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ABB RELION 670 SERIES REG670, Applications Manual

The ABB RELION 670 Series REG670 is a cutting-edge protection relay suitable for various applications. Ensure optimal performance with the Applications Manual, available for free download from 88.208.23.73:8080. This comprehensive manual provides detailed instructions and insights, empowering users to utilize the product efficiently.

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The second part in the parentheses is the error introduced to the measurement of the
line impedance.

If the current on the parallel line has negative sign compared to the current on the
protected line, that is, the current on the parallel line has an opposite direction
compared to the current on the protected line, the distance function will overreach. If
the 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-ground 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 V

A

 in the faulty phase at A side as in equation 

41

.

(

)

0

0

p

3

3

=

1

+

A

L

ph

N

Nm

p

V

Z

I

K

I

K

I

×

×

+

×

EQUATION1278 V4 EN-US

(Equation 41)

One can also notice that 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 42)

Simplification of equation 

42

, solving it for 3I0

p

 and substitution of the result into

equation 

41

 gives that the voltage can be drawn as:

0

0

3

p

p

3

2

p

1

A

L

ph

N

Nm

I

V

Z

I

K

I

K

×

= ×

+

×

+

×

-

æ

ö

ç

÷

è

ø

EQUATION1280 V2 EN-US

(Equation 43)

If we finally divide equation 

43

 with equation 

38

 we can draw the impedance present

to the IED as

Z

p ZI

I

KN

I

KN

I

p

p

I

I

KN

L

ph

m

ph

=

⋅

+

⋅

+

⋅

⋅

−

+

⋅







3

3

2

3

0

0

0

EQUATION1379 V3 EN-US

(Equation 44)

Calculation for a 400 kV line, where we for simplicity have excluded the resistance,
gives with X1L=0.48 Ohm/Mile, X0L=1.4Ohms/Mile, zone 1 reach is set to 90% of
the line reactance p=71% that is, the protection is underreaching with approximately
20%.

Section 8

1MRK 502 071-UUS A

Impedance protection

210

Generator protection REG670 2.2 ANSI and Injection equipment REX060, REX061, REX062

Application manual

Summary of Contents for RELION 670 SERIES REG670

Page 1: ...RELION 670 SERIES Generator protection REG670 Version 2 2 ANSI Application manual ...

Page 2: ......

Page 3: ...Document ID 1MRK 502 071 UUS Issued October 2017 Revision A Product version 2 2 1 Copyright 2017 ABB All rights reserved ...

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: ...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 the IEC 60255 series and ANSI C37 90 The DNP protocol implementation in the IED conform...

Page 7: ... protection functions 49 Control and monitoring functions 50 Communication 55 Basic IED functions 58 Section 3 Configuration 61 Description of REG670 61 Introduction 61 Description of configuration A20 61 Description of configuration B30 62 Description of configuration C30 65 Section 4 Analog inputs 67 Introduction 67 Setting guidelines 67 Setting of the phase reference channel 67 Example 68 Setti...

Page 8: ...nected VT to the IED 88 Example on how to connect an open delta VT to the IED for high impedance grounded or ungrounded networks 90 Example how to connect the open delta VT to the IED for low impedance grounded or solidly grounded power systems 93 Section 5 Local HMI 97 Display 98 LEDs 101 Keypad 102 Local HMI functionality 104 Protection and alarm indication 104 Parameter management 105 Front com...

Page 9: ...nsation for on load tap changer position 141 Differential current alarm 142 Open CT detection 142 Switch onto fault feature 143 Setting example 143 Introduction 143 Typical main CT connections for transformer differential protection 144 Application Examples 145 Summary and conclusions 153 High impedance differential protection single phase HZPDIF 87 155 Identification 155 Application 156 The basic...

Page 10: ...former winding grounded through Zig Zag grounding transformer 187 Autotransformer winding solidly grounded 189 Reactor winding solidly grounded 189 Multi breaker applications 190 CT grounding direction 191 Setting guidelines 191 Setting and configuration 191 Settings 192 Section 8 Impedance protection 195 Full scheme distance measuring Mho characteristic ZMHPDIS 21 195 Identification 195 Applicati...

Page 11: ...CPDIS 21 228 Identification 228 Application 228 System grounding 229 Fault infeed from remote end 231 Load encroachment 232 Short line application 233 Long transmission line application 234 Parallel line application with mutual coupling 235 Tapped line application 242 Series compensation in power systems 245 Steady state voltage regulation and increase of voltage collapse limit 245 Increase in pow...

Page 12: ...tting guidelines 298 Loss of excitation LEXPDIS 40 302 Identification 302 Application 302 Setting guidelines 308 Sensitive rotor earth fault protection injection based ROTIPHIZ 6 4R 312 Identification 312 Application 312 Rotor earth fault protection function 312 Setting guidelines 316 Setting injection unit REX060 316 Connecting and setting voltage inputs 317 Settings for sensitive rotor earth fau...

Page 13: ...41 Instantaneous phase overcurrent protection PHPIOC 50 341 Identification 341 Application 341 Setting guidelines 342 Meshed network without parallel line 343 Meshed network with parallel line 345 Directional phase overcurrent protection four steps OC4PTOC 51_67 347 Identification 347 Application 347 Setting guidelines 348 Settings for each step 350 Setting example 354 Instantaneous residual overc...

Page 14: ...383 Identification 384 Application 384 Setting guidelines 386 Thermal overload protection two time constants TRPTTR 49 395 Identification 395 Application 395 Setting guideline 396 Breaker failure protection CCRBRF 50BF 399 Identification 399 Application 399 Setting guidelines 399 Pole discrepancy protection CCPDSC 52PD 403 Identification 403 Application 403 Setting guidelines 404 Directional under...

Page 15: ...ervoltage seal in 427 Setting guidelines 428 Explanation of the setting parameters 428 Voltage restrained overcurrent protection for generator and step up transformer 429 General settings 430 Overcurrent protection with undervoltage seal in 431 Generator stator overload protection GSPTTR 49S 432 Identification 432 Application 432 Generator rotor overload protection GRPTTR 49R 432 Identification 43...

Page 16: ...n 445 Application 445 Setting guidelines 446 Equipment protection such as for motors generators reactors and transformersEquipment protection for transformers 446 Equipment protection capacitors 446 Stator ground fault protection based on residual voltage measurement 446 Power supply quality 450 High impedance grounded systems 450 Direct grounded system 451 Settings for two step residual overvolta...

Page 17: ...6 Application 476 Setting guidelines 478 Section 12 Multipurpose protection 481 General current and voltage protection CVGAPC 481 Identification 481 Application 481 Current and voltage selection for CVGAPC function 482 Base quantities for CVGAPC function 485 Application possibilities 485 Inadvertent generator energization 486 Setting guidelines 487 Directional negative sequence overcurrent protect...

Page 18: ...tion 503 Application 503 Setting guidelines 505 Setting example 505 Section 14 Secondary system supervision 509 Current circuit supervision 87 509 Identification 509 Application 509 Setting guidelines 510 Fuse failure supervision FUFSPVC 510 Identification 510 Application 510 Setting guidelines 511 General 511 Setting of common parameters 512 Negative sequence based 512 Zero sequence based 513 Del...

Page 19: ...ing guidelines 534 Apparatus control APC 539 Application 539 Bay control QCBAY 545 Switch controller SCSWI 546 Switches SXCBR SXSWI 546 Proxy for signals from switching device via GOOSE XLNPROXY 547 Reservation function QCRSV and RESIN 550 Interaction between modules 552 Setting guidelines 556 Bay control QCBAY 556 Switch controller SCSWI 556 Switch SXCBR SXSWI 557 Proxy for signals from switching...

Page 20: ... arrangement 579 Signals in double breaker arrangement 582 Signals in breaker and a half arrangement 585 Interlocking for busbar grounding switch BB_ES 3 586 Application 586 Signals in single breaker arrangement 587 Signals in double breaker arrangement 591 Signals in breaker and a half arrangement 592 Interlocking for double CB bay DB 3 593 Application 593 Configuration setting 593 Interlocking f...

Page 21: ...omationBits command function for DNP3 0 AUTOBITS 647 Identification 648 Application 648 Setting guidelines 648 Single command 16 signals SINGLECMD 648 Identification 648 Application 649 Setting guidelines 650 Section 16 Logic 653 Tripping logic SMPPTRC 94 653 Identification 653 Application 653 Three pole tripping 654 Single and or three pole tripping 655 Single two or three pole tripping 656 Lock ...

Page 22: ...FXDSIGN 664 Identification 664 Application 664 Boolean 16 to Integer conversion B16I 665 Identification 665 Application 666 Boolean to integer conversion with logical node representation 16 bit BTIGAPC 667 Identification 667 Application 667 Integer to Boolean 16 conversion IB16 668 Identification 668 Application 668 Integer to Boolean 16 conversion with logic node representation ITBGAPC 669 Identi...

Page 23: ...nt 677 Identification 677 Application 678 Zero clamping 679 Setting guidelines 680 Setting examples 683 Gas medium supervision SSIMG 63 690 Identification 690 Application 690 Setting guidelines 691 Liquid medium supervision SSIML 71 692 Identification 692 Application 692 Setting guidelines 692 Breaker monitoring SSCBR 693 Identification 693 Application 693 Setting guidelines 697 Setting procedure ...

Page 24: ...ting guidelines 710 Estimation of transformer insulation life LOLSPTR 26 49HS 710 Application 710 Setting guidelines 715 Setting example 724 Transformer Rated Data 724 Setting parameters for insulation loss of life calculation function LOL1 725 Section 18 Metering 731 Pulse counter logic PCFCNT 731 Identification 731 Application 731 Setting guidelines 731 Function for energy calculation and demand...

Page 25: ... Sending data 745 Receiving data 746 LON communication protocol 748 Application 748 MULTICMDRCV and MULTICMDSND 750 Identification 750 Application 750 Setting guidelines 750 SPA communication protocol 750 Application 750 Setting guidelines 752 IEC 60870 5 103 communication protocol 753 Application 753 Functionality 753 Design 754 Settings 756 Settings for RS485 and optical serial communication 756...

Page 26: ...ctions 773 IED identifiers TERMINALID 773 Application 773 Product information PRODINF 773 Application 773 Factory defined settings 774 Measured value expander block RANGE_XP 774 Identification 775 Application 775 Setting guidelines 775 Parameter setting groups 775 Application 775 Setting guidelines 776 Rated system frequency PRIMVAL 776 Identification 776 Application 776 Setting guidelines 776 Sum...

Page 27: ...hronization 789 Section 24 Requirements 793 Current transformer requirements 793 Current transformer basic classification and requirements 793 Conditions 795 Fault current 796 Secondary wire resistance and additional load 796 General current transformer requirements 797 Rated equivalent secondary e m f requirements 797 Guide for calculation of CT for generator differential protection 798 Transform...

Page 28: ... 809 Voltage transformer requirements 810 SNTP server requirements 811 PTP requirements 811 Sample specification of communication requirements for the protection and control terminals in digital telecommunication networks 811 Section 25 Glossary 813 Table of contents 22 Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 Application manual ...

Page 29: ...alculating 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 principles 1MRK 502 071...

Page 30: ...o engineer the IEDs using the various tools available within the PCM600 software The manual provides instructions on how to set up a PCM600 project and insert IEDs to the project structure The manual also recommends a sequence for the engineering of protection and control functions LHMI functions as well as communication engineering for IEC 60870 5 103 IEC 61850 DNP3 LON and SPA The installation m...

Page 31: ...de assistance for calculating settings The technical manual contains operation principle descriptions and lists function blocks logic diagrams input and output signals setting parameters and technical data sorted per function The manual can be used as a technical reference during the engineering phase installation and commissioning phase and during normal service The communication protocol manual ...

Page 32: ...2 1MRK 511 393 UEN Point list manual DNP3 1MRK 511 397 UUS Accessories guide 1MRK 514 012 BUS Connection and Installation components 1MRK 513 003 BEN Test system COMBITEST 1MRK 512 001 BEN 1 4 Document symbols and conventions 1 4 1 Symbols GUID 2945B229 DAB0 4F15 8A0E B9CF0C2C7B15 v12 The electrical warning icon indicates the presence of a hazard which could result in electrical shock The warning ...

Page 33: ...th 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 v6 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 LHMI menu structure is presented by using the push button icons For example to...

Page 34: ...the suffix cont Dimensions are provided both in inches and millimeters If it is not specifically mentioned then the dimension is in millimeters Illustrations are used as an example and might show other products than the one the manual describes The example that is illustrated is still valid 1 5 IEC 61850 edition 1 edition 2 mapping GUID C5133366 7260 4C47 A975 7DBAB3A33A96 v4 Function block names ...

Page 35: ...C_F13 BFPTRC BFPTRC BFPTRC_F14 BFPTRC BFPTRC BFPTRC_F15 BFPTRC BFPTRC BFPTRC_F16 BFPTRC BFPTRC BFPTRC_F17 BFPTRC BFPTRC BFPTRC_F18 BFPTRC BFPTRC BFPTRC_F19 BFPTRC BFPTRC BFPTRC_F20 BFPTRC BFPTRC BFPTRC_F21 BFPTRC BFPTRC BFPTRC_F22 BFPTRC BFPTRC BFPTRC_F23 BFPTRC BFPTRC BFPTRC_F24 BFPTRC BFPTRC BICPTRC_01 BICPTRC BICPTRC BICPTRC_02 BICPTRC BICPTRC BICPTRC_03 BICPTRC BICPTRC BICPTRC_04 BICPTRC BICPT...

