and 192 lin...

Page 381: ... header Event recorder M12179 444 v4 Event recorder ER function has no dedicated parameters Trip value recorder M12179 442 v3 ZeroAngleRef The parameter defines which analog signal that will be used as phase angle reference for all other analog input signals This signal will also be used for frequency measurement and the measured frequency is used when calculating trip values It is suggested to po...

Page 382: ...850 identification IEC 60617 identification ANSI IEEE C37 2 device number Logical signal status report BINSTATREP 14 7 2 Application GUID F9D225B1 68F7 4D15 AA89 C9211B450D19 v3 The Logical signal status report BINSTATREP function makes it possible to poll signals from various other function blocks BINSTATREP has 16 inputs and 16 outputs The output status follows the inputs and can be read from th...

Page 383: ...alue It is also possible to set the counter to rollover and indicate the overflow as a pulse which lasts up to the first count after rolling over to zero In this case periodic pulses will be generated at multiple overflow of the function 14 8 3 Setting guidelines GUID 5AECCDBC 7385 4D9F 940C 9D4A0E59B106 v1 GUID DA5DA8D7 4821 4BFB 86CC 28658E376270 v2 The parameters for Limit counter L4UFCNT are s...

Page 384: ...onsumer Thereby the voltage distortion must be limited in order to prevent it from spreading to other facilities Voltage harmonic distortion levels can vary drastically depending on the configuration of system These voltage harmonics can damage the equipment as they are designed to operate for certain range of voltage inaccuracy Moreover in four wire distribution systems three phase and neutral th...

Page 385: ...limits are based on measurements which are done at the point of common coupling It should not be applied to either individual pieces of equipment or at locations within a user s facility In most cases harmonic voltages and currents at these locations could be found to be significantly beyond recommended limits at the PCC due to the lack of diversity cancellation and other phenomena that tend to re...

Page 386: ...MMHAI UTHD VTHD 14 11 2 Application GUID 987BCB6C C559 42EE 9AAB 5F71189A58C6 v2 In order to maintain the power quality for better supply harmonics in the system must be monitored Due to the nonlinear loads connected to the system harmonics apart from fundamental frequency component are generated and thereby the system voltage is distorted Voltage distortion appears to have a little effect on oper...

Page 387: ...s at the PCC due to the lack of diversity cancellation and other phenomena that tend to reduce the combined effects of multiple harmonic sources to levels below their algebraic summation 14 11 3 1 Setting procedure on the IED GUID 60CEC5EC 19DC 49E6 946C FE3883B67975 v1 Parameters for VHMMHAI function are set via the local HMI or PCM600 GUID B3611E99 63AD 4722 BFAA 3BC089F9AFF6 v2 Common base IED ...

Page 388: ...c distortion WrnLimit5thHD It defines the warning limit for the calculated fifth harmonic distortion tDelayAlm5thHD It defines the alarm delay time from warning for the calculated fifth harmonic distortion Section 14 1MRK 505 370 UEN D Monitoring 382 Busbar protection REB670 Application manual ...

Page 389: ... pulses from external energy meters An optional number of inputs from an arbitrary input module in IED can be used for this purpose with a frequency of up to 40 Hz The pulse counter logic PCFCNT can also be used as a general purpose counter 15 1 3 Setting guidelines M13396 4 v9 Parameters that can be set individually for each pulse counter from PCM600 Operation Off On tReporting 0 3600s EventMask ...

Page 390: ...n possibility to further increase the total accuracy The function is connected to the instantaneous outputs of CVMMXN as shown in figure 202 CVMMXN P_INST Q_INST ETPMMTR P Q RSTACC RSTDMD STARTACC STOPACC IEC13000190 2 en vsdx IEC13000190 V2 EN US Figure 202 Connection of energy calculation and demand handling function ETPMMTR to the measurements function CVMMXN The energy values can be read throu...

