ABB REL670 2.2 IEC Applications Manual Download Page 500

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AngleRCA

Forward

Area

Iop = I2

Upol=-U2

Reverse

Area

IEC10000031-1-en.vsd

IEC10000031 V1 EN-US

Figure 272:

Relay characteristic angle given in degree

In a transmission network a normal value of RCA is about 80°.

UPolMin

: Minimum polarization (reference) voltage % of

UBase

I>Dir

: Operate residual current level for directional comparison scheme. The

setting is given 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.

9.6

Sensitive directional residual overcurrent and power

protection SDEPSDE

SEMOD171436-1 v4

Section 9

1MRK 506 369-UEN B

Current protection

494

Line distance protection REL670 2.2 IEC

Application manual

Summary of Contents for REL670 2.2 IEC

Page 1: ...RELION 670 SERIES Line distance protection REL670 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: ... Communication 55 Basic IED functions 57 Section 3 Configuration 59 Introduction 59 Description of configuration REL670 60 Introduction 60 Description of configuration A41 60 Description of configuration A42 61 Description of configuration B42 62 Description of configuration D42 63 Section 4 Analog inputs 65 Introduction 65 Setting guidelines 65 Setting of the phase reference channel 66 Example 66...

Page 8: ...high impedance earthed or unearthed networks 89 Example how to connect the open delta VT to the IED for low impedance earthed or solidly earthed power systems 92 Section 5 Local HMI 95 Display 96 LEDs 98 Keypad 99 Local HMI functionality 101 Protection and alarm indication 101 Parameter management 102 Front communication 103 Section 6 Wide area measurement system 105 C37 118 Phasor Measurement Dat...

Page 9: ...tion 142 Alarm level operation 145 Section 8 Impedance protection 147 Distance measuring zone quadrilateral characteristic for series compensated lines ZMCPDIS ZMCAPDIS ZDSRDIR 147 Identification 147 Application 147 Introduction 147 System earthing 148 Fault infeed from remote end 149 Load encroachment 150 Long transmission line application 151 Parallel line application with mutual coupling 152 Ta...

Page 10: ...teristic ZMQPDIS ZMQAPDIS ZDRDIR 209 Identification 209 Application 209 System earthing 210 Fault infeed from remote end 213 Load encroachment 214 Short line application 215 Long transmission line application 216 Parallel line application with mutual coupling 217 Tapped line application 223 Setting guidelines 226 General 226 Setting of zone 1 226 Setting of overreaching zone 226 Setting of reverse...

Page 11: ...el circuits 257 Load impedance limitation without load encroachment function 257 Load impedance limitation with load encroachment function activated 259 Setting of minimum operate currents 260 Setting of directional mode 260 Setting of direction for offset mho 260 Setting of timers for distance protection zones 260 Full scheme distance protection quadrilateral for earth faults ZMMPDIS ZMMAPDIS 261...

Page 12: ...entification with load encroachment FMPSPDIS 286 Identification 286 Application 286 Setting guidelines 287 Load encroachment 288 Distance protection zone quadrilateral characteristic separate settings ZMRPDIS ZMRAPDIS and ZDRDIR 289 Identification 290 Application 290 System earthing 290 Fault infeed from remote end 294 Load encroachment 295 Short line application 296 Long transmission line applica...

Page 13: ...on 325 Identification 325 Application 325 Setting guidelines 326 Load encroachment characteristics 326 Resistive reach with load encroachment characteristic 331 Minimum operate currents 332 High speed distance protection ZMFPDIS 332 Identification 332 Application 332 System earthing 332 Fault infeed from remote end 336 Load encroachment 337 Short line application 338 Long transmission line applica...

Page 14: ...ED of adjacent lines 384 Distance protection 385 Underreaching and overreaching schemes 386 Setting guidelines 392 General 392 Setting of zone 1 393 Setting of overreaching zone 393 Setting of reverse zone 394 Series compensated and adjacent lines 395 Setting of zones for parallel line application 399 Setting of reach in resistive direction 400 Load impedance limitation without load encroachment f...

Page 15: ... preference logic PPLPHIZ 445 Identification 445 Application 445 Setting guidelines 448 Phase preference logic PPL2PHIZ 449 Identification 449 Application 449 Setting guidelines 453 Section 9 Current protection 455 Instantaneous phase overcurrent protection PHPIOC 455 Identification 455 Application 455 Setting guidelines 456 Meshed network without parallel line 456 Meshed network with parallel lin...

Page 16: ...idual overcurrent and power protection SDEPSDE 494 Identification 495 Application 495 Setting guidelines 496 Thermal overload protection one time constant Celsius Fahrenheit LCPTTR LFPTTR 505 Identification 505 Application 505 Setting guideline 506 Breaker failure protection CCRBRF 507 Identification 507 Application 507 Setting guidelines 507 Stub protection STBPTOC 511 Identification 511 Applicat...

Page 17: ...3 Application 533 Setting guidelines 534 Equipment protection such as for motors and generators 534 Disconnected equipment detection 534 Power supply quality 534 Voltage instability mitigation 534 Backup protection for power system faults 534 Settings for two step undervoltage protection 535 Two step overvoltage protection OV2PTOV 536 Identification 536 Application 537 Setting guidelines 537 Equip...

Page 18: ...ltage differential protection VDCPTOV 552 Identification 552 Application 552 Setting guidelines 554 Loss of voltage check LOVPTUV 555 Identification 555 Application 556 Setting guidelines 556 Advanced users settings 556 Radial feeder protection PAPGAPC 556 Identification 556 Application 556 Setting guidelines 557 Section 11 Frequency protection 559 Underfrequency protection SAPTUF 559 Identificati...

Page 19: ...s 577 Voltage restrained overcurrent protection for generator and step up transformer 578 Loss of excitation protection for a generator 579 Section 13 System protection and control 581 Multipurpose filter SMAIHPAC 581 Identification 581 Application 581 Setting guidelines 582 Setting example 582 Section 14 Secondary system supervision 587 Current circuit supervision CCSSPVC 587 Identification 587 A...

Page 20: ...ation 613 Auto reclosing operation Off and On 617 Start auto reclosing and conditions for start of a reclosing cycle 617 Start auto reclosing from circuit breaker open information 618 Blocking of the auto recloser 618 Control of the auto reclosing dead time for shot 1 618 Long trip signal 619 Maximum number of reclosing shots 619 ARMode 3ph normal setting for a three phase shot 619 ARMode 1 2 3ph ...

Page 21: ...nd RESIN 649 Interaction between modules 651 Setting guidelines 653 Bay control QCBAY 654 Switch controller SCSWI 654 Switch SXCBR SXSWI 655 Proxy for signals from switching device via GOOSE XLNPROXY 656 Bay Reserve QCRSV 656 Reservation input RESIN 657 Interlocking 657 Configuration guidelines 658 Interlocking for line bay ABC_LINE 658 Application 658 Signals from bypass busbar 659 Signals from b...

Page 22: ...guration setting 689 Interlocking for 1 1 2 CB BH 690 Application 690 Configuration setting 690 Logic rotating switch for function selection and LHMI presentation SLGAPC 691 Identification 691 Application 691 Setting guidelines 692 Selector mini switch VSGAPC 692 Identification 692 Application 692 Setting guidelines 693 Generic communication function for Double Point indication DPGAPC 693 Identifi...

Page 23: ...on logic for distance protection ZC1PPSCH 709 Identification 709 Application 709 Blocking scheme 711 Permissive schemes 711 Intertrip scheme 713 Setting guidelines 713 Permissive underreache scheme 713 Permissive overreach scheme 714 Blocking scheme 714 Intertrip scheme 714 Current reversal and Weak end infeed logic for distance protection 3 phase ZCRWPSCH 714 Identification 714 Application 714 Cu...

Page 24: ...fer trip logic 727 Application 727 Setting guidelines 728 Low active power and power factor protection LAPPGAPC 728 Identification 729 Application 729 Setting guidelines 729 Compensated over and undervoltage protection COUVGAPC 730 Identification 730 Application 730 Setting guidelines 732 Sudden change in current variation SCCVPTOC 733 Identification 733 Application 733 Setting guidelines 734 Carr...

Page 25: ...on 17 Logic 741 Tripping logic SMPPTRC 741 Identification 741 Application 741 Three phase tripping 742 Single and or three phase tripping 743 Single two or three phase tripping 744 Lock out 744 Example of directional data 745 Blocking of the function block 747 Setting guidelines 747 Trip matrix logic TMAGAPC 747 Identification 747 Application 748 Setting guidelines 748 Logic for group alarm ALMCAL...

Page 26: ...n 756 Application 756 Integer to Boolean 16 conversion with logic node representation ITBGAPC 757 Identification 757 Application 757 Elapsed time integrator with limit transgression and overflow supervision TEIGAPC 758 Identification 758 Application 758 Setting guidelines 759 Comparator for integer inputs INTCOMP 759 Identification 759 Application 759 Setting guidelines 760 Setting example 760 Com...

Page 27: ... guidelines 783 Disturbance report DRPRDRE 784 Identification 784 Application 784 Setting guidelines 785 Recording times 787 Binary input signals 788 Analog input signals 789 Sub function parameters 789 Consideration 790 Logical signal status report BINSTATREP 791 Identification 791 Application 791 Setting guidelines 792 Fault locator LMBRFLO 792 Identification 792 Application 792 Setting guidelin...

Page 28: ...g unit 807 Application 807 Setting guidelines 808 Routes 808 Application 808 Setting guidelines 808 Section 21 Station communication 809 Communication protocols 809 IEC 61850 8 1 communication protocol 809 Application IEC 61850 8 1 809 Setting guidelines 811 Horizontal communication via GOOSE 811 Sending data 811 Receiving data 812 IEC UCA 61850 9 2LE communication protocol 813 Introduction 813 Se...

Page 29: ... Communication protocol 841 Application 841 Section 22 Remote communication 843 Binary signal transfer 843 Identification 843 Application 843 Communication hardware solutions 844 Setting guidelines 845 Section 23 Security 851 Authority status ATHSTAT 851 Application 851 Self supervision with internal event list INTERRSIG 851 Application 851 Change lock CHNGLCK 852 Application 852 Denial of service...

Page 30: ...SMBI 860 Application 860 Setting guidelines 860 Signal matrix for binary outputs SMBO 860 Application 861 Setting guidelines 861 Signal matrix for mA inputs SMMI 861 Application 861 Setting guidelines 861 Signal matrix for analog inputs SMAI 861 Application 861 Frequency values 862 Setting guidelines 863 Test mode functionality TESTMODE 868 Application 868 IEC 61850 protocol test mode 868 Setting ...

Page 31: ...dards 884 Current transformers according to IEC 61869 2 class P PR 884 Current transformers according to IEC 61869 2 class PX PXR and old IEC 60044 6 class TPS and old British Standard class X 885 Current transformers according to ANSI IEEE 885 Voltage transformer requirements 886 SNTP server requirements 886 PTP requirements 887 Sample specification of communication requirements for the protectio...

Page 32: ...26 ...

Page 33: ...vide 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 communication pr...

Page 34: ...t and insert IEDs to the project structure The manual also recommends a sequence for the engineering of protection and control functions as well as communication engineering for IEC 61850 The installation manual contains instructions on how to install the IED The manual provides procedures for mechanical and electrical installation The chapters are organized in the chronological order in which the...

Page 35: ...an be used as a technical reference during the engineering phase installation and commissioning phase and during normal service The communication protocol manual describes the communication protocols supported by the IED The manual concentrates on the vendor specific implementations The point list manual describes the outlook and properties of the data points specific to the IED The manual should ...

Page 36: ...on protocol manual IEC 61850 Edition 2 1MRK 511 393 UEN Communication protocol manual LON 1MRK 511 395 UEN Communication protocol manual SPA 1MRK 511 396 UEN Point list manual DNP3 1MRK 511 397 UUS Accessories guide 1MRK 514 012 BEN Cyber security deployment guideline 1MRK 511 399 UEN Connection and Installation components 1MRK 513 003 BEN Test system COMBITEST 1MRK 512 001 BEN Application guide C...

Page 37: ...t may result in degraded process performance leading to personal injury or death It is important that the user fully complies with all warning and cautionary notices 1 4 2 Document conventions GUID 96DFAB1A 98FE 4B26 8E90 F7CEB14B1AB6 v8 Abbreviations and acronyms in this manual are spelled out in the glossary The glossary also contains definitions of important terms Push button navigation in the ...

Page 38: ...nd Edition 2 logical nodes are shown in the table below Table 1 IEC 61850 edition 1 edition 2 mapping Function block name Edition 1 logical nodes Edition 2 logical nodes AEGPVOC AEGGAPC AEGPVOC AGSAL AGSAL SECLLN0 AGSAL ALMCALH ALMCALH ALMCALH ALTIM ALTIM ALTMS ALTMS ALTRK ALTRK BCZPDIF BCZPDIF BCZPDIF BCZSPDIF BCZSPDIF BCZSPDIF BCZTPDIF BCZTPDIF BCZTPDIF BDCGAPC SWSGGIO BBCSWI BDCGAPC BDZSGAPC BB...

Page 39: ... 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_B8 BUSPTRC BUSPTRC BUSPTRC_B9 BUSPTRC BUSPTRC BUSPTRC_B10 BUSPTRC BUSPTRC BUSPTRC_B11 BUSPTRC BUSPTRC BUSPTRC_B12 BUSPTRC BUSPTRC BUSPTRC_B...

Page 40: ... 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 BZNTGAPC BZNTPDIF BZNTPDIF_B BZNTPDIF BZBTGAPC BZBTPDIF BZNTGAPC BZNTPDIF CBPG...

Page 41: ... 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 FPSRPDI...

Page 42: ...CPHAR L6CPTRC LAPPGAPC LAPPLLN0 LAPPPDUP 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 LM...

Page 43: ...H3PTRC OEXPVPH OEXPVPH OEXPVPH OOSPPAM OOSPPAM OOSPPAM OOSPTRC OV2PTOV GEN2LLN0 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 R...

Page 44: ... SPC8GAPC SPC8GGIO SPC8GAPC SPGAPC SPGGIO SPGAPC SSCBR SSCBR SSCBR SSIMG SSIMG SSIMG SSIML SSIML SSIML STBPTOC STBPTOC BBPMSS STBPTOC STEFPHIZ STEFPHIZ STEFPHIZ STTIPHIZ STTIPHIZ STTIPHIZ SXCBR SXCBR SXCBR SXSWI SXSWI SXSWI T2WPDIF T2WPDIF T2WGAPC T2WPDIF T2WPHAR T2WPTRC T3WPDIF T3WPDIF T3WGAPC T3WPDIF T3WPHAR T3WPTRC TCLYLTC TCLYLTC TCLYLTC TCSLTC TCMYLTC TCMYLTC TCMYLTC TEIGAPC TEIGGIO TEIGAPC T...

Page 45: ...PCPSCH ZPCPSCH ZC1WPSCH ZPCWPSCH ZPCWPSCH ZCLCPSCH ZCLCPLAL ZCLCPSCH ZCPSCH ZCPSCH ZCPSCH ZCRWPSCH ZCRWPSCH ZCRWPSCH ZCVPSOF 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 Z...

Page 46: ...dition 2 logical nodes ZMQPDIS ZMQPDIS ZMQPDIS ZMRAPDIS ZMRAPDIS ZMRAPDIS ZMRPDIS ZMRPDIS ZMRPDIS ZMRPSB ZMRPSB ZMRPSB ZSMGAPC ZSMGAPC ZSMGAPC Section 1 1MRK 506 369 UEN B Introduction 40 Line distance protection REL670 2 2 IEC Application manual ...

Page 47: ...e earthed or isolated networks It includes phase preference logic to select and trip only one line at cross country faults The autorecloser for single two and or three phase tripping and autoreclosing includes priority features for multi breaker arrangements It co operates with the synchrocheck function with high speed or delayed reclosing A high impedance differential protection can be used to pr...

Page 48: ...venient way to test wiring in substations as well as testing configuration logic in the IEDs Basically it means that all binary inputs and outputs on the IED I O modules BOM BIM IOM SOM can be forced to arbitrary 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 incorpo...

Page 49: ...eristic 0 5 ZDRDIR 21D Directional impedance quadrilateral 0 2 ZMCPDIS ZMCAPDIS 21 Distance measuring zone quadrilateral characteristic for series compensated lines 0 6 ZDSRDIR 21D Directional impedance quadrilateral including series compensation 0 2 FDPSPDIS 21 Phase selection quadrilateral characteristic with fixed angle 0 2 ZMHPDIS 21 Full scheme distance protection mho characteristic 0 5 ZMMPD...

Page 50: ...1 PSPPPAM 78 Poleslip out of step protection 0 2 1 B24 1 B24 1 B24 OOSPPAM 78 Out of step protection 0 1 1 1 1 ZCVPSOF Automatic switch onto fault logic voltage and current based 1 1 1 1 1 2 3 Back up protection functions GUID A8D0852F 807F 4442 8730 E44808E194F0 v13 IEC 61850 or function name ANSI Function description Line Distance REL670 Customized REL670 A41 REL670 A42 REL670 B42 REL670 D42 Cur...

Page 51: ...n 0 2 1 C39 1 C39 1 C39 BRCPTOC 46 Broken conductor check 1 1 1 1 1 VRPVOC 51V Voltage restrained overcurrent protection 0 3 1 1 1 1 Voltage protection UV2PTUV 27 Two step undervoltage protection 0 2 1 1 1 1 OV2PTOV 59 Two step overvoltage protection 0 2 1 1 1 1 ROV2PTOV 59N Two step residual overvoltage protection 0 2 1 1 1 1 OEXPVPH 24 Overexcitation protection 0 1 1 D03 1 D03 1 D03 VDCPTOV 60 V...

Page 52: ...on description Line Distance REL670 Customized REL670 A41 REL670 A42 REL670 B42 REL670 D42 Control SESRSYN 25 Synchrocheck energizing check and synchronizing 0 2 1 1 2 1 SMBRREC 79 Autorecloser 0 4 1 1B 1 H04 2B 2 H05 1B 1 H04 APC10 3 Control functionality for a single bay max 10 objects 1CB including interlocking see Table 4 0 1 1 H37 1 H37 1 H37 APC15 3 Control functionality for a single bay max...

Page 53: ...eneric communicatio n function for Double Point indication 16 16 16 16 16 SPC8GAPC Single point generic control function 8 signals 5 5 5 5 5 AUTOBITS Automation bits command function for DNP3 0 3 3 3 3 3 SINGLECMD Single command 16 signals 4 4 4 4 4 I103CMD Function commands for IEC 60870 5 103 1 1 1 1 1 I103GENCMD Function commands generic for IEC 60870 5 103 50 50 50 50 50 I103POSCMD IED command...

Page 54: ...60 Fuse failure supervision based on voltage difference 0 2 1 G03 1 G03 1 G03 1 G03 Logic SMPPTRC 94 Tripping logic 12 12 12 12 12 SMAGAPC General start matrix block 12 12 12 12 12 STARTCOMB Start combinator 32 32 32 32 32 TMAGAPC Trip matrix logic 12 12 12 12 12 ALMCALH Logic for group alarm 5 5 5 5 5 WRNCALH Logic for group warning 5 5 5 5 5 INDCALH Logic for group indication 5 5 5 5 5 AND GATE ...

Page 55: ... function block 1 1 1 1 1 B16I Boolean to integer conversion 16 bit 18 18 18 18 18 BTIGAPC Boolean to integer conversion with logical node representation 16 bit 16 16 16 16 16 IB16 Integer to Boolean 16 conversion 18 18 18 18 18 ITBGAPC Integer to Boolean 16 conversion with Logic Node representation 16 16 16 16 16 TEIGAPC Elapsed time integrator with limit transgression and overflow supervision 12...

Page 56: ...ances SCILO Interlocking 10 BB_ES 3 A1A2_BS 2 A1A2_DC 3 ABC_BC 1 BH_CONN 1 BH_LINE_A 1 BH_LINE_B 1 DB_BUS_A 1 DB_BUS_B 1 DB_LINE 1 ABC_LINE 1 AB_TRAFO 1 SCSWI Switch controller 10 SXSWI Circuit switch 9 QCRSV Apparatus control 2 RESIN1 1 RESIN2 59 POS_EVAL Evaluation of position indication 10 XLNPROXY Proxy for signals from switching device via GOOSE 12 GOOSEXLNRCV GOOSE function block to receive ...

Page 57: ... 59 POS_EVAL Evaluation of position indication 15 XLNPROXY Proxy for signals from switching device via GOOSE 20 GOOSEXLNRCV GOOSE function block to receive a switching device 20 Table 6 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 INVERTERQT 120 ORQT 120 PULSETIMERQT 40 RSMEMO...

Page 58: ...A42 REL670 B42 REL670 D42 Monitoring CVMMXN Power system measurement 6 6 6 6 6 CMMXU Current measurement 10 10 10 10 10 VMMXU Voltage measurement phase phase 6 6 6 6 6 CMSQI Current sequence measurement 6 6 6 6 6 VMSQI Voltage sequence measurement 6 6 6 6 6 VNMMXU Voltage measurement phase earth 6 6 6 6 6 AISVBAS General service value presentation of analog inputs 1 1 1 1 1 EVENT Event function 20...

Page 59: ... for measured values 24 24 24 24 24 BINSTATREP Logical signal status report 3 3 3 3 3 RANGE_XP Measured value expander block 66 66 66 66 66 SSIMG 63 Insulation supervision for gas medium 21 21 21 21 21 SSIML 71 Insulation supervision for liquid medium 3 3 3 3 3 SSCBR Circuit breaker condition monitoring 0 6 3 3 6 3 LMBRFLO Fault locator 1 1 1 1 1 I103MEAS Measurands for IEC 60870 5 103 1 1 1 1 1 I...

Page 60: ... 103 1 1 1 1 1 I103IED IED status for IEC 60870 5 103 1 1 1 1 1 I103SUPERV Supervison status for IEC 60870 5 103 1 1 1 1 1 I103USRDEF Status for user defined signals for IEC 60870 5 103 20 20 20 20 20 L4UFCNT Event counter with limit supervision 30 30 30 30 30 TEILGAPC Running hour meter 6 6 6 6 6 Metering PCFCNT Pulse counter logic 16 16 16 16 16 ETPMMTR Function for energy calculation and demand...

Page 61: ...e 60 60 60 60 60 GOOSESPRCV GOOSE function block to receive a single point value 64 64 64 64 64 MULTICMDRCV MULTICMDSND Multiple command and transmit 60 10 60 10 60 10 60 10 60 10 AGSAL Generic security application component 1 1 1 1 1 LD0LLN0 IEC 61850 LD0 LLN0 1 1 1 1 1 SYSLLN0 IEC 61850 SYS LLN0 1 1 1 1 1 LPHD Physical device information 1 1 1 1 1 PCMACCS IED configuration protocol 1 1 1 1 1 FST...

Page 62: ...heme communication logic for distance protection 0 2 1 B05 1 B05 1 B05 ZCRWPSCH 85 Current reversal and weak end infeed logic for distance protection 0 2 1 1 1 1 ZC1WPSCH 85 Current reversal and weak end infeed logic for phase segregated communication 0 2 1 B05 1 B05 1 B05 ZCLCPSCH Local acceleration logic 0 1 1 1 1 1 ECPSCH 85 Scheme communication logic for residual overcurrent protection 0 1 1 1...

Page 63: ...BININPUT SYNCHCAN SYNCHGPS SYNCHCMPPS SYNCHLON SYNCHPPH SYNCHPPS SNTP SYNCHSPA Time synchronization TIMEZONE Time synchronization IRIG B Time synchronization SETGRPS Number of setting groups ACTVGRP Parameter setting groups TESTMODE Test mode functionality CHNGLCK Change lock function SMBI Signal matrix for binary inputs SMBO Signal matrix for binary outputs SMMI Signal matrix for mA inputs SMAI1 ...

Page 64: ...avior FNKEYTY1 FNKEYTY5 FNKEYMD1 FNKEYMD5 Parameter setting function for HMI in PCM600 LEDGEN General LED indication 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 506 369 UEN B Application 58 Line distance protection REL670 2 2 IEC Application manual ...

Page 65: ...se tripping arrangement Multi breaker arrangement Single phase tripping arrangement The Multi breaker arrangement includes one and a half breaker and ring breaker arrangements The number of IO must be ordered to the application where more IO is foreseen for the single phase tripping arrangements respectively the multi breaker arrangement The basic delivery includes one binary input module and one ...

Page 66: ...TRC 94 1 0 SES RSYN 25 SC VC ZCV PSOF LOV PTUV 27 3U V MSQI MET Usqi VN MMXU MET UN DRP RDRE DFR SER DR V MMXU MET U LMB RFLO 21FL FL ZMF PDIS 21 Z FUF SPVC U I C MMXU MET I C MSQI MET Isqi CV MMXN MET P Q ETP MMTR MET W Varh S CILO 3 Control S CSWI 3 Control VD SPVC 60 Ud CV GAPC 2 I U Q CRSV 3 Control S XSWI 3 Control UV2 PTUV 27 2 3U OV2 PTOV 59 2 3U CC PDSC 52PD PD BRC PTOC 46 Iub PH PIOC 50 3...

Page 67: ...50N IN PH PIOC 50 3I BRC PTOC 46 Iub S SCBR Control S SCBR Control S SCBR Control Other Functions available from the function library S CILO 3 Control S CSWI 3 Control ROV2 PTOV 59N 2 U0 CCS SPVC 87 INd I VDC PTOV 60 Ud NS4 PTOC 46I2 4 I2 HZ PDIF 87 Id CV GAPC 2 I U Optional Functions ZCLC PSCH Q CBAY 3 Control Q CRSV 3 Control S XSWI 3 Control SDE PSDE 67N IN GUP PDUP 37 P PSL PSCH Zpsl VD SPVC 6...

Page 68: ... Zpsl ZC PSCH 85 SMB RREC 79 0 1 SMP PTRC 94 1 0 SES RSYN 25 SC FUF SPVC U I Σ CC PDSC 52PD PD S CILO 3 Control Q CBAY 3 Control S CSWI 3 Control Q CRSV 3 Control S XSWI 3 Control CC RBRF 50BF 3I BF CC RBRF 50BF 3I BF ZCV PSOF PH PIOC 50 3I EF4 PTOC 51N_67N 4 IN OC4 PTOC 51_67 4 3I C MMXU MET I OV2 PTOV 59 2 3U EC PSCH 85 LOV PTUV 27 3U ECRW PSCH 85 VN MMXU MET UN VN MMXU MET UN VN MMXU MET UN WA1...

Page 69: ...FL EC PSCH 85 ZCRW PSCH 85 ZC PSCH 85 ZM RPSB 68 Zpsb ZMF PDIS 21 Z ZCV PSOF FUF SPVC U I SDE PSDE 67N IN GUP PDUP 37 P PSL PSCH Zpsl VD SPVC 60 Ud OEX PVPH 24 U f GOP PDOP 32 P SA PFRC 81 df dt SA PTOF 81 f SA PTUF 81 f PSP PPAM 78 Ucos OOS PPAM 78 Ucos DRP RDRE DFR SER DR OV2 PTOV 59 2 3U ECRW PSCH 85 LOV PTUV 27 3U C MMXU MET I C MSQI MET Isqi ETP MMTR MET W Varh CV MMXN MET P Q ZC1P PSCH 85 ZC...

Page 70: ...64 ...

Page 71: ...ixed to zero degrees and remaining analog channel s phase angle information will be shown in relation to this analog input During testing and 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...

Page 72: ...st be set in the IED The convention of the directionality is defined as follows A positive value of current power and so on means that the quantity has the direction into the object and a negative value means direction out from the object For directional functions the direction into the object is defined as Forward and the direction out from the object is defined as Reverse See Figure 6 A positive...

Page 73: ... CTStarPoint with Transformer as reference object Correct setting is ToObject Setting of current input Set parameter CTStarPoint with Line as reference object Correct setting is FromObject IEC05000753 IEC05 000753 1 en Origin al 1 vsd Is Is Ip Ip Ip IED IED IEC05000753 V2 EN US Figure 7 Example how to set CTStarPoint parameters in the IED Figure 7 shows the normal case where the objects have their...

Page 74: ...0460 V2 EN US Figure 8 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 With these ...

Page 75: ...verse 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 Normally it ...

Page 76: ...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 10 Example how to set CTStarPoint parameters in the IED Section 4 1MRK 506 369 UEN B Analog inpu...

Page 77: ... CTStarPoint ToObject and for all CT inputs marked with 2 in Figure 11 set CTStarPoint FromObject The second solution will be to use all connected bays as reference objects In that case for all CT inputs marked with 1 in Figure 11 set CTStarPoint FromObject and for all CT inputs marked with 2 in Figure 11 set CTStarPoint ToObject Regardless which one of the above two options is selected busbar dif...

Page 78: ...nType phase phase phase earth and GlobalBaseSel ISec I Pri S1 X1 P1 H1 P2 H2 S2 X2 P2 H2 P1 H1 x x a b c en06000641 vsd S2 X2 S1 X1 IEC06000641 V1 EN US Figure 12 Commonly used markings of CT terminals Where a is symbol and terminal marking used in this document Terminals marked with a square indicates the primary and secondary winding terminals with the same that is positive polarity b and c are ...

Page 79: ...g 4 2 2 5 Example on how to connect a star connected three phase CT set to the IED SEMOD55055 352 v11 Figure 13 gives an example about the wiring of a star connected two phase CT set to the IED It gives an overview of the actions which are needed to make this measurement available to the built in protection and control functions within the IED as well For correct terminal designations see the conn...

Page 80: ...ree 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 the example shown in Figure 13 CTprim 600A CTsec 5A CTStarPoint ToObject Ratio of the first two parameters is only used inside the IED The third parameter CTStarPoint ToObject as set in this example causes no change on the measur...

Page 81: ...or IEDs installed in power plants then the setting parameters DFTReference shall be set accordingly Section SMAI in this manual provides information on adaptive frequency tracking for the signal matrix for analogue inputs SMAI 5 AI3P in the SMAI function 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 fre...

Page 82: ...he setting of the parameter CTStarPoint of the used current inputs on the TRM item 2 in Figure 14 and 13 CTprim 600A CTsec 5A CTStarPoint FromObject The ratio of the first two parameters is only used inside the IED The third parameter as set in this example will negate the measured currents in order to ensure that the currents are measured towards the protected object within the IED A third altern...

Page 83: ...phase currents 3 Is the TRM where these current inputs are located It shall be noted that for all these current inputs the following setting values shall be entered CTprim 800A CTsec 1A CTStarPoint FromObject ConnectionType Ph N The ratio of the first two parameters is only used inside the IED The third parameter as set in this example will have no influence on measured currents that is currents a...

Page 84: ...tion 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 default values If frequency tracking and compensation is required this feature is typically required only for IEDs installed in the generating stations then the setting parameters DFTReference shall b...

Page 85: ...IL3 IL3 IL1 1 2 3 4 IEC11000027 3 en vsdx SMAI2 BLOCK REVROT GRP2L1 GRP2L2 GRP2L3 GRP2N AI3P AI1 AI2 AI3 AI4 AIN IEC11000027 V3 EN US Figure 16 Delta DAB connected three phase CT set 1MRK 506 369 UEN B Section 4 Analog inputs Line distance protection REL670 2 2 IEC 79 Application manual ...

Page 86: ...r 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 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 ...

Page 87: ...ered 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 18 gives an example how to connect the single phase CT to the IED It gives an overview of the...

Page 88: ...bject For connection b shown in Figure 18 CTprim 1000 A CTsec 1A CTStarPoint FromObject 3 shows the connection made in SMT tool which connect this CT input to the fourth input channel of the preprocessing function block 4 4 is a Preprocessing block that has the task to digitally filter the connected analog inputs and calculate values The calculated values are then available for all built in protec...

Page 89: ...ake the protection scheme less sensitive however such measures are necessary in order to avoid possible problems with loss of the measurement accuracy in the IED Regardless of the applied relationship between the IBase parameter and the rated CT primary current the corresponding minimum pickup of the function on the CT secondary side must always be verified It is strongly recommended that the mini...

Page 90: ...quare indicate the primary and secondary winding terminals with the same positive polarity b is the equivalent symbol and terminal marking used by IEC ANSI standard for phase to earth connected VTs c is the equivalent symbol and terminal marking used by IEC ANSI standard for open delta connected VTs d is the equivalent symbol and terminal marking used by IEC ANSI standard for phase to phase connec...

Page 91: ...he built in protection and control functions within the IED For correct terminal designations see the connection diagrams valid for the delivered IED L1 IED L2 L3 66 3 110 3 kV V 1 3 2 66 3 110 3 kV V 66 3 110 3 kV V Not used 5 IEC06000599 4 en vsdx 4 SMAI2 BLOCK REVROT GRP2L1 GRP2L2 GRP2L3 GRP2N AI3P AI1 AI2 AI3 AI4 AIN IEC06000599 V4 EN US Figure 20 A Three phase to earth connected VT 1MRK 506 3...

Page 92: ...is the TRM where these three voltage inputs are located For these three voltage inputs the following setting values shall be entered VTprim 132 kV VTsec 110 V Inside the IED only the ratio of these two parameters is used It shall be noted that the ratio of the entered values exactly corresponds to ratio of one individual VT 66 66 3 110 110 3 EQUATION1903 V1 EN US Equation 2 Table continues on next...

Page 93: ...ors 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 the configuration tool For this application most of the preprocessing settings can be left to the default values However the following set...

Page 94: ...ondary side of a phase to phase VT to the VT inputs on the IED 2 is the TRM where these three voltage inputs are located It shall be noted that for these three voltage inputs the following setting values shall be entered VTprim 13 8 kV VTsec 120 V Please note that inside the IED only ratio of these two parameters is used Table continues on next page Section 4 1MRK 506 369 UEN B Analog inputs 88 Li...

Page 95: ...gs shall be set as shown here ConnectionType Ph Ph UBase 13 8 kV If frequency tracking and compensation is required this feature is typically required only for IEDs installed in the generating stations then the setting parameters DFTReference shall be set accordingly 4 2 4 5 Example on how to connect an open delta VT to the IED for high impedance earthed or unearthed networks SEMOD55055 163 v9 Fig...

Page 96: ...1 4 en vsdx Not Used Not Used SMAI2 BLOCK REVROT GRP2L1 GRP2L2 GRP2L3 GRP2N AI3P AI1 AI2 AI3 AI4 AIN IEC06000601 V4 EN US Figure 23 Open delta connected VT in high impedance earthed power system Section 4 1MRK 506 369 UEN B Analog inputs 90 Line distance protection REL670 2 2 IEC Application manual ...

Page 97: ...age input to the fourth input channel of the preprocessing function block 5 5 is a Preprocessing block that has the task to digitally filter the connected analog input 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...

Page 98: ... U EQUATION1926 V1 EN US Equation 7 The primary rated voltage of such VT is always equal to UPh E Therefore three series connected VT secondary windings will give the secondary voltage equal only to one individual VT secondary winding rating Thus the secondary windings of such open delta VTs quite often has a secondary rated voltage close to rated phase to phase VT secondary voltage that is 115V o...

Page 99: ...ot Used Not Used SMAI2 BLOCK REVROT GRP2L1 GRP2L2 GRP2L3 GRP2N AI3P AI1 AI2 AI3 AI4 AIN 2 3 4 5 IEC06000602 V4 EN US Figure 24 Open delta connected VT in low impedance or solidly earthed power system 1MRK 506 369 UEN B Section 4 Analog inputs Line distance protection REL670 2 2 IEC 93 Application manual ...

Page 100: ...h 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 taken as re...

Page 101: ...9 V3 EN US Figure 25 Local human machine interface The LHMI of the IED contains the following elements Keypad Display LCD LED indicators Communication port for PCM600 1MRK 506 369 UEN B Section 5 Local HMI Line distance protection REL670 2 2 IEC 95 Application manual ...

Page 102: ...w depends on the character size and the view that is shown The display view is divided into four basic areas IEC15000270 1 en vsdx IEC15000270 V1 EN US Figure 26 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 S...

Page 103: ...LED pages are available IEC13000240 1 en vsd GUID 5157100F E8C0 4FAB B979 FD4A971475E3 V1 EN US Figure 28 Indication LED panel The function button and indication LED panels are not visible at the same time Each panel is shown by pressing one of the function buttons or the Multipage button Pressing the ESC button clears the panel from the display Both panels have a dynamic width that depends on the...

Page 104: ...LHMI or PCM600 Information panels for the indication LEDs are shown by pressing the Multipage button Pressing that button cycles through the three pages A lit or un acknowledged LED is indicated with a highlight Such lines can be selected by using the Up Down arrow buttons Pressing the Enter key shows details about the selected LED Pressing the ESC button exits from information pop ups as well as ...

Page 105: ...in different views or menus The push buttons are also used to acknowledge alarms reset indications provide help and switch between local and remote control mode The keypad also contains programmable push buttons that can be configured either as menu shortcut or control buttons 1MRK 506 369 UEN B Section 5 Local HMI Line distance protection REL670 2 2 IEC 99 Application manual ...

Page 106: ...bject 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 Section 5 1MRK 506 369 UEN B Local HMI 100 Line distance protection REL670 2 2 IEC Application manual ...

Page 107: ...pply voltage is disconnected On Normal operation Flashing Internal fault has occurred Table 12 Start LED yellow LED state Description Off Normal operation On A protection function has started and an indication message is displayed 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 I...

Page 108: ...he indication has been acknowledged but the activation signal is still on LatchedAck S F sequence The activation signal is on or it is off but the indication has not been acknowledged LatchedReset S sequence The activation signal is on or it is off but the indication has not been acknowledged Flashing Follow F sequence The activation signal is on LatchedAck F S sequence The activation signal is on...

Page 109: ... 45 connector 2 Green indicator LED The default IP address for the IED front port is 10 1 150 3 and the corresponding subnetwork 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 P...

Page 110: ...104 ...