Page 36: ...USPTRC BUSPTRC_B17 BUSPTRC BUSPTRC BUSPTRC_B18 BUSPTRC BUSPTRC BUSPTRC_B19 BUSPTRC BUSPTRC BUSPTRC_B20 BUSPTRC BUSPTRC BUSPTRC_B21 BUSPTRC BUSPTRC BUSPTRC_B22 BUSPTRC BUSPTRC BUSPTRC_B23 BUSPTRC BUSPTRC BUSPTRC_B24 BUSPTRC BUSPTRC BUTPTRC_B1 BUTPTRC BBTPLLN0 BUTPTRC BUTPTRC_B2 BUTPTRC BUTPTRC BUTPTRC_B3 BUTPTRC BUTPTRC BUTPTRC_B4 BUTPTRC BUTPTRC BUTPTRC_B5 BUTPTRC BUTPTRC BUTPTRC_B6 BUTPTRC BUTPTR...

Page 37: ...PC CBPLLN0 CBPMMXU CBPPTRC HOLPTOV HPH1PTOV PH3PTUC PH3PTOC RP3PDOP CBPMMXU CBPPTRC HOLPTOV HPH1PTOV PH3PTOC PH3PTUC RP3PDOP CCPDSC CCRPLD CCPDSC CCRBRF CCRBRF CCRBRF CCRWRBRF CCRWRBRF CCRWRBRF CCSRBRF CCSRBRF CCSRBRF CCSSPVC CCSRDIF CCSSPVC CMMXU CMMXU CMMXU CMSQI CMSQI CMSQI COUVGAPC COUVLLN0 COUVPTOV COUVPTUV COUVPTOV COUVPTUV CVGAPC GF2LLN0 GF2MMXN GF2PHAR GF2PTOV GF2PTUC GF2PTUV GF2PVOC PH1PT...

Page 38: ...RWPIOC EFRWPIOC ETPMMTR ETPMMTR ETPMMTR FDPSPDIS FDPSPDIS FDPSPDIS FMPSPDIS FMPSPDIS FMPSPDIS FRPSPDIS FPSRPDIS FPSRPDIS FTAQFVR FTAQFVR FTAQFVR FUFSPVC SDDRFUF FUFSPVC SDDSPVC GENPDIF GENPDIF GENGAPC GENPDIF GENPHAR GENPTRC GOPPDOP GOPPDOP GOPPDOP PH1PTRC GRPTTR GRPTTR GRPTTR GSPTTR GSPTTR GSPTTR GUPPDUP GUPPDUP GUPPDUP PH1PTRC HZPDIF HZPDIF HZPDIF INDCALCH INDCALH INDCALH ITBGAPC IB16FCVB ITBGAP...

Page 39: ...PTUC LCPTTR LCPTTR LCPTTR LCZSPTOC LCZSPTOC LCZSPTOC LCZSPTOV LCZSPTOV LCZSPTOV LD0LLN0 LLN0 LDLPSCH LDLPDIF LDLPSCH LDRGFC STSGGIO LDRGFC LEXPDIS LEXPDIS LEXPDIS LEXPTRC LFPTTR LFPTTR LFPTTR LMBRFLO LMBRFLO LMBRFLO LOLSPTR LOLSPTR LOLSPTR LOVPTUV LOVPTUV LOVPTUV LPHD LPHD LPTTR LPTTR LPTTR LT3CPDIF LT3CPDIF LT3CGAPC LT3CPDIF LT3CPHAR LT3CPTRC LT6CPDIF LT6CPDIF LT6CGAPC LT6CPDIF LT6CPHAR LT6CPTRC ...

Page 40: ...PAPGAPC PAPGAPC PCFCNT PCGGIO PCFCNT PH4SPTOC GEN4PHAR OCNDLLN0 PH1BPTOC PH1PTRC GEN4PHAR PH1BPTOC PH1PTRC PHPIOC PHPIOC PHPIOC PSLPSCH ZMRPSL PSLPSCH PSPPPAM PSPPPAM PSPPPAM PSPPTRC QCBAY QCBAY BAY LLN0 QCRSV QCRSV QCRSV RCHLCCH RCHLCCH RCHLCCH REFPDIF REFPDIF REFPDIF ROTIPHIZ ROTIPHIZ ROTIPHIZ ROTIPTRC ROV2PTOV GEN2LLN0 PH1PTRC ROV2PTOV PH1PTRC ROV2PTOV SAPFRC SAPFRC SAPFRC SAPTOF SAPTOF SAPTOF ...

Page 41: ...SCBR 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 TEIGGIO TEILGAPC TEILGGIO TEILGAPC TMAGAPC TMAGGIO TMAGAP...

Page 42: ...WRNCALH ZC1PPSCH ZPCPSCH 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...

Page 43: ...MPDIS ZMMPDIS ZMQAPDIS ZMQAPDIS ZMQAPDIS ZMQPDIS ZMQPDIS ZMQPDIS ZMRAPDIS ZMRAPDIS ZMRAPDIS ZMRPDIS ZMRPDIS ZMRPDIS ZMRPSB ZMRPSB ZMRPSB ZSMGAPC ZSMGAPC ZSMGAPC 1MRK 502 071 UUS A Section 1 Introduction Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 37 Application manual ...

Page 44: ...38 ...

Page 45: ...s for pole slip underexcitation rotor ground fault negative sequence current protections and so on are included in the IED The generator differential protection in the REG670 adapted to operate correctly for generator applications where factors as long DC time constants and requirement on short trip time have been considered As many of the protection functions can be used as multiple instances the...

Page 46: ...nected to the IED This feature is essential for proper operation of the protection during generator start up and shut down procedure REG670 can be used in applications with the IEC UCA 61850 9 2LE process bus with up to eight merging units MU depending on the other functionality included in the IED GUID 295DE734 E7DD 42FF B402 151B7F38E36E v3 This adaptive filtering is ensured by proper configurat...

Page 47: ...an be used either as normal overcurrent function or even as generator differential function when currents from two generator sides are summed and connected to the four step overcurrent function Typically for such installations dedicated overcurrent steps are used during such low frequency conditions while some other overcurrent steps with different setting for pickup value and time delay are used ...

Page 48: ...I BF NS2 PTOC 46 I2 TR PTTR 49 Ith PSP PPAM 78 Ucos REX060 REX061 AEG PVOC 50AE U I CV MMXU Meter ROV2 PTOV 59N UN ROTI PHIZ 64R RRE STTI PHIZ 64S RSE REX060 ROV2 PTOV 59N 3Uo VT Y Y D IEC11000201 V2 EN US Figure 2 Generator protection application with generator differential 100 stator ground fault and back up protection Section 2 1MRK 502 071 UUS A Application 42 Generator protection REG670 2 2 A...

Page 49: ...PPAM 78 Ucos REX060 REX061 AEG PVOC 50AE U I CV MMXU Meter ROTI PHIZ 64R RRE STTI PHIZ 64S RSE REX060 ROV2 PTOV 59N 3Uo VT EF4 PTOC 64W IN Y Y S D IEC11000204 V2 EN US Figure 3 Generator protection application for generator with split winding including generator phase differential 100 stator ground fault and back up protection 1MRK 502 071 UUS A Section 2 Application Generator protection REG670 2 ...

Page 50: ...60 REX061 AEG PVOC 50AE U I CV MMXU Meter ROV2 PTOV 59N UN ROTI PHIZ 64R RRE VT EF4 PTOC 64W IN Y Y STTI PHIZ 64S RSE REX060 VT GEN PDIF 87W 3Id I D S IEC11000206 V2 EN US Figure 4 Generator protection application for generator with split winding including generator phase differential generator split phase differential 100 stator ground fault and back up protection Section 2 1MRK 502 071 UUS A App...

Page 51: ...3Uo T3W PDIF 87T 3Id I CV MMXU Meter OEX PVPH 24 U f UV2 PTUV 27 3U OV2 PTOV 59 3U ROV2 PTOV 59N 3Uo REX060 REX061 STTI PHIZ 64S RSE ROTI PHIZ 64R RRE REX060 REX062 Y Y Y Unit Trafo Auxiliary Trafo Excitation Trafo Y Y Grounding Transformer D D D IEC11000202 V2 EN US Figure 5 Unit protection application with overall differential generator differential 100 stator ground fault and back up protection...

Page 52: ...0 51 3I CC RBRF 50BF 3I BF GEN PDIF 87G 3Id I ROV2 PTOV 59N UN CC RBRF 50BF 3I BF OC4 PTOC 51 67 3I AEG PVOC 50AE U I CV MMXU Meter REX060 REX061 STTI PHIZ 64S RSE ROTI PHIZ 64R RRE REX060 CV MMXU Meter Y Y Y Y Y Unit Trafo VT D D D IEC11000203 V2 EN US Figure 6 Unit protection application with overall differential unit transformer differential generator differential 100 stator ground fault and ba...

Page 53: ...IZ 64R RRE REX060 CV MMXU Meter Y Y Y Y Y Unit Trafo ROV2 PTOV 59N 3Uo VT IEC11000207 2 en vsd D D D IEC11000207 V2 EN US Figure 7 Unit protection application with overall differential unit transformer differential generator differential 100 stator ground fault and back up protection Stator winding grounded via primary resistor GUID F5776DD1 BD04 4872 BB89 A0412B4B5CC3 v1 The following tables list...

Page 54: ...ion low impedance 0 3 Impedance protection ZMHPDIS 21 Full scheme distance protection mho characteristic 0 4 ZDMRDIR 21D Directional impedance element for mho characteristic 0 2 ZMFPDIS 21 High speed distance protection quad and mho characteristic 0 1 ZMFCPDIS 21 High speed distance protection for series comp lines quad and mho characteristic 0 1 PSPPPAM 78 Poleslip out of step protection 0 1 OOSP...

Page 55: ...PDUP 37 Directional underpower protection 0 4 GOPPDOP 32 Directional overpower protection 0 4 NS2PTOC 46I2 Negative sequence time overcurrent protection for machines 0 2 AEGPVOC 50AE Accidental energizing protection for synchronous generator 0 2 VRPVOC 51V Voltage restrained overcurrent protection 0 3 GSPTTR 49S Stator overload protection 0 1 GRPTTR 49R Rotor overload protection 0 1 Voltage protec...

Page 56: ... Control functionality for up to 6 bays max 30 objects 6CBs including interlocking see Table 4 0 1 QCBAY Bay control 1 5 APC30 LOCREM Handling of LR switch positions 1 5 APC30 LOCREMCTRL LHMI control of PSTO 1 SXCBR Circuit breaker 18 TCMYLTC 84 Tap changer control and supervision 6 binary inputs 0 4 TCLYLTC 84 Tap changer control and supervision 32 binary inputs 0 4 SLGAPC Logic rotating switch f...

Page 57: ...5 FUFSPVC Fuse failure supervision 0 3 VDSPVC 60 Fuse failure supervision based on voltage difference 0 2 Logic SMPPTRC 94 Tripping logic 12 SMAGAPC General start matrix block 12 TMAGAPC Trip matrix logic 12 ALMCALH Logic for group alarm 5 WRNCALH Logic for group warning 5 INDCALH Logic for group indication 5 AND GATE INV LLD OR PULSETIMER RSMEMORY SRMEMORY TIMERSET XOR Basic configurable logic bl...

Page 58: ... conversion with Logic Node representation 16 TIGAPC Delay on timer with input signal integration 30 TEIGAPC Elapsed time integrator with limit transgression and overflow supervision 12 INTCOMP Comparator for integer inputs 30 REALCOMP Comparator for real inputs 30 Table 3 Total number of instances for basic configurable logic blocks Basic configurable logic block Total number of instances AND 280...

Page 59: ...cation 30 QCBAY Bay control 5 LOCREM Handling of LR switch positions 5 XLNPROXY Proxy for signals from switching device via GOOSE 42 GOOSEXLNRCV GOOSE function block to receive a switching device 42 Table 5 Total number of instances for configurable logic blocks Q T Configurable logic blocks Q T Total number of instances ANDQT 120 INDCOMBSPQT 20 INDEXTSPQT 20 INVALIDQT 22 INVERTERQT 120 ORQT 120 P...

Page 60: ...ion description Generator REG670 Customized Monitoring CVMMXN Power system measurement 6 CMMXU Current measurement 10 VMMXU Voltage measurement phase phase 6 CMSQI Current sequence measurement 6 VMSQI Voltage sequence measurement 6 VNMMXU Voltage measurement phase ground 6 AISVBAS General service value presentation of analog inputs 1 EVENT Event function 20 DRPRDRE A4RADR B1RBDR B22RBDR Disturbanc...