Page 391: ...function ETPMMTR GlobalBaseSel Selects the global base value group used by the function to define IBase UBase and SBase Note that this function will only use IBase value Operation Off On EnaAcc Off On is used to switch the accumulation of energy on and off tEnergy Time interval when energy is measured tEnergyOnPls gives the pulse length ON time of the pulse It should be at least 100 ms when connec...

Page 392: ...386 ...

Page 393: ...when it is not in use Redundancy and PTP cannot be set for the front port Access point 0 as redundant communication and PTP are only available for the rear optical Ethernet ports Subnetwork shows the SCL subnetwork to which the access point is connected This column shows the SCL subnetworks available in the PCM600 project SCL subnetworks can be created deleted in the Subnetworks tab of IEC 61850 C...

Page 394: ...plication manual DHCP can be activated for the front port from the LHMI in Main menu Configuration Communication Ethernet configuration Front port DHCP 1 16 2 Redundant communication 16 2 1 Identification GUID B7AE0374 0336 42B8 90AF 3AE1C79A4116 v1 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number IEC 62439 3 Parallel redundancy protocol PRP IEC ...

Page 395: ...PhyPortB PhyPortA AP1 PhyPortA PhyPortB AP1 PhyPortA PhyPortB AP1 PhyPortB PhyPortA Device 1 Device 2 Device 3 Device 4 IEC16000038 V1 EN US Figure 204 High availability Seamless Redundancy HSR 16 2 3 Setting guidelines GUID 887B0AE2 0F2E 414D 96FD 7EC935C5D2D8 v1 Redundant communication is configured with the Ethernet configuration tool in PCM600 1MRK 505 370 UEN D Section 16 Ethernet based commu...

Page 396: ...ccess point 1 and HSR Access point 3 16 3 Merging unit 16 3 1 Application GUID E630C16F EDB8 40AE A8A2 94189982D15F v1 The IEC UCA 61850 9 2LE process bus communication protocol enables an IED to communicate with devices providing measured values in digital format commonly known as Merging Units MU The rear access points are used for the communication The merging units MU are called so because the...

Page 397: ...The route specifies that when a package is sent to the destination device it should be sent through the selected router If no route is specified the source device will not find the destination device 16 4 2 Setting guidelines GUID 2C4A312A 00DC 44C8 B2D9 CD0822E1C806 v1 Routes are configured using the Ethernet configuration tool in PCM600 Operation for the route can be set to On Off by checking an...

Page 398: ...392 ...

Page 399: ...unication between two or more intelligent electronic devices IEDs from one or several vendors to exchange information and to use it in the performance of their functions and for correct co operation GOOSE Generic Object Oriented Substation Event which is a part of IEC 61850 8 1 standard allows the IEDs to communicate state and control information amongst themselves using a publish subscribe mechan...

Page 400: ...unication Control Protection Control Protection Control and protection GOOSE en05000734 vsd Station HSI MicroSCADA Gateway IED A IED A IED A IED A IED A IEC05000734 V1 EN US Figure 208 Example of a broadcasted GOOSE message 17 2 2 Setting guidelines SEMOD55317 5 v7 There are two settings related to the IEC 61850 8 1 protocol Operation User can set IEC 61850 communication to On or Off Section 17 1M...

Page 401: ...for Measured Value MVGAPC SEMOD55402 1 v3 Application SEMOD55872 5 v10 Generic communication function for measured values MVGAPC function is used to send the instantaneous value of an analog signal to other systems or equipment in the substation It can also be used inside the same IED to attach a RANGE aspect to an analog value and to permit measurement supervision on that value Setting guidelines...

Page 402: ...cation protocol SEMOD172279 v3 17 3 1 Introduction SEMOD166571 1 v2 SEMOD166590 5 v6 Every IED can be provided with communication interfaces enabling it to connect to the process buses in order to get data from analog data acquisition units close to the process primary apparatus commonly known as Merging Units MU The protocol used in this case is the IEC UCA 61850 9 2LE communication protocol The ...

Page 403: ...le The merging units MU are called so because they can gather analog values from one or more measuring transformers sample the data and send the data over process bus to other clients 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 The electr...