Page 111: ...asor client This includes port numbers TCP UDP IP addresses and specific settings for IEEE C37 118 as well as IEEE 1344 protocols 6 1 3 Operation principle GUID 2608FBC4 9036 476A 942B 13452019BC11 v2 The Figure 32 demonstrates the communication configuration diagram As can be seen the IED can support communication with maximum 8 TCP clients and 6 UDP client groups simultaneously Every client can ...

Page 112: ...cation configuration PMUCONF structure in the IED 6 1 3 1 Short guidance for use of TCP GUID 700B2618 3719 4C17 A1F8 3B8F5834FE95 v3 Port 7001 is used by the SPA on TCP IP field service tool If the port is used for any other protocol for example C37 118 the SPA on TCP IP stops working The IED supports 8 concurrent TCP connections using IEEE1344 and or C37 118 protocol The following parameters are ...

Page 113: ...Diagnostics Communication PMU diagnostics PMUSTATUS 1 It is possible to turn off on the TCP data communication by sending a IEEE1344 or C37 118 command frame remotely from the client to the PMU containing RTDOFF RTDON command At any given point of time maximum of 8 TCP clients can be connected to the IED for IEEE1344 C37 118 protocol If there is an attempt made by the 9th client the connection to ...

Page 114: ...ommunication more reliable especially since commands are sent over TCP which performs request acknowledgment exchange to ensure that no data command in this case is lost However by setting the parameter SendCfgOnUDP x to On the configuration frame 2 CFG 2 of IEEEC37 118 data stream is cyclically sent on the corresponding UDP stream UDP client group x once per minute This is useful in case of multi...

Page 115: ...ErrCnt is incremented in PMU Diagnostics on LHMI at Main menu Diagnostics Communication PMU diagnostics PMUSTATUS 1 Even if the parameter SendDataUDP x is set to Off it is still possible for the clients to connect on the TCP port and request the configuration frames 6 2 Protocol reporting via IEEE 1344 and C37 118 PMUREPORT GUID 0C45D2FA 1B95 4FCA B23B A28C2770B817 v1 6 2 1 Identification GUID 009...

Page 116: ...nels PHASORREPORT1 4 blocks 24 analog channels ANALOGREPORT1 3 blocks and 28 digital channels 24 digital report channels in BINARYREPORT1 3 and 4 trigger report channels in PMUREPORT function block Special rules shall be taken into account in PCM600 for Application Configuration and Parameter Settings of multiple PMUREPORT blocks These rules are explained in the the Application Manual in section P...

Page 117: ... the PDC clients as defined in IEEE C37 118 data frame format IEC140000120 2 en vsd IEC140000120 V2 EN US Figure 35 Multiple instances of ANALOGREPORT blocks Figure 36 shows both instances of BINARYREPORT function blocks The instance number is visible in the bottom of each function block For each instance there are three separate BINARYREPORT blocks capable of reporting up to 24 Binary signals 8 B...

Page 118: ...tion message structure and data The PMU complies with all the standard requirements with a specific attention to the Total Vector Error TVE requirement The TVE is calculated using the following equation 2 2 2 2 r r i i r i X n X X n X TVE X X GUID 80D9B1EA A770 4F50 9530 61644B4DEBBE V1 EN US Equation 11 where Xr n and Xi n are the measured values Xr and Xi are the theoretical values In order to c...

Page 119: ...he factory The calibration data is stored in the prepared area of the TRM EEProm The pre processor block is extended with calibration compensation and a new angle reference method based on timestamps The AI3P output of the preprocessor block is used to provide the required information for each respective PMUREPORT phasor channel More information about preprocessor block is available in the section...

Page 120: ...ted reporting of the system frequency to the PDC client In this frequency source selection logic the following general rules are applied Only the voltage phasor channels are used The phasor channel with a lower channel number is prioritized to the one with a higher channel number As a result the first voltage phasor is always the one delivering the system frequency to the PDC client and if by any ...

Page 121: ...ata are filtered in order to suppress aliasing effects as the rate of the C37 118 data is slower than the data rate for internal processing For this purpose there is an anti aliasing filter designed for each reporting rate The correct anti aliasing filter will be automatically selected based on the reporting rate and the performance class P M settings The filters are designed to attenuate all alia...

Page 122: ...E C37 118 2 standard the scale factors conversion factor for analog channels are defined in configuration frame 2 CFG 2 and configuration frame 3 CFG 3 frames as follows CFG 2 frame The field ANUNIT 4 bytes specifies the conversion factor as a signed 24 bit word for user defined scaling Since it is a 24 bit integer in order to support the floating point scale factor the scale factor itself is mult...

Page 123: ...1 EN US The scale factor will be sent as 1 on configuration frame 2 and 0 15 on configuration frame 3 The range of analog values that can be transmitted in this case is 0 15 to 4915 5 and 0 15 to 4915 5 Example 3 10000000000 AnalogXRange IECEQUATION2450 V1 EN US The scale factor is calculated as follows 10000000000 2 0 305180 43 and 0 0 65535 5 scalefactor offset IECEQUATION2451 V1 EN US The scale...

Page 124: ...correct connection of SMAI and PHASORREPORT blocks in ACT Figure 39 shows an example of wrong connection of SMAI and PHASORREPORT blocks in ACT where the SMAI block is working on 3 ms while PHASORREPORT block is working on 0 9 ms cycle time IEC140000125 2 en vsd IEC140000125 V2 EN US Figure 39 An example of wrong connection of SMAI and PHASORREPORT blocks in ACT Violation of rule 1 results in PMU ...

Page 125: ...0126 2 en vsd IEC140000126 V2 EN US Figure 40 PMUREPORT settings in PCM600 PST Figure 41 shows an example of correct connection of SMAI and PHASORREPORT blocks in ACT where two different SMAI blocks are connected to different PHASORREPORT blocks with different instance numbers In this example as the PHASORREPORT blocks have different instance numbers and different settings for SvcClass and ReportR...

Page 126: ...ances differ for SvcClass or ReportRate then PHASOR1 connection in PHASORREPORT1 instance 2 will not be compliant with IEEE C37 118 standard The reason is that the filtering in SMAI 3PHSUM block is adapted according to the performance class SvcClass and reporting rate of the connected instance of PHASORREPORT function block In this example SMAI1 will adapt its filtering according to PHASORREPORT i...

Page 127: ... to In other words both the SMAI reference block and 3PHSUM block 3PHSUM block with external DFT reference shall be connected to the same instance of PHASORREPORT block PHASOR1 32 of Instance number 1 or 2 Figure 43 shows an example of correct connection of 3PHSUM and PHASORREPORT blocks in ACT where SMAI3 is configured as the reference block for DFT reference external out DFTRefExtOut and 3PHSUM ...

Page 128: ...nd PHASORREPORT blocks in ACT IEC140000130 1 en vsd IEC140000130 V1 EN US Figure 44 SMAI1 setting parameters example showing that SMAI3 is selected as the DFT reference DFTRefGrp3 Section 6 1MRK 506 369 UEN B Wide area measurement system 122 Line distance protection REL670 2 2 IEC Application manual ...

Page 129: ...n ACT If settings for PMUREPORT instances PHASORREPORT1 instances 1 and 2 above differ for SvcClass or ReportRate then the synchrophasor reported by PHASOR2 connection from PHASORREPORT1 instance 2 will not be compliant with IEEE C37 118 standard The reason is as in the rule 2 the filtering in SMAI 3PHSUM block is adapted according to the performance class SvcClass and reporting rate of the connec...

Page 130: ...ORREPORT blocks then 3PHSUM block can be freely connected to any of them regardless of 3PHSUM block DFT reference setting or the reference SMAI block connection Note Violation of rules 2 or 3 results in non compliancy with IEEE C37 118 standard for some of the synchrophasors In case of rule 2 violation the non compliancy only applies to synchrophasors from instance 2 and the synchrophasors from in...

Page 131: ...ned value which can be sent with the configuration 3 message It allows uniquely identifying PMUs in a system that has more than 65535 PMUs The coding for the 16 bytes is left to the user for assignment PMUdataStreamIDCODE It refers to the 2 byte IDCODE field of the configuration frame and data frame organization defined in IEEE C37 118 2 message format It is a user assigned ID number 1 65534 for e...

Page 132: ...the parameter settings related to the ANALOGREPORT function block The analog data are sent via the ANALOG field of data frame organization of IEEE C37 118 2 message format Depends on the analog data type the size of ANALOG field can be 2 Integer or 4 Float bytes per IEEE C37 118 2 message More information is available under the section Scaling Factors for ANALOGREPORT channels FrequencyDataType It...

Page 133: ... For example if the selected setting is 15 10 fr s 60 50Hz this means that the synchrophasor data reporting rate would be 15 frames per second if the system frequency is 60Hz Likewise if the system frequency is 50Hz the selected rate is equal to 10 frames per second RptTimetag It refers to the method of time tagging used in the IED which is related to the phasor estimation and filtering technique ...

Page 134: ...requency reporting 3 ANALOGREPORT is the function block responsible for reporting the analog values Each instance of ANALOGREPORT function block has 24 analog channels with the following setting parameters where X is a number from 1 to 24 AnalogXRange This parameter defines a range between AnalogXRange and AnalogXRange for AnalogX value The range will be used by the IED to apply a proper scale fac...

Page 135: ...unction HZPDIF can be used as Generator differential protection Reactor differential protection Busbar differential protection Autotransformer differential protection for common and serial windings only T feeder differential protection Capacitor differential protection Restricted earth fault protection for transformer generator and shunt reactor windings Restricted earth fault protection The appli...

Page 136: ...ears and is well documented in literature publicly available Its operating principle provides very good sensitivity and high speed operation One main benefit offered by the principle is an absolute stability that is no operation for external faults even in the presence of heavy CT saturation The principle is based on the CT secondary current circulating between involved current transformers and no...

Page 137: ...t Otherwise any flash over in CT secondary circuits or any other part of the scheme may prevent correct operation of the high impedance differential relay for an actual internal fault Id IEC05000164 2 en vsd R Metrosil IEC05000164 V3 EN US Figure 48 Example for the high impedance restricted earth fault protection application For a through fault one current transformer might saturate when the other...

Page 138: ...nal unit with stabilizing resistor has a value of either 6800 ohms or 1800 ohms depending on ordered alternative with a sliding link to allow adjustment to the required value Select a suitable value of the resistor based on the UR voltage calculated A higher resistance value will give a higher sensitivity and a lower value a lower sensitivity of the relay The function has a recommended operating c...

Page 139: ...ing resistor R1 ohms Operating current level 5 A Stabilizing resistor R1 ohms Operating current level 5 A 20 V 200 0 100 A 100 0 200 A 40 V 400 0 100 A 200 0 200 A 100 0 400 60 V 600 0 100 A 300 0 200 A 150 0 400 A 80 V 800 0 100 A 400 0 200 A 200 0 400 A 100 V 1000 0 100 A 500 0 200 A 250 0 400 A 150 V 1500 0 100 A 750 0 200 A 375 0 400 A 200 V 2000 0 100 A 1000 0 200 A 500 0 400 A The current tr...

Page 140: ... current measurement is insensitive to DC component in fault current to allow the use of only the AC components of the fault current in the above calculations The voltage dependent resistor Metrosil characteristic is shown in Figure 54 Series resistor thermal capacity SEMOD54734 336 v6 The series resistor is dimensioned for 200 W Preferable the U Trip2 SeriesResistor should always be lower than 20...

Page 141: ...c Internal faults UR Protected Object IEC05000427 2 en vsd IEC05000427 V2 EN US Figure 49 The high impedance principle for one phase with two current transformer inputs 1MRK 506 369 UEN B Section 7 Differential protection Line distance protection REL670 2 2 IEC 135 Application manual ...

Page 142: ...ree phase high impedance differential protection Typical CT connections for three phase high impedance differential protection scheme are shown in figure 50 L1 A L2 B L3 C Protected Object CT 1200 1 Star Wye Connected L1 A L2 B L3 C CT 1200 1 Star Wye Connected 7 8 9 1 0 1 1 1 2 1 2 3 4 5 6 AI01 I AI02 I AI03 I AI04 I AI05 I AI06 I 7 6 X1 R4 R5 R6 1 2 1 2 1 2 11 12 13 14 U U U R1 1 3 4 2 1 3 R2 2 ...

Page 143: ... impedance differential protection HZPDIF GUID D68A237F 610C 4AF0 870F 273117F64D92 v10 Restricted earth fault protection is a typical application for 1Ph High impedance differential protection HZPDIF Typical CT connections for the high impedance based protection scheme are shown in figure 51 L1 A L2 B L3 C Protected Object CT 1500 5 Star Wye Connected 7 8 9 10 11 12 1 2 3 4 5 6 AI01 I AI02 I AI03...

Page 144: ...ifferential function can be switched On or Off U Alarm Set the alarm level The sensitivity can roughly be calculated as a certain percentage of the selected Trip level A typical setting is 10 of U Trip This alarm stage can be used for scheme CT supervision tAlarm Set the time delay for the alarm A typical setting is 2 3 seconds U Trip Set the trip level according to the calculations see examples b...

Page 145: ...rload the current input must be considered especially during the secondary testing 7 1 4 3 T feeder protection M16850 4 v7 In many busbar arrangements such as one and a half breaker ring breaker mesh corner there will be a T feeder from the current transformer at the breakers up to the current transformers in the feeder circuit for example in the transformer bushings It is often required to separa...

Page 146: ...st tap of the CT whenever high impedance protection is used This helps in utilizing maximum CT capability minimize the secondary fault current thereby reducing the stability voltage limit Another factor is that during internal faults the voltage developed across the selected tap is limited by the non linear resistor but in the unused taps owing to auto transformer action voltages induced may be mu...

Page 147: ... so sensitive select SeriesResistor 2000 ohm which gives an IED operating current of 100 mA Calculate the primary sensitivity at operating voltage using the following equation IP approx A 2000 1 100 0 20 0 3 10 60 10 275 3 EQUATION1209 V2 EN US Equation 17 where 100 mA is the current drawn by the IED circuit and 10 mA is the current drawn by each CT just at pickup 20 mA is current drawn by metrosi...

Page 148: ...e most important factors 7 1 4 4 Tertiary reactor protection M16850 118 v5 Reactive power equipment for example shunt reactors and or shunt capacitors can be connected to the tertiary winding of the power transformers The 1Ph High impedance differential protection function HZPDIF can be used to protect the tertiary reactor for phase faults as well as earth faults if the power system of the tertiar...

Page 149: ...helps in utilizing maximum CT capability minimize the secondary fault thereby reducing the stability voltage limit Another factor is that during internal faults the voltage developed across the selected tap is limited by the non linear resistor but in the unused taps owing to auto transformer action voltages much higher than design limits might be induced 1MRK 506 369 UEN B Section 7 Differential ...

Page 150: ... 2 ˣ U Trip Check from the table of selected resistances the required series stabilizing resistor value to use Since this application requires good sensitivity select SeriesResistor 300 ohm which gives an IED current of 100 mA To calculate the sensitivity at operating voltage refer to equation 20 which gives an acceptable value A little lower sensitivity could be selected by using a lower resistan...

Page 151: ... can be either another IED with the same HZPDIF function or be a check about the fault condition which is performed by an earth overcurrent function or neutral point voltage function For such cases where operation is not expected during normal service the alarm output should be used to activate an external shorting of the differential circuit avoiding continuous high voltage in the circuit A time ...

Page 152: ...146 ...

Page 153: ...on ZDSRDIR Z IEC09000167 V1 EN US 21D 8 1 2 Application SEMOD168236 1 v1 8 1 2 1 Introduction SEMOD168232 4 v2 Sub transmission networks are being extended and often become more and more complex consisting of a high number of multi circuit and or multi terminal lines of very different lengths These changes in the network will normally impose more stringent demands on the fault clearing equipment i...

Page 154: ...e shunt admittance may however have some marginal influence on the earth fault current in networks with long transmission lines The earth fault current at single phase to earth in phase L1 can be calculated as equation 21 L1 L1 0 1 2 0 f 1 N f 3 U U 3I Z Z Z 3Z Z Z Z EQUATION1267 V3 EN US Equation 21 Where UL1 is the phase to earth voltage kV in the faulty phase before fault Z1 is the positive seq...

Page 155: ...twork impedances are valid as shown in equation 23 and equation 24 X X 0 1 3 EQUATION1269 V4 EN US Equation 23 R X 0 1 EQUATION1270 V4 EN US Equation 24 The magnitude of the earth fault current in effectively earthed networks is high enough for impedance measuring element to detect earth fault However in the same way as for solid earthed networks distance protection has limited possibilities to de...

Page 156: ...n is called load encroachment and it might occur when an external fault is cleared and high emergency load is transferred on the protected line The effect of load encroachment is illustrated to the left in figure 57 The entrance of the load impedance inside the characteristic is not allowed and the way to handle this with conventional distance protection is to consider this with the settings that ...

Page 157: ...ion with load enchroachment quadrilateral characteristic FDPSPDIS function R X Zm Load impedance area in forward direction RLdRv R Zm ARGLd ARGLd ARGLd ARGLd RLdFw ZL en05000495 vsd IEC05000495 V1 EN US Figure 57 Load encroachment phenomena and shaped load encroachment characteristic 8 1 2 5 Long transmission line application SEMOD168232 128 v3 For long transmission lines the margin to the load im...

Page 158: ... is increasing due to difficulties to get necessary area for new lines Parallel lines introduce an error in the measurement due to the mutual coupling between the parallel lines The lines need not be of the same voltage to experience mutual coupling and some coupling exists even for lines that are separated by 100 meters or more The reason to the introduced error in measuring due to mutual couplin...

Page 159: ...luence the earth return compensation for different distance zones within the same group of setting parameters Different groups of setting parameters for different operating conditions of a protected multi circuit line Most multi circuit lines have two parallel operating circuits The application guide mentioned below recommends in more detail the setting practice for this particular type of line Th...

Page 160: ...s 1 parallel line in service The equivalent circuit of the lines can be simplified as shown in figure 60 A B C Z0m Z0 Z0 m Z0 Z0 m 99000038 vsd IEC99000038 V1 EN US Figure 60 Equivalent zero sequence impedance circuit of the double circuit parallel operating line with a single phase to earth fault at the remote busbar When mutual coupling is introduced the voltage at the IED point A is changed acc...

Page 161: ...n overreaches If the currents have the same direction the distance protection underreaches Maximum overreach occurs if the fault infeed from remote end is weak If we consider a single phase to earth fault at p unit of the line length from A to B on the parallel line for the case when the fault infeed from remote end is zero we can draw the voltage V in the faulty phase at A side as in equation 30 ...

Page 162: ...ach is most pronounced with no infeed in the line IED closest to the fault This reach reduction is normally less than 15 But when the reach is reduced at one line end it is proportionally increased at the opposite line end So this 15 reach reduction does not significantly affect the operation of a permissive under reach scheme Parallel line out of service and earthed SEMOD168232 227 v3 SEMOD168232...

Page 163: ... be considered when calculating the settings All expressions below are proposed for practical use They assume the value of zero sequence mutual resistance R0m equals to zero They consider only the zero sequence mutual reactance X0m Calculate the equivalent X0E and R0E zero sequence parameters according to equation 35 and equation 36 for each particular line section and use them for calculating the...

Page 164: ...his means that the reach of the underreaching distance protection zone is reduced if due to operating conditions the equivalent zero sequence impedance is set according to the conditions when the parallel system is out of operation and earthed at both ends Z Z0 0 m Z Z0 0 m Z0m A B C 99000040 vsd I0 I0 IEC99000040 V1 EN US Figure 64 Equivalent zero sequence impedance circuit for a double circuit l...

Page 165: ...quation 40 The imaginary component of the same factor is equal to equation 41 2 0 2 2 Im Im Re Im m U A X K A A é ù é ù ë û ë û EQUATION1288 V2 EN US Equation 41 Ensure that the underreaching zones from both line ends will overlap a sufficient amount at least 10 in the middle of the protected circuit 8 1 2 7 Tapped line application SEMOD168232 266 v2 1MRK 506 369 UEN B Section 8 Impedance protecti...

Page 166: ...TF IA IC IA DOCUMENT11524 IMG3509 V3 EN US Equation 42 Z Z Z I I I Z U U C Trf CT A C C TF 2 1 2 DOCUMENT11524 IMG3510 V3 EN US Equation 43 Where ZAT and ZCT is the line impedance from the B respective C station to the T point IA and IC is fault current from A respective C station for fault between T and B U2 U1 Transformation ratio for transformation of impedance at U1 side of the transformer to ...

Page 167: ...zones with enough sensitivity without interference with other zone1 settings that is without selectivity conflicts Careful fault calculations are necessary to determine suitable settings and selection of proper scheme communication Fault resistance SEMOD168232 289 v2 The performance of distance protection for single phase to earth faults is very important because normally more than 70 of the fault...

Page 168: ...on Reduced costs of power transmission due to decreased investment costs for new power lines Steady state voltage regulation and increase of voltage collapse limit SEMOD168320 24 v2 A series capacitor is capable of compensating the voltage drop of the series inductance in a transmission line as shown in figure 66 During low loading the system voltage drop is lower and at the same time the voltage ...

Page 169: ...put power from the generator PE and the generator angle is d0 If a 3 phase fault occurs at a point near the machine the electrical output of the generator reduces to zero This means that the speed of the generator increases and the angle difference between the generator and the infinite bus increases during the fault At the time of fault clearing the angle difference has increased to δC After recl...

Page 170: ...between δC and δCR and the accelerating energy It is represented in figure 69 by the area ASM Notice that a substantial increase in the stability margin is obtained by installing a series capacitor The series compensation can improve the situation in two ways it can decrease the initial angle difference δ0 corresponding to a certain power transfer and it also shifts the P δ curve upwards Improve r...

Page 171: ...e transmission line is given by the equation 47 sin sin 1 d d A B A B Line C Line C U U U U P X X X K EQUATION1897 V1 EN US Equation 47 The compensation degree Kc is defined as equation A B jXC PA QA PB QB UA UB U jXL UA UB d D en06000590 vsd IEC06000590 V1 EN US Figure 71 Transmission line with series capacitor The effect on the power transfer when considering a constant angle difference δ betwee...

Page 172: ...osses as shown in figure 73 en06000593 vsd RL1 jXL1 jXC Line 1 jXL2 RL2 Line 2 IEC06000593 V1 EN US Figure 73 Two parallel lines with series capacitor for optimized load sharing and loss reduction To minimize the losses the series capacitor must be installed in the transmission line with the lower resistance The size of the series capacitor that minimizes the total losses is given the following ex...

Page 173: ...re 74 Series compensation is an important alternative to new transmission lines Advancements in series compensation using thyristor switching technology SEMOD168320 102 v3 A thyristor switched series capacitor TSSC can be used for power flow control This is performed by changing the reactance of the transmission circuit in discrete steps as shown in figure 75 A TSSC typically consists of a few seg...

Page 174: ... with a maximum total blocking voltage in the range of hundreds of kV The inductor is an air core reactor with a few mH inductance The wave forms of a TCSC in capacitive boost mode are shown in figure 77 en06000597 vsd UC XC 0 0 02 0 04 0 06 0 08 0 1 0 12 0 14 0 16 0 18 0 2 2 0 2 0 0 02 0 04 0 06 0 08 0 1 0 12 0 14 0 16 0 18 0 2 5 0 5 0 0 02 0 04 0 06 0 08 0 1 0 12 0 14 0 16 0 18 0 2 50 0 50 0 0 0...

Page 175: ...ection of series compensated and adjacent power lines SEMOD168320 10 v2 System planning does not consider any more possible protection issues and difficulties when deciding for a particular non conventional solution of certain operation and stability problems It is supposed that modern communication and state of the art computer technologies provides good basis for the required solution This appli...

Page 176: ... is linearly dependent on distance from the bus if there is no capacitor included in scheme as shown in figure 80 Voltage UM measured at the bus is equal to voltage drop D UL on the faulty line and lags the current IF by 90 electrical degrees The situation changes with series capacitor included in circuit between the IED point and the fault position The fault current IF see figure 80 is increased ...

Page 177: ... as long as XL1 XC This situation corresponds from the directionality point of view to fault conditions on line without series capacitor Voltage UM in IED point will lag the fault current IF in case when L1 C S L1 X X X X EQUATION1902 V1 EN US Equation 50 Where XS is the source impedance behind the IED The IED point voltage inverses its direction due to presence of series capacitor and its dimensi...

Page 178: ...tor F IEC06000607 V1 EN US Figure 81 Current inversion on series compensated line The relative phase position of fault current IF compared to the source voltage US depends in general on the character of the resultant reactance between the source and the fault position Two possibilities appear 1 1 0 0 S C L S C L X X X X X X EQUATION1935 V1 EN US Equation 51 The first case corresponds also to condi...

Page 179: ...mpedances big power plants compared to the capacitor reactance The possibility for current inversion in modern networks is increasing and must be studied carefully during system preparatory studies The current inversion phenomenon should not be studied only for the purposes of protection devices measuring phase currents Directional comparison protections based on residual zero sequence and negativ...

Page 180: ...scribing the circuit in figure 83 without series capacitor is presented by equation 54 sin w l L L L L G di L R i E t dt EQUATION1905 V1 EN US Equation 54 The solution over line current is presented by group of equations 55 0 2 2 sin sin w l j l j w w j é ù ê ú ë û æ ö ç è ø L L R t L G G L L t L L L L E E i t I e Z Z Z R L L atg R EQUATION1906 V1 EN US Equation 55 The line fault current consists ...

Page 181: ...n 1 sin sin cos 2 1 sin 2 2 1 4 a w l j b b w w l j w l l j b l j a b æ ö ç è ø é ù ê ú ê ú ê ú ê ú ë û t G L SC SC L L L G L t SC G L L G C t L t SC G L L SC L L L L L E i t K t K t e Z Z R L C E K I Z E L R E U I Z K E R L Z R L R L C L2 L EQUATION1909 V1 EN US Equation 58 The transient part has an angular frequency b and is damped out with the time constant α The difference in performance of fa...

Page 182: ... series capacitors plays an important role regarding the dependability and security of a complete protection scheme It is on the other hand necessary to point out the particular dependence of those protection schemes which need for their operation information on voltage in IED point Protection schemes with their operating principle depending on current measurement only like line current differenti...

Page 183: ...es reduce the apparent zero sequence source impedance and may cause voltage as well as current inversion in zero sequence equivalent networks for line faults It is for this reason absolutely necessary to study the possible effect on operation of zero sequence directional earth fault overcurrent protection before its installation Dual side instrument transformers SEMOD168320 277 v2 Installations wi...

Page 184: ...makes the picture relatively simple because they either flash over or not The apparent impedance corresponds to the impedance of non compensated line as shown in figure 87 case KC 0 en06000613 vsd jX R KC 0 KC 80 LOC 0 KC 50 LOC 50 jX jX R R KC 2 x 33 LOC 33 66 KC 80 LOC 100 jX jX R R IEC06000613 V1 EN US Figure 87 Apparent impedances seen by distance IED for different SC locations and spark gaps ...

Page 185: ...ated on 33 and 66 of line length The remote end compensation has the same effect The voltage inversion occurs in cases when the capacitor reactance between the IED point and fault appears bigger than the corresponding line reactance Figure 23 80 compensation at local end A voltage inversion occurs in IED point and the distance IED will see wrong direction towards the fault if no special measures h...

Page 186: ... Series capacitor prevails the scheme as long as the line current remains lower or equal to its protective current level I kp INC Line apparent impedance is in this case reduced for the complete reactance of a series capacitor 50 of capacitor reactance appears in series with resistance which corresponds to approximately 36 of capacitor reactance when the line current equals two times the protectiv...

Page 187: ...wing expressions U jI X I I X X B B LB A B LF C 1 EQUATION1912 V2 EN US Equation 61 0 1 LB C B LF A B X X U X I I EQUATION1913 V1 EN US Equation 62 Equation 61 indicates the fact that the infeed current IA increases the apparent value of capacitive reactance in system bigger the infeed of fault current bigger the apparent series capacitor in a complete series compensated network It is possible to ...

Page 188: ...and adjacent lines worldwide It has at the same time caused a lot of challenges to protection society especially when it comes to directional measurement and transient overreach Distance IED in fact does not measure impedance or quotient between line current and voltage Quantity 1 Operating quantity Restraing quantity Quantity 2 Polarizing quantity Typically Operating quantity is the replica imped...

Page 189: ...nd bus Distance protection Zone 1 is often set to 1 11 12 Z S C X K X X X EQUATION1914 V1 EN US Equation 63 Here KS is a safety factor presented graphically in figure 92 which covers for possible overreaching due to low frequency sub harmonic oscillations Here it should be noted separately that compensation degree KC in figure 92 relates to total system reactance inclusive line and source impedanc...

Page 190: ... high degree of overreach which can be considered as a disadvantage from a security point of view en06000620 vsd X11 X12 jXC A B DA DB Permissive Zone A Permissive Zone B IEC06000620 V1 EN US Figure 93 Permissive overreach distance protection scheme Negative IED impedance positive fault current voltage inversion SEMOD168320 367 v3 Assume in equation 64 11 11 C S X X X X EQUATION1898 V1 EN US Equat...

Page 191: ...st be delayed until the gap flashing has taken place If the delay is not acceptable some directional comparison must also be added to the protection of all adjacent power lines As stated above a good protection system must be able to operate correctly both before and after gap flashing occurs Distance protection can be used but careful studies must be made for each individual case The rationale de...

Page 192: ...flashed the situation for protection will be as for an ordinary fault However a good protection system should be able to operate correctly before and after gap flashing occurs en06000625 vsd jX R X11 X12 XC ZS IEC06000625 V1 EN US Figure 95 Cross polarized quadrilateral characteristic en06000584_small vsd jX R X11 X12 XC ZS X FW X RV RFW RRV IEC06000584 SMALL V1 EN US Figure 96 Quadrilateral chara...

Page 193: ... current can also exist for a single phase fault The condition for a negative current in case of an earth fault can be written as follows 1_ 1 0 _ 1 0 _ 1_ 3 2 2 C L L S S X X X X X EQUATION1920 V1 EN US Equation 72 All designations relates to figure 81 A good protection system must be able to cope with both positive and negative direction of the fault current if such conditions can occur A distan...

Page 194: ...is reactance The reach of underreaching distance protection zone 1 for phase to earth measuring loops must further be decreased for such operating conditions en06000628 vsd jXm0 j X0L Xm0 j X0L Xm0 jXC jXC A B IEC06000628 V1 EN US Figure 98 Zero sequence equivalent circuit of a series compensated double circuit line with one circuit disconnected and earthed at both IEDs Zero sequence mutual impeda...

Page 195: ...nd mentioned method has an advantage in that not the whole protection is blocked for the short period The disadvantage is that a local communication is needed between two protection devices in the neighboring bays of the same substation Distance protection used on series compensated lines must have a high overreach to cover the whole transmission line also when the capacitors are bypassed or out o...

Page 196: ...pplication We recommend to compensate setting for the cases when the parallel line is in operation out of service and not earthed and out of service and earthed in both ends The setting of earth fault reach should be selected to be 85 also when parallel line is out of service and earthed at both ends worst case 8 1 3 3 Setting of overreaching zone SEMOD168247 19 v3 The first overreaching zone norm...

Page 197: ...57 V2 EN US Figure 100 Setting of overreaching zone 8 1 3 4 Setting of reverse zone SEMOD168247 33 v2 The reverse zone is applicable for purposes of scheme communication logic current reversal logic weak end infeed logic and so on The same applies to the back up protection of the bus bar or power transformers It is necessary to secure that it always covers the overreaching zone used at the remote ...

Page 198: ... for phase to phase measurement It is also necessary to consider the minimum load impedance limiting conditions Setting of zone 1 SEMOD168247 150 v3 A voltage reversal can cause an artificial internal fault voltage zero on faulty line as well as on the adjacent lines This artificial fault always have a resistive component this is however small and can mostly not be used to prevent tripping of a he...

Page 199: ...fault If only the line reactance is used the degree of compensation will be too high and the zone 1 reach unnecessary reduced The highest degree of compensation will occur at three phase fault and therefore the calculation need only to be performed for three phase faults The compensation degree in earth return path is different than in phases It is for this reason possible to calculate a compensat...

Page 200: ... IEC07000063 V1 EN US Figure 102 Simplified single line diagram of series capacitor located at XLLOC ohm from A station Section 8 1MRK 506 369 UEN B Impedance protection 194 Line distance protection REL670 2 2 IEC Application manual ...

Page 201: ...fined according to figure 101 1 2 is safety factor for fast operation of Zone 1 Compensated line with the series capacitor not into the reach of zone 1 The setting is thus X1 is set to XLine XC p 100 When the calculation of XFw gives a negative value the zone 1 must be permanently blocked For protection on non compensated lines facing series capacitor on next line The setting is thus 1MRK 506 369 ...

Page 202: ...ipping will to a high degree be achieved by the communication scheme With the reduced reach of the under reaching zones not providing effective protection for all faults along the length of the line it becomes essential to provide over reaching schemes like permissive overreach transfer trip POTT or blocking scheme can be used Thus it is of great importance that the zone 2 can detect faults on the...

Page 203: ...ing of zone1 SEMOD168247 50 v2 With reference to section Parallel line application with mutual coupling the zone reach can be set to 85 of protected line Parallel line in service setting of zone2 SEMOD168247 53 v2 Overreaching zones in general zones 2 and 3 must overreach the protected circuit in all cases The greatest reduction of a reach occurs in cases when both parallel circuits are in service...

Page 204: ... ö EQUATION561 V1 EN US Equation 81 X0E X0 1 Xm0 2 R0 2 X0 2 è ø ç æ ö EQUATION562 V1 EN US Equation 82 8 1 3 7 Setting of reach in resistive direction SEMOD168247 76 v2 Set the resistive reach independently for each zone and separately for phase to phase R1PP and phase to earth loop R1PE measurement Set separately the expected fault resistance for phase to phase faults R1PP and for the phase to e...

Page 205: ...which is done by setting the parameter Rld for the Phase Selector to its upper limit If the load encroachment function is to be used for all or some of the measuring zones the load limitation for those zones according to this chapter can be omitted Check the maximum permissible resistive reach for any zone to ensure that there is a sufficient setting margin between the IED boundary and the minimum...

Page 206: ...an three times as large as the maximum expected load impedance angle More accurate calculations are necessary according to the equation below min 2 1 0 0 8 cos sin 2 1 0 load R Zx R Zx RFPEZx Z X Zx X Zx EQUATION578 V5 EN US Equation 90 Where ϑ is a maximum load impedance angle related to the minimum load impedance conditions To avoid load encroachment for the phase to phase measuring elements the...

Page 207: ...t be applications where it is necessary to increase the sensitivity by reducing the minimum operating current down to 10 of IED base current This happens especially in cases when the IED serves as a remote back up protection on series of very long transmission lines If the load current compensation is activated there is an additional criteria IMinOpIN that will block the phase earth loop if the 3I...

Page 208: ... opposite to the wanted fault resistance coverage Therefore the function has a built in algorithm for load encroachment which gives the possibility to enlarge the resistive setting of both the Phase selection with load encroachment and the measuring zones without interfering with the load A current based phase selection is also included The measuring elements continuously measure three phase curre...

Page 209: ... direction RFFwPE and RFRvPE for phase to earth faults and RFFwPP and RFRvPP for phase to phase faults have to be increased to avoid that FDPSPDIS characteristic shall cut off some part of the zone characteristic The necessary increased setting of the fault resistance coverage can be derived from trigonometric evaluation of the basic characteristic for respectively fault type Phase to earth fault ...

Page 210: ...SPDIS and impedance zone ZMQPDIS for phase to earth fault φloop 60 setting parameters in italic 1 FDPSPDIS phase selection red line 2 ZMQPDIS Impedance protection zone 3 RFltRevPGPHS 4 X1PHS XN tan 60 5 RFltFwdPGPHS 6 RFPGZM 7 X1PHS XN 8 φloop 9 X1ZM XN Section 8 1MRK 506 369 UEN B Impedance protection 204 Line distance protection REL670 2 2 IEC Application manual ...

Page 211: ...h M13142 103 v5 The resistive reach must cover RFPE for the overreaching zone to be covered mostly zone 2 Consider the longest overreaching zone if correct fault selection is important in the application Equation 96 gives the minimum recommended resistive reach min 1 1 zm RFFwPE RFPE EQUATION1312 V2 EN US Equation 96 where RFPEZm is the setting RFPE for the longest overreaching zone to be covered ...

Page 212: ... resistance reaches in forward direction RFFwPP must cover RFPPZm with at least 25 margin RFPPZm is the setting of fault resistance for phase to phase fault for the longest overreaching zone to be covered by FDPSPDIS see Figure 105 The minimum recommended reach can be calculated according to equation 98 1 25 zm RFFwPP RFPP EQUATION1318 V3 EN US Equation 98 where RFPPZm is the setting of the longes...

Page 213: ...IS and FDPSPDIS characteristic for phase to phase fault for φline 60 setting parameters in italic 1 FDPSPDIS phase selection red line 2 ZMQPDIS Impedance protection zone 3 0 5 RFRvPP PHS 4 60 tan PHS X1 5 0 5 RFFwPPPHS 6 0 5 RFPPZm 7 X1PHS 8 X1Zm 1MRK 506 369 UEN B Section 8 Impedance protection Line distance protection REL670 2 2 IEC 207 Application manual ...

Page 214: ...um possible load angle at maximum active load A value bigger than 20 must be used The blinder in forward direction RLdFw can be calculated according to equation 100 2 min 0 8 expmax U RLdFw P where Pexp max is the maximum exporting active power Umin is the minimum voltage for which the Pexp max occurs 0 8 is a security factor to ensure that the setting of RLdFw can be lesser than the calculated mi...

Page 215: ...escription IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Distance protection zone quadrilateral characteristic zone 1 ZMQPDIS S00346 V1 EN US 21 Distance protection zone quadrilateral characteristic zone 2 5 ZMQAPDIS S00346 V1 EN US 21 Directional impedance quadrilateral ZDRDIR Z IEC09000167 V1 EN US 21D 8 3 2 Application IP14961 1 v2 M17048 3 v7 Sub transmission ...