Page 61: ... status auto recloser for IEC 60870 5 103 1 I103EF Function status earth fault for IEC 60870 5 103 1 I103FLTPROT Function status fault protection for IEC 60870 5 103 1 I103IED IED status for IEC 60870 5 103 1 I103SUPERV Supervison status for IEC 60870 5 103 1 I103USRDEF Status for user defined signals for IEC 60870 5 103 20 L4UFCNT Event counter with limit supervision 30 TEILGAPC Running hour mete...

Page 62: ... block to receive an integer value 32 GOOSEMVRCV GOOSE function block to receive a measurand value 60 GOOSESPRCV GOOSE function block to receive a single point value 64 MULTICMDRCV MULTICMDSND Multiple command and transmit 60 10 OPTICAL103 IEC 60870 5 103 Optical serial communication 1 RS485103 IEC 60870 5 103 serial communication for RS485 1 AGSAL Generic security application component 1 LD0LLN0 ...

Page 63: ...BinSigTran1_12M BinSigTran1_22M Binary signal transfer 2Mbit receive transmit 3 LDCMTRN Transmission of analog data from LDCM 1 LDCMTRN_2M Transmission of analog data from LDCM 2Mbit 6 LDCMRecBinStat1 LDCMRecBinStat2 LDCMRecBinStat3 Receive binary status from remote LDCM 6 3 3 LDCMRecBinS2_2M Receive binary status from LDCM 2Mbit 3 LDCMRecBinS3_2M Receive binary status from remote LDCM 2Mbit 3 Tab...

Page 64: ...MPPS SYNCHLON SYNCHPPH SYNCHPPS SNTP SYNCHSPA Time synchronization PTP Precision time protocol 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 SMAI1...

Page 65: ...ne language SCREEN Local HMI Local human machine screen behavior 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 1MRK 502 071 UUS A Section 2 Application Generator prote...

Page 66: ...60 ...

Page 67: ...earth fault function and Pole Slip protection function are optional REG670 A20 functional library includes additional functions which are not configured such as additional Overcurrent protection additional Multipurpose protection functions Synchronizing function and so on It is as well possible to order optional two winding transformer differential or high impedance differential protection functio...

Page 68: ...D PD PH PIOC 50 3I EF PIOC 50N IN VDC PTOV 60 Ud Q CBAY 3 Control GR PTTR 49R θ TCM YLTC 84 VD SPVC 60 Ud FTA QFVR 81A f VR PVOC 51V 2 I U Q CRSV 3 Control S CILO 3 Control S CSWI 3 Control S SCBR Control ZMH PDIS 21 Z TR PTTR 49 θ ZDM RDIR 21D Z _ IEC11000068 6 en vsdx S SIML 71 S SIMG 63 S SCBR Control S SCBR Control S XCBR 3 Control PMU REP STTI PHIZ 64S R S XSWI 3 Control FUF SPVC U I NS2 PTOC...

Page 69: ...tor differential protection function and so on It is as well possible to order optional two or three winding transformer differential protection function which than can be used as transformer or block that is overall differential protection Note that REG670 B30 must be re configured if any additional or optional functions are used 1MRK 502 071 UUS A Section 3 Configuration Generator protection REG...

Page 70: ... Isqi IEC11000071 6 en Original vsd SES RSYN 25 SC VC CCS SPVC 87 INd I STTI PHIZ 64S R OOS PPAM 78 Ucos T3W PDIF 87T 3Id I REF PDIF 87N IdN I T2W PDIF 87T 3Id I ROTI PHIZ 64R R HZ PDIF 87 Id SA PFRC 81 df dt Optional Functions SDE PSDE 67N IN NS4 PTOC 46I2 4 I2 PSP PPAM 78 Ucos CC PDSC 52PD PD PH PIOC 50 3I EF PIOC 50N IN VDC PTOV 60 Ud Q CBAY 3 Control GR PTTR 49R θ TCM YLTC 84 VD SPVC 60 Ud FTA...

Page 71: ... differential protection functions Note that Pole Slip protection function is optional See figure 10 example of one possible application REG670 C30 functional library includes additional functions which are not configured such as additional Multipurpose protection functions Synchrocheck function second generator differential protection function and so on Note that REG670 C30 must be re configured ...

Page 72: ... 87T 3Id I FUF SPVC U I C MSQI MET Isqi C MMXU MET I GS PTTR 49S θ SES RSYN 25 SC VC CCS SPVC 87 INd I STTI PHIZ 64S R OOS PPAM 78 Ucos ROTI PHIZ 64R R HZ PDIF 87 Id SA PFRC 81 df dt Other Functions available from the function library SDE PSDE 67N IN NS4 PTOC 46I2 4 I2 PSP PPAM 78 Ucos CC PDSC 52PD PD PH PIOC 50 3I EF PIOC 50N IN VDC PTOV 60 Ud TCM YLTC 84 S SIMG 63 S SIML 71 GR PTTR 49R θ Q CBAY ...

Page 73: ...ays be fixed 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 availability of VT inputs depends on the ordered transformer input module TRM type 4 2 Setting guidelines SEMOD55068 1 v1 SEMOD130348 4...

Page 74: ...rward and the direction out from the object is defined as Reverse See Figure 11 A positive value of current power and so on forward means that the quantity flows towards the object A negative value of current power and so on reverse means that the quantity flows away from the object See Figure 11 Protected Object Line transformer etc Forward Reverse Definition of direction for directional function...

Page 75: ... for CT direction shall be done according to the figure To protect the line direction of the directional functions of the line protection shall be set to Forward This means that the protection is looking towards the line 4 2 2 2 Example 2 SEMOD55055 29 v7 Two IEDs used for protection of two objects and sharing a CT Figure 13 Example how to set CT_WyePoint parameters in the IED This example is simi...

Page 76: ... transformer To look towards the line the direction of the directional functions of the line protection must be set to Reverse The direction Forward Reverse is related to the reference object that is the transformer in this case When a function is set to Reverse and shall protect an object in reverse direction it shall be noted that some directional functions are not symmetrical regarding the reac...

Page 77: ...ward Reverse Definition of direction for directional line functions Setting of current input for transformer functions Set parameter CT_WyePoint with Transformer as reference object Correct setting is ToObject Setting of current input for line functions Set parameter CT_WyePoint with Line as reference object Correct setting is FromObject en05000462_ansi vsd ANSI05000462 V1 EN US Figure 15 Example ...

Page 78: ...uts marked with 1 in Figure 16 set CT_WyePoint ToObject and for all CT inputs marked with 2 in Figure 16 set CT_WyePoint 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 16 set CT_WyePoint FromObject and for all CT inputs marked with 2 in Figure 16 set CT_WyePoint ToObject Section 4 1MRK 502 071 UUS A Analo...

Page 79: ...lock is measuring current or voltage This is done with the parameter AnalogInputType Current Voltage The ConnectionType phase phase phase ground 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 17 Commonly used markings of CT terminals Where a is symbol and terminal marking used in this document Terminals marked with ...

Page 80: ... IED in order to connect CTs with 5A and 10A secondary rating 4 2 2 5 Example on how to connect a wye connected three phase CT set to the IED SEMOD55055 352 v11 Figure 18 gives an example about the wiring of a wye 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 ...

Page 81: ...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 18 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 measured currents In other words currents are already measured t...

Page 82: ...n 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 A B C and neutral quantity in particular the data about fundamental frequency phasors harmoni...

Page 83: ...r CTStarPoint of the used current inputs on the TRM item 2 in Figure 19 and 18 CTprim 600A CTsec 5A CTWyePoint 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 alternative is to have the residu...

Page 84: ...dividual 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 c...

Page 85: ...tions 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 be set accordingly 4 2...

Page 86: ... IB IB IC IC IA 1 2 3 4 ANSI11000027 2 en vsd SMAI_20 ANSI11000027 V2 EN US Figure 21 Delta DAB connected three phase CT set Section 4 1MRK 502 071 UUS A Analog inputs 80 Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 Application manual ...

Page 87: ... 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 and control functions ...

Page 88: ...ype Ph Ph It is important to notice the references in SMAI As inputs at Ph Ph are expected to be A B B Crespectively C A 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 23 gives an example how to connect the single phase CT to the IED It gives an overview of the required actions by the user in order to make this measuremen...

Page 89: ... b shown in Figure 23 CTprim 1000 A CTsec 1A CTWyePoint 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 protection and control func...

Page 90: ... effectively make 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...

Page 91: ...is the symbol and terminal marking used in this document Terminals marked with a square 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 ground connected VTs c is the equivalent symbol and terminal marking used by IEC ANSI standard for open delta connected VTs d is the equival...

Page 92: ...how to connect the three phase to ground connected VT to the IED It gives an overview of required actions by the user in order to make this measurement available to the built in protection and control functions within the IED For correct terminal designations see the connection diagrams valid for the delivered IED Section 4 1MRK 502 071 UUS A Analog inputs 86 Generator protection REG670 2 2 ANSI a...

Page 93: ... GRP2_C GRP2N 4 ANSI06000599 V2 EN US Figure 25 A Three phase to ground connected VT L1 IED L2 132 2 110 2 kV V 1 3 2 132 2 110 2 kV V IEC16000140 1 en vsdx 4 SMAI2 BLOCK GRP2L1 GRP2L2 GRP2L1L2 GRP2N AI2P AI1 AI2 AI3 AI4 AIN 5 IEC16000140 V1 EN US Figure 26 A two phase to earth connected VT 1MRK 502 071 UUS A Section 4 Analog inputs Generator protection REG670 2 2 ANSI and Injection equipment REX0...

Page 94: ...e connected analog inputs and calculate fundamental frequency phasors for all input channels harmonic content for all input channels positive negative and zero sequence quantities by using the fundamental frequency phasors for the first three input channels channel one taken as reference for sequence quantities These calculated values are then available for all built in protection and control func...

Page 95: ...how to connect the secondary 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 1MRK 502 071 UUS A Section...

Page 96: ... ConnectionType Ph Ph VBase 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 grounded or ungrounded networks SEMOD55055 163 v9 Figure 28 gives an example abo...

Page 97: ...t Used 5 ANSI06000601 2 en vsd Not Used Not Used SMAI2 BLOCK GRP2_A GRP2_B GRP2_C GRP2N TYPE AI3P AI1 AI2 AI3 AI4 AIN ANSI06000601 V2 EN US Figure 28 Open delta connected VT in high impedance grounded power system 1MRK 502 071 UUS A Section 4 Analog inputs Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 91 Application manual ...

Page 98: ...th 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 channels channel one...

Page 99: ...V1 EN US Equation 7 The primary rated voltage of such VT is always equal to VPh Gnd 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 or 115 3V as in...

Page 100: ...02 2 en vsd 5 Not Used Not Used Not Used SMAI2 BLOCK GRP2_A GRP2_B GRP2_C GRP2N TYPE AI3P AI1 AI2 AI3 AI4 AIN ANSI06000602 V2 EN US Figure 29 Open delta connected VT in low impedance or solidly grounded power system Section 4 1MRK 502 071 UUS A Analog inputs 94 Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 Application manual ...

Page 101: ...e 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 reference for sequence ...

Page 102: ...96 ...

Page 103: ... ANSI13000239 V2 EN US Figure 30 Local human machine interface The LHMI of the IED contains the following elements 1MRK 502 071 UUS A Section 5 Local HMI Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 97 Application manual ...

Page 104: ...4112 B5C7 217AAF360EA5 v11 The LHMI includes a graphical monochrome liquid crystal display LCD with a resolution of 320 x 240 pixels The character size can vary The display view is divided into four basic areas Section 5 1MRK 502 071 UUS A Local HMI 98 Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 Application manual ...

Page 105: ...st what actions are possible with the function buttons Each function button has a LED indication that can be used as a feedback signal for the function button control action The LED is connected to the required signal with PCM600 1MRK 502 071 UUS A Section 5 Local HMI Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 99 Application manual ...

Page 106: ...A971475E3 V1 EN US Figure 33 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 label string length Section 5 1MRK 502 071 UUS A Local HMI 100 Generator pro...

Page 107: ...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 from the LED pa...

Page 108: ...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 Section 5 1MRK 502 071 UUS A Local HMI 102 Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 Application manual ...

Page 109: ...vigation 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 1MRK 502 071 UUS A Section 5 Local HMI Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 103 Application manual ...

Page 110: ... and an indication message is displayed The pick up indication is latching and must be reset via communication LHMI or binary input on the LEDGEN component To open the reset menu on the LHMI press Flashing The IED is in test mode and protection functions are blocked or the IEC61850 protocol is blocking one or more functions The indication disappears when the IED is no longer in test mode and block...

Page 111: ...s on or it is off but the indication has not been acknowledged LatchedAck F S sequence The 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 ...

Page 112: ... GUID 94AF2358 6905 4782 B37B ACD3DCBF7F9C V1 EN US Figure 36 RJ 45 communication port and green indicator LED 1 RJ 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 Do not conne...

Page 113: ...n order to establish and define a number of TCP and or UDP connections with one or more PDC clients synchrophasor 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 37 demonstrates the communication configuration diagram As can be seen the IED ...