Page 404: ...og values from both classical measuring transformers and merging units 17 3 2 Setting guidelines GUID 29B296B3 6185 459F B06F 8E7F0C6C9460 v4 Merging Units MUs have several settings on local HMI under Main menu Configuration Analog modules MUx 92xx The corresponding settings are also available in PST PCM600 Main menu Configuration Communication Merging units configuration MUx 92xx The correspondin...

Page 405: ...d if the IED hardware time synchronization is lost or the synchronization of the MU time is lost or the IED has lost global common synchronization i e GPS IRIG B or PTP SYNCH output will be set if IED hardware time synchronization is lost MUSYNCH output will be set if either of MU or IED hardware time synchronization is lost 17 3 2 2 Loss of communication when used with LDCM GUID 29EFBCB7 2B4F 4AA...

Page 406: ...Function description IEC 61850 identification Function description IEC 61850 identification Accidental energizing protection for synchronous generator AEGPVOC Two step overvoltage protection OV2PTOV Broken conductor check BRCPTOC Four step single phase overcurrent protection PH4SPTOC Capacitor bank protection CBPGAPC Radial feeder protection PAPGAPC Pole discordance protection CCPDSC Instantaneous...

Page 407: ...ime accumulation protection FTAQFVR Insulation liquid monitoring SSIML Fuse failure supervision FUFSPVC Stub protection STBPTOC Generator differential protection GENPDIF Transformer differential protection two winding T2WPDIF Directional Overpower protection GOPPDOP Transformer differential protection three winding T3WPDIF Generator rotor overload protection GRPTTR Automatic voltage control for ta...

Page 408: ... protection mho characteristic ZMHPDIS Thermal overload protection one time constant LFPTTR Fullscheme distance protection quadrilateral for earth faults ZMMAPDIS Loss of voltage check LOVPTUV Fullscheme distance protection quadrilateral for earth faults ZMMPDIS Line differential protection 3 CT sets with inzone transformers 2 3 line ends LT3CPDIF Distance protection zone quadrilateral characteris...

Page 409: ...hannels from different sources refer to the correct phase angle When only one MU is used as an analog source it is theoretically possible to do without time synchronization However this would mean that timestamps for analog and binary data events become uncorrelated If the IED has no time synchronization source configured then the binary data events will be synchronized with the merging unit Howev...

Page 410: ... be blocked when global common synchronization is lost 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 Two status monitoring signals can be SYNCH signal on the MUx function block indicates that protection fu...

Page 411: ...tion Time Synchronization TIMESYNCHGEN 1 General fineSyncSource can be set to something different to correlate events and data to other IEDs in the station Two status monitoring signals can be SYNCH signal on the MUx function block indicates that protection functions are blocked due to loss of internal time synchronization to the IED MUSYNCH signal on the MUx function block monitors the synchroniz...

Page 412: ...e from the clock If PPS is used for 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 SYNCH signal on the MUx function block indicates that protection functions are blocked due to loss of internal time synchronization to the IED that is loss of the hardware sync...

Page 413: ...s are not blocked To get higher availability in protection functions it is possible to avoid blocking during time synchronization loss if there is a single source of analog data This means that if there is only one physical MU and no TRM parameter SyncLostMode is set to No block but parameter HwSyncSrc is still set to PPS This maintains analog and binary data correlation in disturbance recordings ...

Page 414: ...re do not reflect the quality bits in real time 17 4 LON communication protocol IP14420 1 v1 17 4 1 Application IP14863 1 v1 M14804 3 v6 Control Center IED IED IED Gateway Star coupler RER 111 Station HSI MicroSCADA IEC05000663 1 en vsd IEC05000663 V2 EN US Figure 220 Example of LON communication structure for a substation automation system An optical network can be used within the substation auto...

Page 415: ... Monitor application library LIB520 is required The HV Control 670 software module is included in the LIB520 high voltage process package which is a part of the Application Software Library in MicroSCADA applications The HV Control 670 software module is used for control functions in the IEDs The module contains a process picture dialogues and a tool to generate a process database for the control ...