Page 216: ...ral and earth IEC05000215 V2 EN US Figure 107 Solidly earthed network The earth fault current is as high or even higher than the short circuit current The series impedances determine the magnitude of the fault current The shunt admittance has very limited influence on the earth fault current The shunt admittance may however have some marginal influence on the earth fault current in networks with l...

Page 217: ...fectively earthed if the earth fault factor fe is less than 1 4 The earth fault factor is defined according to equation 102 f U U e pn max EQUATION1268 V4 EN US Equation 102 Where Umax is the highest fundamental frequency voltage on one of the healthy phases at single phase to earth fault Upn is the phase to earth fundamental frequency voltage before fault Another definition for effectively earthe...

Page 218: ...itude of the earth fault current is very low compared to the short circuit current The voltage on the healthy phases will get a magnitude of 3 times the phase voltage during the fault The zero sequence voltage 3U0 will have the same magnitude in different places in the network due to low voltage drop distribution The magnitude of the total fault current can be calculated according to equation 105 ...

Page 219: ...ment elements or the sensitivity will be too low for acceptance For this reason a separate high sensitive earth fault protection is necessary to carry out the fault clearance for single phase to earth fault 8 3 2 2 Fault infeed from remote end M17048 83 v5 All transmission and most all sub transmission networks are operated meshed Typical for this type of network is that fault infeed from remote e...

Page 220: ... The entrance of the load impedance inside the characteristic is of course not allowed and the way to handle this with conventional distance protection is to consider this with the settings that is to have a security margin between the distance zone and the minimum load impedance This has the drawback that it will reduce the sensitivity of the protection that is the ability to detect resistive fau...

Page 221: ...ne application M17048 97 v4 In short line applications the major concern is to get sufficient fault resistance coverage Load encroachment is not so common The line length that can be recognized as a short line is not a fixed length it depends on system parameters such as voltage and source impedance see table 19 Table 19 Definition of short and very short line Line category Un Un 110 kV 500 kV Ver...

Page 222: ...h respect to the performance of distance protection can generally be described as in table 20 long lines have Source impedance ratio SIR s less than 0 5 Table 20 Definition of long and very long lines Line category Un Un 110 kV 500 kV Long lines 77 km 99 km 350 km 450 km Very long lines 99 km 450 km The IED s ability to set resistive and reactive reach independent for positive and zero sequence fa...

Page 223: ...nfluence the zero sequence impedance to the fault point but it does not normally cause voltage inversion It can be shown from analytical calculations of line impedances that the mutual impedances for positive and negative sequence are very small 1 2 of the self impedance and it is a practice to neglect them From an application point of view there exists three types of network configurations classe...

Page 224: ...r different distance zones within the same group of setting parameters Different groups of setting parameters for different operating conditions of a protected multi circuit line Most multi circuit lines have two parallel operating circuits Parallel line applications M17048 560 v4 This type of networks is defined as those networks where the parallel transmission lines terminate at common nodes at ...

Page 225: ...uit of the double circuit parallel operating line with a single phase to earth fault at the remote busbar When mutual coupling is introduced the voltage at the relay point A will be changed according to equation 110 0 0 0 0 1 1 3 3 3 1 3 1 m L L ph p ph L L L Z Z Z U Z I I I Z Z æ ö ç è ø IECEQUATION1276 V3 EN US Equation 110 By dividing equation 110 by equation 109 and after some simplification w...

Page 226: ...t the following relationship exists between the zero sequence currents 3 0 3 0 0 2 0 I Z I Z p L p L EQUATION1279 V3 EN US Equation 113 Simplification of equation 113 solving it for 3I0p and substitution of the result into equation 112 gives that the voltage can be drawn as U p ZI I K I K I p p A L ph N Nm 3 3 2 0 0 IECEQUATION1280 V2 EN US Equation 114 If we finally divide equation 114 with equat...

Page 227: ... figure 115 A B C IEC09000252_1_en vsd I0 I0 Z0m Z0 Z0m Z0 Z0m IEC09000252 V1 EN US Figure 115 Equivalent zero sequence impedance circuit for the double circuit line that operates with one circuit disconnected and earthed at both ends Here the equivalent zero sequence impedance is equal to Z0 Z0m in series with parallel of Z0 Z0m and Z0m which is equal to equation 116 2 2 0 0 om E Z Z Z Z EQUATION...

Page 228: ... the equivalent zero sequence impedance circuit for faults at the remote bus bar can be simplified to the circuit shown in figure 116 The line zero sequence mutual impedance does not influence the measurement of the distance protection in a faulty circuit This means that the reach of the underreaching distance protection zone is reduced if due to operating conditions the equivalent zero sequence i...

Page 229: ... V1 EN US Equation 121 The real component of the KU factor is equal to equation 122 Re Re Re Im K A X A A u m 1 0 2 2 2 EQUATION1287 V3 EN US Equation 122 The imaginary component of the same factor is equal to equation 123 2 0 2 2 Im Im Re Im m U A X K A A é ù é ù ë û ë û EQUATION1288 V2 EN US Equation 123 Ensure that the underreaching zones from both line ends will overlap a sufficient amount at ...

Page 230: ...Z Z I I I Z U U C Trf CT A C C TF 2 1 2 DOCUMENT11524 IMG3510 V3 EN US Equation 125 Where ZAT and ZCT is the line impedance from the A respective C station to the T point IA and IC is fault current from A respective C station for fault between T and B U2 U1 Transformation ratio for transformation of impedance at U1 side of the transformer to the measuring side U2 it is assumed that current and vol...

Page 231: ...hat is without selectivity conflicts Careful fault calculations are necessary to determine suitable settings and selection of proper scheme communication Fault resistance M17048 597 v8 The performance of distance protection for single phase to earth faults is very important because normally more than 70 of the faults on transmission lines are single phase to earth faults At these faults the fault ...

Page 232: ...considered for resistive phase to earth faults Zero sequence mutual coupling from parallel lines 8 3 3 2 Setting of zone 1 SEMOD55087 22 v3 The different errors mentioned earlier usually require a limitation of the underreaching zone normally zone 1 to 75 90 of the protected line In case of parallel lines consider the influence of the mutual coupling according to section Parallel line application ...

Page 233: ... section The whole line must be covered under all conditions The requirement that the zone 2 shall not reach more than 80 of the shortest adjacent line at remote end is highlighted in the example below If a fault occurs at point F see figure 119 the IED at point A senses the impedance Z V I Z I I I Z I I I I R Z I I Z AF A A AC A C A CF A C B A F AC C A C 1 F F C B A F I I I R 1 EQUATION302 V5 EN ...

Page 234: ... of the protected line However influence of mutual impedance has to be taken into account Parallel line in service setting of zone 2 SEMOD55087 55 v4 Overreaching zones in general zones 2 and 3 must overreach the protected circuit in all cases The greatest reduction of a reach occurs in cases when both parallel circuits are in service with a single phase to earth fault located at the end of a prot...

Page 235: ...rresponding zone zero sequence resistance and reactance equal to R0E R0 1 Xm0 2 R0 2 X0 2 è ø ç æ ö EQUATION561 V1 EN US Equation 134 X0E X0 1 Xm0 2 R0 2 X0 2 è ø ç æ ö EQUATION562 V1 EN US Equation 135 8 3 3 6 Setting of reach in resistive direction SEMOD55087 84 v7 Set the resistive reach R1 independently for each zone Set separately the expected fault resistance for phase to phase faults RFPP a...

Page 236: ...lowing instructions are valid when Phase selection with load encroachment quadrilateral characteristic function FDPSPDIS is not used The setting of the load resistance RLdFw and RLdRv in FDPSPDIS must in this case be set to max value 3000 If FDPSPDISis to be used for all or some of the measuring zones the load limitation for those zones according to this chapter can be omitted Check the maximum pe...

Page 237: ...to earth faults is more than three times as large as the maximum expected load impedance angle For the case when the loop characteristic angle is less than three times the load impedance angle more accurate calculations are necessary according to equation 143 RFFwPE Z R R X X load 0 8 2 1 0 2 1 0 cos sin min IEC13000274 V1 EN US Equation 143 Where is a maximum load impedance angle related to the m...

Page 238: ...e parameter IMinOpPP and IMinOpPE The default setting of IMinOpPP and IMinOpPE is 20 of IBase where IBase is the chosen current for the analogue input channels The value has been proven in practice to be suitable in most of the applications However there might be applications where it is necessary to increase the sensitivity by reducing the minimum operating current down to 10 of IBase This happen...

Page 239: ...d phase voltage in phase L1 1 L I is phase current in phase L1 1 2 1L L U is voltage difference between phase L1 and L2 L2 lagging L1 1 2 1L L M U is memorized voltage difference between phase L1 and L2 L2 lagging L1 1 2 L L I is current difference between phase L1 and L2 L2 lagging L1 The setting of ArgDir and ArgNegRes is by default set to 15 15 and 115 degrees respectively as shown in figure 12...

Page 240: ...e positive sequence voltage ensures correct directional discrimination The memory voltage is used for 100 ms or until the positive sequence voltage is restored After 100 ms the following occurs If the current is still above the set value of the minimum operating current between 10 and 30 of the set IED rated current IBase the condition seals in If the fault has caused tripping the trip endures If ...

Page 241: ... description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Full scheme distance protection mho characteristic ZMHPDIS S00346 V1 EN US 21 8 4 2 Application SEMOD154444 1 v1 8 4 2 1 Functionality SEMOD154453 4 v6 Transmission and sub transmission networks are being extended and often become more and more complex consisting of a high number of multi circuit and or mu...

Page 242: ...e shunt admittance may however have some marginal influence on the earth fault current in networks with long transmission lines The earth fault current at single phase to earth in phase L1 can be calculated as equation 148 L1 L1 0 1 2 0 f 1 N f 3 U U 3I Z Z Z 3Z Z Z Z EQUATION1267 V3 EN US Equation 148 Where UL1 is the phase to earth voltage kV in the faulty phase before fault Z1 is the positive s...

Page 243: ...mental frequency voltage before fault Another definition for effectively earthed network is when the following relationships between the symmetrical components of the network impedances are valid see equation 150 and equation 151 X X 0 1 3 EQUATION1269 V4 EN US Equation 150 R X 0 1 EQUATION1270 V4 EN US Equation 151 Where R0 is the zero sequence resistance X0 is the zero sequence reactance X1 is t...

Page 244: ...voltage 3U0 will have the same magnitude in different places in the network due to low voltage drop distribution The magnitude of the total fault current can be calculated according to equation 152 2 2 R L C 0 3I I I I EQUATION1271 V3 EN US Equation 152 where 3I0 is the earth fault current A IR is the current through the neutral point resistor A IL is the current through the neutral point reactor ...

Page 245: ...lement or the sensitivity will be too low for acceptance For this reason a separate high sensitive earth fault protection is necessary to carry out the fault clearance for single phase to earth fault 8 4 2 3 Fault infeed from remote end SEMOD154453 84 v4 All transmission and most all sub transmission networks are operated meshed Typical for this type of network is that we will have fault infeed fr...

Page 246: ...lt is cleared and high emergency load is transferred on the protected line The effect of load encroachment for the mho circle is illustrated to the left in figure 124 The entrance of the load impedance inside the characteristic is of course not allowed and the way to handle this with conventional distance protection is to consider this with the settings that is to have a security margin between th...

Page 247: ...his is valid in both directions R X RLdFw RLdRv ArgLd ArgLd ArgLd ArgLd IEC09000127 1 en vsd IEC09000127 V1 EN US Figure 125 Load encroachment of Faulty phase identification with load encroachment for mho function FMPSPDIS characteristic The use of the load encroachment feature is essential for long heavy loaded lines where there might be a conflict between the necessary emergency load transfer an...

Page 248: ... 1 5 5 km 5 25 km Short line 5 11 km 25 50 km The use of load encroachment algorithm in Full scheme distance protection mho characteristic function ZMHPDIS improves the possibility to detect high resistive faults without conflict with the load impedance see to the right of figure 124 For very short line applications the underreaching zone 1 can not be used due to that the voltage drop distribution...

Page 249: ...148 v2 General SEMOD154453 150 v4 Introduction of parallel lines in the network is increasing due to difficulties to get necessary area for new lines Parallel lines introduce an error in the measurement due to the mutual coupling between the lines The lines need not to be of the same voltage in order to experience mutual coupling and some coupling exists even for lines that are separated by 100 me...

Page 250: ...hen reduced to a single phase problem E I U IEC13000254 1 en vsd O IO IO O O IEC13000254 V1 EN US Figure 127 Mutual coupling of two three phase lines 0 0 0 3 M m Z Z U I IECEQUATION14003 V1 EN US Equation 157 Where ZM is the mutual impedance between two conductors with earth return as defined above This zero sequence mutual impedance can be as high as 70 of the self zero sequence impedance of a pr...

Page 251: ...class we can have three different topologies the parallel line can be in service out of service out of service and earthed in both ends The reach of the distance protection zone 1 will be different depending on the operation condition of the parallel line It is therefore recommended to use the different setting groups to handle the cases when the parallel line is in operation and out of service an...

Page 252: ... ph N E Z U I K I IECEQUATION14004 V1 EN US Equation 161 0 1 0 1 1 1 3 3 m ph E Ep ph ph n E ph n E Z Z Z Z I I I U Z Z Z I K I I K I IECEQUATION14007 V1 EN US Equation 162 Taking earth compensation factor 0 1 1 3 N Z Z K Z for single circuit and 0 1 3 m Nm Z K Z impedance measured by distance relay can be written as 1 1 Nm Ep ph N E Z Z K I I K I é ù ê ú ê ú ë û IECEQUATION14010 V1 EN US Equation...

Page 253: ...ched off and not earthed or earthed only at one line end 3 Case 3 Both lines in service The reach of the distance protection zone 1 will be different depending on the operation condition of the parallel line Compensation of the mutual zero sequence impedance of parallel circuit can be achieved by appropriate selection of zero sequence compensation factor KN when parallel line can be in service out...

Page 254: ...A C A AT TF A I I Z Z Z I EQUATION2302 V1 EN US Equation 166 2 A C C Trf CT TF C I I U2 Z Z Z Z I U1 æ ö æ ö ç ç è ø è ø IECEQUATION1750 V1 EN US Equation 167 where ZAT and ZCT is the line impedance from the A respective C station to the T point IA and IC is fault current from A respective C station for fault between T and B U2 U1 Transformation ratio for transformation of impedance at U1 side of ...

Page 255: ...sary to determine suitable settings and selection of proper scheme communication 8 4 3 Setting guidelines SEMOD154496 1 v2 8 4 3 1 General SEMOD154469 4 v7 The settings for Full scheme distance protection mho characteristic function ZMHPDIS are done in primary values The instrument transformer ratio that has been set for the analog input card is used to automatically convert the measured secondary...

Page 256: ...uld not be used This alternative is intended for use together with Distance protection zone quadrilateral characteristic ZMQPDIS 8 4 3 2 Setting of zone 1 GUID 4A9FE32F DA27 401A ADA1 94060A9F6C76 v1 The zone 1 distance elements must be set to underreach a protected circuit to ensure external fault security The different errors mentioned earlier usually require a limitation of the underreaching zo...

Page 257: ...ng 8 4 3 6 Setting of reverse zone GUID F79912AC E34A 4A6B 90B4 5F4619613CE5 v1 The criterion for setting zone 4 reverse reach would be as under The zone 4 reverse reach must adequately cover expected levels of apparent bus bar fault resistance when allowing for multiple in feeds from other circuits It is difficult to precisely apply the above criterion and in such cases the practice is to set zon...

Page 258: ...rth compensation factor for single circuit set at the relay given by equation Z0m is the zero sequence mutual coupling between the faulted and the parallel line x is the ratio of distance to fault and length of the line 0 1 1 3 N Z Z K Z IECEQUATION14005 V1 EN US Equation 169 K Z Z Nm m 0 1 3 IEC13000297 V1 EN US Equation 170 Case 2 Parallel line switched off and not earthed or earthed at one line...

Page 259: ...ations from above equations for case 1 2 and 3 GUID 6B411616 EB82 4447 BC2D 375D042BE110 v1 In case 1 the lowest impedance is measured that is the highest reach occurs due to the parallel connection of the zero sequence systems of both lines In case 3 the highest impedance is measured which corresponds to the shortest reach The mutual impedance will influence the distance measurement of ground fau...

Page 260: ...nce zones within the same group of setting parameters Alternative 2 Different groups of setting parameters for different operating conditions of a protected multi circuit line Alternative 1 Different kN setting values within the same setting group Setting of underreaching zone GUID 68709DD6 D5A7 4F04 ACE5 350B1F835364 v1 The set zone should fulfill two criteria It should avoid overreach beyond the...

Page 261: ...nd it is extended in the opposite one Therefore this reach reduction does not affect a permissive underreaching scheme Setting of overreaching zone GUID 1C500D3E 12A2 4F0F A5A8 A8054677DF4D v1 Zone 1 is not allowed to overreach under any condition Overreaching zones 2 and 3 are not allowed to underreach the whole line under any condition Setting of zone 2 GUID DB83C2EF A40F 4E18 BFC5 D617CE0C0438 ...

Page 262: ...ote line end KN3 for zone 3 can be set as for a single line that is 0 1 3 1 3 N K Z Z Z IECEQUATION14020 V1 EN US Equation 179 Alternative 2 Different groups of setting parameters for different operating conditions of a protected multi circuit line GUID DB67F163 289C 40C6 A850 074FFE61DEBC v2 Different group of setting parameters can be used for the three cases Parallel line switched off and earth...

Page 263: ...d in relation to the primary reach setting criterion 8 4 3 8 Load impedance limitation without load encroachment function SEMOD154469 91 v5 The following instruction is valid when the load encroachment function or blinder function is not activated BlinderMode Off The load encroachment function will not be activated if RLdFw and RLdRv is set to a value higher than expected minimal load impedance If...

Page 264: ...earth fault loop the following formula can be used Load Z ZPE 1 6 2 1 cos b EQUATION1604 V1 EN US Equation 182 where Zload magnitude of minimum load impedance ZPE 180 2 g 180 2 ArgPE QLoad The formula is derived by trigonometric analyze of the figure 132 The length of the vector from the origin O to the point F on the circle is defined by the law of cosine The result gives the maximum diameter RFP...

Page 265: ...able for all measuring zones when no power swing detection element or blinder is activated for the protection zones Use an additional safety margin of approximately 20 in cases when a power swing detection element is in the protection scheme refer to the description of the power swing detection function 8 4 3 9 Load impedance limitation with load encroachment function activated SEMOD154469 129 v3 ...

Page 266: ...or offset mho SEMOD154469 181 v3 If offset mho has been selected one can select if the offset mho shall be Non Directional Forward or Reverse by setting the parameter OfffsetMhoDir When forward or reverse operation is selected then the operation characteristic will be cut off by the directional lines used for the mho characteristic The setting is by default set to Non Directional 8 4 3 13 Setting ...

Page 267: ...d or multi terminal lines of very different lengths These changes in the network will normally impose more stringent demands on the fault clearing equipment in order to maintain an unchanged or increased security level of the power system The distance protection function in IED is designed to meet basic requirements for application on transmission and sub transmission lines solid earthed systems a...

Page 268: ...is the zero sequence impedance Ω phase Zf is the fault impedance Ω often resistive ZN is the earth return impedance defined as Z0 Z1 3 The voltage on the healthy phases is generally lower than 140 of the nominal phase to earth voltage This corresponds to about 80 of the nominal phase to phase voltage The high zero sequence current in solid earthed networks makes it possible to use impedance measur...

Page 269: ...therefore always be complemented with other protection function s that can carry out the fault clearance in this case High impedance earthed networks SEMOD154680 58 v3 In high impedance networks the neutral of the system transformers are connected to the earth through high impedance mostly a reactance in parallel with a high resistor This type of network is many times operated in radial but can al...

Page 270: ...system operators do not clear single phase to earth faults immediately they clear the line later when it is more convenient In case of cross country faults many network operators want to selectively clear one of the two earth faults To handle this type phenomena a separate function called Phase preference logic PPLPHIZ is needed which is not common to be used in transmission applications In this t...

Page 271: ...g on the differences in source impedances at local and remote end Z ZL Z EsA VA VA A B EsB IA IB Rf p ZL 1 p ZL ZSA ZSB en05000217 vsd IEC05000217 V1 EN US Figure 135 Influence of fault infeed from remote end The effect of fault current infeed from remote end is one of the most driving factors for justify complementary protection to distance protection 8 5 2 4 Load encroachment SEMOD154680 97 v3 I...

Page 272: ...ad transfer and necessary sensitivity of the distance protection ZMMPDIS function can also preferably be used on heavy loaded medium long lines For short lines the major concern is to get sufficient fault resistance coverage and load encroachment is not a major problem So for short lines the load encroachment function could preferable be switched off The settings of the parameters for load encroac...

Page 273: ... SEMOD154680 127 v2 For long transmission lines the margin to the load impedance that is to avoid load encroachment will normally be a major concern It is difficult to achieve high sensitivity for phase to earth fault at remote end of a long lines when the line is heavy loaded The definition of long lines with respect to the performance of distance protection is noted in table 25 Table 25 Definiti...

Page 274: ... line and rail road overhead lines This type of mutual coupling is not so common although it exists and is not treated any further in this manual For each type of network class we can have three different topologies the parallel line can be in service out of service out of service and earthed in both ends The reach of the distance protection zone1 will be different depending on the operation condi...

Page 275: ...mal sub transmission and transmission networks A simplified single line diagram is shown in figure 137 ph ph 0 1 ph N ph 0 1 0 V V Z Z I 3 K I 3I 3 Z I Z EQUATION1275 V3 EN US Equation 192 Where Vph is phase to earth voltage at the IED point Iph is phase current in the faulty phase 3I0 is earth to fault current Z1 is positive sequence impedance Z0 is zero sequence impedance Z0m A B Z Z en05000221 ...

Page 276: ...tection is underreaching with approximately 20 The zero sequence mutual coupling can reduce the reach of distance protection on the protected circuit when the parallel line is in normal operation The reduction of the reach is most pronounced with no infeed in the line IED closest to the fault This reach reduction is normally less than 15 But when the reach is reduced at one line end it is proporti...

Page 277: ... settings It is a recommendation to use a separate setting group for this operation condition since it will reduce the reach considerable when the line is in operation All expressions below are proposed for practical use They assume the value of zero sequence mutual resistance R0m equals to zero They consider only the zero sequence mutual reactance X0m Calculate the equivalent X0E and R0E zero seq...

Page 278: ...s means that the reach of the underreaching distance protection zone is reduced if due to operating conditions the equivalent zero sequence impedance is set according to the conditions when the parallel system is out of operation and earthed at both ends Z Z0 0 m Z Z0 0 m Z0m A B C 99000040 vsd I0 I0 IEC99000040 V1 EN US Figure 142 Equivalent zero sequence impedance circuit for a double circuit li...

Page 279: ...quation 199 The imaginary component of the same factor is equal to equation 200 2 0 2 2 Im Im Re Im m U A X K A A é ù é ù ë û ë û EQUATION1288 V2 EN US Equation 200 Ensure that the underreaching zones from both line ends will overlap a sufficient amount at least 10 in the middle of the protected circuit 8 5 2 8 Tapped line application SEMOD154680 265 v1 1MRK 506 369 UEN B Section 8 Impedance prote...

Page 280: ...IA IC IA DOCUMENT11524 IMG3509 V3 EN US Equation 201 Z Z Z I I I Z U U C Trf CT A C C TF 2 1 2 DOCUMENT11524 IMG3510 V3 EN US Equation 202 Where ZAT and ZCT is the line impedance from the B respective C station to the T point IA and IC is fault current from A respective C station for fault between T and B U2 U1 Transformation ratio for transformation of impedance at U1 side of the transformer to t...

Page 281: ...h enough sensitivity without interference with other zone1 settings that is without selectivity conflicts Careful fault calculations are necessary to determine suitable settings and selection of proper scheme communication Fault resistance SEMOD154680 288 v2 The performance of distance protection for single phase to earth faults is very important because normally more than 70 of the faults on tran...

Page 282: ...equence mutual coupling from parallel lines 8 5 3 2 Setting of zone1 SEMOD154704 15 v1 The different errors mentioned earlier usually require a limitation of the underreaching zone normally zone 1 to 75 90 of the protected line In case of parallel lines consider the influence of the mutual coupling according tosection Parallel line application with mutual coupling and select the case s that are va...

Page 283: ...occurs at point F the IED at point A senses the impedance Z V I Z I I I Z I I I I R Z I I Z AF A A AC A C A CF A C B A F AC C A C 1 F F C B A F I I I R 1 EQUATION302 V5 EN US Equation 204 A B Z C IA IC Z AC Z CB Z CF IA IC IEC05000457 2 en vsd F IB IEC05000457 V2 EN US Figure 144 Setting of overreaching zone 8 5 3 4 Setting of reverse zone SEMOD154704 33 v3 The reverse zone is applicable for purpo...

Page 284: ...ch occurs in cases when both parallel circuits are in service with a single phase to earth fault located at the end of a protected line The equivalent zero sequence impedance circuit for this case is equal to the one in figure 138 in section Parallel line applications The components of the zero sequence impedance for the overreaching zones must be equal to at least R0E R0 Rm0 EQUATION553 V1 EN US ...

Page 285: ...tion 212 8 5 3 6 Setting of reach in resistive direction SEMOD154704 76 v1 Set the resistive reach independently for each zone for phase to earth loop RIPE measurement Set separately the expected fault resistance for the phase to earth faults RFPE for each zone Set all remaining reach setting parameters independently of each other for each distance zone The final reach in resistive direction for p...

Page 286: ... Where U is the minimum phase to phase voltage in kV S is the maximum apparent power in MVA The load impedance Ω phase is a function of the minimum operation voltage and the maximum load current Zload Umin 3 Imax EQUATION574 V1 EN US Equation 217 Minimum voltage Umin and maximum current Imax are related to the same operating conditions Minimum load impedance occurs normally under emergency conditi...

Page 287: ...section Resistive reach with load encroachment characteristic If the characteristic for the impedance measurement shall be shaped with the load encroachment algorithm the parameter OperationLdCmp in the phase selection has to be switched On 8 5 3 9 Setting of minimum operating currents SEMOD154704 132 v2 The operation of the distance function will be blocked if the magnitude of the currents is bel...

Page 288: ...escription IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Additional distance protection directional function for earth faults ZDARDIR S00346 V1 EN US 8 6 2 Application SEMOD154885 5 v9 The phase to earth impedance elements can be supervised by a phase unselective directional function based on symmetrical components option 8 6 3 Setting guidelines SEMOD154897 5 v6 ...

Page 289: ...systems U2 may be larger than U0 If the bus behind the IED location is a strong zero sequence source the negative sequence voltage available at the IED location is higher than the zero sequence voltage negative sequence polarization is not affected by zero sequence mutual coupling zero sequence polarized directional elements may misoperate in parallel lines with high zero sequence mutual coupling ...

Page 290: ...current compensation U0Comp compares the phase angles of zero sequence current I0 with zero sequence voltage added by a phase shifted portion of zero sequence current see equation 220 at the location of the protection The factor k setting Kmag This type of polarization is intended for use in applications where the zero sequence voltage can be too small to be used as the polarizing quantity and the...

Page 291: ...ing scheme is very dependable because it will operate for faults anywhere on the protected line if the communication channel is out of service Conversely it is less secure than permissive schemes because it will trip for external faults within the reach of the tripping function if the communication channel is out of service Inadequate speed or dependability can cause spurious tripping for external...

Page 292: ...ge transformers are used set SIRLevel to 15 the highest level IMinOp The minimum operate current for the SIR measurement is by default set to 20 of IBase 8 8 Faulty phase identification with load encroachment FMPSPDIS SEMOD153819 1 v5 8 8 1 Identification SEMOD155879 2 v3 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Faulty phase identificatio...

Page 293: ...E for release of the phase to earth loop is by default set to 20 of IBase The default setting is suitable in most applications The setting must normally be set to at least 10 lower than the setting of INBlockPPto give priority to open phase to earth loop INRelPE must be above the normal un balance current 3I0 that might exist due to un transposed lines The setting must also be set higher than the ...

Page 294: ...age during the emergency conditions at the IED location 8 8 3 1 Load encroachment SEMOD154782 39 v4 The load encroachment function has two setting parameters RLd for the load resistance and ArgLd for the inclination of the load sector see figure 145 R X RLdFw RLdRv ARGLd ARGLd ARGLd ARGLd en05000226 vsd IEC05000226 V1 EN US Figure 145 Load encroachment characteristic The calculation of the apparen...

Page 295: ...conditions and Smax is the maximal apparent power transfer during emergency conditions The RLd can be calculated according to equation 227 cos RLd ZLoad ArgLd EQUATION1624 V1 EN US Equation 227 The setting of RLd and ArgLd is by default set to 80 ohm phase and 20 degrees Those values must be adapted to the specific application 8 9 Distance protection zone quadrilateral characteristic separate sett...

Page 296: ... or multi terminal lines of very different lengths These changes in the network will normally impose more stringent demands on the fault clearing equipment in order to maintain an unchanged or increased security level of the power system The distance protection function in the IED is designed to meet basic requirements for application on transmission and sub transmission lines although it also can...

Page 297: ...ce impedance Ω phase Zf is the fault impedance Ω often resistive ZN is the earth return impedance defined as Z0 Z1 3 The voltage on the healthy phases is generally lower than 140 of the nominal phase to earth voltage This corresponds to about 80 of the nominal phase to phase voltage The high zero sequence current in solid earthed networks makes it possible to use impedance measuring technique to d...

Page 298: ...nough for impedance measuring element to detect earth fault However in the same way as for solid earthed networks distance protection has limited possibilities to detect high resistance faults and should therefore always be complemented with other protection function s that can carry out the fault clearance in this case High impedance earthed networks GUID 099F53F9 7CD8 4D96 811D 7B55EF249FFF v1 I...

Page 299: ... EN US Figure 147 High impedance earthing network The operation of high impedance earthed networks is different compared to solid earthed networks where all major faults have to be cleared very fast In high impedance earthed networks some system operators do not clear single phase to earth faults immediately they clear the line later when it is more convenient In case of cross country faults many ...

Page 300: ...o figure 148 the equation for the bus voltage UA at A side is A A L A B f V I p Z I I R EQUATION1273 V1 EN US Equation 234 If we divide UA by IA we get Z present to the IED at A side a A B A L f A A V I I Z p Z R I I EQUATION1274 V2 EN US Equation 235 The infeed factor IA IB IA can be very high 10 20 depending on the differences in source impedances at local and remote end Z ZL Z ESA UA UB A B ESB...

Page 301: ...chment algorithm will increase the possibility to detect high fault resistances especially for phase to earth faults at remote line end For example for a given setting of the load angle ArgLd for Phase selection with load encroachment quadrilateral characteristic function FRPSPDIS the resistive blinder for the zone measurement can be expanded according to the figure 149 given higher fault resistan...

Page 302: ...ity to set resistive and reactive reach independent for positive and zero sequence fault loops and individual fault resistance settings for phase to phase and phase to earth fault together with load encroachment algorithm improves the possibility to detect high resistive faults without conflict with the load impedance see figure 149 For very short line applications the underreaching zone 1 can not...

Page 303: ...s in the network is increasing due to difficulties to get necessary area for new lines Parallel lines introduce an error in the measurement due to the mutual coupling between the parallel lines The lines need not be of the same voltage in order to experience mutual coupling and some coupling exists even for lines that are separated by 100 meters or more The mutual coupling does influence the zero ...

Page 304: ...ompensation for different distance zones within the same group of setting parameters Different groups of setting parameters for different operating conditions of a protected multi circuit line Most multi circuit lines have two parallel operating circuits Parallel line applications GUID 9980E92C EDB1 4E0C A4BD 167C896199A1 v1 This type of networks are defined as those networks where the parallel tr...

Page 305: ...IEC09000250 V1 EN US Figure 150 Class 1 parallel line in service The equivalent zero sequence circuit of the lines can be simplified see figure 151 A B C Z0m Z0m Z0 Z0m Z0 IEC09000253_1_en vsd IEC09000253 V1 EN US Figure 151 Equivalent zero sequence impedance circuit of the double circuit parallel operating line with a single phase to earth fault at the remote busbar When mutual coupling is introd...

Page 306: ...he currents have the same direction the distance protection will underreach Maximum overreach will occur if the fault current infeed from remote line end is weak If considering a single phase to earth fault at p unit of the line length from A to B on the parallel line for the case when the fault current infeed from remote line end is zero the voltage UA in the faulty phase at A side as in equation...

Page 307: ...most pronounced with no current infeed in the IED closest to the fault This reach reduction is normally less than 15 But when the reach is reduced at one line end it is proportionally increased at the opposite line end So this 15 reach reduction does not significantly affect the operation of a permissive underreaching scheme Parallel line out of service and earthed GUID 0242E2DB A7F8 4D7F 91D1 1C7...

Page 308: ...e setting group for this operation condition since it will reduce the reach considerably when the line is in operation All expressions below are proposed for practical use They assume the value of zero sequence mutual resistance R0m equals to zero They consider only the zero sequence mutual reactance X0m Calculate the equivalent X0E and R0E zero sequence parameters according to equation 244 and eq...

Page 309: ...n the parallel line to very low values In practice the equivalent zero sequence impedance circuit for faults at the remote bus bar can be simplified to the circuit shown in figure 154 The line zero sequence mutual impedance does not influence the measurement of the distance protection in a faulty circuit A B C IEC09000255_1_en vsd I0 I0 Z0m Z0 Z0m Z0m Z0 IEC09000255 V1 EN US Figure 155 Equivalent ...

Page 310: ...MG3509 V3 EN US Equation 246 Z Z Z I I I Z U U C Trf CT A C C TF 2 1 2 DOCUMENT11524 IMG3510 V3 EN US Equation 247 Where ZAT and ZCT is the line impedance from the A respective C station to the T point IA and IC is fault current from A respective C station for fault between T and B U2 U1 Transformation ratio for transformation of impedance at U1 side of the transformer to the measuring side U2 it ...

Page 311: ...electivity conflicts Careful fault calculations are necessary to determine suitable settings and selection of proper scheme communication Fault resistance GUID 115D7410 1398 45FB BDDD E778740E1641 v1 The performance of distance protection for single phase to earth faults is very important because normally more than 70 of the faults on transmission lines are single phase to earth faults At these fa...

Page 312: ...ting of zone 1 GUID 36A888E8 F209 478E B8C4 76370B644386 v1 The different errors mentioned earlier usually require a limitation of the underreaching zone normally zone 1 to 75 90 of the protected line In case of parallel lines consider the influence of the mutual coupling according to section Parallel line application with mutual coupling and select the case s that are valid in the particular appl...

Page 313: ...e end is highlighted in the example below If a fault occurs at point F see figure 157 the IED at point A senses the impedance Z V I Z I I I Z I I I I R Z I I Z AF A A AC A C A CF A C B A F AC C A C 1 F F C B A F I I I R 1 EQUATION302 V5 EN US Equation 249 A B Z C IC ZAC ZCB ZCF IA IC IEC09000256 2 en vsd F IA IB IEC09000256 V2 EN US Figure 157 Setting of overreaching zone 8 9 3 4 Setting of revers...

Page 314: ...3B 453C 83FC 21E3CFC37CB1 v1 Overreaching zones in general zones 2 and 3 must overreach the protected circuit in all cases The greatest reduction of a reach occurs in cases when both parallel circuits are in service with a single phase to earth fault located at the end of a protected line The equivalent zero sequence impedance circuit for this case is equal to the one in figure 113 in section Para...

Page 315: ...qual to R0E R0 1 Xm0 2 R0 2 X0 2 è ø ç æ ö EQUATION561 V1 EN US Equation 256 X0E X0 1 Xm0 2 R0 2 X0 2 è ø ç æ ö EQUATION562 V1 EN US Equation 257 8 9 3 6 Setting of reach in resistive direction GUID 3BFE80FD 8A51 4B71 8762 73DFA73AB28B v2 Set the resistive independently for each zone Set separately the expected fault resistance for phase to phase faults RFPP and for the phase to earth faults RFPE ...

Page 316: ... load enchroachment quadrilateral characteristic function FRPSPDIS is not activated To deactivate the function the setting of the load resistance RLdFw and RLdRv in FRPSPDIS must be set to max value 3000 If FRPSPDIS is to be used for all or some of the measuring zones the load limitation for those zones according to this chapter can be omitted Check the maximum permissible resistive reach for any ...

Page 317: ...ted load impedance angle For the case when the loop characteristic angle is less than three times the load impedance angle more accurate calculations are necessary according to equation 265 min 2 1 0 0 8 cos sin 2 1 0 load R Zx R Zx RFPEZx Z X Zx X Zx EQUATION578 V5 EN US Equation 265 Where is a maximum load impedance angle related to the maximum load power To avoid load encroachment for the phase...

Page 318: ...e might be applications where it is necessary to increase the sensitivity by reducing the minimum operating current down to 10 of IBase This happens especially in cases when the IED serves as a remote back up protection on series of very long transmission lines Setting IMinOpIN blocks the phase to earth loop if 3I0 IMinOpIN The default setting of IMinOpIN is 5 of IBase The minimum operating fault ...

Page 319: ... in some cases be in opposite to the wanted fault resistance coverage Therefore the function has a built in algorithm for load encroachment which gives the possibility to enlarge the resistive setting of both the Phase selection with load encroachment and the measuring zones without interfering with the load A current based phase selection is also included The measuring elements continuously measu...

Page 320: ... characteristic is dependent on the chosen operation mode of the FRPSPDIS function When output signal STCNDZis selected the characteristic for the FRPSPDIS and also zone measurement depending on settings can be reduced by the load encroachment characteristic as shown in figure 159 Section 8 1MRK 506 369 UEN B Impedance protection 314 Line distance protection REL670 2 2 IEC Application manual ...