Page 114: ...18 1344 C37 118 1344 C37 118 1344 C37 118 1344 C37 118 1344 C37 118 Unicast Multicast 1344 C37 118 Unicast Multicast 1344 C37 118 Unicast Multicast 1344 C37 118 Unicast Multicast 1344 C37 118 Unicast Multicast 1344 C37 118 Unicast Multicast PMU ID PMU ID IEC140000117 1 en vsd IEC140000117 V2 EN US Figure 37 The communication configuration PMUCONF structure in the IED 6 1 3 1 Short guidance for use...

Page 115: ...out of the command if there is a PMUREPORT instance configured in the IED with matching PMU ID then the client connection over TCP with the IED will be established and further communication will take place Otherwise the connection will be terminated and the TCPCtrlCfgErrCnt is incremented in the PMU Diagnostics on the Local HMI under Main menu Diagnostics Communication PMU diagnostics PMUSTATUS 1 ...

Page 116: ...s recommended not to set the parameter SendDataUDP x to SetByProtocol in case of a multicast This is because if one of the clients sends the RTDOFF command all the clients will stop receiving the frames The UDP implementation in the IED is a UDP_TCP This means that by default only the data frames are sent out on UDP stream and the header frame configuration frame and command frame are sent over TC...

Page 117: ...frame 1 config frame 2 config frame 3 or header frame and to disable enable real time data This can be done by connecting to the TCP port selected in TCPportUDPdataCtrl x for each UDP group This connection is done using TCP The IED allows 4 concurrent client connections for every TCPportUDPdataCtrl x port for each UDP client group x If the client tries to connect on TCPportUDPdataCtrl x port using...

Page 118: ...ut same or different data at different reporting rates or different performance service classes There are 2 instances of PMU functionality available in the IED Each instance of PMU functionality includes a set of PMU reporting function blocks tagged by the same instance number 1 or 2 As shown in the following figures each set of PMU reporting function blocks includes PMUREPORT PHASORREPORT1 4 ANAL...

Page 119: ...C140000119 2 en vsd IEC140000119 V2 EN US Figure 39 Multiple instances of PHASORREPORT blocks Figure 40 shows both instances of ANALOGREPORT function blocks The instance number is visible in the bottom of each function block For each instance there are three separate ANALOGREPORT blocks capable of reporting up to 24 Analog signals 8 Analog signals in each ANALOGREPORT block These can include for e...

Page 120: ...ach BINARYREPORT block These binary signals can be for example dis connector or breaker position indications or internal external protection alarm signals IEC140000121 2 en vsd IEC140000121 V2 EN US Figure 41 Multiple instances of BINARYREPORT blocks 6 2 3 Operation principle GUID EB2B9096 2F9D 4264 B2D2 8D9DC65697E8 v3 The Phasor Measurement Unit PMU features three main functional principles Sect...

Page 121: ...1 where Xr n and Xi n are the measured values Xr and Xi are the theoretical values In order to comply with TVE requirements special calibration is done in the factory on the analog input channels of the PMU resulting in increased accuracy of the measurements The IEEE C37 118 standard also imposes a variety of steady state and dynamic requirements which are fulfilled in the IED with the help of hig...

Page 122: ...vide the required information for each respective PMUREPORT phasor channel More information about preprocessor block is available in the section Signal matrix for analog inputs SMAI 6 2 3 1 Frequency reporting GUID 4F3BA7C7 8C9B 4266 9F72 AFB139E9DC21 v2 By using patented algorithm the IED can track the power system frequency in quite wide range from 9 Hz to 95 Hz In order to do that the three pha...

Page 123: ...mber 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 reason this voltage gets disconnected then the next available voltage phasor is automatically used as the frequency source and so on If the first voltage phasor comes back since it has a higher priority compare to the cur...

Page 124: ...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 aliasing frequencies to at least 40 dB a gain of 0 01 at M class The synchrophasor measurement is adaptive as it follows the fundamental frequen...

Page 125: ...tor 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 multiplied in 10 so that a minimum of 0 1 scale factor ca...

Page 126: ...ill 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 factor will be sent as 30...

Page 127: ...0000124 V2 EN US Figure 43 An example of correct connection of SMAI and PHASORREPORT blocks in ACT Figure 44 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 44 An example of wrong connection of SMAI and PHASORREPORT blocks i...

Page 128: ...CM600 Parameter Setting Tool PST IEC140000126 2 en vsd IEC140000126 V2 EN US Figure 45 PMUREPORT settings in PCM600 PST Figure 46 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 di...

Page 129: ...lass 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 instance 1 because of ...

Page 130: ...th 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 48 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 uses external DFT ref...

Page 131: ...s in ACT IEC140000130 1 en vsd IEC140000130 V1 EN US Figure 49 SMAI1 setting parameters example showing that SMAI3 is selected as the DFT reference DFTRefGrp3 1MRK 502 071 UUS A Section 6 Wide area measurement system Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 125 Application manual ...

Page 132: ...I3 IEC140000132 2 en vsd IEC140000132 V2 EN US Figure 51 An example of wrong connection of 3PHSUM and PHASORREPORT blocks in 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...

Page 133: ...tance of PHASORREPORT blocks PHASOR1 32 of Instance number 1 or 2 Note If settings SvcClass and ReportRate are the same for different instances of PHASORREPORT 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 ...

Page 134: ...eport Function Blocks Connection Rules in PCM600 Application Configuration Tool ACT Global_PMU_ID It refers to the 16 byte G_PMU_ID field of the configuration frame 3 CFG 3 organization defined in IEEE C37 118 2 message format It is a 16 character 128 bits user assigned value which can be sent with the configuration 3 message It allows uniquely identifying PMUs in a system that has more than 65535...

Page 135: ...he Bit 2 of the FORMAT field of the configuration frames 1 2 and 3 organization defined in IEEE C37 118 2 message format Here the user can select the type of the analog data which are reported along with the synchrophasor data over IEEE C37 118 2 message The options are Integer or Float data corresponding to the 16 bit integer or 32 bit IEEE floating point values respectively The analog data could...

Page 136: ...entifying the Rate of phasor data transmissions by a 2 byte integer word 32 767 to 32 767 Here the user can select the synchrophasor data reporting rate from the PMU based on the number of frames per second In general the IED has 5 different reporting rates 10 25 50 100 200 fr s on the 50 Hz system frequency and has 8 different reporting rates 10 12 15 20 30 60 120 240 fr s on the 60 Hz system fre...

Page 137: ... connected preprocessor block delivers the frequency data derived from the analog input AC voltage values to the respective voltage phasor channel Every phasor channel has a user settable parameter PhasorXUseFreqSrc to be used as a source of frequency data for reporting to the PDC client It is very important to set this parameter to On for the voltage connected phasor channels There is an automati...

Page 138: ...t type for analog signal X It refers to the 4 byte ANUNIT field of the configuration frames 1 2 organization defined in IEEE C37 118 2 message format The options are Single point on wave RMS of analog input and Peak of analog input Section 6 1MRK 502 071 UUS A Wide area measurement system 132 Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 Application manual ...

Page 139: ...ctive zone does not include the bus work or cables between the circuit breaker and the power transformer In some substations there is a current differential protection relay for the busbar Such a busbar protection will include the bus work or cables between the circuit breaker and the power transformer Internal electrical faults are very serious and will cause immediate damage Short circuits and g...

Page 140: ...urn ratio and the phase shift are correctly compensated However there are several different phenomena other than internal faults that will cause unwanted and false differential currents The main reasons for unwanted differential currents may be mismatch due to varying tap changer positions different characteristics loads and operating conditions of the current transformers zero sequence currents t...

Page 141: ...e second slope is increased to ensure stability under heavy through fault conditions which could lead to increased differential current due to saturation of current transformers Default settings for the operating characteristic with IdMin 0 3pu of the power transformer rated current can be recommended as a default setting in normal applications If the conditions are known more in detail higher or ...

Page 142: ...tion can overcome this problem if the bias is obtained separately from each set of current transformer circuits It is therefore important to avoid paralleling of two or more current transformers for connection to a single restraint input Each current connected to the IED is available for biasing the differential protection function The unrestrained operation level has a default value of IdUnre 10p...

Page 143: ...5000187 V2 EN US Figure 52 Representation of the restrained and the unrestrained operate characteristics 100 Ioperate slope Irestrain D D EQUATION1246 V1 EN US Equation 13 and where the restrained characteristic is defined by the settings 1 IdMin 2 EndSection1 3 EndSection2 4 SlopeSection2 5 SlopeSection3 1MRK 502 071 UUS A Section 7 Differential protection Generator protection REG670 2 2 ANSI and...

Page 144: ...ssary to eliminate the zero sequence current from every individual winding by proper setting of setting parameters ZSCurrSubtrWx Disabled or Enabled 7 1 3 3 Inrush restraint methods M15266 6 v7 With a combination of the second harmonic restraint and the waveform restraint methods it is possible to get a protection with high security and stability against inrush effects and at the same time maintai...

Page 145: ...ommended setting value for this parameter When parameter CrossBlockEn is set to Disabled any cross blocking between phases will be disabled 7 1 3 6 External Internal fault discriminator M15266 269 v10 The external internal fault discriminator operation is based on the relative position of the two phasors in case of a two winding transformer representing the W1 and W2 negative sequence current cont...

Page 146: ...are 180 degrees out of phase or at least in the external fault region the fault is external Under external fault condition and with no current transformer saturation the relative angle is theoretically equal to 180 degrees During internal fault and with no current transformer saturation the angle shall ideally be 0 degrees but due to possible different negative sequence source impedance angles on ...

Page 147: ... whole power transformer is protected including the non connected winding 7 1 3 7 On line compensation for on load tap changer position M15266 326 v5 The Transformer differential function in the IED has a built in facility to on line compensate for on load tap changer operation The following parameters which are set under general settings are related to this compensation feature Parameter Location...

Page 148: ... Open CT detection M15266 340 v5 The Generator differential function has a built in advanced open CT detection feature This feature can block the unexpected operation created by the Generator differential function in case of open CT secondary circuit under normal load condition An alarm signal can also be issued to station operational personnel to make remedy action once the open CT condition is d...

Page 149: ...ted transformer ratio compensation zero sequence current elimination zero sequence current reduction shall be done In the past this was performed with help of interposing CTs or special connection of main CTs delta connected CTs With numerical technology all these compensations are done in IED software The Differential transformer protection is capable to provide differential protection for all st...

Page 150: ... the IED 7 1 4 2 Typical main CT connections for transformer differential protectionSEMOD167749 5 v3 Three most typical main CT connections used for transformer differential protection are shown in figure 53 It is assumed that the primary phase sequence is A B C A IA IA IB IB IC IC IA IA IC IB IA IC IB IA IB IC Protected Transformer Winding CT Wye Connected CT in Delta DAC Connected CT in Delta DA...

Page 151: ...ison with wye connected CTs lead by 30 the primary winding currents this CT connection rotates currents by 30 in anti clockwise direction do not contain zero sequence current component For DAB delta connected main CT ratio shall be set for 3 times smaller in RET 670 then the actual ratio of individual phase CTs The WyePoint parameter for this particular connection shall be set ToObject It shall be...

Page 152: ...300 5 in Delta DAC CT 800 5 Wye 20 9 MVA 69 12 5 kV YNd1 YDAC CT 300 5 Wye CT 800 5 Wye 20 9 MVA 69 12 5 kV YNd1 YDAC en06000554_ansi vsd ANSI06000554 V1 EN US Figure 54 Two differential protection solutions for wye delta connected power transformer For this particular power transformer the 69 kV side phase to ground no load voltages lead by 30 degrees the 12 5 kV side phase to ground no load volt...

Page 153: ...annels used for the LV side CTs Setting parameter Selected value for both solutions CTprim 800 CTsec 5 CT_WyePoint ToObject 5 Enter the following settings for all three CT input channels used for the HV side CTs see table 16 Table 16 CT input channels used for the HV side CTs Setting parameter Selected value for solution 1 wye connected CT Selected value for solution 2 delta connected CT CTprim 30...

Page 154: ...ZSCurrSubtrW2 Off Off TconfigForW1 No No TconfigForW2 No No LocationOLTC1 Not used Not used Other Parameters Not relevant for this application Use default value Not relevant for this application Use default value 1 To compensate for delta connected CTs 2 Zero sequence current is already removed by connecting main CTs in delta Delta wye connected power transformer without tap charger SEMOD167854 20...

Page 155: ...rrents are rotated by 30 in anti clockwise direction Thus the DAB CT delta connection see figure 55 must be used for 24 9 kV CTs in order to put 115 kV 24 9 kV currents in phase To ensure proper application of the IED for this power transformer it is necessary to do the following 1 Check that HV LV CTs are connected to 5 A CT inputs in the IED 2 For second solution make sure that LV delta connecte...

Page 156: ...ee equation 15 6 Enter the following values for the general settings of the differential protection function see table19 Table 19 General settings of the differential protection Setting parameter selected value for both Solution 1 wye conected CT Selected value for both Solution 2 delta connected CT RatedVoltageW1 115 kV 115 kV Rated VoltageW2 24 9 kV 24 9 kV RatedCurrentW1 301 A 301 A RatedCurren...