Page 416: ... 4 2 3 Setting guidelines SEMOD119915 1 v1 Settings M14789 4 v3 The parameters for the multiple command function are set via PCM600 The Mode setting sets the outputs to either a Steady or Pulsed mode 17 5 SPA communication protocol IP14614 1 v1 17 5 1 Application IP14785 1 v1 SEMOD115767 5 v7 SPA communication protocol is an alternative to IEC 60870 5 103 and they use the same rear communication p...

Page 417: ... protocol V2 5 refer to SPA bus Communication Protocol V2 5 17 5 2 Setting guidelines M11876 3 v7 SPA IEC 60870 5 103 and DNP3 use the same rear communication port This port can be set for SPA use on the local HMI under Main menu Configuration Communication Station communication Port configuration SLM optical serial port PROTOCOL 1 When the communication protocol is selected the IED is automatical...

Page 418: ...7109 3 v7 TCP IP Control Center IED IED IED Gateway Star coupler Station HSI IEC05000660 4 en vsd IEC05000660 V4 EN US Figure 222 Example of IEC 60870 5 103 communication structure for a substation automation system IEC 60870 5 103 communication protocol is mainly used when a protection IED communicates with a third party control or monitoring system This system must have software that can interpr...

Page 419: ...erminal Unit RTU in the station using the SPA IEC port the only hardware needed is Optical fibers glass plastic Opto electrical converter for the PC RTU PC RTU Commands M17109 62 v4 The commands defined in the IEC 60870 5 103 protocol are represented in dedicated function blocks These blocks have output signals for all available commands according to the protocol For more information refer to the ...

Page 420: ...irection Function block with defined functions for earth fault indications in monitor direction I103EF This block includes the FUNCTION TYPE parameter and the INFORMATION NUMBER parameter is defined for each output signal Fault indications in monitor direction Function block with defined functions for fault indications in monitor direction I103FLTPROT This block includes the FUNCTION TYPE paramete...

Page 421: ...e report in the Technical reference manual The analog channels that are reported are those connected to the disturbance function blocks A1RADR to A4RADR The eight first ones belong to the public range and the remaining ones to the private range 17 6 2 Settings M17109 116 v1 17 6 2 1 Settings for RS485 and optical serial communication M17109 118 v12 General settings SPA DNP and IEC 60870 5 103 can ...

Page 422: ... being delivered after a new spontaneous event the pending GI event is modified to contain the same value as the spontaneous event As a result the GI dataset is not time correlated 17 6 2 2 Settings from PCM600 M17109 132 v2 I103USEDEF GUID A41170D6 2846 4E5E 8B7F 85B53D4EF6B6 v1 For each input of the I103USEDEF function there is a setting for the information number of the connected signal The inf...

Page 423: ...e processed The channels on disturbance recorder are sent with an ACC as shown in Table 56 Table 56 Channels on disturbance recorder sent with a given ACC DRA Input ACC IEC 60870 5 103 meaning 1 1 IL1 2 2 IL2 3 3 IL3 4 4 IN 5 5 UL1 6 6 UL2 7 7 UL3 8 8 UN 9 64 Private range 10 65 Private range 11 66 Private range 12 67 Private range 13 68 Private range 14 69 Private range 15 70 Private range 16 71 ...

Page 424: ...cation protocol IEC 60870 5 103 To support the information corresponding functions must be included in the protection IED There is no representation for the following parts Generating events for test mode Cause of transmission Info no 11 Local operation Glass or plastic fiber should be used BFOC 2 5 is the recommended interface to use BFOC 2 5 is the same as ST connectors ST connectors are used wi...

Page 425: ... trips In addition to this there are application possibilities for example blocking enabling functionality in the remote substation changing setting group in the remote IED depending on the switching situation in the local substation and so on If equipped with a 64kbit s LDCM module the IED can be configured to send either 192 binary signals or 3 analog and 8 binary signals to a remote IED If equi...