Page 321: ...th a distance measuring zone the resultant operate characteristic could look something like in figure 160 The figure shows a distance measuring zone operating in forward direction Thus the operating area of the zone together with the load encroachment area is highlighted in black 1MRK 506 369 UEN B Section 8 Impedance protection Line distance protection REL670 2 2 IEC 315 Application manual ...

Page 322: ...rding to figure 161 Notice in particular what happens with the resistive blinders of the phase selection quadrilateral zone Due to the 30 degree rotation the angle of the blinder in quadrant one is now 100 degrees instead of the original 70 degrees The blinder that is nominally located to quadrant four will at the same time tilt outwards and increase the resistive reach around the R axis Consequen...

Page 323: ...en two phases is presented in fig 162 Since the load characteristic is based on the same measurement as the quadrilateral characteristic it will rotate with the quadrilateral characteristic clockwise by 30 degrees when subject to a pure phase to phase fault At the same time the characteristic shrinks by 2 3 from the full RLdFw RLdRv reach which is valid at load or three phase fault 1MRK 506 369 UE...

Page 324: ...es 8 10 3 Load encroachment characteristics GUID DD9A62C3 A56D 411B 8303 6F7BC4C6092D v1 The phase selector must at least cover the overreaching zone 2 in order to achieve correct phase selection for utilizing single phase autoreclosing for faults on the entire line It is not necessary to cover all distance protection zones A safety margin of at least 10 is recommended In order to get operation fr...

Page 325: ...ting guideline considers normal overhead lines applications and provides two different setting alternatives A A recommended characteristic angle of 60 degrees for the phase selection B A characteristic angle of 90 and 70 degrees for phase to earth and phase to phase respectively like implemented in the REL500 series The following figures illustrate alternative B 8 10 3 1 Phase to earth fault in fo...

Page 326: ...c Reactive reach GUID 8C693495 10FA 47D5 BEFC E72C8577E88B v1 The reactive reach in forward direction must as minimum be set to cover the measuring zone used in the Teleprotection schemes mostly zone 2 Equation 269 and equation 270 gives the minimum recommended reactive reach These recommendations are valid for both 60 and 90 deg characteristic angle PHS Zm X1 1 44 X1 EQUATION1309 V1 EN US Equatio...

Page 327: ... RFPE EQUATION2224 V2 EN US Equation 272 The security margin has to be increased in the case where φloop 60 to avoid that FRPSPDIS characteristic cuts off some part of the zone measurement characteristic RFFwPP and RFFRvPP must be set in a way that the loop characteristic angle can be 60 degrees or alternatively the same or lower compared to the measuring zone that must be covered If the character...

Page 328: ...7D9A 4DE5 92F1 FA1280BB899D v1 The fault resistance reaches in forward direction RFFwPP must cover RFPPZm with at least 25 margin RFPPZm is the setting of fault resistance for phase to phase fault for the longest overreaching zone to be covered by FRPSPDIS as shown in figure 164 The minimum recommended reach can be calculated according to equation 274 and 275 Index PHS in images and equations refe...

Page 329: ...tated 30 anti clock wise R1Zm X1Zm X1Zm 0 5 RFPPZm R1Zm 0 5 RFPPZM 0 5 RFPPZm 0 5 RFPPPm 0 5 RFPPZm R 70 j phase W 70 j PHS Zm RFFwPP 5 0 RFRvPP 5 0 RFRvPP 5 0 0 5 RFPPZm en08000249 vsd tan 70 1 X PHS tan 70 1 X PHS X1 R1PP R1PP X phase W IEC08000249 V1 EN US Figure 164 Relation between measuring zone and FRPSPDIS characteristic for phase to phase fault for φline 70 setting parameters in italic 1M...

Page 330: ...forward and reverse direction so it could be suitable to begin to calculate the setting for that parameter Set the parameter to the maximum possible load angle at maximum active load A value bigger than 20 must be used The blinder in forward direction RLdFw can be calculated according to equation 277 2 min 0 8 expmax U RLdFw P where Pexp max is the maximum exporting active power Umin is the minimu...

Page 331: ...election quad fixed angle load encroachment FDPSPDIS IP12400 1 v4 8 11 1 Identification 8 11 1 1 Identification M14850 1 v6 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Phase selection quad fixed angle load encroachment FDPSPDIS Z phs SYMBOL DD V1 EN US 21 8 11 2 Application M13138 3 v3 The operation of transmission networks today is in many ...

Page 332: ... connected to input on ZMQPDIS distance measuring block For normal overhead lines the angle for the loop impedance φ for phase to earth fault is defined according to equation 278 L L X1 arctan R1 j XN RN EQUATION2115 V1 EN US Equation 278 In some applications for instance cable lines the angle of the loop might be less than 60 In these applications the settings of fault resistance coverage in forw...

Page 333: ...SPDIS and impedance zone ZMQPDIS for phase to earth fault φloop 60 setting parameters in italic 1 FDPSPDIS phase selection red line 2 ZMQPDIS Impedance protection zone 3 RFltRevPGPHS 4 X1PHS XN tan 60 5 RFltFwdPGPHS 6 RFPGZM 7 X1PHS XN 8 φloop 9 X1ZM XN 1MRK 506 369 UEN B Section 8 Impedance protection Line distance protection REL670 2 2 IEC 327 Application manual ...

Page 334: ...ch M13142 103 v5 The resistive reach must cover RFPE for the overreaching zone to be covered mostly zone 2 Consider the longest overreaching zone if correct fault selection is important in the application Equation 281 gives the minimum recommended resistive reach min 1 1 zm RFFwPE RFPE EQUATION1312 V2 EN US Equation 281 where RFPEZm is the setting RFPE for the longest overreaching zone to be cover...

Page 335: ...esistance reaches in forward direction RFFwPP must cover RFPPZm with at least 25 margin RFPPZm is the setting of fault resistance for phase to phase fault for the longest overreaching zone to be covered by FDPSPDIS see Figure 167 The minimum recommended reach can be calculated according to equation 283 1 25 zm RFFwPP RFPP EQUATION1318 V3 EN US Equation 283 where RFPPZm is the setting of the longes...

Page 336: ...IS and FDPSPDIS characteristic for phase to phase fault for φline 60 setting parameters in italic 1 FDPSPDIS phase selection red line 2 ZMQPDIS Impedance protection zone 3 0 5 RFRvPP PHS 4 60 tan PHS X1 5 0 5 RFFwPPPHS 6 0 5 RFPPZm 7 X1PHS 8 X1Zm Section 8 1MRK 506 369 UEN B Impedance protection 330 Line distance protection REL670 2 2 IEC Application manual ...

Page 337: ...um possible load angle at maximum active load A value bigger than 20 must be used The blinder in forward direction RLdFw can be calculated according to equation 285 2 min 0 8 expmax U RLdFw P where Pexp max is the maximum exporting active power Umin is the minimum voltage for which the Pexp max occurs 0 8 is a security factor to ensure that the setting of RLdFw can be lesser than the calculated mi...

Page 338: ... 2 device number High speed distance protection zone ZMFPDIS S00346 V1 EN US 21 8 12 2 Application IP14961 1 v2 GUID 2F952D87 6BEB 4425 B823 DF8511B9E742 v3 The fast distance protection function ZMFPDIS in the IED is designed to provide sub cycle down to half cycle operating time for basic faults At the same time it is specifically designed for extra care during difficult conditions in high voltag...

Page 339: ... negative sequence impedance Ω phase Z0 is the zero sequence impedance Ω phase Zf is the fault impedance Ω often resistive ZN is the earth return impedance defined as Z0 Z1 3 The high zero sequence current in solidly earthed networks makes it possible to use impedance measuring techniques to detect earth faults However distance protection has limited possibilities to detect high resistance faults ...

Page 340: ...d possibilities to detect high resistance faults and should therefore always be complemented with other protection function s that can carry out the fault clearance in this case High impedance earthed networks GUID 02F306F5 1038 42AC AFAE 3F8423C4C066 v5 In high impedance networks the neutral of the system transformers are connected to the earth through high impedance mostly a reactance in paralle...

Page 341: ...ase to earth faults immediately they clear the line later when it is more convenient In case of cross country faults many network operators want to selectively clear one of the two earth faults In this type of network it is mostly not possible to use distance protection for detection and clearance of earth faults The low magnitude of the earth fault current might not give start of the zero sequenc...

Page 342: ...A ZA p ZL Rf EQUATION1274 IEC 650 V1 EN US Equation 293 The infeed factor IA IB IA can be very high 10 20 depending on the differences in source impedances at local and remote end Z ZL Z ESA UA UB A B ESB IA IB Rf p ZL 1 p ZL ZSA ZSB IEC09000247 1 en vsd IEC09000247 V1 EN US Figure 171 Influence of fault current infeed from remote line end The effect of fault current infeed from the remote line en...

Page 343: ...lity to detect high fault resistances especially for phase to earth faults at the remote line end For example for a given setting of the load angle ArgLd the resistive blinder for the zone measurement can be set according to figure 172 affording higher fault resistance coverage without risk for unwanted operation due to load encroachment Separate resistive blinder settings are available in forward...

Page 344: ...hing 8 12 2 5 Long transmission line application GUID 0C99A197 06CD 4668 A017 3CA9E5E01ED2 v4 For long transmission lines the margin to the load impedance that is to avoid load encroachment will normally be a major concern It is well known that it is difficult to achieve high sensitivity for phase to earth fault at remote line end of long lines when the line is heavy loaded What can be recognized ...

Page 345: ...allel circuits with common positive but isolated zero sequence network 3 Parallel circuits with positive and zero sequence sources isolated One example of class 3 networks could be the mutual coupling between a 400 kV line and rail road overhead lines This type of mutual coupling is not so common although it exists and is not treated any further in this manual For each type of network class there ...

Page 346: ...networks Let us analyze what happens when a fault occurs on the parallel line see figure 173 From symmetrical components we can derive the impedance Z at the relay point for normal lines without mutual coupling according to equation 294 Z U I I Z Z Z U I I K ph ph ph ph N 3 3 3 0 0 1 1 0 IECEQUATION1275 V2 EN US Equation 294 Where Uph is phase to earth voltage at the relay point Iph is phase curre...

Page 347: ...s the error introduced to the measurement of the line impedance If the current on the parallel line has negative sign compared to the current on the protected line that is the current on the parallel line has an opposite direction compared to the current on the protected line the distance function will overreach If the currents have the same direction the distance protection will underreach Maximu...

Page 348: ...tance p 71 that is the protection is underreaching with approximately 20 The zero sequence mutual coupling can reduce the reach of distance protection on the protected circuit when the parallel line is in normal operation The reduction of the reach is most pronounced with no current infeed in the IED closest to the fault This reach reduction is normally less than 15 But when the reach is reduced a...

Page 349: ...rement will be a considerable overreach which must be considered when calculating the settings It is recommended to use a separate setting group for this operation condition since it will reduce the reach considerably when the line is in operation All expressions below are proposed for practical use They assume the value of zero sequence mutual resistance R0m equals to zero They consider only the ...

Page 350: ... of the underreaching distance protection zone is reduced if due to operating conditions the equivalent zero sequence impedance is set according to the conditions when the parallel system is out of operation and earthed at both ends A B C IEC09000255_1_en vsd I0 I0 Z0m Z0 Z0m Z0m Z0 IEC09000255 V1 EN US Figure 178 Equivalent zero sequence impedance circuit for a double circuit line with one circui...

Page 351: ...ë û EQUATION1288 V2 EN US Equation 308 Ensure that the underreaching zones from both line ends will overlap a sufficient amount at least 10 in the middle of the protected circuit 8 12 2 7 Tapped line application GUID 740E8C46 45EE 4CE8 8718 9FAE658E9FCE v1 GUID 7AA566A4 B6E9 41A7 9927 4DAB50BE8D1A v1 C B BC IEC09000160 3 en vsd A IEC09000160 V3 EN US Figure 179 Example of tapped line with Auto tra...

Page 352: ...point to the fault divided by the IED current For the IED at C the impedance on the high voltage side U1 has to be transferred to the measuring voltage level by the transformer ratio Another complication that might occur depending on the topology is that the current from one end can have a reverse direction for fault on the protected line For example for faults at T the current from B might go in ...

Page 353: ...ting guidelines IP14962 1 v1 8 12 3 1 General GUID BA20D421 4435 44CA A6E9 743E461F8C59 v2 The settings for Distance measuring zones quadrilateral characteristic ZMFPDIS are done in primary values The instrument transformer ratio that has been set for the analog input card is used to automatically convert the measured secondary input signals to primary values used in ZMFPDIS The following basics m...

Page 354: ... higher than the fault current at the IED location The setting shall generally not exceed 80 of the following impedances The impedance corresponding to the protected line plus the first zone reach of the shortest adjacent line The impedance corresponding to the protected line plus the impedance of the maximum number of transformers operating in parallel on the bus at the remote end of the protecte...

Page 355: ... direction when the zone is used for blocking scheme weak end infeed and so on 1 2 2 Zrev ZL Z rem EQUATION1525 V5 EN US Equation 313 Where ZL is the protected line impedance Z2rem is zone 2 setting at remote end of protected line In many applications it might be necessary to consider the enlarging factor due to fault current infeed from adjacent lines in the reverse direction in order to obtain c...

Page 356: ... zero sequence mutual coupling The reach is reduced for a factor 0 0 1 2 1 0 m f Z K Z Z R EQUATION1426 V1 EN US Equation 316 If the denominator in equation 316 is called B and Z0m is simplified to X0m then the real and imaginary part of the reach reduction factor for the overreaching zones can be written as 2 2 0 Re Re 0 1 Re Im X m B K B B EQUATION1427 V2 EN US Equation 317 2 2 0 Im Im 0 Re Im X...

Page 357: ...ATION2304 V2 EN US Equation 322 Setting of the resistive reach for the underreaching zone 1 should follow the condition to minimize the risk for overreaching RFPEZx 4 5 X1Zx IECEQUATION2305 V2 EN US Equation 323 The fault resistance for phase to phase faults is normally quite low compared to the fault resistance for phase to earth faults To minimize the risk for overreaching limit the setting of t...

Page 358: ...as reference points to improve the performance of the phase selection The maximum permissible resistive reach for any zone must be checked to ensure that there is a sufficient setting margin between the boundary and the minimum load impedance The minimum load impedance Ω phase is calculated with equation 325 Zloadmin U 2 S EQUATION571 V1 EN US Equation 325 Where U the minimum phase to phase voltag...

Page 359: ... related to the maximum load power To avoid load encroachment for the phase to phase measuring elements the set resistive reach of any distance protection zone must be less than 160 of the minimum load impedance load 1 6 Z RFPPZx EQUATION579 V3 EN US Equation 329 Equation 329 is applicable only when the loop characteristic angle for the phase to phase faults is more than three times as large as th...

Page 360: ...For a phase to earth fault it corresponds to the per loop impedance including the earth return impedance R X RLdFw RLdRv ArgLd 90 10 10 ARGLd Possible load ARGLd ARGLd R X RLdFw RLdRv XLd XLd ARGLd ARGLd ARGLd ARGLd IEC12000176 2 en vsd IEC12000176 V2 EN US Figure 181 Load impedance limitation with load encroachment During the initial current change for phase to phase and for phase to earth faults...

Page 361: ...n IMinOpPP Zx ILmLn is the RMS value of the vector difference between phase currents Lm and Ln Both current limits IMinOpPEZx and IMinOpPPZx are automatically reduced to 75 of regular set values if the zone is set to operate in reverse direction that is OperationDir is set to Reverse OpModePPZx and OpModePEZx These settings two per zone x 1 2 5 RV with options Off Quadrilateral Mho Offset are used...

Page 362: ...g zones 3 to 5 tPPZx tPEZx TimerModeZx ZoneLinkStart and TimerLinksZx The logic for the linking of the timer settings can be described with a module diagram The figure 183 shows only the case when TimerModeZx is selected to Ph Ph and Ph E Section 8 1MRK 506 369 UEN B Impedance protection 356 Line distance protection REL670 2 2 IEC Application manual ...

Page 363: ...ferro resonance This component is practically idle during normal load and fault conditions hence the name passive CVTs that have a high resistive burden to mitigate ferro resonance also fall into this category Any This option is primarily related to the so called active type CVT which uses a set of reactive components to form a filter circuit that essentially attenuates frequencies other than the ...

Page 364: ... circuits of a double line One specific situation where the INReleasePE setting should be altered is for cross country faults in high impedance earthed networks in order to make sure that operation is phase to earth This is particularly important when using phase preference logic since it is only working per phase not for phase to phase measurement The limit should be set so that it will be exceed...

Page 365: ...fault clearing equipment in order to maintain an unchanged or increased security level of the power system The high speed distance protection function ZMFCPDIS in the IED is designed to provide sub cycle down to half cycle operate time for basic faults At the same time it is specifically designed for extra care during difficult conditions in high voltage transmission networks like faults on long h...

Page 366: ...ce impedance Ω phase Zf is the fault impedance Ω often resistive ZN is the earth return impedance defined as Z0 Z1 3 The voltage on the healthy phases is generally lower than 140 of the nominal phase to earth voltage This corresponds to about 80 of the nominal phase to phase voltage The high zero sequence current in solidly earthed networks makes it possible to use impedance measuring techniques t...

Page 367: ...ly earthed networks is high enough for impedance measuring elements to detect earth faults However in the same way as for solidly earthed networks distance protection has limited possibilities to detect high resistance faults and should therefore always be complemented with other protection function s that can carry out the fault clearance in this case High impedance earthed networks GUID 123D2D9D...

Page 368: ... US Equation 339 The infeed factor IA IB IA can be very high 10 20 depending on the differences in source impedances at local and remote end Z ZL Z ESA UA UB A B ESB IA IB Rf p ZL 1 p ZL ZSA ZSB IEC09000247 1 en vsd IEC09000247 V1 EN US Figure 185 Influence of fault current infeed from remote line end The effect of fault current infeed from remote line end is one of the most driving factors to jus...

Page 369: ...example for a given setting of the load angle ArgLd the resistive blinder for the zone measurement can be expanded according to the right part of the figure 186 given higher fault resistance coverage without risk for unwanted operation due to load encroachment This is valid in both directions The use of the load encroachment feature is essential for long heavily loaded lines where there might be a...

Page 370: ...ent is normally no problem for short line applications 8 13 2 5 Long transmission line application GUID AD1A1A5B B4F5 4B48 9DBD 59D28D71BA9C v3 For long transmission lines the margin to the load impedance to avoid load encroachment is a major concern It is difficult to achieve high sensitivity for phase to earth fault at remote line end of long lines when the line is heavy loaded What can be recog...

Page 371: ...eparated by 100 meters or more The mutual coupling does not normally cause voltage inversion It can be shown from analytical calculations of line impedances that the mutual impedances for positive and negative sequence are very small 1 2 of the self impedance and it is a practice to neglect them From an application point of view there exists three types of network configurations classes that must ...

Page 372: ...nes within the same group of setting parameters Different groups of setting parameters for different operating conditions of a protected multi circuit line Most multi circuit lines have two parallel operating circuits Parallel line applications GUID 74355B21 61D3 47A9 A3AE 2D56B2EDDC3C v2 This type of networks is defined as those networks where the parallel transmission lines terminate at common n...

Page 373: ...uit of the double circuit parallel operating line with a single phase to earth fault at the remote busbar When mutual coupling is introduced the voltage at the relay point A will be changed according to equation 341 0 0 0 0 1 1 3 3 3 1 3 1 m L L ph p ph L L L Z Z Z U Z I I I Z Z æ ö ç è ø IECEQUATION1276 V3 EN US Equation 341 By dividing equation 341 by equation 340 and after some simplification w...

Page 374: ...n the zero sequence currents 3 0 3 0 0 2 0 I Z I Z p L p L EQUATION1279 V3 EN US Equation 344 Simplification of equation 344 solving it for 3I0p and substitution of the result into equation 343 gives that the voltage can be drawn as U p ZI I K I K I p p A L ph N Nm 3 3 2 0 0 IECEQUATION1280 V2 EN US Equation 345 If we finally divide equation 345 with equation 340 we can draw the impedance present ...

Page 375: ... Z0 Z0m Z0 Z0m IEC09000252 V1 EN US Figure 191 Equivalent zero sequence impedance circuit for the double circuit line that operates with one circuit disconnected and earthed at both ends Here the equivalent zero sequence impedance is equal to Z0 Z0m in parallel with Z0 Z0m Z0 Z0m Z0m which is equal to equation 347 2 2 0 0 om E Z Z Z Z EQUATION2002 V4 EN US Equation 347 The influence on the distanc...

Page 376: ... on the parallel line to very low values In practice the equivalent zero sequence impedance circuit for faults at the remote bus bar can be simplified to the circuit shown in figure 192 The line zero sequence mutual impedance does not influence the measurement of the distance protection in a faulty circuit This means that the reach of the underreaching distance protection zone is reduced if due to...

Page 377: ...on 352 The real component of the KU factor is equal to equation 353 Re Re Re Im K A X A A u m 1 0 2 2 2 EQUATION1287 V3 EN US Equation 353 The imaginary component of the same factor is equal to equation 354 2 0 2 2 Im Im Re Im m U A X K A A é ù é ù ë û ë û EQUATION1288 V2 EN US Equation 354 Ensure that the underreaching zones from both line ends will overlap a sufficient amount at least 10 in the ...

Page 378: ...Equation 355 Z Z Z I I I Z U U C Trf CT A C C TF 2 1 2 DOCUMENT11524 IMG3510 V3 EN US Equation 356 Where ZAT and ZCT is the line impedance from the A respective C station to the T point IA and IC is fault current from A respective C station for fault between T and B U2 U1 Transformation ratio for transformation of impedance at U1 side of the transformer to the measuring side U2 it is assumed that ...

Page 379: ...essary to determine suitable settings and selection of proper scheme communication Fault resistance GUID D42B3721 E63B 411E A7DD 5F606ECA4576 v1 The performance of distance protection for single phase to earth faults is very important because normally more than 70 of the faults on transmission lines are single phase to earth faults At these faults the fault resistance is composed of three parts ar...

Page 380: ...pse limit GUID 0AB9B4B5 92DF 4A3B 9046 FC3A460DA658 v1 A series capacitor is capable of compensating the voltage drop of the series inductance in a transmission line as shown in figure 195 During low loading the system voltage drop is lower and at the same time the voltage drop on the series capacitor is lower When the loading increases and the voltage drop become larger the contribution of the se...

Page 381: ...ying the circuit shown in figure 197 The power transfer on the transmission line is given by the equation 360 sin sin 1 d d A B A B Line C Line C U U U U P X X X K EQUATION1897 V1 EN US Equation 360 The compensation degree Kc is defined as equation A B jXC PA QA PB QB UA UB U jXL UA UB d D en06000590 vsd IEC06000590 V1 EN US Figure 197 Transmission line with series capacitor The effect on the powe...

Page 382: ...nd fault on the protected line Figure 200 presents the corresponding phasor diagrams for the cases with bypassed and fully inserted series capacitor Voltage distribution on faulty lossless serial compensated line from fault point F to the bus is linearly dependent on distance from the bus if there is no capacitor included in scheme as shown in figure 200 Voltage UM measured at the bus is equal to ...

Page 383: ...N US Figure 200 Phasor diagrams of currents and voltages for the bypassed and inserted series capacitor during voltage inversion It is obvious that voltage UM will lead the fault current IF as long as XL1 XC This situation corresponds from the directionality point of view to fault conditions on line without series capacitor Voltage UM in IED point will lag the fault current IF in case when L1 C S ...

Page 384: ...rce It is generally anticipated that fault current IF flows on non compensated lines from power source towards the fault F on the protected line Series capacitor may change the situation en06000607 vsd Z XS XL1 IF U UM Source Fault voltage Pre fault voltage XC Source voltage U M With bypassed capacitor With inserted capacitor F IEC06000607 V1 EN US Figure 201 Current inversion on series compensate...

Page 385: ...nes with possible current inversion Equation 364 shows also big dependence of possible current inversion on series compensated lines on location of series capacitors XL1 0 for faults just behind the capacitor when located at line IED and only the source impedance prevents current inversion Current inversion has been considered for many years only a theoretical possibility due to relatively low val...

Page 386: ...05 LOC 0 which requires special design of distance measuring elements to cope with such phenomena The advantage of such installation is that the protection zone covers also the series capacitor as a part of protected power line so that line protection will detect and cleared also parallel faults on series capacitor Line side instrument transformers GUID 3E5897C4 9A15 4A51 90C2 F619D4E083A6 v1 CT2 ...

Page 387: ...D69661A020D v2 Series capacitors reduce due to their character the apparent impedance measured by distance IEDs on protected power lines Figure 204 presents typical locations of capacitor banks on power lines together with corresponding compensation degrees Distance IED near the feeding bus will see in different cases fault on remote end bus depending on type of overvoltage protection used on capa...

Page 388: ...t 50 of line length and 33 compensation located on 33 and 66 of line length The remote end compensation has the same effect The voltage inversion occurs in cases when the capacitor reactance between the IED point and fault appears bigger than the corresponding line reactance Figure 205 80 compensation at local end A voltage inversion occurs in IED point and the distance IED will see wrong directio...

Page 389: ...located at line end case LOC 0 in figure 205 Series capacitor prevails the scheme as long as the line current remains lower or equal to its protective current level I kp INC Line apparent impedance is in this case reduced for the complete reactance of a series capacitor 50 of capacitor reactance appears in series with resistance which corresponds to approximately 36 of capacitor reactance when the...

Page 390: ...ves the following expressions U jI X I I X X B B LB A B LF C 1 EQUATION1912 V2 EN US Equation 367 0 1 LB C B LF A B X X U X I I EQUATION1913 V1 EN US Equation 368 Equation 367 indicates the fact that the infeed current IA increases the apparent value of capacitive reactance in system bigger the infeed of fault current bigger the apparent series capacitor in a complete series compensated network It...

Page 391: ...ries compensated and adjacent lines worldwide It has at the same time caused a lot of challenges to protection society especially when it comes to directional measurement and transient overreach Distance IED in fact does not measure impedance or quotient between line current and voltage Quantity 1 Operating quantity Restrain quantity Quantity 2 Polarizing quantity Typically Operating quantity is t...

Page 392: ...rgin the remote end bus Distance protection Zone 1 is often set to 1 11 12 Z S C X K X X X EQUATION1914 V1 EN US Equation 369 Here KS is a safety factor presented graphically in figure 210 which covers for possible overreaching due to low frequency sub harmonic oscillations Here it should be noted separately that compensation degree KC in figure 210 relates to total system reactance inclusive line...

Page 393: ...f overreach which can be considered as a disadvantage from a security point of view en06000620 vsd X11 X12 jXC A B DA DB Permissive Zone A Permissive Zone B IEC06000620 V1 EN US Figure 211 Permissive overreach distance protection scheme Negative IED impedance positive fault current voltage inversion GUID 4FB71D72 36F1 4FCD 9321 D069CF6E9835 v2 Assume in equation 370 11 11 C S X X X X EQUATION1898 ...

Page 394: ... must be delayed until the gap flashing has taken place If the delay is not acceptable some directional comparison must also be added to the protection of all adjacent power lines As stated above a good protection system must be able to operate correctly both before and after gap flashing occurs Distance protection can be used but careful studies must be made for each individual case The rationale...

Page 395: ... has flashed the situation for protection will be as for an ordinary fault However a good protection system should be able to operate correctly before and after gap flashing occurs en06000625 vsd jX R X11 X12 XC ZS IEC06000625 V1 EN US Figure 213 Cross polarized quadrilateral characteristic en06000584_small vsd jX R X11 X12 XC ZS X FW X RV RFW RRV IEC06000584 SMALL V1 EN US Figure 214 Quadrilatera...

Page 396: ...tion for a negative current in case of an earth fault can be written as follows 1_ 1 0 _ 1 0 _ 1_ 3 2 2 C L L S S X X X X X EQUATION1920 V1 EN US Equation 378 All designations relates to figure 201 A good protection system must be able to cope with both positive and negative direction of the fault current if such conditions can occur A distance protection cannot operate for negative fault current ...

Page 397: ...ce may disturb also correct operation of distance protection for external evolving faults when one circuit has already been disconnected in one phase and runs non symmetrical during dead time of single pole autoreclosing cycle All such operating conditions must carefully be studied in advance and simulated by dynamic simulations in order to fine tune settings of distance IEDs If the fault occurs i...

Page 398: ...ies will be accentuated because the ratio of mutual impedance against self impedance will be much higher than for a non compensated line If non unit protection is to be used in a directional comparison mode schemes based on negative sequence quantities offer the advantage that they are insensitive to mutual coupling However they can only be used for phase to earth and phase to phase faults For thr...

Page 399: ... protected line Considering the different errors that might influence the measurement in the same way as for zone 1 it is necessary to increase the reach of the overreaching zone to at least 120 of the protected line The zone 2 reach can be even higher if the fault infeed from adjacent lines at the remote end is considerably higher than the fault current that comes from behind of the IED towards t...

Page 400: ...n of the bus bar or power transformers It is necessary to secure that it always covers the overreaching zone used at the remote line IED for the telecommunication purposes Consider the possible enlarging factor that might exist due to fault infeed from adjacent lines The equation can be used to calculate the reach in reverse direction when the zone is used for blocking scheme weak end infeed and s...

Page 401: ...ith respect to this apparent fault as the protection at the bus Different settings of the reach for the zone ZMFCPDIS characteristic in forward and reverse direction makes it possible to optimize the settings in order to maximize dependability and security for independent zone1 Due to the sub harmonic oscillation swinging caused by the series capacitor at fault conditions the reach of the under re...

Page 402: ... zone 1 reach unnecessary reduced The highest degree of compensation will occur at three phase fault and therefore the calculation need only to be performed for three phase faults The compensation degree in earth return path is different than in phases It is for this reason possible to calculate a compensation degree separately for the phase to phase and three phase faults on one side and for the ...

Page 403: ... approximate 33 of XLine X1Fw is set to XLine XC p 100 X1Rv max 1 5 x XC XLLOCC X1Fw is defined according to figure 219 When the calculation of X1Fwgives a negative value the zone 1 must be permanently blocked For protection on non compensated lines facing series capacitor on next line The setting is thus X1Fw is set to XLine XC K p 100 1MRK 506 369 UEN B Section 8 Impedance protection Line distan...

Page 404: ...he sub harmonic swinging the tripping will to a high degree be achieved by the communication scheme With the reduced reach of the under reaching zones not providing effective protection for all faults along the length of the line it becomes essential to provide over reaching schemes like permissive overreach transfer trip POTT or blocking scheme can be used Thus it is of great importance that the ...

Page 405: ... v1 Parallel line in service Setting of zone 1 GUID 1EDD265C 43D4 4D1A A9DC 830E18B3267C v1 With reference to section Parallel line applications the zone reach can be set to 85 of the protected line However influence of mutual impedance has to be taken into account Parallel line in service setting of zone 2 GUID 0985014F B0CB 4872 8644 F87B34973B1F v1 Overreaching zones in general zones 2 and 3 mu...

Page 406: ...rresponding zone zero sequence resistance and reactance equal to R0E R0 1 Xm0 2 R0 2 X0 2 è ø ç æ ö EQUATION561 V1 EN US Equation 387 X0E X0 1 Xm0 2 R0 2 X0 2 è ø ç æ ö EQUATION562 V1 EN US Equation 388 8 13 4 7 Setting of reach in resistive direction GUID 43EE13AF BEBC 4A13 95B3 53C28B9164CB v3 Set the resistive reach R1 independently for each zone Set separately the expected fault resistance for...

Page 407: ... encroachment functionality is not needed that is when the load is not encroaching on the distance zones Always define the load encroachment boundary according to the actual load or in consideration of how far the phase selection must actually reach 8 13 4 8 Load impedance limitation without load encroachment function GUID 16C2EB30 7FEA 42E4 98C8 52CCC36644C6 v5 The following instructions are vali...

Page 408: ...Z EQUATION792 V2 EN US Equation 395 This equation is applicable only when the loop characteristic angle for the single phase to earth faults is more than three times as large as the maximum expected load impedance angle For the case when the loop characteristic angle is less than three times the load impedance angle more accurate calculations are necessary according to equation 396 min 2 1 0 0 8 c...

Page 409: ... soon as the symmetrical load impedance crosses the vertical boundaries defined by RLdFw and RLdRv 9 or the lines defined by ArgLd So it is necessary to consider some margin It is recommended to set RLdFw and RLdRv to 90 of the per phase resistance that corresponds to maximum load min 0 9 load RLdFw R IECEQUATION2419 V2 EN US Equation 399 min 0 9 load RLdRv R IECEQUATION2420 V2 EN US Equation 400 ...

Page 410: ...ergency load for the pole open situation Again this is only for the application where there is a risk that one breaker pole would open without a preceding fault If this never happens for example when there is no parallel circuit there is no need to change any phase to earth reach according to the pole open scenario 8 13 4 10 Parameter setting guidelines GUID B28677F4 B909 42C1 B1B7 1C118B26E67D v4...

Page 411: ...The result from respective set value is illustrated in figure 222 below where positive impedance corresponds to the direction out on the protected line IEC05000182 2 en vsdx R X R X R X Non directional Forward Reverse IEC05000182 V2 EN US Figure 222 Directional operating modes of the distance measuring zones 3 to 5 tPPZx tPEZx TimerModeZx ZoneLinkStart and TimerLinksZx Refer to chapter Simplified ...

Page 412: ...ied at all None Magnetic This option should be selected if the voltage transformer is fully magnetic INReleasePE This setting opens up an opportunity to enable phase to earth measurement for phase to phase earth faults It determines the level of residual current 3I0 above which phase to earth measurement is activated and phase to phase measurement is blocked The relations are defined by the follow...

Page 413: ...ed minimum impedance value An impedance that is lower than ZMin has the quality attribute as Out of Range 8 14 Power swing detection ZMRPSB IP14499 1 v3 8 14 1 Identification M14853 1 v3 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Power swing detection ZMRPSB Zpsb SYMBOL EE V1 EN US 68 8 14 2 Application IP14969 1 v1 8 14 2 1 General M13874 ...

Page 414: ... Impedance plane with Power swing detection operating characteristic and impedance locus at power swing 8 14 2 2 Basic characteristics M13874 11 v6 Power swing detection function ZMRPSB reliably detects power swings with periodic time of swinging as low as 200 ms which means slip frequency as high as 10 of the rated frequency on the 50 Hz basis It detects the swings under normal system operation c...

Page 415: ...on the corresponding busbar It is necessary to consider separate contributions of different connected circuits The required data is as follows 400 r U kV EQUATION1321 V1 EN US Rated system voltage min 380 U kV EQUATION1322 V1 EN US Minimum expected system voltage under critical system conditions 50 r f Hz EQUATION1323 V1 EN US Rated system frequency 400 3 p U kV EQUATION1324 V1 EN US Rated primary...

Page 416: ...minimum load impedance at minimum expected system voltage is equal to equation 402 2 2 min min max 380 144 4 1000 L U Z S W EQUATION1337 V1 EN US Equation 402 The minimum load resistance RLmin at maximum load and minimum system voltage is equal to equation 403 min min max cos 144 4 0 95 137 2 L L R Z j W EQUATION1338 V1 EN US Equation 403 The system impedance ZS is determined as a sum of all imped...

Page 417: ...QUATION1342 V1 EN US Equation 406 The center of oscillation resides on the impedance point according to equation 407 1 7 43 33 9 2 S CO SA Z Z Z j W EQUATION1341 V1 EN US Equation 407 1MRK 506 369 UEN B Section 8 Impedance protection Line distance protection REL670 2 2 IEC 411 Application manual ...

Page 418: ...t with certain safety margin KL compared to the minimum expected load resistance RLmin When the exact value of the minimum load resistance is not known the following approximations may be considered for lines with a rated voltage of 400 kV KL 0 9 for lines longer than 150 km KL 0 85 for lines between 80 and 150 km KL 0 8 for lines shorter than 80 km Section 8 1MRK 506 369 UEN B Impedance protectio...

Page 419: ...al δIn boundary of proposed oscillation detection characteristic in forward direction are calculated with sufficient accuracy according to equation 410 and 411 respectively 155 75 2 arc tan 2 arc tan 64 5 2 2 123 5 d æ ö æ ö ç ç ç è ø è ø S Out Z RLdOutFw EQUATION1345 V1 EN US Equation 410 max 155 75 2 arctan 2 arc tan 76 5 2 2 98 8 d æ ö æ ö ç ç ç è ø è ø S In Z RLdInFw EQUATION1346 V1 EN US Equa...

Page 420: ... of tP2 time remains higher than 10 ms see equation 417 max 91 5 64 5 2 10 7 360 7 360 In Out sc tP ms f d d EQUATION1352 V1 EN US Equation 417 The final proposed settings are as follows RLdOutFw 123 5Ω kLdRFw 0 61 tP1 30 ms tP2 10 ms Consider RLdInFw 75 0Ω Do not forget to adjust the setting of load encroachment resistance RLdFw in Phase selection with load encroachment FDPSPDIS or FRPSPDIS to th...

Page 421: ...recommended to use different setting groups for operating conditions which are changing only between different periods of year summer winter System studies should determine the settings for the hold timer tH The purpose of this timer is to secure continuous output signal from the Power swing detection function ZMRPSB during the power swing even after the transient impedance leaves ZMRPSB operating...

Page 422: ...tinguish between the following main cases A fault occurs on a so far healthy power line over which the power swing has been detected and the fast distance protection zone has been blocked by ZMRPSB element The power swing occurs over two phases of a protected line during the dead time of a singlepole auto reclosing after the Ph E fault has been correctly cleared by the distance protection The seco...

Page 423: ...aults on so far healthy lines with detected power swings In these cases it is recommended to use an optionally available directional overcurrent earth fault protection with scheme communication logic R jX B A Measured impedance at initital fault position Impedance locus at initial power swing after the fault clearance ZMRPSB operating characteristic Zone 2 Zone 1 IEC99000181_2_en vsd IEC99000181 V...