Page 157: ...applicable for protection of autotransformer with not loaded tertiary delta winding as well CT 500 5 Wye 31 5 31 5 10 5 MVA 110 11 1 5 36 75 10 5 kV YNyn0 d5 CT 200 1 Wye CT 500 5 in Delta DAB 31 5 31 5 10 5 MVA 110 11 1 5 36 75 10 5 kV YNyn0 d5 CT 200 1 in Delta DAB en06000558_ansi vsd ANSI06000558 V1 EN US Figure 56 Two differential protection solutions for wye wye connected transformer For this...

Page 158: ... see table 20 Table 20 CT input channels used for the HV side CTs Setting parameter Selected value for both solution 1 wye connected CTs Selected value for both Solution 2 delta connected CTs CTprim 200 200 115 3 EQUATION1891 V1 EN US Equation 16 CTsec 1 1 CT_WyePoint FromObject ToObject To compensate for delta connected CTs see equation 16 6 Enter the following settings for all three CT input cha...

Page 159: ...g 1 W1 LowTapPosOLTC1 1 1 RatedTapOLTC1 12 12 HighTapPsOLTC1 23 23 TapHighVoltTC1 23 23 StepSizeOLTC1 1 5 1 5 Other parameters Not relevant for this application Use default value Not relevant for this application Use default value 1 Zero sequence current is already removed by connecting main CTs in delta 7 1 4 4 Summary and conclusions SEMOD168160 5 v3 The IED can be used for differential protecti...

Page 160: ...mmarizes the most commonly used wye delta phase shift around the world and provides information about the required type of main CT delta connection on the wye side of the protected transformer IEC vector group ANSI designation Positive sequence no load voltage phasor diagram Required delta CT connection type on wye side of the protected power transformer and internal vector group setting in the IE...

Page 161: ...yn5 DY150 Y IEC06000564 V1 EN US DAC Yy6 7 2 High impedance differential protection single phase HZPDIF 87 IP14239 1 v4 7 2 1 Identification M14813 1 v4 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number High impedance differential protection single phase HZPDIF Id SYMBOL CC V2 EN US 87 1MRK 502 071 UUS A Section 7 Differential protection Generator...

Page 162: ...rial windings only T feeder differential protection Capacitor differential protection Restricted ground fault protection for transformer generator and shunt reactor windings Restricted ground fault protection The application is dependent on the primary system arrangements and location of breakers available CT cores and so on Section 7 1MRK 502 071 UUS A Differential protection 156 Generator protec...

Page 163: ...7 87N 3 87T G 3 87G 3 87B 3 87T 3 87 3 87 3 87B ANSI05000163 V2 EN US 1MRK 502 071 UUS A Section 7 Differential protection Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 157 Application manual ...

Page 164: ...ormers and not through the IED due to high impedance in the measuring branch This stabilizing resistance is in the range of hundreds of ohms and sometimes above one kilo Ohm When an internal fault occurs the current cannot circulate and is forced through the measuring branch causing relay operation It should be remembered that the whole scheme its built in components and wiring must be adequately ...

Page 165: ...made with the worst situations in mind and a minimum operating voltage VR is calculated according to equation 18 max VR IF Rct Rl EQUATION1531 ANSI V1 EN US Equation 18 where IFmax is the maximum through fault current at the secondary side of the CT Rct is the current transformer secondary winding resistance and Rl is the maximum loop resistance of the circuit at any CT 1MRK 502 071 UUS A Section ...

Page 166: ...l give a higher sensitivity and a lower value a lower sensitivity of the relay The function has a recommended operating current range 40 mA to 1 0A for 1 A inputs and 200 mA to 5A for 5A inputs This together with the selected and set value is used to calculate the required value of current at the set TripPickup and R series values The CT inputs used for 1Ph High impedance differential protection H...

Page 167: ...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 transformer saturation voltage must be at least 2 ˣ TripPickup to have sufficient operating margin This must be checked after calculation of TripPickup Wh...

Page 168: ...rent 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 65 Series resistor thermal capacity SEMOD54734 336 v6 The series resistor is dimensioned for 200 W Care shall be exercised while testing to ensure that if current needs to be injected continuously or for a significant duration of t...

Page 169: ...c Internal faults VR Protected Object ANSI05000427 V2 EN US Figure 59 The high impedance principle for one phase with two current transformer inputs 1MRK 502 071 UUS A Section 7 Differential protection Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 163 Application manual ...

Page 170: ...ion is a typical application for three phase high impedance differential protection Typical CT connections for three phase high impedance differential protection scheme are shown in figure 60 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 ...

Page 171: ...int connector must be removed for installations with 670 series IEDs This star point is required for RADHA schemes only 7 Connections of three individual phase currents for high impedance scheme to three CT inputs in the IED 7 2 3 2 Connections for 1Ph High impedance differential protection HZPDIF 87 GUID D68A237F 610C 4AF0 870F 273117F64D92 v10 Restricted earth fault protection is a typical appli...

Page 172: ...me 2 One phase plate with stabilizing resistor and metrosil Protective ground is a separate 4 mm screw terminal on the plate 3 Necessary connection for the metrosil 4 Position of optional test switch for secondary injection into the high impedance differential IED 5 Necessary connection for stabilizing resistor 6 How to connect the high impedance restricted earth fault protection scheme to one CT ...

Page 173: ...re the value achieved and set this value for this parameter The value shall always be high impedance This means for example for 1A circuits say bigger than 400 ohms 400 VA and for 5 A circuits say bigger than 100 ohms 2500 VA This ensures that the current will circulate and not go through the differential circuit at through faults That the settings of U Alarm U Trip and SeriesResistor must be chos...

Page 174: ...h one scheme while the T zone is protected with a separate differential protection scheme The 1Ph high impedance differential HZPDIF 87 function in the IED allows this to be done efficiently see Figure 62 Section 7 1MRK 502 071 UUS A Differential protection 168 Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 Application manual ...

Page 175: ...SI05000165 V1 EN US 3 87 ANSI05000739 2 en vsd ANSI05000739 V2 EN US 1MRK 502 071 UUS A Section 7 Differential protection Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 169 Application manual ...

Page 176: ...sformer ratio 2000 5A CT Class C800 At max tap of 2000 5A Secondary resistance 0 5 Ohm 2000 5A tap Cable loop resistance 2 Max fault current Equal to switchgear rated fault current 40 kA Calculation 40000 0 5 0 4 90 400 VR V EQUATION1751 ANSI V1 EN US Equation 20 Select a setting of TripPickup 100 V The current transformer saturation voltage must be at least twice the set operating voltage TripPic...

Page 177: ... The selection of the stabilizing resistor and the level of the magnetizing current mostly dependent of the number of turns are the most important factors 7 2 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 funct...

Page 178: ...igh impedance protection is used This helps in utilizing maximum CT capability minimize the secondary fault thereby reducing the stability voltage limit Another factor is that during internal faults the voltage developed across the selected tap is limited by the non linear resistor Section 7 1MRK 502 071 UUS A Differential protection 172 Generator protection REG670 2 2 ANSI and Injection equipment...

Page 179: ...768 ANSI V1 EN US Equation 23 Select a setting of TripPickup 30 V The current transformer knee point voltage must be at least twice the set operating voltage TripPickup 2 0 1 100 0 7 147 V VkneeANSI EQUATION1779 ANSI V2 EN US Equation 24 that is greater than 2 ˣ TripPickup Check from the table of selected resistances the required series stabilizing resistor value to use Since this application requ...

Page 180: ... earth faults in the transformer winding Sensitivities of 2 8 can be achieved whereas the normal differential function will have sensitivities of 20 40 The sensitivity for high impedance restricted ground fault function is mostly dependent on the current transformers magnetizing currents The connection of a restricted earth fault function is shown in Figure 64 It is connected across each directly ...

Page 181: ...ited to approx 0 05 Ohms at 75 C gives loop resistance 2 ˣ 0 05 0 1 Ohms Max fault current The maximum through fault current is limited by the transformer reactance use 15 ˣ rated current of the transformer Calculation 250 15 0 1 0 1 6 25 600 5 VR V EQUATION1775 ANSI V1 EN US Equation 26 Select a setting of TripPickup 40 V The current transformerknee point voltage can roughly be calculated from th...

Page 182: ...on is normally high which means that the function will in many cases operate also for short circuits or open current transformer secondary circuits However the stabilizing resistor can be selected to achieve sensitivity higher than normal load current and or separate criteria can be added to the operation like a check zone This can be either another IED with the same HZPDIF 87 function or be a che...

Page 183: ...tator windings causes normally very large fault currents The short circuit generates risk of damages on insulation windings and stator core The large short circuit currents cause large current forces which can damage other components in the power plant such as turbine and generator turbine shaft The short circuit can also initiate explosion and fire When a short circuit occurs in a generator there...

Page 184: ...rcuits shall be relatively sensitive thus detecting small fault currents It is also of great importance that the generator short circuit protection does not trip for external faults when large fault current is fed from the generator In order to combine fast fault clearance sensitivity and selectivity the Generator current differential protection GENPDIF 87G is normally the best choice for phase to...

Page 185: ...s in the differential function Percentage restrained differential analysis DC 2nd and 5th harmonic analysis Internal external fault discriminator Adaptive frequency tracking must be properly configured and set for the Signal Matrix for analog inputs SMAI preprocessing blocks in order to ensure proper operation of the generator differential protection function during varying frequency conditions 1M...

Page 186: ...h a transformer differential protection within the same IED the direction of the terminal CT may be referred towards the step up transformer This will give wrong reference direction for the generator differential protection This can be adjusted by setting the parameter InvertCT2curr to Yes Operation GENPDIF 87G is set Enabled or Disabled with this setting 7 3 3 2 Percentage restrained differential...

Page 187: ...mes the generator rated current EndSection1 is proposed to be set to 1 25 times the generator rated current In section 2 a certain minor slope is introduced which is supposed to cope with false differential currents proportional to higher than normal currents through the current transformers EndSection2 is proposed to be set to about 3 times the generator rated current The SlopeSection2 defined as...

Page 188: ...Diff is set to Yes for activation of the negative sequence differential features both the internal or external fault discrimination and the sensitive negative sequence differential current feature It is recommended to have this feature enabled IMinNegSeq IMinNegSeq is the setting of the smallest negative sequence current when the negative sequence based functions shall be active This sensitivity c...

Page 189: ...rmal load condition An alarm signal can also be issued to station operational personnel to make remedy action once the open CT condition is detected The following setting parameters are related to this feature Setting parameter OpenCTEnable enables disables this feature Setting parameter tOCTAlarmDelay defines the time delay after which the alarm signal will be given Setting parameter tOCTReset de...

Page 190: ...er electronic converters a higher setting might be used to prevent unwanted blocking TempIdMin If the binary input raise pick up DESENSIT is activated the operation level of IdMin is increased to the TempIdMin Section 1 Operate conditionally UnrestrainedLimit Section 2 Section 3 Restrain Operate unconditionally 5 4 3 2 1 0 0 1 2 3 4 5 IdMin EndSection1 EndSection2 restrain current times IBase oper...

Page 191: ...haracteristics It is also recommended to set the parameter OperDCBiasing Enabled for all shunt reactor applications The DC component is always calculated from the instantaneous differential current for each phase in primary Amperes The value of DC component can be read from function outputs IDDCL1 IDDCL2 and IDDCL3 For special purpose the DC component from phase currents can also be calculated by ...

Page 192: ... connected windings or through a separate grounding transformer in case of delta connected windings The low impedance restricted ground fault protection REFPDIF 87N is a winding protection function It protects the power transformer winding against faults involving ground Observe that single phase to ground faults are the most common fault types in transformers Therefore a sensitive ground fault pr...

Page 193: ...on is shown in Figure 72 REFPDIF 87N I3P I3PW1CT1 ANSI05000210_3_en vsd ANSI05000210 V3 EN US Figure 72 Connection of the low impedance Restricted earth fault function REFPDIF 87N for a directly solidly grounded transformer winding 7 4 2 2 Transformer winding grounded through Zig Zag grounding transformer M13048 8 v10 A common application is for low reactance grounded transformer where the groundi...

Page 194: ...0211_3_en vsd ANSI05000211 V3 EN US Figure 73 Connection of the low impedance Restricted earth fault function REFPDIF for a zig zag grounding transformer Section 7 1MRK 502 071 UUS A Differential protection 188 Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 Application manual ...

Page 195: ...W2CT1 REFPDIF 87N ANSI05000212 4 en vsd ANSI05000212 V4 EN US Figure 74 Connection of restricted ground fault low impedance function REFPDIF 87N for an autotransformer solidly grounded 7 4 2 4 Reactor winding solidly grounded M13048 18 v10 Reactors can be protected with restricted ground fault protection low impedance function REFPDIF 87N The connection of REFPDIF 87N for this application is shown...

Page 196: ...rangements have two sets of current transformers on the phase side The restricted earth fault protection low impedance function REFPDIF 87N has inputs to allow two current inputs from each side of the transformer The second winding set is only applicable for autotransformers A typical connection for a star delta transformer is shown in figure 76 Section 7 1MRK 502 071 UUS A Differential protection...