Page 426: ...tup results in a master master master configuration but without the benefit of reverting to a slave master slave configuration in case of a communication link interruption In case of a communication link interruption all three IEDs would be blocked 18 1 2 1 Communication hardware solutions M12844 11 v7 The LDCM Line Data Communication Module has an optical connection such that two IEDs can be conn...

Page 427: ...ions in substations where dynamic zone selection is required it is typically necessary to wire the normally open and normally closed auxiliary contacts from every monitored disconnector and or circuit breaker to the optocoupler inputs of the busbar protection When one phase version of REB670 is used then six optocoupler inputs that is two in each phase IED are required for every primary switchgear...

Page 428: ...ems However time delay caused by LDCM communication can be crucial for circuit breakers status In such cases it is strongly recommended that at least the circuit breaker closing command from every circuit breaker is directly wired to all three phases IEDs to minimize any risk for unwanted operation of the busbar differential protection zones due to late inclusion of respective bay current into the...

Page 429: ...t 306 set TerminalNo to 4 and RemoteTermNo to 3 The redundant channel is always configured to the lower position for example Slot 305 main channel Slot 306 redundant channel The same is applicable for slot 312 313 and slot 322 323 DiffSync defines the method of time synchronization for the line differential function Echo or GPS Using Echo in this case is safe only if there is no risk of varying tr...

Page 430: ...m receiver sensitivity 32 5 dBm 32 5 dBm 30 dBm 30 dBm Optical link budget2 11 5 dB 18 8 dB 26 8 dB 28 7 dB 1 Minimum output power is measured with 1 m of the selected fiber and the high power mode 2 The optical budget includes a satisfactory margin for aging in transmitter and receiver during 20 30 years Table 58 Example of input data for calculating the optical budget maximum distance Type of LD...

Page 431: ...efines the time delay for communication failure alarm reset RedChSwTime defines the time delay before switching over to a redundant channel in case of primary channel failure RedChRturnTime defines the time delay before switching back to the primary channel after channel failure AsymDelay denotes asymmetry which is defined as transmission delay minus receive delay If fixed asymmetry is known Echo ...

Page 432: ...2 is used instead of the TRM this parameter shall be set to 5 CompRange value indicates the current peak value over which truncation is made To set this value knowledge of fault current levels is required It is recommended to set the minimum range that will cover the expected fault current value For example if a 40kA fault level is expected on the network the 0 50kA settings range should be chosen...

Page 433: ... indicate possible faults through a hardware contact on the power supply module and or through the communication Internal events are generated by the built in supervisory functions The supervisory functions supervise the status of the various modules in the IED and in case of failure a corresponding event is generated Similarly when the failure is corrected a corresponding event is generated Apart...

Page 434: ...rom test mode Change of active setting group 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 GUID 8C333BC0 AA7A 4ED1 A772 18C22E8EEE62 v6 When CHNGLCK has a logical one on its input then all attempts to modify the IED configuration and setting wi...

Page 435: ...Access point diagnostics function block measure the IED load from communication and if necessary limit it for not jeopardizing the IEDs control and protection functionality due to high CPU load The function has the following denial of service related outputs LINKSTS indicates the Ethernet link status for the rear ports single communication CHALISTS and CHBLISTS indicates the Ethernet link status f...

Page 436: ...430 ...

Page 437: ... visible on the local HMI under Main menu Diagnostics IED status Product identifiers and under Main menu Diagnostics IED Status Identifiers ProductVer ProductDef FirmwareVer SerialNo OrderingNo ProductionDate IEDProdType Figure 228 IED summary This information is very helpful when interacting with ABB product support for example during repair and maintenance 20 2 2 Factory defined settings M11789 ...

Page 438: ...ning line protection SerialNo OrderingNo ProductionDate 20 3 Measured value expander block RANGE_XP SEMOD52451 1 v2 20 3 1 Identification SEMOD113212 2 v3 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Measured value expander block RANGE_XP 20 3 2 Application SEMOD52434 4 v6 The current and voltage measurements functions CVMMXN CMMXU VMMXU and ...