Page 424: ... remote line end It is preferred to use the communication channels over the optionally available Line Data Communication Module LDCM and the Binary signal transfer to remote end function It is also possible to include in an easy way by means of configuration possibilities the complete functionality into regular scheme communication logic for the distance protection function The communication schem...

Page 425: ... input should be connected to the starting signal of the power swing detection ZMRPSB function which becomes active in cases of detected system oscillations The CSUR functional input should be connected to the starting output of the power swing distance protection zone which is used as a local tripping criteria during power swings in PUTT schemes When the POTT scheme is used also on series compens...

Page 426: ...of the circuit breaker used etc Time difference between 100 ms and 150 ms is generally sufficient Reactive reach setting of power swing distance protection zones SEMOD131360 37 v2 Set the reactive reach for the power swing zones according to the system selectivity planning The reach of the underreaching zone should not exceed 85 of the protected line length The reach of the overreaching zone shoul...

Page 427: ...ete protection system These settings differ within different power systems The recommended settings consider only the general system conditions and the most used practice at different utilities It is always necessary to check the local system conditions The carrier send timer tCS is used for safety reasons within the logic It requires continuous presence of the input signal STPSD before it can iss...

Page 428: ...l boundaries STZML BLOCK STMZH STZMPSD STPSD t tDZ t tZL 1 loop 1 STZMLL BLKZMH en06000237 vsd IEC06000237 V1 EN US Figure 229 Blocking and tripping logic for evolving power swings No system oscillation should be detected in power system Configure for this reason the STPSD functional input to the START functional output of ZMRPSB function or to any binary input signal indicating the detected oscil...

Page 429: ...acteristic longer than the set time tZL Its setting depends on the expected speed of the initial swings and on the setting of the time delay for the overreaching zone 2 The release timer must still permit selective tripping of the distance protection within the complete network A setting between 200 and 300 ms is generally sufficient 8 16 Pole slip protection PSPPPAM SEMOD156709 1 v2 8 16 1 Identi...

Page 430: ...illate against each other If the connection between the generators is too weak the amplitude of the oscillations will increase until the angular stability is lost At the moment of pole slip there will be a centre of this pole slip which is equivalent with distance protection impedance measurement of a three phase If this point is situated in the generator itself the generator should be tripped as ...

Page 431: ...the generator before the pole slip For this fault the under excitation protection and PSPPPAM function will give mutual redundancy The operation of a generator having pole slip will give risk of damages to the generator block At each pole slip there will be significant torque impact on the generator turbine shaft In asynchronous operation there will be induction of currents in parts of the generat...

Page 432: ... guidelines SEMOD167596 1 v1 SEMOD167582 4 v4 GlobalBaseSel Selects the global base value group used by the function to define IBase UBase and SBase as applicable Operation With the parameter Operation the function can be set On or Off MeasureMode The voltage and current used for the impedance measurement is set by the parameter MeasureMode The setting possibilities are PosSeq L1 L2 L2 L3 or L3 L1...

Page 433: ...ransformer impedance XT and the equivalent impedance of the external system ZS The impedance is given in of the base impedance according to equation 425 3 Base UBase Z IBase EQUATION1883 V1 EN US Equation 425 The ImpedanceZB is the reverse impedance as show in figure 232 ZB should be equal to the generator transient reactance X d The impedance is given in of the base impedance see equation 425 1MR...

Page 434: ...within zone 1 that is the node of the pole slip is within the generator transformer block The default value 1 is recommended to minimize the stress on the generator and turbine at out of step conditions N2Limit The setting N2Limit gives the number of pole slips that should occur before trip if the crossing of the slip line ZA ZB is within zone 2 that is the node of the pole slip is in the external...

Page 435: ...ata UBase 400 kV SBase set to 1000 MVA Short circuit power at station 1 without infeed from the protected line 5000 MVA assumed to a pure reactance Short circuit power at station 2 without infeed from the protected line 5000 MVA assumed to a pure reactance Line impedance 2 j20 ohm With all phase voltages and phase currents available and fed to the protection IED it is recommended to set the Measur...

Page 436: ...s to 32 0 20 0 20 90 160 j ZB j pu pu Ð EQUATION1964 V1 EN US Equation 430 Set ZB to 0 2 This corresponds to 2 20 0 0125 0 125 0 126 84 160 j ZC j pu pu Ð EQUATION1966 V1 EN US Equation 431 Set ZC to 0 13 and AnglePhi to 88 The warning angle StartAngle should be chosen not to cross into normal operating area The maximum line power is assumed to be 2000 MVA This corresponds to apparent impedance 2 ...

Page 437: ...to 110 For the TripAngle it is recommended to set this parameter to 90 to assure limited stress for the circuit breaker In a power system it is desirable to split the system into predefined parts in case of pole slip The protection is therefore situated at lines where this predefined split shall take place Normally the N1Limit is set to 1 so that the line will be tripped at the first pole slip If ...

Page 438: ...if it is situated in the network zone 2 ZC ZA ZB en07000017 vsd IEC07000017 V1 EN US Figure 236 Generator application of pole slip protection If the apparent impedance crosses the impedance line ZB ZA this is the detected criterion of out of step conditions see figure 237 Section 8 1MRK 506 369 UEN B Impedance protection 432 Line distance protection REL670 2 2 IEC Application manual ...

Page 439: ...source impedance in the forward direction ZB The generator transient reactance ZC The block transformer reactance AnglePhi The impedance phase angle Use the following generator data UBase 20 kV SBase set to 200 MVA Xd 25 Use the following block transformer data UBase 20 kV low voltage side SBase set to 200 MVA ek 15 1MRK 506 369 UEN B Section 8 Impedance protection Line distance protection REL670 ...

Page 440: ...200 5000 ZA Z transf Zsc network j j j ohm EQUATION1970 V1 EN US Equation 435 This corresponds to 0 38 0 19 0 19 90 2 0 j ZA j pu pu Ð EQUATION1971 V1 EN US Equation 436 Set ZA to 0 19 2 20 0 25 0 5 200 d ZB jX j j ohm EQUATION1972 V2 EN US Equation 437 This corresponds to 0 5 0 25 0 25 90 2 0 j ZB j pu pu Ð EQUATION1973 V1 EN US Equation 438 Set ZB to 0 25 2 20 0 15 0 3 200 T ZC jX j j ohm EQUATI...

Page 441: ...ee figure 238 ZA ZB Zload R X en07000016 vsd IEC07000016 V1 EN US Figure 238 Simplified figure to derive StartAngle 0 0 arctan arctan arctan arctan 7 1 5 4 0 25 0 19 13 2 2 ZB ZA angleStart Zload Zload EQUATION1977 V2 EN US Equation 442 In case of minor damped oscillations at normal operation we do not want the protection to start Therefore we set the start angle with large margin Set StartAngle t...

Page 442: ...wer on the generator axis minus the small losses in the generator In the case of a three phase fault electrically close to the generator no active power can be delivered Almost all mechanical power from the turbine is under this condition used to accelerate the moving parts that is the rotor and the turbine If the fault is not cleared quickly the generator may not remain in synchronism after the f...

Page 443: ...e detailed stability studies for each particular power system and or subsystem On the other hand if severe swings occur from which a fast recovery is improbable an attempt should be made to isolate the affected area from the rest of the system by opening connections at predetermined points The electrical system parts swinging to each other can be separated with the lines closest to the center of t...

Page 444: ...fter oscillations around the nominal speed the rotational speed returns to the nominal corresponding to 50 or 60 Hz damped oscillations 3 rd pole slip 1 corresponds to 50 or 60 Hz 2 nd pole slip 1 st pole slip For 260 ms long 3 phase fault generator loses synchronism Generator operates in asynchronous mode at speeds nominal IEC10000108 2 en vsd IEC10000108 V2 EN US Figure 240 Stable and unstable c...

Page 445: ...nsformer Single power line Power system Data required UBase Ugen 13 8 kV IBase Igen 8367 A Xd 0 2960 pu Rs 0 0029 pu U1 13 8 kV U2 230 kV usc 10 I1 12 551 A Xt 0 1000 pu transf ZBase Rt 0 0054 pu transf ZBase Uline 230 kV Xline km 0 4289 Ω km Rline km 0 0659 Ω km Unom 230 kV SC level 5000 MVA SC current 12 551 A φ 84 289 Ze 10 5801 Ω 1 st step in calculation ZBase 0 9522 Ω generator Xd 0 2960 0 95...

Page 446: ...must be finally expressed in percent of ZBase where ZBase is for the example shown in Table 32 the base impedance of the generator ZBase 0 9522 Ω Observe that the power transformer s base impedance is different ZBase 0 6348 Ω Observe that this latter power transformer ZBase 0 6348 Ω must be used when the power transformer reactance and resistance are transformed For the synchronous machines as the...

Page 447: ...an the default 0 0 s where 0 0 s means that tBreaker is unknown then this alternative way to determine the moment when a command to open the breaker is sent is automatically chosen instead of the more approximate method based on the TripAngle tReset Interval of time since the last pole slip detected when the Out of step protection is reset If there is no more pole slips detected under the time int...

Page 448: ...rator output terminals then UBase is the nominal rated phase to phase voltage of the protected generator All the resistances and reactances are measured and displayed referred to voltage Ubase Observe that ReverseX ForwardX ReverseR and ForwardR must be given referred to UBase IBase is the protected generator nominal rated current if the Out of step protection belongs to a generator protection sch...

Page 449: ... dependability in the scheme When the voltage transformers are situated on the bus side the automatic switch onto fault detection based on dead line detection is not possible In such cases the deadline detection is bypassed using the breaker closing status and the switch onto fault logic is activated 8 18 3 Setting guidelines M13855 4 v10 The parameters for automatic switch onto fault logic voltag...

Page 450: ...PSOF is by default set to 1 0 seconds which is suitable for most applications tDLD The time delay for activating ZCVPSOF by the internal dead line detection is by default set to 0 2 seconds It is suitable in most applications The delay shall not be set too short to avoid unwanted activations during transients in the system Mode The operation of ZCVPSOF has three modes for defining the criteria for...

Page 451: ...esistive earthing principle the earth faults in the system gives very low fault currents typically below 25 A At the same time the occurring system voltages on the healthy phases will increase to line voltage level as the neutral displacement is equal to the phase voltage level at a fully developed earth fault This increase of the healthy phase voltage together with slow tripping gives a considera...

Page 452: ...in a sub transmission network high impedance resistance reactance earthed PPLPHIZ is connected between Distance protection zone quadrilateral characteristic function ZMQPDIS and ZMQAPDIS and Phase selection with load encroachment quadrilateral characteristic function FDPSPDIS as shown in figure 243 The integer from the phase selection function which gives the type of fault undergoes a check and wi...

Page 453: ...ART STFWL1 STFWL2 STFWL3 STFWPE STRVL1 STRVL2 STRVL3 STRVPE STNDL1 STNDL2 STNDL3 STNDPE STFW1PH STFW2PH STFW3PH STPE STPP STCNDZ STCNDLE ZMQAPDIS TRIP TRL1 TRL2 TRL3 START STL1 STL2 STL3 STND IEC06000552 V3 EN US Figure 243 The connection of Phase preference logic function PPLPHIZ between Distance protection zone quadrilateral characteristic ZMQPDIS and ZMQAPDIS and Phase selection with load encro...

Page 454: ...o normal praxis including earth fault loops although earth fault loops will only be active during a cross country fault GlobalBaseSel Selects the global base value group used by the function to define IBase UBase and SBase as applicable OperMode The operating mode is selected Choices includes cyclic or acyclic phase selection in the preferred mode This setting must be identical for all IEDs in the...

Page 455: ...the faulty phase A high sensitivity need not to be achieved as the two phase fault level normally is well above base current tIN The time delay for detecting that the fault is cross country Normal time setting is 0 1 0 15 s tUN The time delay for a secure UN detecting that the fault is an earth fault or double earth fault with residual voltage Normal time setting is 0 1 0 15 s tOffUN The UN voltag...

Page 456: ... country fault and then continue to run the system The PPL2PHIZ function is designed to enable this strategy being able to properly select the phase which shall be tripped first based on set phase preference scheme If the cross country faults are very far apart or the network is relatively meshed it can be difficult to obtain phase preference The PPL2PHIZ function will still enable tripping althou...

Page 457: ...ugh there will be some current See Figure 247 Only in the one phase with the fault on the protected feeder a significant fault current may be measured by the relay The result is a residual current of the same magnitude This residual current may be used as an indication of a cross country fault IL3 IN IL1 IN en06000553 vsd IEC06000553 V1 EN US Figure 247 The currents in the phases at a double earth...

Page 458: ...hen all relays detect the two correct phases The PPL2PHIZ function is using the voltage criteria described above Once the faulty phases are detected together with residual current preference may be obtained and transferred to the distance protection by activating one of three enabling signals one for each phase Technically the three signals are first coded into a word together with three signals r...

Page 459: ...nected network part UPN The setting of the phase to earth voltage level phase voltage which is used by the evaluation logic to verify that a fault exists in the phase Normally in a high impedance earthed system the voltage drop is big and the setting can typically be set to 70 which is 70 of UBase divided by 3 UPP The setting of the phase to phase voltage level line voltage which is used by the ev...

Page 460: ...al time setting is 0 1 0 15 s tUN The time delay for a secure UN detecting that the fault is an earth fault or double earth fault with residual voltage Normal time setting is 0 1 0 15 s It should not be set shorter than tIN because that might bypass tIN prematurely tOffUN The UN voltage has a reset drop off to ensure correct function without timing problems Normal time setting is 0 1 s In the High...

Page 461: ...erous because no power can be transmitted through the fault point during fault conditions The magnitude of the fault current A high fault current indicates that the decrease of transmitted power is high The total fault clearing time The phase angles between the EMFs of the generators on both sides of the transmission line increase over the permitted stability limits if the total fault clearing tim...

Page 462: ...BASVAL function for reference of base values Operation Set the protection to On Off OpMode This parameter can be set to 2 out of 3 or 1 out of 3 The setting controls the minimum number of phase currents that must be larger than the set operate current IP for operation Normally this parameter is set to 1 out of 3and will thus detect all fault types If the protection is to be used mainly for multi p...

Page 463: ...nsidered IEC09000023 1 en vsd ZA ZB ZL A B IED I fA Fault IEC09000023 V1 EN US Figure 250 Through fault current from B to A IfA The IED must not trip for any of the two through fault currents Hence the minimum theoretical current setting Imin will be Imin MAX IfA IfB EQUATION78 V1 EN US Equation 443 A safety margin of 5 for the maximum protection static inaccuracy and a safety margin of 5 for the ...

Page 464: ...ent from the parallel line to the protected line has to be considered One example is given in Figure 252 where the two lines are connected to the same busbars In this case the influence of the induced fault current from the faulty line line 1 to the healthy line line 2 is considered together with the two through fault currents IfA and IfB mentioned previously The maximal influence from the paralle...

Page 465: ...entioned previously the minimum setting Is for the instantaneous phase overcurrent protection 3 phase output is then Is 1 3 Imin EQUATION83 V2 EN US Equation 447 The protection function can be used for the specific application only if this setting value is equal or less than the maximum phase fault current that the IED has to clear The IED setting value IP is given in percentage of the primary bas...

Page 466: ...eral steps with different current pickup levels and time delays are needed OC4PTOC can have up 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 selectivi...

Page 467: ...protection The inrush current has a large 2nd harmonic content This can be used to avoid unwanted operation of the protection function Therefore OC4PTOC has a possibility of 2nd harmonic restrain if the level of 2nd harmonic current reaches a value above a set percent of the fundamental current The phase overcurrent protection is often used as a protection for two and three phase short circuits In...

Page 468: ...oop current has the angle RCA the direction to the fault is forward AngleROA Angle value given in degrees to define the angle sector of the directional function shown in Figure 253 StartPhSel Number of phases with high current required for operation The setting possibilities are 1 out of 3 2 out of 3 and 3 out of 3 The default setting is 1 out of 3 IMinOpPhSel Minimum current setting level for rel...

Page 469: ...ep 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 different types of inverse time characteristics are available according to Table 33 1MRK 506 369 UEN B Section 9 Current protection Line distance protection REL670 2 2 IEC 463 Ap...

Page 470: ...ting If Ix is set outside Ix Max and Ix Min the closest of the limits to Ix is used by the function If Ix Max is smaller than Ix Min the limits are swapped tx Definite time delay for step x The definite time tx is added to the inverse time when 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 inv...

Page 471: ...In order to fully comply with the definition of the curve the setting parameter txMin shall be set to a value equal to the operating time of the selected inverse curve for twenty times the set current pickup value Note that the operate time is dependent on the selected time multiplier setting kx ResetTypeCrvx The reset of the delay timer can be made as shown in Table 34 Table 34 Reset possibilitie...

Page 472: ...TRCrvx tCRCrvx These parameters are used by the customer to create the inverse reset time characteristic curve For more information refer to Technical manual HarmRestrainx Enables the block of step x from the harmonic restrain function 2nd harmonic This function should be used when there is a risk of an unwanted trip caused by power transformer inrush currents It can be set to Off On 9 2 3 2 Setti...

Page 473: ...d for several years In most cases the setting values are updated once every five years or less often Investigate the maximum load current that the equipment on the line can withstand Study components such as line conductors current transformers circuit breakers and disconnectors The manufacturer of the equipment normally gives the maximum thermal load current of the equipment The maximum load curr...

Page 474: ...h must be considered due to a possible DC component of the short circuit current The lowest current setting of the fastest stage can be written according to max 1 2 t sc high I k I EQUATION1265 V1 EN US Equation 453 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 05 Iscmax is...

Page 475: ...ions in the radial network there has to be a minimum time difference Dt between the time delays of two protections To determine the shortest possible time difference the operation time of the protection the breaker opening time and the protection resetting time must be known These time delays can vary significantly between different protective equipment The following time delays can be estimated P...

Page 476: ...257 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 breaker opening time is t3 t2 t t4 is when the overcurrent protection at IED A1 resets The protection reset...

Page 477: ...to a defined value by the object impedance an instantaneous earth fault protection can provide fast and selective tripping The Instantaneous residual overcurrent EFPIOC which can operate in 15 ms 50 Hz nominal system frequency for faults characterized by very high currents is included in the IED 9 3 3 Setting guidelines IP14985 1 v1 M12762 44 v2 M12762 4 v4 The parameters for the Instantaneous res...

Page 478: ...ce impedance ZA and low source impedance ZB should be used For the fault at the home busbar this fault current is IfA In this calculation the operational state with low source impedance ZA and high source impedance ZB should be used ZA ZB ZL A B IED I fB Fault IEC09000022 1 en vsd IEC09000022 V1 EN US Figure 258 Through fault current from A to B IfB IEC09000023 1 en vsd ZA ZB ZL A B IED I fA Fault...

Page 479: ...1 en vsd ZA ZB ZL1 A B I M Fault IED ZL2 M C Line 1 Line 2 IEC09000025 V1 EN US Figure 260 Two parallel lines Influence from parallel line to the through fault current IM The minimum theoretical current setting Imin will in this case be Imin M AX IfA IfB IM EQUATION287 V1 EN US Equation 457 Where IfA and IfB have been described for the single line case Considering the safety margins mentioned prev...

Page 480: ...N Min the limits are swapped StValMult The set operate current can be changed by activation of the binary input ENMULT to the set factor StValMult 9 4 Directional residual overcurrent protection four steps EF4PTOC IP14509 1 v8 9 4 1 Identification M14881 1 v6 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Directional residual overcurrent protec...

Page 481: ...otection is also well suited to operate in teleprotection communication schemes which enables fast clearance of earth faults on transmission lines The directional function uses the polarizing quantity as decided by setting Voltage polarizing is the most commonly used but alternatively current polarizing where currents in transformer neutrals providing the neutral source ZN is used to polarize IN Z...

Page 482: ...ve a large inrush current when being energized This inrush current can produce residual current component The phenomenon is due to saturation of the transformer magnetic core during parts of the cycle There is a risk that inrush current will give a residual current that reaches level above the operating current of the residual overcurrent protection The inrush current has a large second harmonic c...

Page 483: ...pe of current polarising quantity i e Zero seq or Neg seq for direction detection SeqTypeIDir This is used to select the type of operating current quantity i e Zero seq or Neg seq for direction detection 9 4 3 1 Common settings for all steps M15282 81 v10 AngleRCA Relay characteristic angle given in degree This angle is defined as shown in Figure 261 The angle is defined positive when the residual...

Page 484: ...he dual polarizing method is used it is important that the setting INx or the product 3I0 ZNpol is not greater than 3U0 If so there is a risk for incorrect operation for faults in the reverse direction IPolMin is the minimum earth fault current accepted for directional evaluation For smaller currents than this value the operation will be blocked A typical setting is 5 10 of IB UPolMin Minimum pola...

Page 485: ...dual fundamental current will however be significant The inrush current of the transformer in service before the parallel transformer energizing will be a little delayed compared to the first transformer Therefore we will have high 2nd harmonic current initially After a short period this current will however be small and the normal 2nd harmonic blocking will reset en05000136 vsd Power System IN IN...

Page 486: ... harmonic restrain will prevent unwanted function in case of transformer inrush current The under time function has a set time delay Below the settings for switch on to fault logics are described SOTF This parameter can be set Off SOTF Under Time SOTF Under Time ActivationSOTF This setting will select the signal to activate SOTF function CB position open CB position closed CB close command StepFor...

Page 487: ...protective equipment The following time delays can be estimated Protection operate time 15 60 ms Protection resetting time 15 60 ms Breaker opening time 20 120 ms The different characteristics are described in the technical reference manual tx Definite time delay for step x The definite time tx is added to the inverse time when inverse time characteristic is selected Note that the value set is the...

Page 488: ...pickup value Note that the operate time value is dependent on the selected setting value for time multiplier kx INxMult Multiplier for scaling of the current setting value If a binary input signal ENMULTx is activated the current operation level is increased by this setting constant ResetTypeCrvx The reset of the delay timer can be made in different ways The possibilities are described in the tech...

Page 489: ...ibed one application possibility to be used in meshed and effectively earthed systems The protection measures the residual current out on the protected line The protection function has a directional function where the polarizing voltage zero sequence voltage is the polarizing quantity The polarizing voltage and current can be internally generated when a three phase set of voltage transformers and ...

Page 490: ...calculated at a fault on the remote busbar one or two phase to earth fault To assure selectivity it is required that step 1 shall not give a trip at this fault The requirement can be formulated according to Equation 461 step1 0 I 1 2 3I remote busbar EQUATION1199 V3 EN US Equation 461 As a consequence of the distribution of zero sequence current in the power system the current to the protection mi...

Page 491: ...cessary if a big power transformer Y0 D at remote bus bar is disconnected A special case occurs at double circuit lines with mutual zero sequence impedance between the parallel lines see Figure 267 IN One phase to earth fault 3I0 IEC05000152 en 2 vsd IEC05000152 V2 EN US Figure 267 Step 1 third calculation In this case the residual current out on the line can be larger than in the case of earth fa...

Page 492: ... Figure 268 Step 2 check of reach calculation The residual current out on the line is calculated at an operational case with minimal earth fault current The requirement that the whole line shall be covered by step 2 can be formulated according to equation 464 step2 0 I 0 7 3I at remote busbar EQUATION1202 V4 EN US Equation 464 To assure selectivity the current setting must be chosen so that step 2...

Page 493: ... 8 s Step 3 shall enable selective trip of earth faults having higher fault resistance to earth compared to step 2 The requirement on step 3 is selectivity to other earth fault protections in the network One criterion for setting is shown in Figure 270 IEC05000156 3 en vsd IN One phase to earth fault 3I0 IN 3I02 IEC05000156 V3 EN US Figure 270 Step 3 Selectivity calculation 1 0 step3 step2 02 3I I...

Page 494: ...plications definite time delay in the range 1 2 2 0 s is used In other applications a current dependent inverse time characteristic is used This enables a higher degree of selectivity also for sensitive earth fault current protection 9 5 Four step directional negative phase sequence overcurrent protection NS4PTOC GUID E8CF8AA2 AF54 4FD1 A379 3E55DCA2FA3A v1 9 5 1 Identification GUID E1720ADA 7F80 ...

Page 495: ...oth selectivity and fast fault clearance the directional function can be necessary This can be the case for unsymmetrical fault 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...

Page 496: ...p level This multiplication factor is activated from a binary input signal ENMULTx to the function 9 5 3 Setting guidelines GUID 460D6C58 598C 421E AA9E FD240210A6CC v3 The parameters for Four step negative sequence overcurrent protection NS4PTOC are set via the local HMI or Protection and Control Manager PCM600 The following settings can be done for the four step negative sequence overcurrent pro...

Page 497: ...lable Table 37 Inverse time characteristics Curve name ANSI Extremely Inverse ANSI Very Inverse ANSI Normal Inverse ANSI Moderately Inverse ANSI IEEE Definite time ANSI Long Time Extremely Inverse ANSI Long Time Very Inverse ANSI Long Time Inverse IEC Normal Inverse IEC Very Inverse IEC Inverse IEC Extremely Inverse IEC Short Time Inverse IEC Long Time Inverse IEC Definite Time User Programmable A...

Page 498: ...his setting constant txMin Minimum operation time for inverse time characteristics At high currents the inverse time characteristic might give a very short operation time By setting this parameter the operation time of the step can never be shorter than the setting IMinx Operate time Current tx txMin IEC10000058 IEC10000058 V2 EN US Figure 271 Minimum operate current and operation time for inverse...

Page 499: ...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 467 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 467 Further description can be found in the Technical reference manual TRM tPRCrvx tTRCrvx tCRCrvx Parameters for customer creation of inverse re...

Page 500: ...I Dir Operate residual current level for directional comparison scheme The setting is given 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 9 6 Sensitive directional residual overcurrent and power protection SDEPSDE SEMOD171436 1 v4 Section 9 1MRK 506 369 UEN B Current protectio...

Page 501: ... 3I0 3U0 cos φ where φ is the angle between the residual current and the reference residual voltage compensated with a characteristic angle A normal non directional residual current function can also be used with definite or inverse time delay A backup neutral point voltage function is also available for non directional residual overvoltage protection In an isolated network that is the network is ...

Page 502: ... high zero resistive fault currents Phase currents Phase ground voltages IN UN IEC13000013 1 en vsd IEC13000013 V1 EN US Figure 273 Connection of SDEPSDE to analog preprocessing function block Overcurrent functionality uses true 3I0 i e sum of GRPxL1 GRPxL2 and GRPxL3 For 3I0 to be calculated connection is needed to all three phase inputs Directional and power functionality uses IN and UN If a con...

Page 503: ...lt Rf is the resistance to earth in the fault point and Z0 is the system zero sequence impedance to earth The fault current in the fault point can be calculated as phase j 0 0 f 3 U I 3I Z 3 R EQUATION1944 V1 EN US Equation 469 The impedance Z0 is dependent on the system earthing In an isolated system without neutral point apparatus the impedance is equal to the capacitive coupling between the pha...

Page 504: ...QUATION1947 V1 EN US Equation 472 Where Xn is the reactance of the Petersen coil If the Petersen coil is well tuned we have 3Xn Xc In this case the impedance Z0 will be Z0 3Rn Now consider a system with an earthing via a resistor giving higher earth fault current than the high impedance earthing The series impedances in the system can no longer be neglected The system with a single phase to earth ...

Page 505: ... Equation 473 Where Uphase is the phase voltage in the fault point before the fault Z1 is the total positive sequence impedance to the fault point Z1 Zsc ZT 1 ZlineAB 1 ZlineBC 1 Z0 is the total zero sequence impedance to the fault point Z0 ZT 0 3RN ZlineAB 0 ZlineBC 0 Rf is the fault resistance The residual voltages in stations A and B can be written 0A 0 T 0 N U 3I Z 3R EQUATION1949 V1 EN US Equ...

Page 506: ...s base for the inverse time delay The inverse time delay is defined as 0 0 inv 0 0 kSN 3I 3U cos reference t 3I 3U cos measured j j EQUATION1942 V2 EN US Equation 480 The function can be set On Off with the setting of Operation Common base IED values for primary current IBase primary voltage UBase and primary power SBase are set in a Global base values for settings function GBASVAL GlobalBaseSel I...

Page 507: ...ADir equal to 90 is shown in Figure 276 IEC06000649_3_en vsd ref U 90 90 RCADir ROADir 0 3I 0 3 ϕ I cos ϕ 0 3 ref ang I ang U 0 3U IEC06000649 V3 EN US Figure 276 Characteristic for RCADir equal to 90 When OpMode is set to 3U03I0cosfi the apparent residual power component in the direction is measured When OpMode is set to 3I0 and fi the function will operate if the residual current is larger than ...

Page 508: ... be detected tDef is the definite time delay given in s for the directional residual current protection tReset is the time delay before the definite timer gets reset given in s With a tReset time of few cycles there is an increased possibility to clear intermittent earth faults correctly The setting shall be much shorter than the set trip delay In case of intermittent earth faults the fault curren...

Page 509: ...t transformers Hence there is no specific requirement for the external CT core i e any CT core can be used If the time delay for residual power is chosen the delay time is dependent on two setting parameters SRef is the reference residual power given in of SBase kSN is the time multiplier The time delay will follow the following expression inv 0 0 kSN Sref t 3I 3U cos measured j EQUATION1957 V1 EN...

Page 510: ...al for the description of different characteristics tPCrv tACrv tBCrv tCCrv Parameters for customer creation of inverse time characteristic curve Curve type 17 The time characteristic equation is æ ö ç ç ç æ ö ç ç è ø è ø p A t s B InMult i C in EQUATION1958 V1 EN US Equation 482 tINNonDir is the definite time delay for the non directional earth fault current protection given in s OpUN is set On t...

Page 511: ...terial will be destroyed In cables the insulation can be damaged as a consequence of the overtemperature As a consequence of this phase to phase or phase to earth faults can occur In stressed situations in the power system it can be required to overload lines and cables for a limited time This should be done while managing the risks safely The thermal overload protection provides information that ...

Page 512: ...f cable and earth thermal resistivity From manuals for overhead conductor temperatures and corresponding current is given Tau The thermal time constant of the protected circuit given in minutes Please refer to manufacturers manuals for details TripTemp Temperature value for trip of the protected circuit For cables a maximum allowed conductor temperature is often stated to be 90 C 194 F For overhea...

Page 513: ...tput CCRBRF will issue a back up trip command to adjacent circuit breakers in case of failure to trip of the normal circuit breaker for the protected object The detection of failure to break the current through the breaker is made by means of current measurement or as detection of remaining trip signal unconditional CCRBRF can also give a re trip This means that a second trip signal is sent to the...

Page 514: ...nMode Description Retrip Off N A the re trip function is not activated CB Pos Check Current re trip is done if the phase current is larger than the operate level after re trip time has elapsed Contact re trip is done when auxiliary contact position indicates that breaker is still closed after re trip time has elapsed Current Contact both methods according to above are used but taken into account a...

Page 515: ...earthed systems the setting of the earth fault current protection can be chosen to relatively low current level The BuTripMode is set 1 out of 4 The current setting should be chosen in accordance to the setting of the sensitive earth fault protection The setting can be given within the range 2 200 of IBase t1 Time delay of the re trip The setting can be given within the range 0 60s in steps of 0 0...

Page 516: ...eparated back up trip functions tripping different back up circuit breakers tCBAlarm Time delay for alarm in case of indication of faulty circuit breaker There is a binary input CBFLT from the circuit breaker This signal is activated when internal supervision in the circuit breaker detect that the circuit breaker is unable to clear fault This could be the case when gas pressure is low in a SF6 cir...

Page 517: ...tchyard in operation This is done by opening the disconnector to the protected object This will however disable the normal object protection for example the distance protection of the energized part between the circuit breakers and the open disconnector Stub protection STBPTOC is a simple phase overcurrent protection fed from the two current transformer groups feeding the object taken out of servi...

Page 518: ...plicable Operation Off On ReleaseMode This parameter can be set Release or Continuous With theRelease setting the function is only active when a binary release signal RELEASE into the function is activated This signal is normally taken from an auxiliary contact normally closed of the line disconnector and connected to a binary input RELEASE of the IED With the settingContinuous the function is act...

Page 519: ...give stress on rotating machines Zero sequence currents that might give unwanted operation of sensitive earth fault protections in the power system It is therefore important to detect situations with pole discordance of circuit breakers When this is detected the breaker should be tripped directly Pole discordance protection CCPDSC will detect situation with deviating positions of the poles of the ...

Page 520: ...nitor In the alternative CB oper monitor the function is activated only directly in connection to breaker open or close command during 200 ms In the alternative Continuous monitor function is continuously activated CurrUnsymLevel Unsymmetrical magnitude of lowest phase current compared to the highest set in of the highest phase current Natural difference between phase currents in 1 1 2 breaker ins...

Page 521: ... shutdown of many thermal power units the reverse power protection gives the tripping impulse to the generator breaker the unit breaker By doing so one prevents the disconnection of the unit before the mechanical power has become zero Earlier disconnection would cause an acceleration of the turbine generator at all routine shutdowns This should have caused overspeed and high centrifugal stresses W...

Page 522: ...he system 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 280 illustrates the reverse power protection with underpower protection and ...

Page 523: ...Seq 3 PosSeq PosSeq S U I EQUATION1699 V1 EN US Equation 487 L1L2 1 2 1 2 L L L L S U I I EQUATION1700 V1 EN US Equation 488 L2L3 2 3 2 3 L L L L S U I I EQUATION1701 V1 EN US Equation 489 L3L1 3 1 3 1 L L L L S U I I EQUATION1702 V1 EN US Equation 490 L1 1 1 3 L L S U I EQUATION1703 V1 EN US Equation 491 L2 2 2 3 L L S U I EQUATION1704 V1 EN US Equation 492 L3 3 3 3 L L S U I EQUATION1705 V1 EN U...

Page 524: ...0 2 of SN when metering class CT inputs into the IED are used 3 N S UBase IBase EQUATION1708 V1 EN US Equation 494 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 9 1MRK 506 369 U...

Page 525: ...n 495 The drop out power will be Power1 2 Hysteresis1 2 The possibility to have low pass filtering of the measured power can be made as shown in the formula 1 Old Calculated S k S k S EQUATION1893 V1 EN US Equation 496 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 calculat...

Page 526: ... 9 12 2 Application SEMOD172358 4 v2 The task of a generator in a power plant is to convert mechanical energy available as a torque on a rotating shaft to electric energy Sometimes the mechanical power from a prime mover may decrease so much that it does not cover bearing losses and ventilation losses Then the synchronous generator becomes a synchronous motor and starts to take electric power from...

Page 527: ...ime to overheating of a steam turbine varies from about 0 5 to 30 minutes depending on the type of turbine A high pressure turbine with small and thin blades will become overheated more easily than a low pressure turbine with long and heavy blades The conditions vary from turbine to turbine and it is necessary to ask the turbine manufacturer in each case Power to the power plant auxiliaries may co...

Page 528: ... set the underpower IED to trip if the active power from the generator is less than about 2 One should set the overpower IED to trip if the power flow from the network to the generator is higher than 1 Underpower IED Overpower IED Q Q P P Operating point without turbine torque Margin Margin Operate Line Operate Line Operating point without turbine torque IEC06000315 2 en vsd IEC06000315 V2 EN US F...

Page 529: ...1 EN US Equation 502 L3L1 3 1 3 1 L L L L S U I I EQUATION1702 V1 EN US Equation 503 L1 1 1 3 L L S U I EQUATION1703 V1 EN US Equation 504 L2 2 2 3 L L S U I EQUATION1704 V1 EN US Equation 505 L3 3 3 3 L L S U I EQUATION1705 V1 EN US Equation 506 The function has two stages that can be set independently With the parameter OpMode1 2 the function can be set On Off The function gives trip if the powe...

Page 530: ... 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 507 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 Section 9 1MRK 506 369 UEN B ...

Page 531: ...ation 508 The drop out power will be Power1 2 Hysteresis1 2 The possibility to have low pass filtering of the measured power can be made as shown in the formula 1 Old Calculated S k S k S EQUATION1893 V1 EN US Equation 509 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 calc...

Page 532: ...ken conductor check BRCPTOC 46 9 13 2 Application SEMOD171858 5 v3 Conventional protection functions can not detect the broken conductor condition Broken conductor check BRCPTOC function consisting of continuous current unsymmetrical check on the line where the IED connected will give alarm or trip at detecting broken conductors 9 13 3 Setting guidelines SEMOD171866 5 v4 Broken conductor check BRC...

Page 533: ...plication of the voltage restrained time overcurrent protection is in the generator protection system where it is used as backup protection If a phase to phase fault affects a generator the fault current amplitude is a function of time and it depends on generator characteristic reactances and time constants its load conditions immediately before the fault and excitation system performance and char...

Page 534: ... entered as rated phase current of the protected object in primary amperes UBase shall be entered as rated phase to phase voltage of the protected object in primary kV 9 14 2 2 Application possibilities GUID 5053F964 C2D6 4611 B5EF AC3DB0889F51 v5 VRPVOC function can be used in one of the following applications voltage controlled over current voltage restrained over current In both applications a ...

Page 535: ...581096 v3 Common base IED values for the primary current IBase 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 as applicable 9 14 3 1 Explanation of the setting parameters GUID 9B777E6D 602B 4214 9170 A44ED2D725BF v3 Operation Set to On in...

Page 536: ...r than the setting StartVolt The setting can be very low for example lower than 10 VDepMode Selection of the characteristic of the start level of the overcurrent stage as a function of the phase to phase voltage two options are available Slope and Step See Technical Manual for details about the characteristics VDepFact Slope mode it is the start level of the overcurrent stage given in of StartCurr...

Page 537: ...t VDepFact to the value 25 default value 11 Set UHighLimit to the value 100 default value All other settings can be left at the default values 9 14 3 3 Overcurrent protection with undervoltage seal in GUID B58E1CD6 F9AE 4301 ABE7 90DBFC987D69 v6 To obtain this functionality the IED application configuration shall include a logic in accordance to figure 286 and of course the relevant three phase ge...