Page 197: ...lways uses reference directions towards the protected transformers as shown in Figure 76 Thus the IED always measures the primary currents on all sides and in the neutral of the power transformer with the same reference direction towards the power transformer windings The grounding can be freely selected for each of the involved current transformers 7 4 3 Setting guidelines IP14942 1 v1 7 4 3 1 Se...

Page 198: ...t is activated when all operating criteria are fulfilled DIR_INT The output is activated when the directional criteria has been fulfilled BLK2H The output is activated when the function is blocked due to high level of second harmonic 7 4 3 2 Settings M13052 28 v13 The parameters for the restricted earth fault protection low impedance function REFPDIF 87N are set via the local HMI or PCM600 Common ...

Page 199: ...rimary rating IBase CTFactorPri2 A factor to allow a sensitive function also at multi breaker arrangement where the rating in the bay is much higher than the rated current of the transformer winding The stabilizing can then be high so an unnecessary high fault level can be required The setting is normally 1 0 but in multi breaker arrangement the setting shall be CT primary rating IBase CTFactorSec...

Page 200: ...194 ...

Page 201: ...ection in order to protect generator against sustained faults The mho distance protection in REG670 can be used for this purpose if the following guidelines are followed Configuration for every zone is identical 8 1 3 Setting guidelines SEMOD154496 1 v2 8 1 3 1 Configuration GUID 5EB33045 361C 4849 8E53 C793A209E3FA v3 First of all it is required to configure the Mho function in the way shown in f...

Page 202: ...D 40EE B579 5DFA16144C20 v4 Full scheme distance measuring Mho characteristic ZMHPDIS 21 used as an under impedance function shall be set for the application example shown in figure 78 Section 8 1MRK 502 071 UUS A Impedance protection 196 Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 Application manual ...

Page 203: ...3kV xt 10 REG670 IEC10000102 V1 EN US Figure 78 Application example for generator under impedance function The first under impedance protection zone shall cover 100 of the step up transformer impedance with a time delay of 1 0s 1MRK 502 071 UUS A Section 8 Impedance protection Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 197 Application manual ...

Page 204: ...rimary ohms for forward and reserve reach and time delay shall be entered accordingly Parameter ZPP shall be set to 0 260Ω Parameter ZrevPP shall be set to 0 260Ω Parameter tPP shall be set to 1 0000s Parameter ZAngPP shall be set to default value 85 Deg Set the following for the directional element ZDMRDIR The parameter GlobalBaseSel shall be set in order to select the global base value group GBA...

Page 205: ...cation description below only if VT and CT of the line feeder are wired to REG670 8 2 1 Identification GUID 8ACD3565 C607 4399 89D2 A05657840E6D v3 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number High speed distance protection zone ZMFPDIS S00346 V1 EN US 21 1MRK 502 071 UUS A Section 8 Impedance protection Generator protection REG670 2 2 ANSI a...

Page 206: ... below Solidly grounded networks GUID 6B0F02F4 18ED 415E 8D48 0A1648F7CE00 v2 In solidly grounded systems the transformer neutrals are connected directly to ground without any impedance between the transformer neutral and ground ANSI05000215 V2 EN US Figure 80 Solidly grounded network The ground fault current is as high or even higher than the short circuit current The series impedances determine ...

Page 207: ...ways be complemented with other protection function s that can carry out the fault clearance in those cases Effectively grounded networks GUID 39CAF169 315E 4E3E 9EE6 28CBF624B90E v5 A network is defined as effectively grounded if the ground fault factor fe is less than 1 4 The ground fault factor is defined according to equation 31 max e pn V f V ANSIEQUATION1268 V1 EN US Equation 31 Where Vmax i...

Page 208: ...ugh high impedance mostly a reactance in parallel with a high resistor This type of network is often operated radially but can also be found operating as a meshed network What is typical for this type of network is that the magnitude of the ground fault current is very low compared to the short circuit current The voltage on the healthy phases will get a magnitude of 3 times the phase voltage duri...

Page 209: ...r the sensitivity will be too low for acceptance For this reason a separate high sensitive ground fault protection is necessary to carry out the fault clearance for single phase to ground fault For cross country faults and when using phase preference it is necessary to make sure that the distance protection is operating in the phase to earth loops independently whenever possible See guidelines for...

Page 210: ...h compensates the overreach tendency of zone 1 at the exporting end No settings are required for this feature 8 2 2 3 Load encroachment GUID 6785BF05 2775 4422 8077 A663D01C6C07 v6 In some cases the measured load impedance might enter the set zone characteristic without any fault on the protected line This phenomenon is called load encroachment and it might occur when an external fault is cleared ...

Page 211: ... long lines For short lines the major concern is to get sufficient fault resistance coverage Load encroachment is not a major problem R X Zm RldRev R Zm RLdFwd ZL ANSI05000495_2_en vsd Load impedance area in forward direction LdAngle LdAngle LdAngle LdAngle ANSI05000495 V2 EN US Figure 83 Load encroachment phenomena and shaped load encroachment characteristic 1 8 2 2 4 Short line application GUID ...

Page 212: ...not impossible to apply distance protection for short lines It is possible to apply an overreaching pilot communication based POTT or Blocking scheme protection for such lines to have fast tripping along the entire line Usually a unit protection based on comparison of currents at the ends of the lines is applied for such lines 8 2 2 5 Long transmission line application GUID 0C99A197 06CD 4668 A017...

Page 213: ...pedances for positive and negative sequence are very small 1 2 of the self impedance and it is a common practice to neglect them From an application point of view there exists three types of network configurations classes that must be considered when making the settings for the protection function The different network configuration classes are 1 Parallel line with common positive and zero sequenc...

Page 214: ...es are 1 Parallel line in service 2 Parallel line out of service and grounded 3 Parallel line out of service and not grounded Parallel line in service GUID 22E1A46C 92BD 4EE4 9A2D 9EFE2DB7B4D8 v3 This type of application is very common and applies to all normal sub transmission and transmission networks Let us analyze what happens when a fault occurs on the parallel line see figure 84 From symmetr...

Page 215: ...hen mutual coupling is introduced the voltage at the relay point A will be changed according to equation 39 0 0 0 0 1 1 3 3 3 1 3 1 m L L ph p ph L L L Z Z Z V Z I I I Z Z æ ö ç è ø EQUATION1276 V4 EN US Equation 39 By dividing equation 39 by equation 38 and after some simplification we can write the impedance present to the relay at A side as 3 0 1 1 3 0 æ ö ç è ø L I KNm Z Z I ph I KN EQUATION12...

Page 216: ...EQUATION1278 V4 EN US Equation 41 One can also notice that 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 42 Simplification of equation 42 solving it for 3I0p and substitution of the result into equation 41 gives that the voltage can be drawn as 0 0 3 p p 3 2 p 1 A L ph N Nm I V Z I K I K æ ö ç è ø EQUATION1280 V2 E...

Page 217: ...NSI05000222 V1 EN US Figure 86 The parallel line is out of service and grounded When the parallel line is out of service and grounded at both line ends on the bus bar side of the line CTs so that zero sequence current can flow on the parallel line the equivalent zero sequence circuit of the parallel lines will be according to figure 87 A B C IEC09000252_1_en vsd I0 I0 Z0m Z0 Z0m Z0 Z0m IEC09000252...

Page 218: ...NT11520 IMG3503 V2 EN US Equation 47 Parallel line out of service and not grounded GUID 949669D3 8B9F 4ECA 8F09 52A783A494E1 v2 Z0m A OPEN 21 21 en05000223_ansi vsd CLOSED OPEN CLOSED B ANSI05000223 V1 EN US Figure 88 Parallel line is out of service and not grounded When the parallel line is out of service and not grounded the zero sequence on that line can only flow through the line admittance to...

Page 219: ... K Z Z Z R Z Z R EQUATION1284 V1 EN US Equation 48 This means that the reach is reduced in reactive and resistive directions If the real and imaginary components of the constant A are equal to equation 49 and equation 50 Re 0 2 1 0 3 0 0 2 1 A R R R Rf X X X EQUATION1285 V1 EN US Equation 49 0 1 0 1 0 1 0 Im 2 3 2 A X R R R R X X EQUATION1286 V1 EN US Equation 50 The real component of the KU facto...

Page 220: ...D1A v1 C A B BC ANSI05000224 2 en vsd ANSI05000224 V2 EN US Figure 90 Example of tapped line with Auto transformer This application gives rise to similar problem that was highlighted in section Fault infeed from remote end that is increased measured impedance due to fault current infeed For example for faults between the T point and B station the measured impedance at A and C will be Section 8 1MR...

Page 221: ...e 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 reverse direction from B to C depending on the system parameters see the dotted line in figure 90 given that the distance protection in B to T will measure wrong d...

Page 222: ... to ground RFPGZx and phase to phase RFPPZx should be as high as possible without interfering with the load impedance in order to obtain reliable fault detection 8 2 3 Setting guidelines IP14962 1 v1 8 2 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 ...

Page 223: ...500474DB v2 The first overreaching zone normally zone 2 must detect faults on the whole 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 remote end is con...

Page 224: ...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 line IED for the telecommunication purposes Consider the possible enlarging factor that might exist due to...

Page 225: ...in service with a single phase to ground 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 85 in section Parallel line in service The components of the zero sequence impedance for the overreaching zones must be equal to at least R0E R0 Rm0 EQUATION553 V1 EN US Equation 58 X0E X0 Xm0 EQUATION554 V1 EN US Equation ...

Page 226: ... the reach with respect to load GUID ED84BDE6 16CD 45ED A45D 5CFB828A9040 v6 Set separately the expected fault resistance for phase to phase faults RFPPZx and for the phase to ground faults RFPGZx for each zone For each distance zone set all remaining reach setting parameters independently of each other The final reach in the resistive direction for phase to ground fault loop measurement automatic...

Page 227: ...h the settings RLdFwd and RldRev XLd is representing a per phase load impedance of a symmetrical star coupled representation For a symmetrical load or three phase and phase to phase faults this means per phase or positive sequence impedance During a phase to earth fault it means the per loop impedance including the earth return impedance 8 2 3 7 Zone reach setting lower than minimum load impedance...

Page 228: ...ound faults both phase to phase and phase to ground fault operating characteristics should be considered To avoid load encroachment for the phase to ground measuring elements the set resistive reach of any distance protection zone must be less than 80 of the minimum load impedance load RFPG 0 8 Z EQUATION1720 V1 EN US Equation 71 This equation is applicable only when the loop characteristic angle ...

Page 229: ...ce GUID 78D0227F 2568 4C9A 8921 45812B4ABAF2 v5 The impedance zones are enabled as soon as the symmetrical load impedance crosses the vertical boundaries defined by RLdFwd and RldRev or the lines defined by ArgLd So it is necessary to consider some margin It is recommended to set RLdFwd and RldRev to 90 of the per phase resistance that corresponds to maximum load The absolute value of the margin t...

Page 230: ... the phase to ground reach RFPG of all instantaneous zones has to be set below the emergency 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 ground reach according to the pole open scenar...

Page 231: ...ection for zones Z3 Z4 and Z5 the directionality of zones Z1 Z2 and ZRV is fixed The options are Non directional Forward or Reverse The result from respective set value is illustrated in figure93 where the 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 93 Directional operating m...

Page 232: ... 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 nominal to rest...

Page 233: ...faults two ground faults at the same time one each on the two circuits of a double line One specific situation where the 3I0Enable_PG setting should be altered is for cross country faults in high impedance grounded networks in order to make sure that operation is phase to ground This is particularly important when using phase preference logic since it is only working per phase not for phase to pha...

Page 234: ...d distance protection zone zone 1 6 ZMFCPDIS S00346 V1 EN US 21 8 3 2 Application IP14961 1 v2 GUID 12188AB4 5922 428B 86F5 5F3897D29807 v3 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 t...

Page 235: ...it current The series impedances determine the magnitude of the fault current The shunt admittance has very limited influence on the ground fault current The shunt admittance may however have some marginal influence on the ground fault current in networks with long transmission lines The ground fault current at single phase to ground in phase A can be calculated as equation 76 A A 0 1 2 0 f 1 N f ...

Page 236: ... factor is defined according to equation 77 max e pn V f V ANSIEQUATION1268 V1 EN US Equation 77 Where Vmax is the highest fundamental frequency voltage on one of the healthy phases at single phase to ground fault Vpn is the phase to ground fundamental frequency voltage before fault Another definition for effectively grounded network is when the following relationships between the symmetrical comp...

Page 237: ...carry out the fault clearance for single phase to ground fault 8 3 2 2 Fault infeed from remote end GUID DDFE8B5C A064 4956 B8BB 49DEAC38558E v3 All transmission and most sub transmission networks are operated meshed Typical for this type of network is that fault infeed from remote end will happen when fault occurs on the protected line The fault current infeed will enlarge the fault impedance see...

Page 238: ...ay of avoiding this situation is to set the distance zone resistive reach with a security margin to the minimum load impedance The drawback with this approach is that the sensitivity of the protection to detect resistive faults is reduced The IED has a built in function which shapes the characteristic according to the right part of figure 97 The load encroachment algorithm will increase the possib...

Page 239: ...o the protected line s impedance SIR SIR s of about 4 or greater generally define a short line Medium lines are those with SIR s greater than 0 5 and less than 4 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 su...