Page 439: ...ilable in the IED Any of them can be activated through the different programmable binary inputs by means of external or internal control signals A function block SETGRPS defines how many setting groups are used Setting is done with parameter MAXSETGR and shall be set to the required value for each IED Only the number of setting groups set will be available in the Parameter Setting tool for activat...

Page 440: ...ference The reference DFT block InternalDFT Ref DFTRefGrp1 or External DFT ref DFTRefGrp1 This setting means use own internal adaptive DFT reference this setting makes the SUM3PH self DFT adaptive that is it will use the measured frequency for the summation signal to adapt DFT InternalDFTRef Gives fixed window DFT to nominal system frequency ExternalDFTRef This setting means that the DFT samples p...

Page 441: ...ut the IED typically SBase 3 UBase IBase 20 8 Signal matrix for binary inputs SMBI SEMOD55793 1 v2 20 8 1 Application M15310 3 v2 The Signal matrix for binary inputs function SMBI is used within the Application Configuration tool in direct relation with the Signal Matrix tool SMBI represents the way binary inputs are brought in for one IED configuration 20 8 2 Setting guidelines M15312 3 v3 There ...

Page 442: ...nents and so on This information is then used by the respective functions connected to this SMAI block in ACT for example protection measurement or monitoring functions 20 11 2 Frequency values GUID B494B93C B5AA 4FD6 8080 8611C34C2AD8 v5 The SMAI function includes a functionality based on the level of positive sequence voltage MinValFreqMeas to validate if the frequency measurement is valid or no...

Page 443: ...s and one neutral value either voltage or current SMAI outputs give information about every aspect of the 3ph analog signals acquired phase angle RMS value frequency and frequency derivates and so on 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 Application functions should be connected to a SMA...

Page 444: ...alogInputType of a SMAI block to Current the MinValFreqMeas is still visible However using the current channel values as base for frequency measurement is not recommendable for a number of reasons not last among them being the low level of currents that one can have in normal operating conditions Examples of adaptive frequency tracking Preprocessing block shall only be used to feed functions withi...

Page 445: ...h4 IEC07000197 V2 EN US Figure 230 Twelve SMAI instances are grouped within one task time SMAI blocks are available in three different task times in the IED Two pointed instances are used in the following examples The examples shows a situation with adaptive frequency tracking with one reference selected for all instances In practice each instance can be adapted to the needs of the actual applicat...

Page 446: ...ive sequence voltage is used for the frequency tracking feature For task time group 1 this gives the following settings see Figure 230 for numbering SMAI1 1 DFTRefExtOut DFTRefGrp7 to route SMAI7 7 reference to the SPFCOUT output DFTReference DFTRefGrp7 for SMAI1 1 to use SMAI7 7 as reference see Figure 231 SMAI2 2 SMAI12 12 DFTReference DFTRefGrp7 for SMAI2 2 SMAI12 12 to use SMAI7 7 as reference...

Page 447: ...e group 2 this gives the following settings SMAI1 13 DFTRefExtOut DFTRefGrp4 to route SMAI4 16 reference to the SPFCOUT output DFTReference DFTRefGrp4 for SMAI1 13 to use SMAI4 16 as reference see Figure 232 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 in...

Page 448: ...in Communication protocol manual IEC 61850 Edition 2 When the function block TESTMODE is in test mode the Start LED on the LHMI is turned on with steady light The parameter Mod of any specific function block can be configured under Main menu Test Function test modes Communication Station Communication The parameter Mod can be set on the LHMI to the same values as for the DataObject Mod of the Root...

Page 449: ...re two possible ways to place the IED in the TestMode On state If the IED is set to normal operation TestMode Off but the functions are still shown being in the test mode the input signal IED_TEST on the TESTMODE function block is activated in the configuration Forcing of binary input and output signals is only possible when the IED is in IED test mode 20 13 Time synchronization TIMESYNCHGEN IP175...