Page 538: ... of the magnitude of the generator voltage 7 Set Operation_UV to On to activate the undervoltage stage 8 Set StartVolt to the values 70 9 Set tDef_UV to 3 0 s 10 Set EnBlkLowV to Off default value to disable the cut off level for low voltage of the undervoltage stage The other parameters may be left at their default value Section 9 1MRK 506 369 UEN B Current protection 532 Line distance protection...

Page 539: ...tage regulator or wrong settings under manual control symmetrical voltage decrease Overload symmetrical voltage decrease Short circuits often as phase to earth faults unsymmetrical voltage decrease UV2PTUV is used in combination with overcurrent protections either as restraint or in logic and gates of the trip signals issued by the two functions It can also be used to Detect no voltage conditions ...

Page 540: ... Equipment protection such as for motors and generators M13851 50 v3 The setting must be below the lowest occurring normal voltage and above the lowest acceptable voltage for the equipment 10 1 3 2 Disconnected equipment detection M13851 53 v3 The setting must be below the lowest occurring normal voltage and above the highest occurring voltage caused by inductive or capacitive coupling when the eq...

Page 541: ...f 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 supervision function and 3 out of 3 is selected Un Set operate undervoltage operation value for step n given as of the parameter U...

Page 542: ... of trip Block all In case of a low voltage the undervoltage function can be blocked This function can be used to prevent function when the protected object is switched off If the parameter is set Block of trip or Block all unwanted trip is prevented IntBlkStValn Voltage level under which the blocking is activated set in of UBase This setting must be lower than the setting Un As switch of shall be...

Page 543: ...ower system like metallic connection to a higher voltage level broken conductor falling down to a crossing overhead line transformer flash over fault from the high voltage winding to the low voltage winding and so on 2 Malfunctioning of a voltage regulator or wrong settings under manual control symmetrical voltage decrease 3 Low load compared to the reactive power generation symmetrical voltage de...

Page 544: ... capacitors M13852 13 v1 High voltage will deteriorate the dielectricum and the insulation The setting has to be well above the highest occurring normal voltage and well below the highest acceptable voltage for the capacitor 10 2 3 3 Power supply quality M13852 16 v1 The setting has to be well above the highest occurring normal voltage and below the highest acceptable voltage due to regulation goo...

Page 545: ...curve The choice is highly dependent of the protection application OpModen This parameter describes how many of the three measured voltages that should be above the set level to give operation The setting can be 1 out of 3 2 out of 3 3 out of 3 In most applications it is sufficient that one phase voltage is high to give operation If the function shall be insensitive for single phase to earth fault...

Page 546: ...n 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 Therefore a tuning parameter CrvSatn is set to compensate for...

Page 547: ...ance the residual voltage will reach different values The highest residual voltage equal to three times the phase to earth voltage is achieved for a single phase to earth fault The residual voltage increases approximately to the same level in the whole system and does not provide any guidance in finding the faulted component Therefore ROV2PTOV is often used as a backup protection or as a release s...

Page 548: ... voltage for the capacitor 10 3 3 3 Power supply quality M13853 15 v3 The setting must be above the highest occurring normal residual voltage and below the highest acceptable residual voltage due to regulation good practice or other agreements 10 3 3 4 High impedance earthed systems M13853 18 v10 In high impedance earthed systems earth faults cause a neutral voltage in the feeding transformer neut...

Page 549: ...ase is indicated by voltage collapse in that phase The other healthy phase will still have normal phase to earth voltage The residual sum will have the same value as the remaining phase to earth voltage which is shown in Figure 288 UL1 IEC07000189 2 en vsd IEC07000189 V2 EN US Figure 288 Earth fault in Direct earthed system 1MRK 506 369 UEN B Section 10 Voltage protection Line distance protection ...

Page 550: ...e setting parameters described below are identical for the two steps n step 1 and 2 Therefore the setting parameters are described only once OperationStepn This is to enable disable operation of step n Characteristicn Selected inverse time characteristic for step n This parameter gives the type of time delay to be used The setting can be Definite time or Inverse curve A or Inverse curve B or Inver...

Page 551: ...vn PCrvn Parameters for step n to set to create programmable undervoltage inverse time characteristic Description of this can be found in the technical reference manual CrvSatn Set tuning parameter for step n When the denominator in the expression of the programmable curve is equal to zero the time delay will be infinite There will be an undesired discontinuity Therefore a tuning parameter CrvSatn...

Page 552: ...s of load or load shedding can also result in overexcitation if the voltage control and frequency governor is not functioning properly Loss of load or load shedding at a transformer substation can result in overexcitation if the voltage control function is insufficient or out of order Low frequency in a system isolated from the main network can result in overexcitation if the voltage regulating sy...

Page 553: ... after a short time interval the heating will start from a higher level therefore OEXPVPH must have thermal memory A fixed cooling time constant is settable within a wide range The general experience is that the overexcitation characteristics for a number of power transformers are not in accordance with standard inverse time curves In order to make optimal settings possible a transformer adapted c...

Page 554: ...PVPH has a thermal memory which can take a long time to reset Activation of the RESET input will reset the function instantaneously Recommendations for Output signals M6496 84 v7 Please see the default factory configuration for examples of configuration ERROR The output indicates a measuring error The reason for example can be configuration problems where analogue signals are missing START The STA...

Page 555: ...ntage factor Normal setting is around 110 180 depending of the capability curve of the transformer generator Setting should be above the knee point when the characteristic starts to be straight on the high side XLeak The transformer leakage reactance on which the compensation of voltage measurement with load current is based The setting shall be the transformer leak reactance in primary ohms If no...

Page 556: ...ion is given in an overexcitation capability diagram as shown in figure 290 The settings V Hz and V Hz are made in per unit of the rated voltage of the transformer winding at rated frequency Set the transformer adapted curve for a transformer with overexcitation characteristics in according to figure 290 V Hz for the protection is set equal to the permissible continuous overexcitation according to...

Page 557: ...2 5 50 200 110 120 130 140 150 100 0 05 0 1 0 2 0 5 10 20 100 V Hz Continous Time minutes t6 t5 t4 t3 t2 t1 transformer capability curve relay operate characteristic en01000377 vsd IEC01000377 V1 EN US Figure 290 Example on overexcitation capability curve and V Hz protection settings for power transformer 1MRK 506 369 UEN B Section 10 Voltage protection Line distance protection REL670 2 2 IEC 551 ...

Page 558: ...us is supervised with the voltage in the capacitor bank phase by phase Difference indicates a fault either short circuited or open element in the capacitor bank 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 re...

Page 559: ...that a fuse failure alarm is given instead of a Undervoltage or Differential voltage alarm and or tripping Fuse failure supervision SDDRFUF function for voltage transformers In many application the voltages of two fuse groups of the same voltage transformer or fuse groups of two separate voltage transformers measuring the same voltage can be supervised with this function It will be an alternative ...

Page 560: ...ges in the phases are low RFLx Is the setting of the voltage ratio compensation factor where possible differences between the voltages is compensated for The differences can be due to different voltage transformer ratios different voltage levels e g the voltage measurement inside the capacitor bank can have a different voltage level but the difference can also e g be used by voltage drop in the se...

Page 561: ...efault setting is 70 U2Low The setting of the undervoltage level for the second voltage input is decided by this parameter The proposed default setting is 70 tBlock The time delay for blocking of the function at detected undervoltages is set by this parameter UDAlarm The voltage differential level required for alarm is set with this parameter For application on capacitor banks the setting will dep...

Page 562: ... of the global parameter UBase level Set the time delay tTrip 5 20 seconds 10 6 3 1 Advanced users settings SEMOD171929 8 v4 For advanced users the following parameters need also to be set Set the length of the trip pulse to typical tPulse 0 15 sec Set the blocking time tBlock to block Loss of voltage check LOVPTUV if some but not all voltage are low to typical 5 0 seconds and set the time delay f...

Page 563: ... function are set via the local HMI or Protection and Control Manager PCM600 Operation The function can be set On Off GlobalBaseSel Used to select a GBASVAL function for reference of base values primary current IBase primary voltage UBase and primary power SBase UPhSel Faulted phase voltage in of quadrature phase phase voltage divided by sqrt 3 Setting this value to 100 is equivalent to disabling ...

Page 564: ...558 ...

Page 565: ...t change gas turbine start up and so on Sometimes shunt reactors are automatically switched in due to low frequency in order to reduce the power system voltage 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 underfrequ...

Page 566: ...sitive loads The setting level the number of levels and the distance between two levels in time and or in frequency depends very much on the characteristics of the power system under consideration The size of the largest loss of production compared to the size of the power system is a critical parameter In large systems the load shedding can be set at a fairly high frequency level and the time del...

Page 567: ...r system against breakdown by shedding generation in over production situations The overfrequency start value is set in Hz All voltage magnitude related settings are made as a percentage of a settable global base voltage parameter UBase The UBase value should be set as a primary phase to phase value Some applications and related setting guidelines for the frequency level are given below Equipment ...

Page 568: ...s are required at a rather high frequency level but in combination with a large negative rate of change of frequency the underfrequency protection can be used at a rather high setting 11 3 3 Setting guidelines M14971 3 v7 The parameters for Rate of change frequency protection SAPFRC are set via the local HMI or or through the Protection and Control Manager PCM600 All the frequency and voltage magn...

Page 569: ...supply a stable value It is recommended to have a time delay long enough to take care of signal noise However the time rate of change frequency and frequency steps between different actions might be critical and sometimes a rather short operation time is required for example down to 70 ms Smaller industrial systems might experience rate of change frequency as large as 5 Hz s due to a single event ...

Page 570: ...564 ...

Page 571: ...r voltage controlled restrained The over under voltage protection is applied on power system elements such as generators transformers motors and power lines in order to detect abnormal voltage conditions Depending on the type of voltage deviation and type of power system abnormal condition different over under voltage protections based on measurement of phase to earth phase to phase residual or se...

Page 572: ... both steps 4 Two undervoltage steps with the following built in features Definite time delay or Inverse Time Overcurrent TOC IDMT delay for both steps All these four protection elements within one general protection function works independently from each other and they can be individually enabled or disabled However note that all these four protection elements measure one selected current quantit...

Page 573: ...2 current phasor IL1 IL2 11 phase2 phase3 CVGAPC function will measure the current phasor internally calculated as the vector difference between the phase L2 current phasor and phase L3 current phasor IL2 IL3 12 phase3 phase1 CVGAPC function will measure the current phasor internally calculated as the vector difference between the phase L3 current phasor and phase L1 current phasor IL3 IL1 13 MaxP...

Page 574: ...ge phasor and phase L2 voltage phasor UL1 UL2 11 phase2 phase3 CVGAPC function will measure the voltage phasor internally calculated as the vector difference between the phase L2 voltage phasor and phase L3 voltage phasor UL2 UL3 12 phase3 phase1 CVGAPC function will measure the voltage phasor internally calculated as the vector difference between the phase L3 voltage phasor and phase L1 voltage p...

Page 575: ...xibility 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 directional characteristic Underimpedance protection circular mho characteristic Voltage Controlled Restrained Overcurrent prote...

Page 576: ...e including the block transformer Higher quantities of machine current and voltage 3 to 4 per unit current and 50 to 70 rated voltage can be expected if the generator is connected to a strong system Lower current and voltage values 1 to 2 per unit current and 20 to 40 rated voltage are representative of weaker systems Since a generator behaves similarly to an induction motor high currents will dev...

Page 577: ... 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 as applicable The overcurrent steps has a IMinx x 1 or 2 depending on step setting to set the minimum operate current Set IMinx below StartCurr_OCx for every step to achieve ANSI reset characteristic according to standard If IMinx...

Page 578: ...t stage for example OC1 10 By parameter CurveType_OC1 select appropriate TOC IDMT or definite time delayed curve in accordance with your network protection philosophy 11 Set StartCurr_OC1 to value between 3 10 typical values 12 Set tDef_OC1 or parameter k when TOC IDMT curves are used to insure proper time coordination with other earth fault protections installed in the vicinity of this power line...

Page 579: ...gnals Furthermore the other built in UC OV and UV protection elements can be used for other protection and alarming purposes 12 1 3 2 Negative sequence overcurrent protection M13088 5 v4 Example will be given how to use one CVGAPC function to provide negative sequence inverse time overcurrent protection for a generator with capability constant of 20s and maximum continuous negative sequence rating...

Page 580: ...S Equation 518 where top is the operating time in seconds of the Inverse Time Overcurrent TOC IDMT algorithm k is time multiplier parameter setting 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 515 is compared with the equation 5...

Page 581: ...use OC2 for negative sequence overcurrent alarm and OV1 for negative sequence overvoltage alarm 12 1 3 3 Generator stator overload protection in accordance with IEC or ANSI standards M13088 81 v3 Example will be given how to use one CVGAPC function to provide generator stator overload protection in accordance with IEC or ANSI standard if minimum operating current shall be set to 116 of generator r...

Page 582: ...e CVGAPC instance for example GF01 2 Set parameter CurrentInput to value PosSeq 3 Set base current value to the rated generator current in primary amperes 4 Enable one overcurrent step for example OC1 5 Select parameter CurveType_OC1 to value Programmable op P A t k B M C æ ö ç è ø EQUATION1375 V1 EN US Equation 522 where top is the operating time in seconds of the Inverse Time Overcurrent TOC IDM...

Page 583: ...protection and alarming purposes In the similar way rotor overload protection in accordance with ANSI standard can be achieved 12 1 3 4 Open phase protection for transformer lines or generators and circuit breaker head flashover protection for generators M13088 142 v3 Example will be given how to use one CVGAPC function to provide open phase protection This can be achieved by using one CVGAPC func...

Page 584: ... time coordination study gives the following required settings Inverse Time Over Current TOC IDMT curve ANSI very inverse Pickup current of 185 of generator rated current at rated generator voltage Pickup current 25 of the original pickup current value for generator voltages below 25 of rated voltage This functionality can be achieved by using one CVGAPC function The following shall be done in ord...

Page 585: ...ase generator voltages to one CVGAPC instance for example GF02 2 Set parameter CurrentInput to PosSeq 3 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 7 Set parameter ROADir t...

Page 586: ... 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 293 Loss of excitation Section 12 1MRK 506 369 UEN B Multipurpose protection 580 Line distance protection REL670 2 2 IEC Application manual ...

Page 587: ...al system cycle are first stored When enough samples are available in the internal memory the phasor values at set frequency defined by the setting parameter SetFrequency are calculated The following values are internally available for each of the calculated phasors Magnitude Phase angle Exact frequency of the extracted signal The SMAI HPAC filter is always used in conjunction with some other prot...

Page 588: ...cal configuration connections required to utilize this filter in conjunction with multi purpose function as non directional overcurrent protection IEC13000179 1 en vsd IEC13000179 V1 EN US Figure 294 Required ACT configuration Such overcurrent arrangement can be for example used to achieve the subsynchronous resonance protection for turbo generators 13 1 3 Setting guidelines 13 1 3 1 Setting examp...

Page 589: ... s f Hz Hz Hz EQUATION13000030 V1 EN US Equation 524 In order to properly extract the weak subsynchronous signal in presence of the dominating 50Hz signal the SMAI HPAC filter shall be set as given in the following table Table 45 Proposed settings for SMAIHPAC I_HPAC_31_5Hz SMAIHPAC 1 ConnectionType Ph N SetFrequency 31 5 FreqBandWidth 0 0 FilterLength 1 0 s OverLap 75 Operation On Now the setting...

Page 590: ... one is set in IS0 300A 35566 118 55 300 so A K I 01 0 64 B T 0 0 C 1 0 p 1 0 k then exact replica of the existing relay will be achieved The following table summarizes all required settings for the multi purpose function Setting Group1 Operation On CurrentInput MaxPh IBase 1000 VoltageInput MaxPh UBase 20 50 OPerHarmRestr Off I_2ndI_fund 20 0 BlkLevel2nd 5000 EnRestrainCurr Off RestrCurrInput Pos...

Page 591: ...C1 2 0 CurveType_OC1 Programmable tDef_OC1 0 00 k_OC1 1 00 tMin1 30 tMin_OC1 1 40 ResCrvType_OC1 Instantaneous tResetDef_OC1 0 00 P_OC1 1 000 A_OC1 118 55 B_OC1 0 640 C_OC1 0 000 1MRK 506 369 UEN B Section 13 System protection and control Line distance protection REL670 2 2 IEC 585 Application manual ...

Page 592: ...586 ...

Page 593: ...currents unequal transient saturation of CT cores with different remanence or different saturation factor may result in differences in the secondary currents from the two CT sets Unwanted blocking of protection functions during the transient stage must then be avoided Current circuit supervision CCSSPVC must be sensitive and have short operate time in order to prevent unwanted tripping from fast a...

Page 594: ... of the measured voltage in the relay point Examples are impedance protection functions undervoltage function energizing check function and voltage check for the weak infeed logic These functions can operate unintentionally if a fault occurs in the secondary circuits between the voltage instrument transformers and the IED It is possible to use different measures to prevent such unwanted operations...

Page 595: ...tries in the primary system and differences in the current and voltage instrument transformers The minimum value for the operation of the current and voltage measuring elements must always be set with a safety margin of 10 to 20 depending on the system operating conditions Pay special attention to the dissymmetry of the measuring quantities when the function is used on long untransposed lines on m...

Page 596: ...sINs or OptimZsNs In mode UZsIZs OR UNsINs both negative and zero sequence based algorithms are activated and working in an OR condition Also in mode OptimZsNs both negative and zero sequence algorithms are activated and the one that has the highest magnitude of measured negative or zero sequence current will operate If there is a requirement to increase the security of the fuse failure function O...

Page 597: ...Base is the base voltage for the function according to the setting GlobalBaseSel The setting of the current limit 3I0 is done in percentage of IBase The setting of 3I0 must be higher than the normal unbalance current that might exist in the system The setting can be calculated according to equation 530 3 0 3 0 100 I I IBase EQUATION2293 V3 EN US Equation 530 where 3I0 is the maximal zero sequence ...

Page 598: ...lower than the IMinOp for the distance protection function A 5 10 lower value is recommended 14 2 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 reco...

Page 599: ... VDSPVC is designed to detect fuse failures or faults in voltage measurement circuit based on comparison of the voltages of the main and pilot fused circuits phase wise VDSPVC output can be configured to block voltage dependent protection functions such as high speed distance protection undervoltage relays underimpedance relays and so on FuseFailSupvn IED L1 L2 L3 U2L1 U2L2 U2L3 U1L1 U1L2 U1L3 IEC...

Page 600: ...set low approximately 30 of UBase so that they are sensitive to the fault on the voltage measurement circuit since the voltage on both sides are equal in the healthy condition If USetPrim is the desired pick up primary phase to phase voltage of measured fuse group the setting of Ud MainBlock and Ud PilotAlarm will be given according to equation 533 or 100 S etPrim Base U Ud MainBlock Ud PilotAlarm...

Page 601: ...s threshold value the system is defined to have a parallel circuit and the synchrocheck function is used The synchronizing function measures the difference between the U Line and the U Bus It operates and enables a closing command to the circuit breaker when the calculated closing angle is equal to the measured phase angle and the following conditions are simultaneously fulfilled The voltages U Li...

Page 602: ...degrees at different allowed slip frequencies for synchronizing To minimize the moment stress when synchronizing near a power station a narrower limit for the CloseAngleMax needs to be used Table 46 Dependencies between tBreaker and SlipFrequency with different CloseAngleMax values tBreaker s max settable value with CloseAngleMax 15 degrees default value tBreaker s max settable value with CloseAng...

Page 603: ...n through other stations The need for a check of synchronization increases if the meshed system decreases since the risk of the two networks being out of synchronization at manual or automatic closing is greater The synchrocheck function measures the conditions across the circuit breaker and compares them to set limits Output is generated only when all measured conditions are within their set limi...

Page 604: ... the phase angle difference is smaller To fulfill the above requirements the synchrocheck function is provided with duplicate settings one for steady Manual conditions and one for operation under disturbed conditions Auto SynchroCheck UHighBusSC 50 120 of GblBaseSelBus UHighLineSC 50 120 of GblBaseSelLine UDiffSC 0 02 0 50 p u PhaseDiffM 5 90 degrees PhaseDiffA 5 90 degrees FreqDiffM 3 1000 mHz Fr...

Page 605: ...elBus and GblBaseSelLine which are defined in the Global Base Value groups in a similar way the equipment is considered non energized Dead if the voltage is below the set value for ULowBusEnerg or ULowLineEnerg of the respective Global Base Value groups A disconnected line can have a considerable potential due to factors such as induction from a line running in parallel or feeding via extinguishin...

Page 606: ... supervision function can also be used if a three phase voltage is present The signal BLKU from the internal fuse failure supervision function is then used and connected to the fuse supervision inputs of the SESRSYN function block In case of a fuse failure the SESRSYN energizing function is blocked The UB1OK UB2OK and UB1FF UB2FF inputs are related to the busbar voltage and the ULN1OK ULN2OK and U...

Page 607: ... 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 below in example are typical and can be changed by use of configuration and signal matrix tools The SESRSYN and connected SMAI function block instances must have the same cycle time in the application configuration...

Page 608: ...on principles for a single busbar For the SESRSYN function there is one voltage transformer on each side of the circuit breaker The voltage transformer circuit connections are straightforward no special voltage selection is necessary The voltage from busbar VT is connected to U3PBB1 and the voltage from the line VT is connected to U3PLN1 The conditions of the VT fuses shall also be connected as sh...

Page 609: ... from the two busbars are selected based on the position of the busbar disconnectors This means that the connections to the function block will be the same as for the single busbar arrangement The voltage selection parameter CBConfig is set to No voltage sel 15 1 3 3 Single circuit breaker with double busbar internal voltage selection M12326 3 v7 WA1 WA2 QB1 QB2 LINE QA1 IEC10000095 6 en vsd WA1_M...

Page 610: ...aker arrangement requires two function blocks one for breaker WA1_QA1 and one for breaker WA2_QA1 No voltage selection is necessary because the voltage from busbar 1 VT is connected to U3PBB1 on SESRSYN for WA1_QA1 and the voltage from busbar 2 VT is connected to U3PBB1 on SESRSYN for WA2_QA1 The voltage from the line VT is connected to U3PLN1 on both function blocks The condition of VT fuses shal...

Page 611: ... on all three function blocks The positions of the disconnectors and VT fuses shall be connected as shown in Figure 304 1MRK 506 369 UEN B Section 15 Control Line distance protection REL670 2 2 IEC 605 Application manual ...

Page 612: ...LD B2 QOPEN B2 QCLD LN1 QOPEN LN1 QCLD LN2 QOPEN LN2 QCLD UB1OK UB1FF UB2OK UB2FF ULN1OK ULN1FF ULN2OK ULN2FF U3PLN2 U3PLN1 U3PBB2 WA1_VT WA2_VT LINE1_VT LINE2_VT WA1_QA1 TIE_QA1 LINE1_QB9 LINE2_QB9 WA1_MCB WA2_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...

Page 613: ...pervision of LINE2_MCB fuse Setting CBConfig 1 1 2 bus CB TIE_QA1 B1QOPEN CLD Position of WA1_QA1 breaker and belonging disconnectors B2QOPEN CLD Position of WA2_QA1 breaker and belonging disconnectors LN1QOPEN CLD Position of LINE1_QB9 disconnector LN2QOPEN CLD Position of LINE2_QB9 disconnector UB1OK FF Supervision of WA1_MCB fuse UB2OK FF Supervision of WA2_MCB fuse ULN1OK FF Supervision of LIN...

Page 614: ...nder Main menu Settings IED Settings Control Synchronizing 25 SC VC SESRSYN 25 SC VC X has been divided into four different setting groups General Synchronizing Synchrocheck and Energizingcheck General settings Operation The operation mode can be set On or Off The setting Off disables the whole function GblBaseSelBus and GblBaseSelLine These configuration settings are used for selecting one of twe...

Page 615: ...output signal depends on the input conditions UHighBusSynch and UHighLineSynch The voltage level settings shall be chosen in relation to the bus line network voltage The threshold voltages UHighBusSynch and UHighLineSynch have to be set lower than the value where the network is expected to be synchronized A typical value is 80 of the rated voltage UDiffSynch Setting of the voltage difference betwe...

Page 616: ...onizing near a power station a narrower limit should be used A typical value is 15 degrees tBreaker The tBreaker shall be set to match the closing time for the circuit breaker and should also include the possible auxiliary relays in the closing circuit It is important to check that no slow logic components are used in the configuration of the IED as there then can be big variations in closing time...

Page 617: ...tting is 0 10 0 15 p u FreqDiffM and FreqDiffA The frequency difference level settings FreqDiffM and FreqDiffA shall be chosen depending on the condition in the network At steady conditions a low frequency difference setting is needed where the FreqDiffM setting is used For autoreclosing a bigger frequency difference setting is preferable where the FreqDiffA setting is used A typical value for Fre...

Page 618: ...hLineEnerg Both energizing can be done in both directions DLLB or DBLL ManEnergDBDL If the parameter is set to On manual closing is also enabled when both line voltage and bus voltage are below ULowLineEnerg and ULowBusEnerg respectively and ManEnerg is set to DLLB DBLL or Both UHighBusEnerg and UHighLineEnerg The voltage level settings must be chosen in relation to the bus or line network voltage...

Page 619: ...on ANSI IEEE C37 2 device number Autorecloser for 1 phase 2 phase and or 3 phase SMBRREC 5 0 1 IEC15000204 V1 EN US 79 15 2 2 Application M12391 3 v8 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 operati...

Page 620: ...ngle phase auto reclosing is of particular value During the single phase dead time the system is still capable of transmitting load on the two healthy phases and the system is still synchronized It requires that each circuit breaker pole can be operated individually which is usually the case for higher transmission voltages A somewhat longer dead time may be required for single phase reclosing com...

Page 621: ...Arranged in such a way that sequential reclosing of the two CBs can be arranged with a priority circuit available in the auto recloser In case of a permanent fault and unsuccessful reclosing of the first CB reclosing of the second CB is cancelled and thus the stress on the power system is limited The auto recloser can be selected to perform single phase and or three phase automatic reclosing from ...

Page 622: ...rmally one must be the master and be connected to inhibit the other auto recloser if it has started This inhibit can for example be done from an auto recloser for 3 phase operation in progress signal When Single and or three phase auto reclosing is considered there are a number of cases where the tripping shall be three phase anyway For example Evolving fault where the fault during the dead time s...

Page 623: ...ance protection aided trip In some cases also directional earth fault protection aided trip can be connected to start an auto reclose attempt If general trip is used to start the auto recloser it is important to block it from other functions that should not start an auto reclosing sequence In cases where one wants to differentiate three phase auto reclosing dead time for different power system con...

Page 624: ...up zones might not be required Breaker failure trip local and remote must however always be connected 15 2 2 5 Control of the auto reclosing dead time for shot 1 M12391 113 v5 Up to four different time settings can be used for the first shot and one extension time There are separate settings for single two and three phase auto reclosing dead time t1 1Ph t1 2Ph t1 3Ph If no particular input signal ...

Page 625: ...ee phase trip is also made in the tripping logic SMPTTRC function block where the setting 3 phase 1ph 3Ph or 1ph 2ph 3Ph is selected 15 2 2 8 ARMode 3ph normal setting for a three phase shot M12391 124 v5 Three phase auto reclosing one to five shots according to the NoOfShots setting The prepare three phase trip PREP3P output is always set high A trip operation is made as a three phase trip for al...

Page 626: ...ase tripping the operation is as in the example described above program mode 1 2 3ph If the first reclosing shot fails a three phase trip will be issued and three phase auto reclosing can follow if selected In the event of a three phase trip TR3P input high the auto recloser will be inhibited and no auto reclosing takes place 15 2 2 11 ARMode 1ph 1 2ph 1 phase or 2 phase reclosing in the first sho...

Page 627: ...r three phase auto reclosing Table 47 Type of reclosing shots at different settings of ARMode or integer inputs to MODEINT MODEINT integer ARMode Type of fault 1st shot 2nd 5th shot 1 3ph 1ph 3ph 3ph 2ph 3ph 3ph 3ph 3ph 3ph 2 1 2 3ph 1ph 1ph 3ph 2ph 2ph 3ph 3ph 3ph 3ph 3 1 2ph 1ph 1ph 3ph 2ph 2ph 3ph 3ph 4 1ph 1 2ph 1ph 1ph 3ph 2ph 2ph 3ph 5 1 2ph 1 3ph 1ph 1ph 3ph 2ph 2ph 3ph 3ph 3ph 6 1ph 1 2 3p...

Page 628: ...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 recloser operation counter is incremented There is a counter for each type ...

Page 629: ...t initiation M12391 214 v8 In many cases there is a requirement that a lock out is generated when the auto reclosing attempt fails This is done with logic connected to the in and outputs of the auto recloser and 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 ph...

Page 630: ...hich leads to single phase tripping and then the fault spreads to another phase The second fault is then cleared by three phase tripping The auto recloser will first receive a start signal START without any three phase signal TR3P The auto recloser will start a single phase auto reclosing sequence if programmed to do so At the evolving fault clearance there will be a new START signal and three pha...

Page 631: ... auto reclosing back is activated it will keep the auto recloser on a hold until it is reset There may thus be a considerable delay between start of the auto recloser and the breaker closing command to the circuit breaker An external logic limiting the time and sending an inhibit to the INHIBIT input can be used The input can also be used to set the auto recloser on hold for a longer or shorter pe...

Page 632: ...then used for the combination MODEINT The auto reclosing mode is selected with the ARMode setting As an alternative to the setting the mode can be selected by connecting an integer for example from function block B16I to the MODEINT input The six possible modes are described in table 6 with their corresponding MODEINT integer value When a valid integer is connected to the input MODEINT the selecte...

Page 633: ...t 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 high source TRUE The signal is required for three phase shots 1 5 to proceed Note Not the high speed step THOLHOLD Signal Therm...

Page 634: ... increased shot number Every new increase of the shot number needs a new activation of the ZONESTEP input This functionality is controlled by the setting ZoneSeqCoord Recommendations for output signals M12399 46 v9 Please see Figure 309 Figure 310 and Figure 311 and default factory configuration for examples 1PT1 and 2PT1 Indicates that single phase or two phase auto reclosing is in progress It is...

Page 635: ... instead The selected mode is reported as an integer on the MODE output The six possible modes are described in Table 47 with their corresponding MODEINT integer value PERMIT1P Permit single phase trip is the inverse of PREP3P It can be connected to a binary output relay for connection to external protection or trip relays In case of a total loss of auxiliary power the output relay drops and does ...

Page 636: ...utput will be activated UNSUCCL Indicates unsuccessful reclosing WFMASTER Wait from master is used in high priority units to hold back auto reclosing of the low priority unit during sequential auto reclosing Refer to the recommendation for multi breaker arrangements in Figure 311 Connection and setting examples Figure 309 is showing an example of how to connect the auto recloser when used for thre...

Page 637: ...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 309 Example of I O signal connections at a three phase auto reclosing sequence 1MRK 506 369 UEN B Section 15 Control Line distance protection REL670 2 2 IEC 631 Appli...

Page 638: ...ulti breaker arrangement the setting for the first circuit breaker the master is Priority High and for the other circuit breaker Priority Low While the auto reclosing of the master is in progress it issues the WFMASTER output 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...

Page 639: ...ve unit interrupts the auto reclosing sequence of the latter The signals can be cross connected to allow simple changing of the priority by just setting the High and the Low priorities without changing the configuration The input CBCLOSED for each circuit breaker is important in multi breaker arrangements to ensure that the circuit breaker was closed at the beginning of the cycle If the High prior...

Page 640: ... 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 PREP3P 3PT1 2PT1 1PT1 3PT5 ACTIVE UNSUCCL READY BLOCKED SETON INPROGR x x SUCCL SMBRREC IEC04000137 V4 EN US Figure 311 Additional input and output signals at multi breaker arrangement The connections can be made symmetrical to m...

Page 641: ...phase faults is an attractive alternative for maintaining service and system stability AutoContinue Automatic continuation to the next shot if the circuit breaker is not closed within the set time of tAutoContWait The normal setting is AutoContinue Off tAutoContWait This is the length in time the auto recloser waits to see if the circuit breaker is closed when AutoContinue is set to On Normally th...

Page 642: ... the C O sequence For the selection CO circuit breaker ready for a Close Open cycle the condition is also checked after the set auto reclosing dead time This selection has a value first of all at multi shot auto reclosing to ensure that the circuit breaker is ready for a C O sequence at shot two and further shots During single shot auto reclosing the OCO selection can be used A breaker shall accor...

Page 643: ... time and other settings of the synchrocheck function Attention should also be paid to the possibility of a power swing when reclosing after a line fault Too short a time may prevent a potentially successful auto reclosing tCBClosedMin A typical setting is 5 0 s If the circuit breaker has not been closed for at least this minimum time an auto reclosing start will not be accepted tSuccessful If the...

Page 644: ... There is also a separate time setting facility for three phase high speed auto reclosing t1 3PhHS This high speed auto reclosing is activated by the STARTHS input and is used when auto reclosing is done without the requirement of synchrocheck conditions to be fulfilled A typical dead time is 400ms t2 3Ph t3 3Ph t4 3Ph t5 3Ph The delay of auto reclosing shot two and possible later shots are usuall...

Page 645: ...e same time 15 3 Apparatus control IP14560 1 v3 15 3 1 Application M13443 4 v14 The apparatus control is a functionality for control and supervising of 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 c...

Page 646: ...t simultaneous operation Selection and supervision of operator place Command supervision Block deblock of operation Block deblock of updating of position indications Substitution of position indications Overriding of interlocking functions Overriding of synchrocheck Pole discordance supervision Operation counter Suppression of mid position The apparatus control function is realized by means of a n...

Page 647: ...re below is the logical node for interlocking When the circuit breaker or switch is located in a breaker IED two more functions are added GOOSE receive for switching device GOOSEXLNRCV Proxy for signals from switching device via GOOSE XLNPROXY The extension of the signal flow and the usage of the GOOSE communication are shown in Figure 314 en05000116 vsd IEC 61850 IEC05000116 V2 EN US Figure 313 S...

Page 648: ...trol functions with XCBR and XSWI located in a breaker IED Control operation can be performed from the local IED HMI If users are defined in the IED then the local remote switch is under authority control otherwise the default user can perform control operations from the local IED HMI without logging in The default position of the local remote switch is on remote Section 15 1MRK 506 369 UEN B Cont...

Page 649: ...4 5 6 PSTO All then it is no priority between operator places All operator places are allowed to operate According to IEC 61850 standard the orCat attribute in originator category are defined in Table 49 Table 49 orCat attribute according to IE C61850 Value Description 0 not supported 1 bay control 2 station control 3 remote control 4 automatic bay 5 automatic station 6 automatic remote 7 maintena...

Page 650: ...so provides blocking functions that can be distributed to different apparatuses within the bay There are two different blocking alternatives Blocking of update of positions Blocking of commands IEC13000016 2 en vsd IEC13000016 V2 EN US Figure 315 APC Local remote function block 15 3 3 Switch controller SCSWI M16596 3 v6 SCSWI may handle and operate on one three phase device or three one phase swit...

Page 651: ...on the type of switching device SXCBR or SXSWI The switch controller represents the content of the SCSWI logical node according to IEC 61850 with mandatory functionality 15 3 4 Switches SXCBR SXSWI M16602 3 v7 Switches are functions used to close and interrupt an ac power circuit under normal conditions or to interrupt the circuit under fault or emergency conditions The intention with these functi...

Page 652: ...h modeled in a breaker IED as if represented by a SXCBR or SXSWI function The command response functionality is dependent on the connection of the execution information XIN from the SCSWI function controlling the represented switch Otherwise the function only reflects the current status of the switch such as blocking selection position operating capability and operation counter Since different swi...

Page 653: ... Figure 316 Configuration with XLNPROXY and GOOSEXLNRCV where all the IEC 61850 modelled data is used including selection 1MRK 506 369 UEN B Section 15 Control Line distance protection REL670 2 2 IEC 647 Application manual ...

Page 654: ...ch to start moving it checks if the switch is blocked for the operation When the switch has started moving and no blocking condition has been detected XLNPROXY issues a response to the SCSWI function that the command has started If OPOK is used this response is given when XLNPROXY receives the signal If no movement of the switch is registered within the limit tStartMove the command is considered f...

Page 655: ...ely SwOpCap for a XSWI The interpretation for the command following is controlled through the setting SwitchType 15 3 6 Reservation function QCRSV and RESIN M16609 3 v4 The purpose of the reservation function is primarily to transfer interlocking information between IEDs in a safe way and to prevent double operation in a bay switchyard part or complete substation For interlocking evaluation in a s...

Page 656: ...s are either the request for reservation from another bay or the acknowledgment from each bay respectively which have received a request from this bay Also the information of valid transmission over the station bus must be received en05000117 vsd IED IED From other SCSWI in the bay To other SCSWI in the bay 3 Station bus 3 RESIN EXCH_OUT EXCH_IN RESIN EXCH_OUT EXCH_IN SCSWI RES_RQ RES_GRT RES_DATA...

Page 657: ...n in Figure 318 but instead have a higher availability since no acknowledgment is required SCSWI SELECTED RES_EXT IED IED OR Other SCWI in the bay Station bus SPGAPC IN RESGRANT IntlReceive RESGRANT IntlReceive IEC05000178 3 en vsd IEC05000178 V3 EN US Figure 320 Application principle for an alternative reservation solution 15 3 7 Interaction between modules M16626 3 v9 A typical bay with apparatu...

Page 658: ...be transmitted to SXCBR The Autorecloser SMBRREC consists of the facilities to automatically close a tripped breaker with respect to a number of configurable conditions The logical node Interlocking SCILO provides the information to SCSWI whether it is permitted to operate due to the switchyard topology The interlocking conditions are evaluated with separate logic and connected to SCILO The Synchr...

Page 659: ...Close Open Close Enable close Enable open Open rel Close rel Open rel SMPPTRC 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 321 Example overview of the interactions between functions in a typical bay 15 3 8 Set...