Page 240: ... be a major concern It is well known that it is difficult to achieve high sensitivity for phase to ground fault at remote line end of long lines when the line is heavy loaded What can be recognized as long lines with respect to the performance of distance protection can generally be described as in table 28 long lines have Source impedance ratio SIR s less than 0 5 Table 28 Definition of long and ...

Page 241: ...need not be of the same voltage in order to have mutual coupling and some coupling exists even for lines that are separated 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 n...

Page 242: ...ence mutual coupling on the measurement at single phase to ground faults in the following ways by using The possibility of different setting values that influence the ground return compensation for different distance zones within the same group of setting parameters Different groups of setting parameters for different operating conditions of a protected multi circuit line Most multi circuit lines ...

Page 243: ...nce Z0 is zero sequence impedance Z0m A B 21 21 en05000221_ansi vsd FAULT ANSI05000221 V1 EN US Figure 99 Class 1 parallel line in service The equivalent circuit of the lines can be simplified see figure 100 A B C Z0m Z0m Z0 Z0m Z0 IEC09000253_1_en vsd IEC09000253 V1 EN US Figure 100 Equivalent zero sequence impedance circuit of the double circuit parallel operating line with a single phase to gro...

Page 244: ...pposite 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 Maximum overreach will occur if the fault current infeed from remote line end is weak If considering a single phase to ground fault at p unit of the line length from A to B on the parallel line for the case when the fau...

Page 245: ...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 at one line end it is proportionally increased at the opposite line end So this 15 reach reduction does not sign...

Page 246: ...nsiderable 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 zero sequence mutua...

Page 247: ...mpedance 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 impedance is set according to the conditions when the parallel system is out of operation and grounded at both ends A B C IEC09000255_1_en vsd I0 I0 Z0m Z0 Z0m Z0m Z0...

Page 248: ... Im K A X A A u m 1 0 2 2 2 EQUATION1287 V3 EN US Equation 95 The imaginary component of the same factor is equal to equation 96 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 96 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 3 2 7 Tapped line application GUID 4DFD6015 E...

Page 249: ...en the T point and B station the measured impedance at A and C will be ZA ZAT ZTF IA IC IA DOCUMENT11524 IMG3509 V3 EN US Equation 97 A C 2 C Trf CT TB C I I V2 Z Z Z Z V1 I EQUATION1714 V1 EN US Equation 98 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 Table continues on next ...

Page 250: ...ion it might be necessary to accept zone 2 trip in one end or sequential trip in one end Generally for this type of application it is difficult to select settings of zone 1 that both gives overlapping of the zones with enough sensitivity without interference with other zone 1 settings that is without selectivity conflicts Careful fault calculations are necessary to determine suitable settings and ...

Page 251: ...wer transfer capability by raising the dynamic stability limit Improved reactive power balance Increase in power transfer capacity Reduced costs of power transmission due to decreased investment costs for new power lines 8 3 3 1 Steady state voltage regulation and increase of voltage collapse limit GUID 0AB9B4B5 92DF 4A3B 9046 FC3A460DA658 v1 A series capacitor is capable of compensating the volta...

Page 252: ... power line with 0 30 50 and 70 of compensation 8 3 3 2 Increase in power transfer GUID C9163D4E CC2B 4645 B2AC 2C8A3FE3D337 v3 The increase in power transfer capability as a function of the degree of compensation for a transmission line can be explained by studying the circuit shown in figure 108 The power transfer on the transmission line is given by the equation 102 A B A B Line C Line C V V si...

Page 253: ...0F F4FA 4646 9235 AE6DB0255E80 v1 Series capacitors influence the magnitude and the direction of fault currents in series compensated networks They consequently influence phase angles of voltages measured in different points of series compensated networks and this performances of different protection functions which have their operation based on properties of measured voltage and current phasors V...

Page 254: ...nt by 90 degrees Voltage drop DVC on series capacitor lags the fault current by 90 degrees Note that line impedance XL1 could be divided into two parts one between the IED point and the capacitor and one between the capacitor and the fault position The resulting voltage VM in IED point is this way proportional to sum of voltage drops on partial impedances between the IED point and the fault positi...

Page 255: ...s in series compensated networks depend on their operating principle The most known effect has voltage inversion on directional measurement of distance IEDs see chapter Distance protection for more details which must for this reason comprise special measures against this phenomenon There will be no voltage inversion phenomena for reverse faults in system with VTs located on the bus side of series ...

Page 256: ...ed lines and in cases when the capacitor is bypassed either by spark gap or by the bypass switch as shown in phasor diagram in figure 113 The resultant reactance is in this case of inductive nature and the fault currents lags source voltage by 90 electrical degrees The resultant reactance is of capacitive nature in the second case Fault current will for this reason lead the source voltage by 90 el...

Page 257: ...y 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 negative sequence currents should be considered in studies as well Current inversion...

Page 258: ...case with line side instrument transformers The protective devices will not be exposed to voltage and current inversion for faults on the protected line which increases the dependability Distance protection zone 1 may be active in most applications which is not the case when the bus side instrument transformers are used Distance IEDs are exposed especially to voltage inversion for close in reverse...

Page 259: ...ure 115 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 capacitor bank spark gap or MOV and SC location on protected power line en06000612_ansi vsd EA 0 33 50 66 KC 80 33 33 50 21 100 80 X ANSI0600061...

Page 260: ...e wrong directional measurement Such cases are presented in figure 116 for 50 compensation at 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 116 80 compensation at lo...

Page 261: ... US Figure 118 Equivalent impedance of MOV protected capacitor in dependence of protection factor KP Figure 118 presents three typical cases for series capacitor located at line end case LOC 0 in figure 116 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...

Page 262: ...oltage inversion in series compensated network due to fault current infeed Voltage at the B bus as shown in figure 119 is calculated for the loss less system according to the equation below B D B LB A B LF C B LB V V I jX I I j X X I jX EQUATION1998 ANSI V1 EN US Equation 108 Further development of equation 108 gives the following expressions 1 é ù æ ö ê ç ú è ø ë û A B B LB LF C B I V jI X X X I ...

Page 263: ...uct at all At the same time this kind of investigation must consider also the maximum sensitivity and possible resistive reach of distance protection devices which on the other hand simplifies the problem Application of MOVs as non linear elements for capacitor overvoltage protection makes simple calculations often impossible Different kinds of transient or dynamic network simulations are in such ...

Page 264: ...istance underreaching protection zone must be set to a reach less than the reactance of the compensated line in accordance with figure 120 en06000618 vsd X11 X12 jXC A B DA DB Zone 1A Zone 1B Zone 2A Zone 2B G IEC06000618 V1 EN US Figure 120 Underreaching Zone 1 and overreaching Zone 2 on series compensated line The underreaching zone will have reduced reach in cases of bypassed series capacitor a...

Page 265: ...kind of directional or unit protection must be used The overreach must be of an order so it overreaches when the capacitor is bypassed or out of service Figure 122 shows the permissive zones The first underreaching zone can be kept in the total protection but it only has the feature of a back up protection for close up faults The overreach is usually of the same order as the permissive zone When t...

Page 266: ...tive voltage drop on XC is amplified and a protection far away from the faulty line can maloperate by its instantaneous operating distance zone if no precaution is taken Impedances seen by distance IEDs on adjacent power lines are presented by equations 113 to 116 1 2 3 I I I I EQUATION1915 V1 EN US Equation 113 X X I I X X DA A F A C 1 1 1 11 EQUATION1916 V2 EN US Equation 114 X X I I X X DA A F ...

Page 267: ...actance and voltage inversion phenomenon may occur also on remote end of adjacent lines Distance protection of such line must have built in functionality which applies normally to protection of series compensated lines It usually takes a bit of a time before the spark gap flashes and sometimes the fault current will be of such a magnitude that there will not be any flashover and the negative imped...

Page 268: ... a case by case basis as shown in figure 124 Distance IEDs with separate impedance and directional measurement offer additional setting and operational flexibility when it comes to measurement of negative apparent impedance as shown in figure 125 Negative IED impedance negative fault current current inversion GUID F858877A E736 4B1C 97B4 8A2B5F8EE644 v2 If equation 119 is valid in Figure 112 and a...

Page 269: ...trically close vicinity to each other and ending at the same busbar at both ends as shown in figure 126 causes some challenges for distance protection because of the mutual impedance in the zero sequence system The current reversal phenomenon also raises problems from the protection point of view particularly when the power lines are short and when permissive overreach schemes are used en06000627 ...

Page 270: ...arrier signal CSAB to the remote line end where this signal will be received as a carrier receive signal CRBB en06000629_ansi vsd RAA RBA IFC1 IFC1 X F RAB RBB IFC2 CSAB CRBB RAA RBA IFC1 X F RAB RBB IFC2 CSAB CRBB ANSI06000629 V1 EN US Figure 128 Current reversal phenomenon on parallel operating circuits It is possible to expect faster IED operation and breaker opening at the bus closer to fault ...

Page 271: ...n must be provided 8 3 4 Setting guidelines IP14962 1 v1 8 3 4 1 General GUID B9958CEF 90ED 4644 B169 C6B4A018193B v1 The settings for Distance measuring zones quadrilateral characteristic ZMFCPDIS 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 ZM...

Page 272: ...y higher than the fault current that comes from behind of the IED towards the fault The setting must 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 remo...

Page 273: ...er 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 so on Zrev 1 2 Z2rem ZL _ GUID ABFB1C53 F12A 45D5 90CC 907C9FA0EFC3 V1 EN US Equation 122 Where ZL is the protected line impedance Z2rem is the zone 2 setting zone used in the POT...

Page 274: ...erent settings of the reach for the zone ZMFCPDIS 21 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 reaching zone 1 must be further reduced Zone 1 can only be set with...

Page 275: ...ary 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 ground 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 single phase to groun...

Page 276: ...ce up to the series capacitor in the picture 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 130 When the calculation of X1Fwgives a negative value the zone 1 must be permanently blocked Section 8 1MRK 502 071 UUS A Impedance protection 270 Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 Applicatio...

Page 277: ...ing zone 2 GUID F3704F5E 5604 470D 829F C4594329ABFB v2 In series compensated network where independent tripping zones will have reduced reach due to the negative reactance in the capacitor and the 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 alon...

Page 278: ...itional distance protection zones zone 4 for example are used they must be set according to the influence of the series capacitor 8 3 4 6 Setting of zones for parallel line application GUID E1228762 EBF7 4E58 9A52 96C5D22A0F0D 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 ...

Page 279: ...B K B B EQUATION1428 V2 EN US Equation 128 Parallel line is out of service and grounded in both ends GUID EC052207 C9AF 47EC 999A BD485378FD9E v1 Apply the same measures as in the case with a single set of setting parameters This means that an underreaching zone must not overreach the end of a protected circuit for the single phase to ground faults Set the values of the corresponding zone zero seq...

Page 280: ...1 EN US Equation 133 The fault resistance for phase to phase faults is normally quite low compared to the fault resistance for phase to ground faults To minimize the risk for overreaching limit the setting of the zone 1 reach in resistive direction for phase to phase loop measurement to 6 1 RFPPZx X Zx IECEQUATION2306 V3 EN US Equation 134 Note that RLdFwd and RldRev are not only defining the load...

Page 281: ... 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 min load max Z V 3 I EQUATION1719 V1 EN US Equation 136 Minimum voltage Vmin and maximum current Imax are related to the same operating conditions Minimum load impedance occurs normally under emergency conditions To avoid load encroac...

Page 282: ... Power swing detection function ZMRPSB 78 is activated in the IED Use an additional safety margin of approximately 20 in cases when a ZMRPSB 78 function is activated in the IED refer to the description of Power swing detection function ZMRPSB 78 8 3 4 9 Zone reach setting higher than minimum load impedance GUID 78D0227F 2568 4C9A 8921 45812B4ABAF2 v5 The impedance zones are enabled as soon as the ...

Page 283: ... of that phase increase there is actually no way of distinguish this from a real fault with similar characteristics Should this accidental event be given precaution the phase to ground reach RFPG of all instantaneous zones has to be set below the emergency 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 preced...

Page 284: ...ral characteristic for the three Ph E measuring loops DirModeZx These settings define the operating direction for Zones Z3 Z4 and Z5 the directionality of zones Z1 Z2 and ZRV is fixed The options are Non directional Forward or Reverse The result from respective set value is illustrated in figure 133 below where positive impedance corresponds to the direction out on the protected line IEC05000182 2...

Page 285: ...rcuit is always involved during transient conditions regardless of voltage level This option should also be used for types that do not fall under the other two categories for example CVTs with power electronic damping devices or if the type cannot be identified at all None Magnetic This option should be selected if the voltage transformer is fully magnetic 3I0Enable_PG This setting opens up an opp...

Page 286: ...e in the data class MV measured value with the type ENUMERATED normal high low high high and low low in ZMFCPDIS ZMMMXU ZLimHys Hysteresis value in of range ZMax ZMin common for all limits It is used to avoid the frequent update of the value for the attribute range ZMax Estimated maximum impedance value An impedance that is higher than ZMax has the quality attribute as Out of Range ZMin Estimated ...