Page 450: ...bout PTP see the Technical manual IEEE 1588 PTP PTP according to IEEE 1588 2008 and specifically its profile IEC IEEE 61850 9 3 for power utility automation is a synchronization method that can be used to maintain a common time within a station This time can be synchronized to the global time using for instance a GPS receiver If PTP is enabled on the IEDs and the switches that connect the station ...

Page 451: ...can have the following values Off SNTP Server Set the course time synchronizing source CoarseSyncSrc to Off when GPS time synchronization of line differential function is used Set the fine time synchronization source FineSyncSource to GPS The GPS will thus provide the complete time synchronization GPS alone shall synchronize the analogue values in such systems IEEE 1588 PTP GUID 424227EC 74A1 4628...

Page 452: ...dary clock to provide synch to the SAM600 The REL contains a GTM card which has a PPS output that is used to synchronize merging units that are not 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 On the REL the parameter FineSyncSource under Configuration Time Synchronization TIME...

Page 453: ...global common time is lost If PTP is not used use the same synchronization method for the HwSyncSrc as the merging unit provides For instance if the merging unit provides PPS as synchronization use PPS as HwSyncSrc If either PMU or LDCM in GPS mode is used that is the hardware and software clocks are connected to each other HwSyncSrc is not used and other means to synchronize the merging unit to t...

Page 454: ...448 ...

Page 455: ...maximum 10 of the saturation flux The Non Remanence type with big airgaps in the iron core and the remanent flux can be neglected Even though no limit of the remanent flux is specified in the IEC standard for closed core CTs it is a common opinion that the remanent flux is normally limited to maximum 75 80 of the saturation flux Since approximately year 2000 some CT manufactures have introduced ne...

Page 456: ... unit protections for external faults 2 Unacceptably delayed or even missing operation of all types of protections for example distance differential overcurrent etc which can result in loosing protection selectivity in the network No information is available about how frequent the use of the new iron core material is for protection CT cores but it is known that some CT manufacturers are using the ...

Page 457: ...ymmetrical fault current will not exist in all phases at the same time 21 1 3 Fault current M11613 3 v1 M11613 4 v4 The current transformer requirements are based on the maximum fault current for faults in different positions Maximum fault current will occur for three phase faults or single phase to earth faults The current for a single phase to earth fault will exceed the current for a three phas...

Page 458: ... 3 v2 With regard to saturation of the current transformer all current transformers of high remanence and low remanence type that fulfill the requirements on the rated equivalent limiting secondary e m f Eal below can be used The characteristic of the non remanence type CT TPZ is not well defined as far as the phase angle error is concerned If no explicit recommendation is given for a specific fun...

Page 459: ...r equal to required secondary e m f Ealreq below sr R al alreq f max ct L 2 pr r I S E E 0 2 I R R I I æ ö ç è ø EQUATION1536 V2 EN US Equation 94 21 1 6 2 Breaker failure protection M11621 3 v5 The CTs must have a rated equivalent limiting secondary e m f Eal that is larger than or equal to the required rated equivalent limiting secondary e m f Ealreq below sr R al alreq op ct L 2 pr r I S E E 5 ...

Page 460: ...of an IED current input channel VA SR 0 020 VA channel for Ir 1 A and SR 0 150 VA channel for Ir 5 A 21 1 6 4 Non directional inverse time delayed phase and residual overcurrent protection M11339 3 v5 The requirement according to Equation 97 and Equation 98 does not need to be fulfilled if the high set instantaneous or definitive time stage is used In this case Equation is the only necessary requi...

Page 461: ...plications it is possible to approximately calculate a secondary e m f of the CT comparable with Eal By comparing this with the required rated equivalent limiting secondary e m f Ealreq it is possible to judge if the CT fulfills the requirements The requirements according to some other standards are specified below 21 1 7 1 Current transformers according to IEC 61869 2 class P PR M11623 6 v4 A CT ...

Page 462: ...r the specific C class W UANSI The secondary terminal voltage for the specific C class V The CTs according to class C must have a calculated rated equivalent limiting secondary e m f EalANSI that fulfils the following alANSI alreq E maximum of E EQUATION1384 V2 EN US Equation 102 A CT according to ANSI IEEE is also specified by the knee point voltage UkneeANSI that is graphically defined from an e...