Page 660: ...mand is desired the model direct control with normal security is used At control with enhanced security there is an additional supervision of the status value by the control object which means that each command sequence must be terminated by a termination command The parameter PosDependent gives permission to operate depending on the position indication that is at Always permitted it is always per...

Page 661: ...nd operate Sel Op phase or only at operate Op phase 15 3 8 3 Switch SXCBR SXSWI M16675 3 v8 tStartMove is the supervision time for the apparatus to start moving after a command execution is done from the SCSWI function When the time has expired the command supervision is reset and a cause code is given During the tIntermediate time the position indication is allowed to be in an intermediate 00 sta...

Page 662: ...During the tIntermediate time the position indication is allowed to be in an intermediate 00 state When the time has expired the command supervision is reset and a cause code is given The indication of the mid position at SCSWI is suppressed during this time period when the position changes from open to close or vice versa if the parameter SuppressMidPos is set to On in the SCSWI function In most ...

Page 663: ...To connect or disconnect a parallel circuit carrying load current The switching voltage across the open contacts is thus virtually zero thanks to the parallel circuit for example 1 of rated voltage Paralleling of power transformers is not allowed Earthing switches are allowed to connect and disconnect earthing of isolated points Due to capacitive or inductive coupling there may be some voltage for...

Page 664: ...peration 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 15 4 1 Configuration guidelines M13529 4 v4 The following sections describe how the interlocking for a certain switchgear config...

Page 665: ...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 the abo...

Page 666: ...B1 WA7 C C B2 A2 en04000479 vsd IEC04000479 V1 EN US Figure 324 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 busba...

Page 667: ...erent busbars that is 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 s...

Page 668: ...B2 EXDU_BC sect 2 BC_12_CL VP_BC_12 BC_17_OP BC_17_CL VP_BC_17 BC_27_OP BC_27_CL VP_BC_27 EXDU_BC en04000480 vsd IEC04000480 V1 EN US Figure 325 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 15 4 2 4 Configuration setting M13560 108 v4 If there is no b...

Page 669: ... busbar WA2 and therefore no QB2 disconnector then the interlocking for QB2 is not used The state for QB2 QC21 BC_12 BC_27 are set to open by setting the appropriate module inputs as follows In the functional block diagram 0 and 1 are 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 15 4 3 Interlocking for bus coupler bay ABC_BC IP1414...

Page 670: ...C are described below 15 4 3 3 Signals from all feeders M13553 6 v4 To derive the signals Signal BBTR_OP No busbar transfer is in progress concerning this bus coupler VP_BBTR 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_TRAF...

Page 671: ...82 V1 EN US Figure 328 Busbars divided by bus section disconnectors circuit breakers The following signals from each bus section disconnector bay A1A2_DC are needed For B1B2_DC corresponding signals from busbar B are used The same type of module A1A2_DC is used for different busbars that is for both bus section disconnector A1A2_DC and B1B2_DC Signal DCOPTR The bus section disconnector is open VPD...

Page 672: ...R_OP 1 IEC04000483 V1 EN US Figure 329 Signals to a bus coupler bay in section 1 from any bays in each section For a bus coupler bay in section 2 the same conditions as above are valid by changing section 1 to section 2 and vice versa 15 4 3 4 Signals from bus coupler M13553 58 v5 If the busbar is divided by bus section disconnectors into bus sections the signals BC_12 from the busbar coupler of t...

Page 673: ...C Signal DCCLTR The bus section disconnector is closed VPDCTR The switch status of bus section disconnector DC is valid EXDU_DC No transmission error from the bay that contains the above information If the busbar is divided by bus section circuit breakers the signals from the bus section coupler bay A1A2_BS rather than the bus section disconnector bay A1A2_DC must be used For B1B2_BS corresponding...

Page 674: ...terlocking for QB2 and QB7 is not used The states for QB2 QB7 QC71 are set to open by setting the appropriate module inputs as follows In the functional block diagram 0 and 1 are designated 0 FALSE and 1 TRUE QB2_OP 1 QB2_CL 0 QB7_OP 1 QB7_CL 0 QC71_OP 1 QC71_CL 0 If there is no second busbar B and therefore no QB2 and QB20 disconnectors then the interlocking for QB2 and QB20 are not used The stat...

Page 675: ...ween circuit breaker and transformer Otherwise the interlocking for line bay ABC_LINE function can be used This function can also be used in single busbar arrangements QB1 QB2 QC1 QA1 QC2 WA1 A WA2 B QA2 QC3 T QC4 QB4 QB3 QA2 and QC4 are not used in this interlocking AB_TRAFO en04000515 vsd IEC04000515 V1 EN US Figure 332 Switchyard layout AB_TRAFO M13566 4 v4 The signals from other bays connected...

Page 676: ...line bay ABC_LINE Signal BC_12_CL A bus coupler connection exists between busbar WA1 and WA2 VP_BC_12 The switch status of BC_12 is valid EXDU_BC No transmission error from bus coupler bay BC The logic is identical to the double busbar configuration Signals from bus coupler 15 4 4 3 Configuration setting M13566 22 v5 If there are no second busbar B and therefore no QB2 disconnector then the interl...

Page 677: ...h 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 334 Switchyard layout A1A2_BS M15111 4 v3 The signals from other bays connected to the module A1A2_BS are described below 15 4 5 2 Signals from all feeders M15111 6 v4 If the busbar is divided by bus section circuit breakers into bus sections and both circuit breake...

Page 678: ...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 above information These signals from the bus section circuit breaker ba...

Page 679: ... 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 336 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 1MRK 506 369 UEN B...

Page 680: ... 1 EXDU_12 bay n sect 1 EXDU_BS A1A2 EXDU_BC sect 1 EXDU_BC sect 2 IEC04000491 V1 EN US Figure 337 Signals from any bays for a bus section circuit breaker between sections B1 and B2 15 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 o...

Page 681: ...4 6 2 Signals in single breaker arrangement M13542 6 v5 If the busbar is divided by bus section disconnectors the condition no other disconnector connected to the bus section must be made by a project specific logic The same type of module A1A2_DC is used for different busbars that is for both bus section disconnector A1A2_DC and B1B2_DC But for B1B2_DC corresponding signals from busbar B are used...

Page 682: ...there is an additional bus section disconnector the signal from the bus section disconnector bay A1A2_DC must be used 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 there is an additional bus section circuit breaker rather than an additional bus sec...

Page 683: ...he A2 busbar section are valid QB1OPTR bay 1 sect A2 S2DC_OP VPS2_DC EXDU_BB en04000495 vsd QB1OPTR bay n sect A2 VPQB1TR bay 1 sect A2 VPQB1TR bay n sect A2 VPDCTR A2 A3 EXDU_BB bay n sect A2 DCOPTR A2 A3 EXDU_BB bay 1 sect A2 EXDU_DC A2 A3 IEC04000495 V1 EN US Figure 341 Signals from any bays in section A2 to a bus section disconnector For a bus section disconnector these conditions from the B1 ...

Page 684: ...0TR bay n sect B2 VPDCTR B2 B3 EXDU_BB bay n sect B2 DCOPTR B2 B3 EXDU_BB bay 1 sect B2 EXDU_DC B2 B3 IEC04000497 V1 EN US Figure 343 Signals from any bays in section B2 to a bus section disconnector 15 4 6 3 Signals in double breaker arrangement M13542 80 v5 If the busbar is divided by bus section disconnectors the condition for the busbar disconnector bay no other disconnector connected to the b...

Page 685: ...ction 2 is valid EXDU_BB No transmission error from double breaker bay DB 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 valid VPQB2TR The switch status of QB2 is valid EXDU_DB No transmission error from the bay that contains the above information The logic is identi...

Page 686: ...se 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 A2 EXDU_DB bay n sect A2 IEC04000500 V1 EN US Figure 346 Signals from double breaker bays in section A2 to a bus section disconnector For a bus section disconnector these conditions from the B1 busbar se...

Page 687: ...2 EXDU_DB bay 1 sect B2 EXDU_DB bay n sect B2 IEC04000502 V1 EN US Figure 348 Signals from double breaker bays in section B2 to a bus section disconnector 15 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...

Page 688: ... No transmission error from breaker and a half BH that contains the above information 15 4 7 Interlocking for busbar earthing switch BB_ES IP14164 1 v4 15 4 7 1 Application M15015 3 v7 The interlocking for busbar earthing switch BB_ES function is used for one busbar earthing switch on any busbar parts according to figure 350 QC en04000504 vsd IEC04000504 V1 EN US Figure 350 Switchyard layout BB_ES...

Page 689: ... open VPQB1TR The switch status of QB1 is valid VPQB2TR The switch status of QB2 is valid VQB220TR The switch status of QB2and QB20 is valid VPQB7TR The switch status of QB7 is valid EXDU_BB No transmission error from the bay that contains the above information These signals from each bus section disconnector bay A1A2_DC are also needed For B1B2_DC corresponding signals from busbar B are used The ...

Page 690: ..._BS No transmission error from the bay BS bus section coupler bay that contains the above information For a busbar earthing switch these conditions from the A1 busbar section are valid QB1OPTR bay 1 sect A1 BB_DC_OP VP_BB_DC EXDU_BB en04000506 vsd QB1OPTR bay n sect A1 VPQB1TR bay 1 sect A1 VPQB1TR bay n sect A1 VPDCTR A1 A2 EXDU_BB bay n sect A1 DCOPTR A1 A2 EXDU_BB bay 1 sect A1 EXDU_DC A1 A2 IE...

Page 691: ... the B1 busbar section are valid QB2OPTR QB220OTR bay 1 sect B1 BB_DC_OP VP_BB_DC EXDU_BB en04000508 vsd QB2OPTR QB220OTR bay n sect B1 VPQB2TR VQB220TR bay 1 sect B1 VPQB2TR VQB220TR bay n sect B1 VPDCTR B1 B2 EXDU_BB bay n sect B1 DCOPTR B1 B2 EXDU_BB bay 1 sect B1 EXDU_DC B1 B2 IEC04000508 V1 EN US Figure 354 Signals from any bays in section B1 to a busbar earthing switch in the same section Fo...

Page 692: ... section For a busbar earthing switch on bypass busbar C these conditions are valid QB7OPTR bay 1 BB_DC_OP VP_BB_DC EXDU_BB en04000510 vsd QB7OPTR bay n VPQB7TR bay 1 VPQB7TR bay n EXDU_BB bay 1 EXDU_BB bay n IEC04000510 V1 EN US Figure 356 Signals from bypass busbar to busbar earthing switch 15 4 7 3 Signals in double breaker arrangement M15053 83 v4 The busbar earthing switch is only allowed to ...

Page 693: ...m the bay that contains the above information These signals from each bus section disconnector bay A1A2_DC are also needed For B1B2_DC corresponding signals from busbar B are used The same type of module A1A2_DC is used for different busbars that is for both bus section disconnectors A1A2_DC and B1B2_DC Signal DCOPTR The bus section disconnector is open VPDCTR The switch status of bus section disc...

Page 694: ...on this part of the busbar are open VP_BB_DC The switch status of all disconnectors on this part of the busbar is valid EXDU_BB No transmission error from any bay that contains the above information 15 4 8 Interlocking for double CB bay DB IP14167 1 v2 15 4 8 1 Application M13585 3 v10 The interlocking for a double busbar double circuit breaker bay including DB_BUS_A DB_BUS_B and DB_LINE functions...

Page 695: ...QC9 just set the appropriate inputs to open state and disregard the outputs In the functional block diagram 0 and 1 are designated 0 FALSE and 1 TRUE 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 t...

Page 696: ...v4 Three types of interlocking modules per diameter are defined BH_LINE_A and BH_LINE_B are the connections from a line 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 15 4 9 2 Configuration setting M13569 6 v5 For application witho...

Page 697: ...on and LHMI presentation function SLGAPC or the selector switch function block as it is also known is used to get a selector switch functionality similar with the one provided by a hardware multi position selector switch Hardware selector switches are used extensively by utilities in order to have different functions operating on pre set values Hardware switches are however sources for maintenance...

Page 698: ...it gives the length of the pulse in seconds tDelay The delay between the UP or DOWN activation signal positive front and the output activation StopAtExtremes Sets the behavior of the switch at the end positions if set to Disabled when pressing UP while on first position the switch will jump to the last position when pressing DOWN at the last position the switch will jump to the first position when...

Page 699: ...loser from local HMI through Selector mini switch VSGAPC is also provided with IEC 61850 communication so it can be controlled from SA system as well 15 6 3 Setting guidelines SEMOD158807 4 v4 Selector mini switch VSGAPC function can generate pulsed or steady commands by setting the Mode parameter When pulsed commands are generated the length of the pulse can be set using the tPulse parameter Also...

Page 700: ...tive the values of the OPEN and CLOSE inputs determine the two bit integer value of the output POSITION The timestamp of the output POSITION will have the latest updated timestamp of the inputs OPEN and CLOSE When the input signal VALID is inactive DPGAPC function forces the position to intermediated state When the value of the input signal VALID changes the timestamp of the output POSITION will b...

Page 701: ...C 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 15 8 3 Setting guidelines SEMOD176518 4 v7 The parameters for the single point generic control 8 signals SPC8GAPC function are set via the local HMI or PCM600 ...

Page 702: ...l code of latch On latch Off pulse On pulse Off Trip or Close The remaining parameters are regarded as appropriate For example pulse On on time 100 off time 300 count 5 would give 5 positive 100 ms pulses 300 ms apart For description of the DNP3 protocol implementation refer to the Communication manual 15 9 3 Setting guidelines SEMOD158639 5 v3 AUTOBITS function block has one setting Operation On ...

Page 703: ... apparatus This type of command control is normally carried out by sending a pulse to the binary outputs of the IED Figure 362 shows a close operation An open breaker operation is performed in a similar way but without the synchro check condition Single command function SINGLECMD CMDOUTy OUTy Close CB1 User defined conditions Synchro check Configuration logic circuits en04000206 vsd IEC04000206 V2...

Page 704: ...ice 1 User defined conditions Configuration logic circuits en04000208 vsd IEC04000208 V2 EN US Figure 364 Application example showing a logic diagram for control of external devices via configuration logic circuits 15 10 3 Setting guidelines M12448 3 v2 The parameters for Single command 16 signals SINGLECMD are set via the local HMI or PCM600 Section 15 1MRK 506 369 UEN B Control 698 Line distance...

Page 705: ...rator 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 sent from the station level is changed from 0 to 1 That means the configured logic connected to the command function block may not have a cycle time longer than the cycle time for the command function block...

Page 706: ...700 ...

Page 707: ...t signals Communication speed or minimum time delay is always of utmost importance because the purpose for using communication is to improve the tripping speed of the scheme To avoid false signals that could cause false tripping it is necessary to pay attention to the security of the communication channel At the same time it is important to pay attention to the communication channel dependability ...

Page 708: ... tripping function if the communication channel is out of service Inadequate speed or dependability can cause spurious tripping for external faults Inadequate security can cause delayed tripping for internal faults To secure that the send signal will arrive before the zone used in the communication scheme will trip the trip is released first after the time delay tCoord has elapsed The setting of t...

Page 709: ...f the communication channel is out of service Conversely it is less secure than permissive schemes because it will trip for external faults within the reach of the tripping function if the communication channel is out of service Inadequate speed or dependability can cause spurious tripping for external faults Inadequate security can cause delayed tripping for internal faults Since the blocking sig...

Page 710: ...t a gap between the protection zones where faults would not be detected If the underreaching zone do not meet the required sensitivity due to for instance fault infeed from the remote end a blocking or permissive overreaching scheme should be considered The received signal CR must be received when the overreaching zone is activated to achieve an instantaneous trip In some cases due to the fault cu...

Page 711: ...eme must consider besides the general requirement of fast and secure operation also consider requirement on the dependability Inadequate security can cause unwanted tripping for external faults Inadequate speed or dependability can cause delayed tripping for internal faults or even unwanted operations This scheme may use virtually any communication media that is not adversely affected by electrica...

Page 712: ...ne end thereby disabling the communication channel To overcome the lower dependability in permissive schemes an unblocking function can be used Use this function at older less reliable power line carrier PLC communication where the signal has to be sent through the primary fault The unblocking function uses a guard signal CRG which must always be present even when no CR signal is received The abse...

Page 713: ...ication logic function are set via the local HMI or PCM600 Configure the zones used for the CS send and for scheme communication tripping by using the ACT configuration tool The recommended settings of tCoord timer are based on maximal recommended transmission time for analogue channels according to IEC 60834 1 It is recommended to coordinate the proposed settings with actual performance for the t...

Page 714: ... 3 4 Permissive overreaching scheme M13869 34 v4 Set Operation On Set Scheme type Permissive OR Set tCoord 0 ms Set tSendMin 0 1 s 0 s in parallel line applications Set Unblock Off Set tSecurity 0 035 s 16 1 3 5 Unblocking scheme M13869 43 v4 Set Unblock Restart Loss of guard signal will give both trip and alarm Choose NoRestart if only trip is required Set tSecurity 0 035 s 16 1 3 6 Intertrip sch...

Page 715: ...lated to the transmission channels speed and security against false or lost signals Special communication channels are used for this purpose When power line carrier is used for communication these special channels are strongly recommended due to the communication disturbance caused by the primary fault Communication speed or minimum time delay is always of utmost importance because the purpose for...

Page 716: ...rotection IEDs relative to the faults The protection IED near the faults detects the faults on the protected line as a forward fault and on the parallel line in reverse direction The directional phase selector in the two IEDs near the faults can discriminate between the faults and issue correct single pole tripping commands L1 L2 L3 Earth IED IED L1 L2 L3 Station A Station B IEC06000309_2_en vsd I...

Page 717: ...the trip is released first after the time delay tCoord has elapsed The setting of tCoord must be set longer than the maximum transmission time of the channel A security margin of at least 10 ms should be considered The timer tSendMin for prolonging the carrier send signal is proposed to set to zero in blocking schemes 16 2 2 2 Permissive schemes SEMOD141790 30 v2 In permissive scheme permission to...

Page 718: ...overreaching zone used in the teleprotection scheme must be activated at the same time as the received signal is present The scheme can be used for all type line lengths In permissive overreach schemes the communication channel plays an essential roll to obtaining fast tripping at both ends Failure of the communication channel may affect the selectivity and delay tripping at one end at least for f...

Page 719: ...ication channel The general requirement for teleprotection equipment operating in intertripping applications is that it should be very secure and very dependable since both inadequate security and dependability may cause unwanted operation In some applications the equipment shall be able to receive while transmitting and commands may be transmitted over longer time period than for other teleprotec...

Page 720: ...SendMin 0 1 s 16 3 Current reversal and Weak end infeed logic for distance protection 3 phase ZCRWPSCH IP15751 1 v4 16 3 1 Identification M15073 1 v5 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Current reversal and weak end infeed logic for distance protection 3 phase ZCRWPSCH 85 16 3 2 Application IP15023 1 v1 16 3 2 1 Current reversal logi...

Page 721: ... the send signal CS or CSLn from B2 is held back until the reverse zone IRVLn has reset and the tDelayRev time has been elapsed To achieve this the reverse zone on the distance protection shall be connected to input IRV and the output IRVL shall be connected to input BLKCS on the communication function block ZCPSCH The function can be blocked by activating the input IRVBLK or the general BLOCK inp...

Page 722: ...not possible to use the echo function to send the echo signal to the remote line IED The echo signal would block the operation of the distance protection at the remote line end and in this way prevents the correct operation of a complete protection scheme A separate direct intertrip channel must be arranged from the remote end when a trip or accelerated trip is given there The intertrip receive si...

Page 723: ...Set WEI to Echo to activate the weak end infeed function with only echo function Set WEI to Echo Trip to obtain echo with trip The tPickUpWEI is the on time delay to activate the weak end infeed function Set tPickUpWEI to 10 ms a short delay is recommended to avoid that spurious carrier received signals will activate WEI and cause unwanted carrier send ECHO signals When single phase tripping is re...

Page 724: ...tion L1 L2 A1 A2 B1 B2 IEC14000002 1 en vsd IEC14000002 V1 EN US Figure 372 Current distribution for a fault close to B side when all breakers are closed When the breaker B1 opens for clearing the fault the fault current through B2 bay will invert If the communication signal has not reset at the same time as the distance protection function used in the teleprotection scheme has switched on to forw...

Page 725: ...er with the blocking teleprotection scheme some limitations apply Only the trip part of the function can be used together with the blocking scheme It is not possible to use the echo function to send the echo signal to the remote line IED The echo signal would block the operation of the distance protection at the remote line end and in this way prevents the correct operation of a complete protectio...

Page 726: ...ations Set the voltage criterion UPP and UPE for the weak end trip to 70 of the system base voltage UBase The setting should be below the minimum operate voltage of the system but above the voltage that occurs for fault on the protected line The phase to phase elements must be verified to not operate for phase to earth faults When single phase tripping is required a detailed study of the voltages ...

Page 727: ...inimum load current on the line during normal operation conditions The timer tLoadOn is used to increase the security of the loss of load function for example to avoid unwanted release due to transient inrush current when energizing the line power transformer The loss of load function will be released after the timer tLoadOn has elapsed at the same time as the load current in all three phases are ...

Page 728: ...signals In the directional scheme information of the fault current direction must be transmitted to the other line end With directional comparison in permissive schemes a short operate time of the protection including a channel transmission time can be achieved This short operate time enables rapid autoreclosing function after the fault clearance During a single phase reclosing cycle the autoreclo...

Page 729: ...f Intertrip Permissive UR Permissive OR or Blocking tCoord Delay time for trip from ECPSCH function For Permissive under overreaching schemes this timer shall be set to at least 20 ms plus maximum reset time of the communication channel as a security margin For Blocking scheme the setting should be maximum signal transmission time 10 ms Unblock Select Off if unblocking scheme with no alarm for los...

Page 730: ...fault close to B side when breaker at B1 is opened When the breaker on the parallel line operates the fault current on the healthy line is reversed The IED at B2 recognizes the fault in forward direction from reverse direction before breaker operates As IED at B2 already received permissive signal from A2 and IED at B2 is now detecting the fault as forward fault it will immediately trip breaker at...

Page 731: ...L function for reference of base values 16 7 3 1 Current reversal M13933 6 v5 The current reversal function is set on or off by setting the parameter CurrRev to On or Off Time delays shall be set for the timers tPickUpRev and tDelayRev tPickUpRev is chosen shorter 80 than the breaker opening time but minimum 20 ms tDelayRev is chosen at a minimum to the sum of protection reset time and the communi...

Page 732: ...to the protection function operate and reset time Time Fault occurs Protection pick up CS initiation CR to teleprot eq CR to prot func Fault current reversal Sending protection reset CS to communication drop CR reception drop CR to prot func drop Minimum setting of tDelay IEC05000536 2 en vsd IEC05000536 V2 EN US Figure 377 Time sequence of signaling at current reversal 16 7 3 2 Weak end infeed M1...

Page 733: ... be compromised due to the risk of a false communication signal A false CR signal could unnecessarily trip the line Therefore a local criterion is used to provide an additional trip criterion at the same location as the line circuit breaker The local criterion must detect the abnormal conditions at the end of the protected line and transformer and permit the CR signal to trip the circuit breaker A...

Page 734: ...ailure protection OR Low active power and power factor protection Analog input U3P I3P IEC09000773 1 en vsd LocalCheck CR1 CR2 CR1 CR2 Impedance protection Breaker Failure LCCRPTRC CarrierReceiveLogic IEC09000773 V1 EN US Figure 379 DTT scheme 16 8 2 Setting guidelines GUID 9E9CD5E0 1556 4E56 8A5D 5ACC17DAA00F v2 Setting guidelines for Direct transfer trip functions are outlined in the following s...

Page 735: ...power is ensured in at least two phases simultaneously before sending the trip signal Line which is tripped at the remote end will have low active power flowing through it which also results in low power factor in the respective phase A low power factor criterion could also be an added check of the local criterion in DTT In this function phase wise power factor is calculated and a comparison is ma...

Page 736: ...on calculates the remote end voltage of the transmission line utilizing local measured voltage current and with the help of transmission line parameters that is line resistance reactance capacitance and local shunt reactor For protection of long transmission line for in zone faults this function can be incorporated with other local criteria checks within direct transfer trip logic to ensure trippi...

Page 737: ...esult into undervoltage at the remote end There can be undervoltage at remote end also due to heavy loading or poor power factor on lagging side A fault in a line connected beyond the remote end bus can also produce undervoltage at remote end The compensated voltage calculated at the local end can detect such undervoltages The undervoltage caused by a fault can be asymmetrical while that due to ov...

Page 738: ...effect of XSR Hence this setting should be configured during installing and then connection and disconnection of shunt reactor breaker should be handled by the input SWIPOS Also for shunt reactor connected through the breaker or disconnector status of the same must be configured in the IED as shown in figure 381 Frequently the input current to the line protection IED is already corrected for the c...

Page 739: ...during non disturbed network operation tOV Time delay for trip in case of high voltage detection R1 Positive sequence line resistance given in ohm X1 Positive sequence line reactance given in ohm Xc Half the value of the equivalent Positive sequence capacitive shunt reactance of the line given in ohm EnShuntReactor Set On or Off to enable the charging current to be involved in the voltage compensa...

Page 740: ...efault value 0 5 s is recommended tDelay Trip time is set according to the individual application 16 8 6 Carrier receive logic LCCRPTRC GUID 13BF45AF B04C 4C6D B59D 79A51241C449 v1 16 8 6 1 Identification GUID D420E532 37DC 442F B847 8F73EE8527A7 v1 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Carrier receive logic LCCRPTRC 94 16 8 6 2 Applic...

Page 741: ... LCNSPTOV 47 16 8 7 2 Application GUID 4FDDBF7D 801B 4C7A AAE1 8D3ED41D950E v1 Negative sequence symmetrical components are present in all types of fault condition In case of three phase short circuits the negative sequence voltages and current have transient nature and will therefore decline to zero after some periods Negative sequence overvoltage protection LCNSPTOV is a definite time stage comp...

Page 742: ...ence symmetrical components are present in all abnormal conditions involving earth They have a considerably high value during earth faults Zero sequence overvoltage protection LCZSPTOV is a definite time stage comparator function The Zero sequence input voltage from the SMAI block is connected as input to the function through a group connection U3P in PCM600 This voltage is compared against the pr...

Page 743: ...ation IEC 60617 identification ANSI IEEE C37 2 device number Negative sequence overcurrent protection LCNSPTOC 46 16 8 9 2 Application GUID D47B89E9 2279 4057 B77D F27CDF84F1CE v1 Negative sequence symmetrical components are present in all types of fault condition Negative sequence overcurrent protection LCNSPTOC is a definite time stage comparator function The negative sequence input current from...

Page 744: ... components are present in all abnormal conditions involving earth They are having a considerably high value during earth faults Zero sequence overcurrent protection LCZSPTOC is a definite time stage comparator function The zero sequence input current from the SMAI block is connected as input to the function through a group connection I3P in PCM600 This current is compared against the preset value...

Page 745: ...he system LCP3PTOC could be used as a back up for other local criterion checks 16 8 11 3 Setting guidelines GUID BEC224BD F45D 4D42 8287 D9D9F4AB3D7B v2 GlobalBaseSel Selects the global base value group used by the function to define IBase UBase and SBase as applicable IOC Level of high phase current detection given in of IBase This setting can be based on evaluation of the largest current that ca...

Page 746: ...nt and helps to trip the circuit breaker at this end instantaneously or after a time delay according to the requirement 16 8 12 3 Setting guidelines GUID 8A4C4842 F9DB 4B44 8114 DCEE18CC6E59 v2 GlobalBaseSel Selects the global base value group used by the function to define IBase UBase and SBase as applicable IUC Level of low phase current detection given in of IBase This setting is highly dependi...

Page 747: ...le phase tripping for single phase faults two phase tripping for two phase faults and three phase tripping for three phase faults 1ph 2ph 3ph operating mode The logic also issues a three phase tripping command when phase selection within the operating protection functions is not possible or when external conditions request three phase tripping To meet the different double 1 breaker and other multi...

Page 748: ...xample could be the starting of breaker failure protection The three outputs TRL1 TRL2 TRL3 will always be activated at every trip and can be utilized on individual trip outputs if single phase operating devices are available on the circuit breaker even when a three phase tripping scheme is selected Set the function block to Program 3 phase and set the required length of the trip pulse to for exam...

Page 749: ... outputs TRL1 TRL2 and TRL3 The output TRIP is a general trip and is always activated independent of which phase is involved Depending on which phases are involved the outputs TR1P TR2P and TR3P will be activated as well When single phase tripping schemes are used a single phase autoreclosing attempt is expected to follow For cases where the autoreclosing is not in service or will not follow for s...

Page 750: ...le phase tripping application 17 1 2 3 Single two or three phase tripping M14828 15 v5 The single two three phase tripping mode provides single phase tripping for single phase faults two phase tripping for two phase faults and three phase tripping for three phase faults The operating mode is always used together with an autoreclosing scheme with setting ARMode 1 2 3 ph or ARMode 1 2 ph The functio...

Page 751: ... input SETLKOUT will result in lock out This is normally the case for overhead line protection where most faults are transient Unsuccessful autoreclose and back up zone tripping can in such cases be connected to initiate lock out by activating the input SETLKOUT 17 1 2 5 Example of directional data GUID 08AC09AB 2B2F 4095 B06E 1171CF225869 v2 An example how to connect the directional data from dif...

Page 752: ...EVN BLOCK START FW REV STL1 FWL1 REVL1 STL2 FWL2 REVL2 STL3 FWL3 REVL3 STDIR STARTCOMB STN FWN REVN STN FWN REVN PROTECTION 3 IEC16000180 2 en vsdx IEC16000180 V2 EN US Figure 384 Example of the connection of directional start logic The Start Matrix SMAGAPC merges start and directional output signals from different application functions and creates a common directional output signal STDIR to be co...

Page 753: ...d latches the TRIP related outputs The normal selection is Off AutoLock Sets the scheme for lock out Off only activates lock out through the input SETLKOUT On additionally allows lock out activation via the trip inputs The normal selection is Off tTripMin Sets the required minimum duration of the trip pulse It should be set to ensure that the circuit breaker is opened correctly The normal setting ...

Page 754: ...activation conditions no longer are fulfilled It is only used in Steady mode When used for direct tripping of circuit breaker s the off delay time shall be set to at least 0 150 seconds in order to obtain a satisfactory minimum duration of the trip pulse to the circuit breaker trip coils ModeOutputx Defines if output signal OUTPUTx where x 1 3 is Steady or Pulsed 17 3 Logic for group alarm ALMCALH...

Page 755: ...according to the specific application needs 17 4 1 2 Setting guidelines GUID B08F2636 33DA 4937 92EB 1A8AC0909AB4 v2 OperationOn or Off 17 5 Logic for group indication INDCALH 17 5 1 Identification GUID 3B5D4371 420D 4249 B6A4 5A168920D635 v4 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Logic for group indication INDCALH 17 5 1 1 Application ...

Page 756: ...logical function have the capability to propagate timestamp and quality are also available Those blocks have a designation including the letters QT like ANDQT ORQT etc 17 6 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...

Page 757: ...mp and quality of input signals The execution of different function blocks within the same cycle is determined by the order of their serial execution numbers Always remember this when connecting two or more 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 carefu...

Page 758: ...ignal in FXDSIGN The Restricted earth fault function REFPDIF can be used both for auto transformers and normal transformers When used for auto transformers information from both windings parts together with the neutral point current needs to be available to the function This means that three inputs are needed I3PW1CT1 I3PW2CT1 I3P REFPDIF IEC09000619_3_en vsd IEC09000619 V3 EN US Figure 387 REFPDI...

Page 759: ...an 16 to integer conversion function B16I 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 activate...

Page 760: ...n all INx where 1 x 16 are active that is 1 is 65535 65535 is the highest boolean value that can be converted to an integer by the B16I function block 17 9 Boolean to integer conversion with logical node representation 16 bit BTIGAPC SEMOD175753 1 v4 17 9 1 Identification SEMOD175757 2 v5 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Boolean t...

Page 761: ...sponds to the integer presented on the output OUT on the function block BTIGAPC Name of input Type Default Description Value when activated Value when deactivated IN1 BOOLEAN 0 Input 1 1 0 IN2 BOOLEAN 0 Input 2 2 0 IN3 BOOLEAN 0 Input 3 4 0 IN4 BOOLEAN 0 Input 4 8 0 IN5 BOOLEAN 0 Input 5 16 0 IN6 BOOLEAN 0 Input 6 32 0 IN7 BOOLEAN 0 Input 7 64 0 IN8 BOOLEAN 0 Input 8 128 0 IN9 BOOLEAN 0 Input 9 25...

Page 762: ...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 IB16 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 function block IB16 for 1 x 16 T...

Page 763: ...ean 16 conversion with logic node representation function ITBGAPC is used to transform an integer into a set of 16 boolean signals ITBGAPC function can receive an integer from a station computer for example over IEC 61850 8 1 This function is very useful when the user wants to generate logical commands for selector switches or voltage controllers by inputting an integer number ITBGAPC function has...

Page 764: ...6 are active equals 65535 This is the highest integer that can be converted by the ITBGAPC function block 17 12 Elapsed time integrator with limit transgression and overflow supervision TEIGAPC 17 12 1 Identification GUID 1913E066 37D1 4689 9178 5B3C8B029815 v3 Function Description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Elapsed time integrator TEIGAPC 17 12...

Page 765: ...9 999 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 17 13 Comparator for integer inputs INTCOMP 17 13 1 Identification GUID 5992B0F2 FC1B 4838 9BAB 2D2542BB264D v1 Function description IEC 61850 identification IEC 60617 identification ANSI ...

Page 766: ...ence value from input REF Set Value The function will take reference value from setting SetValue SetValue This setting is used to set the reference value for comparison when setting RefSource is selected as SetValue 17 13 4 Setting example GUID 13302FD6 1585 42FE BD6D 44F231982C59 v2 For absolute comparison between inputs Set the EnaAbs Absolute Set the RefSource Input REF Similarly for Signed com...

Page 767: ...ng is used to select the comparison type between signed and absolute values Absolute Comparison is performed with absolute values of input and reference Signed Comparison is performed with signed values of input and reference RefSource This setting is used to select the reference source between input and setting for comparison Input REF The function will take reference value from input REF Set Val...

Page 768: ...ned with settings as follows EnaAbs Absolute RefSource Set Value SetValue 100 RefPrefix Kilo EqualBandHigh 5 0 of reference value EqualBandLow 5 0 of reference value Operation The function will set the outputs for the following conditions INEQUAL will set when the INPUT is between the ranges of 95 to 105 kA INHIGH will set when the INPUT crosses above 105 kA INLOW will set when the INPUT crosses b...

Page 769: ...Voltage sequence component measurement VMSQI U1 U2 U0 SYMBOL TT V1 EN US Phase neutral voltage measurement VNMMXU U SYMBOL UU V1 EN US 18 1 2 Application SEMOD54488 4 v12 Measurement functions are used for power system measurement supervision and reporting to the local HMI monitoring tool within PCM600 or to station level for example via IEC 61850 The possibility to continuously monitor measured v...

Page 770: ...ision can be used to report measured signal value to station level when change in measured value is above set threshold limit or time integral of all changes since the last time value updating exceeds the threshold limit Measure value can also be based on periodic reporting Main menu Measurement Monitoring Service values CVMMXN The measurement function CVMMXN provides the following power system qu...

Page 771: ...s regarding any settings or parameters Zero clampings are also handled entirely by ZeroDb separately for each function s every output signal For example zero clamping of U12 is handled by UL12ZeroDb in VMMXU zero clamping of I1 is handled by IL1ZeroDb in CMMXU and so on Example of CVMMXN operation Outputs seen on the local HMI under Main menu Measurements Monitoring Servicevalues P_Q CVMMXN P_Q S ...

Page 772: ...out of operation Off The following general settings can be set for the Measurement function CVMMXN PowAmpFact Amplitude factor to scale power calculations PowAngComp Angle compensation for phase shift between measured I U Mode Selection of measured current and voltage There are 9 different ways of calculating monitored three phase values depending on the available VT inputs connected to the IED Se...

Page 773: ...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 measured value is below UGenZeroDb and or IGenZeroDb calculated S P Q and PF will be zero and these settings will override XZeroDb XRepTyp Reporting ty...

Page 774: ...he reference see Section Analog inputs Calibration curves It is possible to calibrate the functions CVMMXN CMMXU VMMXU and VNMMXU to get class 0 5 presentations of currents voltages and powers This is accomplished by amplitude and angle compensation at 5 30 and 100 of rated current and voltage The compensation curve will have the characteristic for amplitude and angle compensation of currents as s...

Page 775: ...MOD54481 12 v11 Single line diagram for this application is given in figure 390 400kV Busbar 400kV OHL P Q 1000 1 A IEC09000039 3 en vsdx IED kV 3 1 0 3 400 IEC09000039 1 EN V3 EN US Figure 390 Single line diagram for 400kV OHL application In order to monitor supervise and calibrate the active and reactive power as indicated in figure 390 it is necessary to do the following 1 Set correctly CT and ...

Page 776: ...quired UGenZeroDb Zero point clamping in of Ubase 25 Set minimum voltage level to 25 Voltage below 25 will force S P and Q to zero IGenZeroDb Zero point clamping in of Ibase 3 Set minimum current level to 3 Current below 3 will force S P and Q to zero UBase set in Global base Base setting for voltage level in kV 400 00 Set rated OHL phase to phase voltage IBase set in Global base Base setting for ...

Page 777: ... value Comments IAmpComp5 Amplitude factor to calibrate current at 5 of Ir 0 00 IAmpComp30 Amplitude factor to calibrate current at 30 of Ir 0 00 IAmpComp100 Amplitude factor to calibrate current at 100 of Ir 0 00 UAmpComp5 Amplitude factor to calibrate voltage at 5 of Ur 0 00 UAmpComp30 Amplitude factor to calibrate voltage at 30 of Ur 0 00 UAmpComp100 Amplitude factor to calibrate voltage at 100...