Page 463: ...ents GUID 741CC863 D760 49D6 85B2 AFECA222A8C3 v1 For PTP to perform properly the Ethernet equipment that is used needs to be compliant with IEEE1588 The clocks used must follow the IEEE1588 standard BMC Best Master Algorithm and shall for instance not claim class 7 for a longer time than it can guarantee 1us absolute accuracy 21 5 Sample specification of communication requirements for the protect...

Page 464: ... 11 v5 The merging units that supply the IED with measured values via the process bus must fulfill the IEC UCA 61850 9 2LE standard This part of the IEC 61850 is specifying Communication Service Mapping SCSM Sampled values over ISO IEC 8802 in other words sampled data over Ethernet The 9 2 part of the IEC 61850 protocol uses also definitions from 7 2 Basic communication structure for substation an...

Page 465: ...step response truncating A D conversion inaccuracy time tagging accuracy etc In principle the accuracy of the current and voltage transformers together with the merging unit shall have the same quality as direct input of currents and voltages 1MRK 505 370 UEN D Section 21 Requirements Busbar protection REB670 459 Application manual ...

Page 466: ...460 ...

Page 467: ...ule BOS Binary outputs status BR External bistable relay BS British Standards BSR Binary signal transfer function receiver blocks BST Binary signal transfer function transmit blocks C37 94 IEEE ANSI protocol used when sending binary signals between IEDs CAN Controller Area Network ISO standard ISO 11898 for serial communication CB Circuit breaker CBM Combined backplane module CCITT Consultative Co...

Page 468: ...Communication unit CVT or CCVT Capacitive voltage transformer DAR 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 DC Direct current DFC Data flow control DFT Discrete Fourier transform DHCP Dynamic Host Configuration Protocol DIP switch Small switch mounted on a printed circuit board D...

Page 469: ... command GIS Gas insulated switchgear GOOSE Generic object oriented substation event GPS Global positioning system GSAL Generic security application GSE Generic substation event HDLC protocol High level data link control protocol based on the HDLC standard HFBR connector type Plastic fiber connector HLV circuit Hazardous Live Voltage according to IEC60255 27 HMI Human machine interface HSAR High s...

Page 470: ...ay an instance of a function in the IED is representative of a type of function IP 1 Internet protocol The network layer for the TCP IP protocol suite widely used on Ethernet networks IP is a connectionless best effort packet switching protocol It provides packet routing fragmentation and reassembly through the data link layer 2 Ingression protection according to IEC 60529 IP 20 Ingression protect...

Page 471: ... Low Voltage circuit type according to IEC60255 27 PMC PCI Mezzanine card POR Permissive overreach POTT Permissive overreach transfer trip Process bus Bus or LAN used at the process level that is in near proximity to the measured and or controlled components PRP Parallel redundancy protocol PSM Power supply module PST Parameter setting tool within PCM600 PTP Precision time protocol PT ratio Potent...

Page 472: ... communication SRY Switch for CB ready condition ST Switch or push button to trip Starpoint Neutral point of transformer or generator SVC Static VAr compensation TC Trip coil TCS Trip circuit supervision TCP Transmission control protocol The most common transport layer protocol used on Ethernet and the Internet TCP IP Transmission control protocol over Internet Protocol The de facto standard Ether...

Page 473: ... Atomic Time TAI by the addition of a whole number of leap seconds to synchronize it with Universal Time 1 UT1 thus allowing for the eccentricity of the Earth s orbit the rotational axis tilt 23 5 degrees but still showing the Earth s irregular rotation on which UT1 is based The Coordinated Universal Time is expressed using a 24 hour clock and uses the Gregorian calendar It is used for aeroplane a...

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Page 476: ...B AB Grid Automation Products SE 721 59 Västerås Sweden Phone 46 0 21 32 50 00 www abb com protection control Copyright 2017 ABB All rights reserved Scan this QR code to visit our website 1MRK 505 370 UEN ...

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