Page 778: ...1 it is necessary to do the following 1 Set correctly all CT and VT and phase angle reference channel PhaseAngleRef see Section Setting of the phase reference channel data using PCM600 for analog input channels 2 Connect in PCM600 measurement function to LV side CT VT inputs 3 Set the setting parameters for relevant Measurement function as shown in the following table 57 Section 18 1MRK 506 369 UE...

Page 779: ...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 IGenZeroDb Zero point clamping in of Ibase 3 Set minimum current level to 3 UBase set in Global base Base setting for voltage level in kV 35 00 Set LV side rat...

Page 780: ... it is necessary to do the following 1 Set correctly all CT and VT data and phase angle reference channel PhaseAngleRef see Section Setting of the phase reference channel 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 18 1MRK 506 369 ...

Page 781: ...age level in kV 15 65 Set generator rated phase to phase voltage IBase set in Global base Base setting for current level in A 3690 Set generator rated current 18 2 Gas medium supervision SSIMG GUID 358AD8F8 AE06 4AEA 9969 46E5299D5B4B v3 18 2 1 Identification GUID AD96C26E C3E5 4B21 9ED6 12E540954AC3 v4 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device n...

Page 782: ...PressureAlarm This is used to set the time delay for a pressure alarm indication given in s tPressureLO This is used to set the time delay for a pressure lockout indication given in s tTempAlarm This is used to set the time delay for a temperature alarm indication given in s tTempLockOut This is used to set the time delay for a temperature lockout indication given in s tResetPressAlm This is used ...

Page 783: ... GUID 0C8E498B 2A65 44ED 91D6 53EC72F49222 v4 The parameters for Liquid medium supervision SSIML can be set via local HMI or Protection and Control Manager PCM600 Operation This is used to disable enable the operation of liquid medium supervision i e Off On LevelAlmLimit This is used to set the limit for a level alarm condition in the oil insulated device LevelLOLimit This is used to set the limit...

Page 784: ...because there could be a number of abnormal operations or few operations with high level currents within the predetermined maintenance interval Hence condition based maintenance scheduling is an optimum solution in assessing the condition of circuit breakers Circuit breaker contact travel time Auxiliary contacts provide information about the mechanical operation opening time and closing time of a ...

Page 785: ... 50000 20000 10000 2000 5000 1000 100 200 500 10 20 50 0 1 0 2 0 5 1 2 5 10 20 50 100 IEC12000623_1_en vsd IEC12000623 V1 EN US Figure 393 An example for estimating the remaining life of a circuit breaker Calculation for estimating the remaining life The graph shows that there are 10000 possible operations at the rated operating current and 900 operations at 10 kA and 50 operations at rated fault ...

Page 786: ...the previous value The accumulated energy value can be reset to initial accumulation energy value by using the Reset accumulating energy input RSTIPOW Circuit breaker operation cycles Routine breaker maintenance like lubricating breaker mechanism is based on the number of operations A suitable threshold setting helps in preventive maintenance This can also be used to indicate the requirement for o...

Page 787: ... IPOWLOPH TRVTOPAL and TRVTCLAL signals are not used in SAM600 IO 18 4 3 1 Setting procedure on the IED GUID 4E895FEA 74BF 4B11 A239 0574F8FF5188 v5 The parameters for breaker monitoring SSCBR can be set via the local HMI or Protection and Control Manager PCM600 Common base IED values for primary current IBase primary voltage UBase and primary power SBase are set in Global base values for settings...

Page 788: ...re lockout DirCoef Directional coefficient for circuit breaker life calculation RatedOperCurr Rated operating current of the circuit breaker RatedFltCurr Rated fault current of the circuit breaker OperNoRated Number of operations possible at rated current OperNoFault Number of operations possible at rated fault current CBLifeAlmLevel Alarm level for circuit breaker remaining life AccSelCal Selecti...

Page 789: ...nputs can be set individually as NoEvents OnSet at pick up of the signal OnReset at drop out of the signal OnChange at both pick up and drop out of the signal AutoDetect the EVENT function makes the reporting decision reporting criteria for integers have no semantic prefer to be set by the user LONChannelMask or SPAChannelMask M12811 15 v2 Definition of which part of the event function block that ...

Page 790: ...ing equipment and so on This information can also be used in a longer perspective when planning for and designing new installations that is a disturbance recording could be a part of Functional Analysis FA Disturbance report DRPRDRE always included in the IED acquires sampled data of all selected analog and binary signals connected to the function blocks that is Maximum 30 external analog signals ...

Page 791: ...g 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 and Event list EL function User defined names of binary and analog input signals are set using PCM600 The analog and binary signals appear with their user defined names The ...

Page 792: ...nctions Three LED indications placed above the LCD screen makes it possible to get quick status information about the IED Green LED 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...

Page 793: ... recordings stored in the IED is 100 The oldest recording will be overwritten when a new recording arrives FIFO To be able to delete disturbance records Operation parameter has to be On The maximum number of recordings depend on each recordings total recording time Long recording time will reduce the number of recordings to less than 100 The IED flash disk should NOT be used to store any user file...

Page 794: ... line In order to capture the new disturbance it is possible to allow retriggering PostRetrig On during the post fault time In this case a new complete recording will start and during a period run in parallel with the initial recording When the retrig parameter is disabled PostRetrig Off a new recording will not start until the post fault PostFaultrecT or TimeLimit period is terminated If a new tr...

Page 795: ...will be recorded and reported in graph However Trip value pre fault and fault value will be recorded and reported The input channel can still be used to trig the disturbance recorder If OperationM On waveform samples will also be recorded and reported in graph NomValueM Nominal value for input M OverTrigOpM UnderTrigOpM Over or Under trig operation Disturbance report may trig for high low level of...

Page 796: ...ested to point out a sampled voltage input signal for example a line or busbar phase voltage channel 1 30 Event list M12179 440 v3 Event list EL SOE function has no dedicated parameters 18 6 3 5 Consideration M12179 420 v6 The density of recording equipment in power systems is increasing since the number of modern IEDs where recorders are included is increasing This leads to a vast number of recor...

Page 797: ...gnal status report BINSTATREP GUID E7A2DB38 DD96 4296 B3D5 EB7FBE77CE07 v2 18 7 1 Identification GUID E0247779 27A2 4E6C A6DD D4C31516CA5C v3 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Logical signal status report BINSTATREP 18 7 2 Application GUID F9D225B1 68F7 4D15 AA89 C9211B450D19 v3 The Logical signal status report BINSTATREP function ...

Page 798: ... distance to fault is very important for those involved in operation and maintenance Reliable information on the fault location greatly decreases the downtime of the protected lines and increases the total availability of a power system The fault locator is started with the input CALCDIST to which trip signals indicating in line faults are connected typically distance protection zone 1 and acceler...

Page 799: ...rved bay protected line and residual current from a parallel bay line which is mutual coupled to protected line The Fault locator has close connection to the Disturbance report function All external analog inputs channel 1 30 connected to the Disturbance report function are available to the Fault locator and the function uses information calculated by the Trip value recorder After allocation of an...

Page 800: ... is not constant in the network However this has a minor influence on the accuracy of the distance to fault calculation because only the phase angle of the distribution factor has an influence on the accuracy The phase angle of the distribution factor is normally very low and practically constant because the positive sequence line impedance which has an angle close to 90 dominates it Always set th...

Page 801: ...fication GUID F3FB7B33 B189 4819 A1F0 8AC7762E9B7E v3 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Limit counter L4UFCNT 18 9 2 Application GUID 41B13135 5069 4A5A 86CE B7DBE9CFEF38 v2 Limit counter L4UFCNT is intended for applications where positive and or negative flanks on a binary signal need to be counted 1MRK 506 369 UEN B Section 18 Mo...

Page 802: ...58E376270 v2 The parameters for Limit counter L4UFCNT are set via the local HMI or PCM600 18 10 Running hour meter TEILGAPC 18 10 1 Identification GUID 3F9EF4FA 74FA 4D1D 88A0 E948B722B64F v1 Function Description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Running hour meter TEILGAPC 18 10 2 Application GUID 225D8341 2D31 49F1 9B49 571346C0FE26 v1 The function i...

Page 803: ... no check if tAlarm tWarning The limit for the overflow supervision is fixed at 99999 9 hours The setting tAddToTime is a user settable time parameter in hours 1MRK 506 369 UEN B Section 18 Monitoring Line distance protection REL670 2 2 IEC 797 Application manual ...

Page 804: ...798 ...

Page 805: ...e substation automation system or read via the station monitoring system as a service value When using IEC 61850 8 1 a scaled service value is available over the station bus The normal use for this function is the counting of energy 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 ...

Page 806: ... the same board used for pulse counting 19 2 Function for energy calculation and demand handling ETPMMTR SEMOD153638 1 v2 19 2 1 Identification SEMOD175537 2 v4 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Function for energy calculation and demand handling ETPMMTR W_Varh 19 2 2 Application SEMOD175546 4 v5 Energy calculation and demand handl...

Page 807: ...d with the pulse output setting values EAFAccPlsQty EARAccPlsQty ERFAccPlsQty and ERVAccPlsQty of the energy metering function and then the pulse counter can be set up to present the correct values by scaling in this function Pulse counter values can then be presented on the local HMI in the same way and or sent to the SA Substation Automation system through communication where the total energy th...

Page 808: ...Wh value in each pulse It should be selected together with the setting of the Pulse counter PCGGIO settings to give the correct total pulse value ERFAccPlsQty and ERVAccPlsQty gives the MVArh value in each pulse It should be selected together with the setting of the Pulse counter PCGGIO settings to give the correct total pulse value For the advanced user there are a number of settings for directio...

Page 809: ...iguration tool ECT in PCM600 The access point is activated if the Operation checkbox is checked for the respective access point and a partial or common write to IED is performed To increase security it is recommended to deactivate the access point 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 r...

Page 810: ...he other subnetwork By default this is set to 0 0 0 0 which means that no default gateway is selected ECT validates the entered value but the default gateway has to be in the same subnetwork as the access point The default gateway is the router that is being used as default that is when no route has been set up for the destination If communication with a device in another subnetwork is needed a ro...

Page 811: ...h availability Seamless Redundancy HSR provides redundant communication over station bus running the available communication protocols The redundant communication uses two Ethernet ports IEC09000758 4 en vsd Switch A AP1 PhyPortB PhyPortA AP1 PhyPortA PhyPortB AP1 PhyPortB PhyPortA AP1 PhyPortA PhyPortB Switch B Device 1 Device 2 Device 3 Device 4 IEC09000758 V4 EN US Figure 399 Parallel Redundanc...

Page 812: ...ed when the parameter is set to PRP 0 PRP 1 or HSR The settings for the next access point will be hidden and PhyPortB will show the second port information Redundant communication is activated after a common write to IED is done PRP 1 should be used primarily PRP 0 is intended only for use in existing PRP networks PRP 1 and HSR can be combined in a mixed network If the access point is not taken in...

Page 813: ...s Merging Units MU The rear access points are used for the communication 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 ...

Page 814: ...te 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 20 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 and unche...

Page 815: ...tal communication 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 subscrib...

Page 816: ...with IEC 61850 8 1 M16925 3 v4 Figure404 shows the GOOSE peer to peer communication 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 404 Example of a broadcasted GOOSE message Section 21 1MRK 506 369 UEN B Station communication 810 Line distance protection REL670 2 2 IEC Applic...

Page 817: ...ion for Single Point Value SPGAPC function is used to send one single logical output to other systems or equipment in the substation SP16GAPC can be used to send up to 16 single point values from the application functions running in the same cycle time SPGAPC has one visible input and SPGAPC16 has 16 visible inputs that should be connected in the ACT tool Setting guidelines SEMOD55376 5 v5 There a...

Page 818: ...pplication GUID 808177B7 02CA 40DF B41B 8B580E38478B v1 The GOOSE receive function blocks are used to receive subscribed data from the GOOSE protocol The validity of the data value is exposed as outputs of the function block as well as the validity of the communication It is recommended to use these outputs to ensure that only valid data is handled on the subscriber IED An example could be to cont...

Page 819: ...nd the inaccuracy added by the merging unit must be coordinated with the requirement for the actual type of protection function Factors influencing the accuracy of the sampled values from the merging unit are for example anti aliasing filters frequency range step response truncating A D conversion inaccuracy time tagging accuracy etc In principle the accuracy of the current and voltage transformer...

Page 820: ...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 electronic pa...

Page 821: ... 8 1 Station Wide SCADA System Station Wide GPS Clock Other Relays IEC61850 8 1 en08000069 3 vsd IEC08000069 V2 EN US Figure 407 Example of a station configuration with the IED receiving analog values from both classical measuring transformers and merging units 1MRK 506 369 UEN B Section 21 Station communication Line distance protection REL670 2 2 IEC 815 Application manual ...

Page 822: ...ays IEC61850 8 1 en08000070 3 vsd IEC08000070 V2 EN US Figure 408 Example of a station configuration with the IED receiving analogue values from merging units 21 3 2 Setting guidelines GUID 29B296B3 6185 459F B06F 8E7F0C6C9460 v4 Merging Units MUs have several settings on local HMI under Section 21 1MRK 506 369 UEN B Station communication 816 Line distance protection REL670 2 2 IEC Application man...

Page 823: ...r is set to Block and the IED hardware time synchronization is lost or the synchronization to the MU time is lost the protection functions in the list 59 will be blocked due to conditional blocking If this parameter is set to BlockOnLostUTC the protection functions in list 59 are blocked if the IED hardware time synchronization is lost or the synchronization of the MU time is lost or the IED has l...

Page 824: ...d and processd normally DTT from the remote end is still processed IEC13000299 2 en vsd Direct transfer trip DTT local remote IED IED MU Not OK OK IEC13000299 V2 EN US Figure 410 MU failed mixed system Case 3 Failure of one MU sample lost blocks the sending and receiving of binary signals through LDCM DTT from the remote end is not working Section 21 1MRK 506 369 UEN B Station communication 818 Li...

Page 825: ...ailure protection CCRBRF PoleSlip Out of step protection PSPPPAM Breaker failure protection single phase version CCSRBRF Restricted earth fault protection low impedance REFPDIF Current circuit supervison CCSSPVC Two step residual overvoltage protection ROV2PTOV Compensated over and undervoltage protection COUVGAPC Rate of change frequency protection SAPFRC General currrent and voltage protection C...

Page 826: ...TR1ATCC Generator stator overload protection GSPTTR Automatic voltage control for tapchanger parallel control TR8ATCC Directional Underpower protection GUPPDUP Thermal overload protection two time constants TRPTTR 1Ph High impedance differential protection HZPDIF Two step undervoltage protection UV2PTUV Line differential protection 3 CT sets 2 3 line ends L3CPDIF Voltage differential protection VD...

Page 827: ...uadrilateral 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 characteristic ZMQAPDIS Line differential protection 6 CT sets with inzone transformers 3 5 line ends LT6CPDIF Distance protection zone...

Page 828: ... 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 However the global complete time might not be correct Disturbance recordings then ...

Page 829: ...o PTP SyncLostMode set to Block to block protection functions if time synchronization is lost or set to BlockOnLostUTC if the protection functions are to 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 con...

Page 830: ...061 V2 EN US Figure 413 Setting example when MU is the synchronizing source Settings on the local HMI under Main menu Configuration Time Synchronization TIMESYNCHGEN 1 IEC61850 9 2 HwSyncSrc set to PPS as generated by the MU ABB MU SyncLostMode set to Block to block protection functions if time synchronization is lost SyncAccLevel can be set to 4μs since this corresponds to a maximum phase angle e...

Page 831: ...PS IRIG B STATION CLOCK IEC10000074 2 en Original vsd IEC10000074 V2 EN US Figure 414 Setting example with external synchronization Settings on the local HMI under Main menu Configuration Time Synchronization TIMESYNCHGEN 1 IEC61850 9 2 HwSyncSrc set to PPS IRIG B depending on available outputs on the clock SyncLostMode set to Block to block protection functions if time synchronization is lost Syn...

Page 832: ... report is used IEC UCA 61850 9 2LE Data MU IED IEC10000075 2 en Original vsd IEC10000075 V2 EN US Figure 415 Setting example without time synchronization It is also possible to use IEC UCA 61850 9 2LE communication without time synchronization Settings on the local HMI under Main menu Configuration Time Synchronization TIMESYNCHGEN 1 IEC61850 9 2 HwSyncSrc set to Off SyncLostMode set to No block ...

Page 833: ...used to display the detailed quality of an IEC UCA 61850 9 2LE analog channel The component expands the channel quality output of a Merging Unit analog channel received in the IED as per the IEC 61850 7 3 standard This component can be used during the ACT monitoring to get the particular channel quality of the Merging Unit Figure 416 depicts the usage of the quality expander block in ACT IEC160000...

Page 834: ...l center and also from other IEDs via bay to bay horizontal communication For LON communication an SLM card should be ordered for the IEDs The fiber optic LON bus is implemented using either glass core or plastic core fiber optic cables Table 60 Specification of the fiber optic connectors Glass fiber Plastic fiber Cable connector ST connector snap in connector Cable diameter 62 5 125 m 1 mm Max ca...

Page 835: ... 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 application in MicroSCADA When using MicroSCADA Monitor Pro instead of the Classic Monitor SA LIB is used together with 670 series Object Type files The HV Control 670 software module and 670 series Object Type files are used with both 650 and ...

Page 836: ...915 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 21 5 SPA communication protocol IP14614 1 v1 21 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 port When communicating with a PC c...

Page 837: ...iple where the IED is a slave and the PC is the master Only one master can be applied on each fiber optic loop A program is required in the master computer for interpretation of the SPA bus codes and for translation of the data that should be sent to the IED For the specification of the SPA protocol V2 5 refer to SPA bus Communication Protocol V2 5 21 5 2 Setting guidelines M11876 3 v7 SPA IEC 608...

Page 838: ...ifferent communication speeds are used in the same fiber optical loop or RS485 network take this into account when making the communication setup in the communication master the PC With local fiber optic communication communication speed is usually set to 19200 or 38400 baud With telephone communication the speed setting depends on the quality of the connection and the type of modem used Refer to ...

Page 839: ... RTU connected to the Communication and processing module the only hardware needed is optical fibers and an opto electrical converter for the PC RTU or a RS 485 connection depending on the used IED communication interface 21 6 1 1 Functionality M17109 38 v3 IEC 60870 5 103 is an unbalanced master slave protocol for coded bit serial communication exchanging information with a control system In IEC ...

Page 840: ...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 Communication protocol manual IEC 60870 5 103 IED commands in control direction Function block with defined IED functions in control direction...

Page 841: ...FORMATION NUMBER parameter for each input signal Supervision indications in monitor direction Function block with defined functions for supervision indications in monitor direction I103Superv This block includes the FUNCTION TYPE parameter and the INFORMATION NUMBER parameter is defined for each output signal Earth fault indications in monitor direction Function block with defined functions for ea...

Page 842: ...ted when the fault locator function is included in the IED Disturbance recordings M17109 111 v9 The transfer functionality is based on the Disturbance recorder function The analog and binary signals recorded will be reported to the master by polling The eight last disturbances that are recorded are available for transfer to the master A file that has been transferred and acknowledged by the master...

Page 843: ...Configuration Communication Station Communication IEC60870 5 103 config selector SlaveAddress BaudRate RevPolarity optical channel only CycMeasRepTime MasterTimeDomain TimeSyncMode EvalTimeAccuracy EventRepMode CmdMode RepIntermediatePos config selector is OPTICAL103 1 for the optical serial channel on the SLM RS485103 1 for the RS485 port 2 The protocol to activate on a physical port is selected ...

Page 844: ...e delivered All GI data from a single block will come from the same cycle If EventRepMode HiPriSpont spontaneous events will be delivered prior to GI event To prevent old GI data from 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 21 6 2 2 Settings from PCM600 M17109...

Page 845: ... on the disturbance recorder for each input The user must set these parameters to whatever he connects to the corresponding input Refer to description of Main Function type set on the local HMI Recorded analog channels are sent with ASDU26 and ASDU31 One information element in these ASDUs is called ACC and it indicates the actual channel to be processed The channels on disturbance recorder are sen...

Page 846: ...ange 36 91 Private range 37 92 Private range 38 93 Private range 39 94 Private range 40 95 Private range 21 6 3 Function and information types M17109 145 v7 Product type IEC103mainFunType value Comment REL 128 Compatible range REC 242 Private range use default RED 192 Compatible range RET 176 Compatible range REB 207 Private range REG 150 Private range REQ 245 Private range RER 152 Private range R...

Page 847: ...lastic 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 with the optical power as specified in standard For more information refer to IEC standard IEC 60870 5 103 21 7 DNP3 Communication protocol 21 7 1 Application GUID EF1F0C38 9FF6 4683 8B10 AAA372D42185 v1 For more information on the application and setting guidelines...

Page 848: ...842 ...

Page 849: ...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 equipped wi...

Page 850: ...th the local three currents In order to forward the logic signals for example inter trip or inter block between IED A and IED C the setting LinkForwarded should be defined In IED B it is set to LDCM313 for Ldcm312 and to LDCM312 for ldcm313 This setup results in a master master master configuration but without the benefit of reverting to a slave master slave configuration in case of a communicatio...

Page 851: ...nic G 703 IEC05000527 V2 EN US Figure 423 LDCM with an external optical to galvanic converter and a multiplexer When an external modem G 703 is used the connection between LDCM and the modem is made with a multimode fiber of max 3 km length The IEEE ANSI C37 94 protocol is always used between LDCM and the modem 22 1 3 Setting guidelines M12454 3 v7 64 kbit and 2 Mbit mode common settings ChannelMo...

Page 852: ...ique address is necessary to give high security against incorrect addressing in the communication system If the same number is used for TerminalNo in some of the LDCMs a loop back test in the communication system can give an incorrect trip RemoteTermNo is used to assign a number to each related LDCM in the remote IED For each LDCM RemoteTermNo is set to a different value than TerminalNo but equal ...

Page 853: ...ort range LDCM Use LowPower for fibres 0 1 km and HighPower for fibers greater than 1 km Medium range LDCM Typical distance 80 km for both LowPower and HighPower Long range LDCM Typical distance 120 km for both LowPower and HighPower An optical budget calculation should be made for the actual case For medium range LDCM and long range LDCM the recommendation is to use the LowPower setting to minimi...

Page 854: ...m 0 32 dB km 0 21 dB km Attenuation Contact 1 5 dB ST 1 5 dB ST 0 3 dB FC PC 0 3 dB FC PC Factory splice attenuation 0 5 dB splice 0 3 splices km 0 5 dB splice 0 1 splices km 0 08 dB splice 0 1 splices km 0 08 dB splice 0 1 splices km Repair splices 0 25 dB splice 0 1 splices km 0 25 dB splice 0 1 splices km 0 1 dB splice 0 05 splices km 0 1 dB splice 0 05 splices km Fiber margin for aging 0 1 dB ...

Page 855: ...es asymmetry which is defined as transmission delay minus receive delay If fixed asymmetry is known Echo synchronization method can be used provided that AsymDelay is properly set From the definition follows that asymmetry is always positive at one end and negative at the other end MaxTransmDelay indicates maximum transmission delay Data for maximum 40 ms transmission delay can be buffered up Dela...

Page 856: ...es 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 2 Mbit mode specific settings RedundantCh is used to set the channel as a redundant ...

Page 857: ...included self supervision with internal event list function block provides good supervision of the IED The fault signals make it easier to analyze and locate a fault Both hardware and software supervision is included and it is also possible to indicate possible faults through a hardware contact on the power supply module and or through the communication Internal events are generated by the built i...

Page 858: ...48775D0 ACF0 49C6 A7F6 69AF37F1C68F v1 23 3 1 Application GUID 51EEC9C7 8ECF 4546 BC26 326861654340 v4 Change lock function CHNGLCK is used to block further changes to the IED configuration once the commissioning is complete The purpose is to make it impossible to perform inadvertent IED configuration and setting changes However when activated CHNGLCK will still allow the following actions that do...

Page 859: ...ad that can be produced by Ethernet network traffic on the IED The communication facilities must not be allowed to compromise the primary functionality of the device All inbound network traffic will be quota controlled so that too heavy network loads can be controlled Heavy network load might for instance be the result of malfunctioning equipment connected to the network The functions Access point...

Page 860: ...854 ...

Page 861: ...ngeable data that uniquely identifies the IED Product information data is visible on the local HMI under Main menu Diagnostics IED status Product identifiers and under Main menu Diagnostics IED Status Identifiers Product information data is visible on the local HMI under Main menu Diagnostics IED status Product identifiers and under Main menu Diagnostics IED Status Identifiers ProductVer ProductDe...

Page 862: ...us Product identifiers Firmware version numbers run independently from the release production numbers For every release number there can be one or more firmware versions depending on the small issues corrected in between releases ProductVer Describes the product version Example 2 1 0 1 is the Major version of the manufactured product this means new platform of the product 2 is the Minor version of...

Page 863: ...ing groups IP1745 1 v1 24 4 1 Application M12007 6 v10 Six sets of settings are available to optimize IED operation for different power system conditions By creating and switching between fine tuned setting sets either from the local HMI or configurable binary inputs results in a highly adaptable IED that can cope with a variety of power system scenarios Different conditions in networks with diffe...

Page 864: ...ly the selected number of setting groups will be available in the Parameter Setting tool PST for activation with the ActiveGroup function block 24 5 Rated system frequency PRIMVAL IP15064 1 v2 24 5 1 Identification GUID B8B3535D 227B 4151 9E98 BEB85F4D54DE v1 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Primary system values PRIMVAL 24 5 2 Ap...

Page 865: ...ominal system frequency ExternalDFTRef This setting means that the DFT samples per cycle adaptive DFT will be controlled by SMAI1 SPFCOUT FreqMeasMinVal The minimum value of the voltage for which the frequency is calculated expressed as percent of UBasebase voltage setting for each instance x GlobalBaseSel Selects the global base value group used by the function to define IBase UBase and SBase 24 ...

Page 866: ...unctions throughout the IED typically SBase 3 UBase IBase 24 8 Signal matrix for binary inputs SMBI SEMOD55793 1 v2 24 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 24 8 2 Setting guidelines M...

Page 867: ...tool SMMI represents the way milliamp mA inputs are brought in for one IED configuration 24 10 2 Setting guidelines SEMOD55247 5 v2 There are no setting parameters for the Signal matrix for mA inputs SMMI available to the user in the Parameter Setting tool However the user must give a name to SMMI instance and SMMI inputs directly in the Application Configuration tool 24 11 Signal matrix for analo...

Page 868: ...ing ConnectionType is Ph Ph the user is advised to connect two not three of the inputs GRPxL1 GRPxL2 and GRPxL3 to the same voltage input as shown in figure 425 to make SMAI calculate a positive sequence voltage SMAI1 BLOCK DFTSPFC REVROT GRP1L1 GRP1L2 GRP1L3 GRP1N SPFCOUT G1AI3P G1AI1 G1AI2 G1AI4 G1N NEUTRAL PHASEL3 PHASEL2 PHASEL1 UL1L2 SAPTOF U3P BLOCK BLKTRIP TRIP START BLKDMAGN FREQ TRM_40 CH...

Page 869: ...FTRef will use fixed DFT reference based on set system frequency DFTRefGrp n will use DFT reference from the selected group block when own group is selected an adaptive DFT reference will be used based on calculated signal frequency from own group The setting ExternalDFTRef will use reference based on what is connected to input DFTSPFC The setting ConnectionType Connection type for that specific i...

Page 870: ...ncy tracking Preprocessing block shall only be used to feed functions within the same execution cycles e g use preprocessing block with cycle 1 to feed transformer differential protection The only exceptions are measurement functions CVMMXN CMMXU VMMXU etc which shall be fed by preprocessing blocks with cycle 8 When two or more preprocessing blocks are used to feed one protection function e g over...

Page 871: ...7000197 V2 EN US Figure 426 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 application The...

Page 872: ...uence voltage is used for the frequency tracking feature For task time group 1 this gives the following settings see Figure 426 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 427 SMAI2 2 SMAI12 12 DFTReference DFTRefGrp7 for SMAI2 2 SMAI12 12 to use SMAI7 7 as reference For ta...

Page 873: ...pe Observe that positive sequence voltage is used for the frequency tracking feature For task time group 1 this gives the following settings see Figure 426 for numbering SMAI1 1 SMAI12 12 DFTReference ExternalDFTRef to use DFTSPFC input as reference SMAI4 16 For task time group 2 this gives the following settings SMAI1 13 DFTRefExtOut DFTRefGrp4 to route SMAI4 16 reference to the SPFCOUT output DF...

Page 874: ...protocol manual IEC 61850 Edition 1 and Edition 2 There is no setting in PCM600 via PST for the TESTMODE function block To be able to set the function block TESTMODE remotely the setting via path on LHMI and in PST Main menu Configuration Communication Station Communication IEC61850 8 1 IEC61850 8 1 1RemoteModControl may not be set to Off The possible values of the parameter RemoteModControl are O...

Page 875: ...ate the abnormal operation of the IED The IEC 61850 7 4 gives a detailed overview over all aspects of the test mode and other states of mode and behavior The status of a function block behavior Beh is shown on the LHMI under the Main menu Test Function status Function group Function block descriptive name LN name Outputs When the Beh of a function block is set to Test the function block is not blo...

Page 876: ...cations can be easily performed and a more accurate view of the actual sequence of events can be obtained Time tagging of internal events and disturbances are an excellent help when evaluating faults Without time synchronization only the events within one IED can be compared with each other With time synchronization events and disturbances within the whole network can be compared and evaluated In ...

Page 877: ...oose SNTP as the time source If PTP is activated the device with the best accuracy within the synchronizing group will be selected as the source For more information about 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 withi...

Page 878: ...alternatives are FineSyncSource can have the following values Off SPA LON BIN Binary Minute Pulse GPS GPS SPA GPS LON GPS BIN SNTP GPS SNTP IRIG B GPS IRIG B PPS CoarseSyncSrc which can have the following values Off SPA LON DNP IEC 60870 5 103 The function input to be used for minute pulse synchronization is called BININPUT For a description of the BININPUT settings see the Technical Manual The sy...

Page 879: ... be set to On Off or Slave only When set to Slave only the IED is connected to the PTP group and will synchronize to the grandmaster but cannot function as the grandmaster A PTP group is set up by connecting the IEDs to a network and enabling PTP To set one IED as the grandmaster change Priority2 to 127 instead of the default 128 IEC16000089 1 en vsdx IEC16000089 V1 EN US Figure 429 Enabling PTP i...

Page 880: ...e parameter FineSyncSource under Configuration Time Synchronization TIMESYNCHGEN 1 General is set to GPS if there is a GPS antenna attached If the GTM is used as a PPS output only the FineSynchSource is not set 24 13 2 3 Process bus IEC UCA 61850 9 2LE synchronization GUID 6E384BDB 5598 4108 99B4 0B4A4E1828B2 v4 When process bus communication IEC UCA 61850 9 2LE protocol is used it is essential th...

Page 881: ...t 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 the IED is required Either FineSyncSource is set to the same source that the merging unit uses or the PPS output from the GTM module is used to synchronize the m...

Page 882: ...876 ...

Page 883: ...ese types are related to the design of the iron core and the presence of airgaps Airgaps affects the properties of the remanent flux The following three different types of protection CTs have been specified The High Remanence type with closed iron core and no specified limit of the remanent flux The Low Remanence type with small airgaps in the iron core and the remanent flux limit is specified to ...

Page 884: ...ves a remanent flux higher than 80 of the saturation flux The High Remanence HR type is a CT with closed iron core for example protection classes TPX P PX according to IEC class C K according to ANSI IEEE but with an iron core material traditional material that gives a remanent flux that is limited to maximum 80 of the saturation flux The Low Remanence LR type is a CT with small airgaps in the iro...

Page 885: ...ormed in our network simulator The current transformer models are representative for current transformers of high remanence and low remanence type The results may not always be valid for non remanence type CTs TPZ The performances of the protection functions have been checked in the range from symmetrical to fully asymmetrical fault currents Primary time constants of at least 120 ms have been cons...

Page 886: ...mum fault current for the relevant fault position should be used and therefore both fault types have to be considered 25 1 4 Secondary wire resistance and additional load M11614 3 v1 M11614 4 v4 The voltage at the current transformer secondary terminals directly affects the current transformer saturation This voltage is developed in a loop containing the secondary wires and the burden of all relay...

Page 887: ...d equivalent secondary e m f requirements SEMOD53723 1 v1 M11616 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 con...

Page 888: ...r 1 A and SR 0 150 VA channel for Ir 5 A The non remanence type CT CTs of non remanence type for example TPZ can be used but in this case the CTs within the differential zone must be of non remanence type They must fulfill the same requirements as for the low remanence type CTs and have a rated equivalent secondary e m f Eal that is larger than or equal to required secondary e m f Ealreq below sr ...

Page 889: ...nction of the primary DC time constant of the close in fault current k This factor depends on the design of the protection function and can be a function of the primary DC time constant of the fault current for a fault at the set reach of zone 1 The a and k factors have the following values for the different types of distance function High speed distance ZMFPDIS and ZMFCPDIS Quadrilateral characte...

Page 890: ...r CTs according to other standards SEMOD53771 1 v1 M11623 4 v3 All kinds of conventional magnetic core CTs are possible to use with the IEDs if they fulfill the requirements corresponding to the above specified expressed as the rated equivalent limiting secondary e m f Eal according to the IEC 61869 2 standard From different standards and available data for relaying applications it is possible to ...

Page 891: ...1623 22 v6 Current transformers according to ANSI IEEE are partly specified in different ways A rated secondary terminal voltage UANSI is specified for a CT of class C UANSI is the secondary terminal voltage the CT will deliver to a standard burden at 20 times rated secondary current without exceeding 10 ratio correction There are a number of standardized UANSI values for example UANSI is 400 V fo...

Page 892: ...rd regarding ferro resonance and transients The ferro resonance requirements of the CVTs are specified in chapter 6 502 of the standard The transient responses for three different standard transient response classes T1 T2 and T3 are specified in chapter 6 503 of the standard CVTs according to all classes can be used The protection IED has effective filters for these transients which gives secure a...

Page 893: ...10 6 during disturbed operation During disturbed conditions the trip security function can cope with high bit error rates up to 10 5 or even up to 10 4 The trip security can be configured to be independent of COMFAIL from the differential protection communication supervision or blocked when COMFAIL is issued after receive error 100ms Default Synchronization in SDH systems with G 703 E1 or IEEE C37...

Page 894: ...ver 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 and feeder equipment Abstract communication service interface ACSI The set of functionality implemented in the IED IEC UCA 61850 9 2LE is a subset of the IEC 61850 9 2 For example the IED covers the client part of the standard...

Page 895: ...ponse 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 506 369 UEN B Section 25 Requirements Line distance protection REL670 2 2 IEC 889 Application manual ...

Page 896: ...890 ...

Page 897: ...rican Wire Gauge standard BBP Busbar protection BFOC 2 5 Bayonet fiber optic connector BFP Breaker failure protection BI Binary input BIM Binary input module BOM Binary output module 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 sen...

Page 898: ...urbance recorder according to IEEE ANSI C37 111 1999 IEC 60255 24 Contra directional Way of transmitting G 703 over a balanced line Involves four twisted pairs two of which are used for transmitting data in both directions and two for transmitting clock signals COT Cause of transmission CPU Central processing unit CR Carrier receive CRC Cyclic redundancy check CROB Control relay output block CS Ca...

Page 899: ...erformance architecture ESD Electrostatic discharge F SMA Type of optical fiber connector FAN Fault number FCB Flow control bit Frame count bit FOX 20 Modular 20 channel telecommunication system for speech data and protection signals FOX 512 515 Access multiplexer FOX 6Plus Compact time division multiplexer for the transmission of up to seven duplex channels of digital data over optical fibers FPN...

Page 900: ...urrent transformers for transient performance IEC 60870 5 103 Communication standard for protection equipment A serial master slave protocol for point to point communication IEC 61850 Substation automation communication standard IEC 61850 8 1 Communication protocol standard IEEE Institute of Electrical and Electronics Engineers IEEE 802 12 A network technology standard that provides 100 Mbits s on...

Page 901: ...l It provides packet routing fragmentation and reassembly through the data link layer 2 Ingression protection according to IEC 60529 IP 20 Ingression protection according to IEC 60529 level 20 IP 40 Ingression protection according to IEC 60529 level 40 IP 54 Ingression protection according to IEC 60529 level 54 IRF Internal failure signal IRIG B InterRange Instrumentation Group Time code format B ...

Page 902: ...rhaps it should not have seen it PCI Peripheral component interconnect a local data bus PCM Pulse code modulation PCM600 Protection and control IED manager PC MIP Mezzanine card standard PELV circuit Protected Extra 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 lev...

Page 903: ...Optical Ethernet port explanation SLM Serial communication module SMA connector Subminiature version A A threaded connector with constant impedance SMT Signal matrix tool within PCM600 SMS Station monitoring system SNTP Simple network time protocol is used to synchronize computer clocks on local area networks This reduces the requirement to have accurate hardware clocks in every embedded system in...

Page 904: ... Transformer Module This module transforms currents and voltages taken from the process into levels suitable for further signal processing TYP Type identification UMT User management tool Underreach A term used to describe how the relay behaves during a fault condition For example a distance relay is underreaching when the impedance presented to it is greater than the apparent impedance to the fau...

Page 905: ...ds for Z which stands for longitude zero UV Undervoltage WEI Weak end infeed logic VT Voltage transformer X 21 A digital signalling interface primarily used for telecom equipment 3IO Three times zero sequence current Often referred to as the residual or the earth fault current 3UO Three times the zero sequence voltage Often referred to as the residual voltage or the neutral point voltage 1MRK 506 ...

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Page 908: ... AB Grid Automation Products 721 59 Västerås Sweden Phone 46 0 21 32 50 00 abb com protection control Copyright 2017 ABB All rights reserved Specifications subject to change without notice 1MRK 506 369 UEN ...

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