Page 287: ...l power grid close to the generator If the fault clearance time is too long the generator will accelerate so much so the synchronism cannot be maintained The relative generator phase angle at a fault and pole slip relative to the external power system is shown in figure 134 en06000313 vsd IEC06000313 V1 EN US Figure 134 Relative generator phase angle at a fault and pole slip relative to the extern...

Page 288: ...a three phase If this point is situated in the generator itself the generator should be tripped as fast as possible If the locus of the out of step centre is located in the power system outside the generators the power system should if possible be split into two parts and the generators should be kept in service This split can be made at predefined locations trip of predefined lines after function...

Page 289: ...will absorb a significant amount of reactive power thus risking overload of the windings PSPPPAM 78 function shall detect out of step conditions and trip the generator as fast as possible if the locus of the pole slip is inside the generator If the centre of pole slip is outside the generator situated out in the power grid the first action should be to split the network into two parts after line p...

Page 290: ...the forward impedance as show in figure 136 ZA should be the sum of the transformer impedance XT and the equivalent impedance of the external system ZS The impedance is given in of the base impedance according to equation 143 3 Base UBase Z IBase EQUATION1883 V1 EN US Equation 143 Section 8 1MRK 502 071 UUS A Impedance protection 284 Generator protection REG670 2 2 ANSI and Injection equipment REX...

Page 291: ...he rotor angle gets below the set TripAngle The default value 90 is recommended N1Limit The setting N1Limit gives the number of pole slips that should occur before trip if the crossing of the slip line ZA ZB is 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 st...

Page 292: ...cation of pole slip protection If the apparent impedance crosses the impedance line ZB ZA this is the detection criterion of out of step conditions see figure 138 Section 8 1MRK 502 071 UUS A Impedance protection 286 Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 Application manual ...

Page 293: ...ce in the forward direction AnglePhi The impedance phase angle Use the following data 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 1MRK 502 071 UUS A Section 8 Impedan...

Page 294: ...orresponds to 2 52 0 0125 0 325 0 325 88 160 j ZA j pu pu Ð EQUATION1962 V1 EN US Equation 146 Set ZA to 0 32 2 400 1 32 5000 ZB Zsc station j j ohm EQUATION1963 V1 EN US Equation 147 This corresponds to 32 0 20 0 20 90 160 j ZB j pu pu Ð EQUATION1964 V1 EN US Equation 148 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 149 Set ZC to 0...

Page 295: ...0016 vsd IEC07000016 V1 EN US Figure 139 Simplified figure to derive StartAngle 0 0 32 52 arctan arctan arctan arctan 21 8 33 0 55 80 80 ZB ZA angleStart Zload Zload EQUATION1968 V2 EN US Equation 151 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 to 110 1MRK 502 071 UUS A Section 8 I...

Page 296: ...mit is set to 1 In other cases a larger number is recommended 8 4 3 2 Setting example for generator application SEMOD172162 90 v4 In case of out of step conditions this shall be checked if the pole slip centre is inside the generator zone 1 or if it is situated in the network zone 2 ZC ZA ZB en07000017 vsd IEC07000017 V1 EN US Figure 140 Generator application of pole slip protection If the apparen...

Page 297: ...ion are ZA Block transformer 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 VBase 20 kV SBase set to 200 MVA Xd 25 1MRK 502 071 UUS A Section 8 Impedance protection Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 291 Application ma...

Page 298: ...ase as reference 2 2 20 2 0 200 UBase ZBase ohm SBase EQUATION1969 V1 EN US Equation 152 2 2 20 20 0 15 0 38 200 5000 ZA Z transf Zsc network j j j ohm EQUATION1970 V1 EN US Equation 153 This corresponds to 0 38 0 19 0 19 90 2 0 j ZA j pu pu Ð EQUATION1971 V1 EN US Equation 154 Set ZA to 0 19 2 20 0 25 0 5 200 d ZB jX j j ohm EQUATION1972 V2 EN US Equation 155 This corresponds to 0 5 0 25 0 25 90 ...

Page 299: ...le should be chosen not to cross into normal operating area The maximum line power is assumed to be 200 MVA This corresponds to apparent impedance 2 2 20 2 200 U Z ohm S EQUATION1976 V1 EN US Equation 159 Simplified the example can be shown as a triangle see figure 142 1MRK 502 071 UUS A Section 8 Impedance protection Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX06...

Page 300: ...art angle with large margin Set StartAngle to 110 For the TripAngle it is recommended to set this parameter to 90 to assure limited stress for the circuit breaker If the centre of pole slip is within the generator block set N1Limit to 1 to get trip at first pole slip If the centre of pole slip is within the network set N2Limit to 3 to get enable split of the system before generator trip Section 8 ...

Page 301: ... 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 fault has been cleared If the generator loses synchronism Out of step with the rest of the system pole slipping occurs This is characterized by a wild flow of synchronizing power which reverse...

Page 302: ...her protection relays their locations and settings require 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 c...

Page 303: ... the synchronism cannot be maintained even if the power system is restored to the pre fault configuration see Figure 144 0 500 1000 1500 2000 2500 3000 0 95 1 1 05 1 1 time in milliseconds Generator rotational speed in per unit unstable stable 260 ms 200 ms 3 ph fault For fault clearing time 200 ms generator remains stable and in synchronism After oscillations around the nominal speed the rotation...

Page 304: ... of a swing 4 Detect the first and the subsequent pole slips 5 Prevent stress on the circuit breaker 6 Distinguish between generator and motor out of step conditions 7 Provide information for post disturbance analysis 8 5 3 Setting guidelines GUID CB86FCF6 8718 40BE BDF2 028C24AB367D v6 The setting example for generator protection application shows how to calculate the most important settings Forw...

Page 305: ... two machine equivalent system or as a single machine infinite bus equivalent power system Then the impedances from the position of the Out of step protection in the direction of the normal load flow can be taken as forward The settings ForwardX ForwardR ReverseX and ReverseR must if possible take into account the post disturbance configuration of the simplified power system This is not always eas...

Page 306: ...e value of this setting Whenever the complex impedance Z R X enters the lens this is a sign of instability The angle recommended is 110 or 120 degrees because it is at this rotor angle where problems with dynamic stability usually begin Power angle 120 degrees is sometimes called the angle of no return because if this angle is reached under generator swings the generator is most likely to lose syn...

Page 307: ...with centre of the electromagnetic oscillation within zone 1 are ignored Default setting Enabled More likely to be used is the option to extend zone 1 so that zone 1 even covers zone 2 This feature is activated by the input to extend the zone 1 EXTZ1 OperationZ2 Operation zone 2 Enabled Disabled If OperationZ1 Disabled all pole slips with centre of the electromagnetic oscillation within zone 2 are...

Page 308: ...between the generator rotor and stator hence the external power system The machine may lose the synchronism and starts to operate like an induction machine Then the reactive consumption will increase Even if the machine does not lose synchronism it may not be acceptable to operate in this state for a long time Loss of excitation increases the generation of heat in the end region of the synchronous...

Page 309: ...e The angle δ is the phase angle difference between the voltages E and Enet If the excitation of the generator is decreased loss of field the voltage E becomes low In order to maintain the active power output the angle δ must be increased It is obvious that the maximum power is achieved at 90 If the active power cannot be reached at 90º static stability cannot be maintained The complex apparent po...

Page 310: ...he generator should be tripped at low excitation A suitable area in the PQ plane for protection operation is shown in figure 147 In this example limit is set to a small negative reactive power independent of active power Section 8 1MRK 502 071 UUS A Impedance protection 304 Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 Application manual ...

Page 311: ...le area in the PQ plane for protection operation Often the capability curve of a generator describes also low excitation capability of the generator see figure 148 1MRK 502 071 UUS A Section 8 Impedance protection Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 305 Application manual ...

Page 312: ...due to turbine output power limitation EF Steady state limit without AVR Xs Source impedance of connected power system Loss of excitation protection can be based on directional power measurement or impedance measurement The straight line EF in the P Q plane can be transferred into the impedance plane by using the relation shown in equation 162 2 2 2 2 2 2 2 2 V V V V V S V P V Q Z j R jX I I V S S...

Page 313: ...tection Operation area en06000452 vsd IEC06000452 V2 EN US Figure 149 The straight line in the PQ diagram is equivalent with a circle in the impedance plane LEXPDIS 40 in the IED is realised by two impedance circles and a directional restraint possibility as shown in figure 150 1MRK 502 071 UUS A Section 8 Impedance protection Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX...

Page 314: ...he stability Zone 2 will give a trip after a longer delay if the generator reaches the static limitation of stability There is also a directional criterion used to prevent trip at close in external faults in case of zones reaching into the impedance area as shown in figure 150 Operation With the setting Operation LEXPDIS 40 function can be set Enabled Disabled IBase refer to GlobalBaseSel The sett...

Page 315: ...e impedance settings are made as shown in figure 151 R X Z1 or Z2 XoffsetZ1 or XoffsetZ2 Z1diameter or Z2diameter IEC06000460_2_en vsd IEC06000460 V2 EN US Figure 151 Impedance settings for the fast Z1 and slow Z2 zone The impedances are given in pu of the base impedance calculated according to equation 164 1MRK 502 071 UUS A Section 8 Impedance protection Generator protection REG670 2 2 ANSI and ...

Page 316: ...e 21 2010 Slide 1 IEC10000201 1 en vsd IEC10000201 V1 EN US Figure 152 Loss of excitation characteristics recommended by IEEE It is recommended to set XoffsetZ2 equal to Xd 2 and Z2diamater equal to Xd tZ2 tZ2 is the setting of trip delay for Z2 and this parameter is recommended to set 2 0 s not to risk unwanted trip at oscillations with temporary apparent impedance within the characteristic Secti...

Page 317: ...n figure 153 XoffsetDirLine is set in of the base impedance according to equation 164 XoffsetDirLine is given a positive value if X 0 DirAngle is set in degrees with negative value in the 4th quadrant Typical value is 13 R X Underexcitation Protection Restrain area DirAngle XoffsetDirLine en06000461 2 vsd IEC06000461 V2 EN US Figure 153 The settings XoffsetDirLine and DirAngle 1MRK 502 071 UUS A S...

Page 318: ...r winding of the generator The magnitude of the injected voltage signal is measured at the injection point the magnitude of the injected current is measured through a resistive shunt located within REX060 These two measurements are fed to the IED Based on these two measured quantities the IED determines the rotor winding resistance to ground The resistance value is then compared to the preset faul...

Page 319: ...ated as 1 ref rot Z j C w EQUATION2510 V1 EN US alternative 1 rot ref j C Z w EQUATION2511 V1 EN US Where 2 inj f w p EQUATION2512 V1 EN US The injected frequency finj of the square wave is a set value different from the fundamental frequency 50 or 60 Hz The injected frequency can be set within the range 75 250 Hz with the recommended value 113 Hz in 50 Hz systems and 137 Hz in 60 Hz systems Rseri...

Page 320: ...ircuit 5 Connection for measurement of injected current This signal is amplified in REX060 before it is passed on to IED for evaluation 6 Connection for measurement of injected voltage This signal is amplified in REX060 before it is passed on to IED for evaluation 7 Two VT inputs into IED which are used to measure injected current and voltage 8 Protection for excessive over voltages posed by gener...

Page 321: ... given in the settings The values of RAlarm and RTrip are given in Ω An alarm signal ALARM is given after a set delay tAlarm if Rf RAlarm A initiate signal BFI is given if Rf RTrip For the tripping times see figure 158 Accuracy for ROTIPHIZ 64R is installation dependent because harmonics in static excitation system large variation of the ambient temperature and variation of rotor capacitance and c...

Page 322: ...tor When selected only one digit can be adjusted at the time by the Up or Down buttons Store the new value by Enter button or alternatively recover the last stored value by Clear button Gain setting can be set in four discreet steps in the main menu The selected step result in pre defined voltage and current gain factors In other words voltage and current gain cannot be set independently Store the...

Page 323: ...measured quantities for STTIPHIZ REX060 X61 9 8 8 9 11 10 11 10 X81 STATOR MODULE SIM ROTOR MODULE RIM IED VOLTAGE MEASURE V VOLTAGE MEASURE V CURRENT MEASURE V CURRENT MEASURE V ANSI11000209_1_en vsd ANSI11000209 V1 EN US Figure 156 Separate analog inputs for stator STTIPHIZ 64S and rotor ROTIPHIZ 64R protection 2 It is possible to use a mixed connection that requires only two IED voltage channel...

Page 324: ...pre processor block It is possible to connect two REG670 IEDs in parallel to the REX060 injection unit in order to obtain redundant measurement in the two IEDs However at commissioning both IEDs must be connected during the calibration procedure It is important that REX060 REX061 and REX062 chassis are solidly grounded Protective ground is a separate 0 15 screw terminal that is a part of the metal...

Page 325: ...ency 50 or 60 Hz should be avoided as well as other harmonics related to other frequencies in the power system for instance railway electrical systems with the fundamental frequency 16 2 3 Hz or 20 Hz The recommended setting is 113Hz in 50Hz power system and 137Hz in 60Hz power system The setting is fine tuned in connection to the commissioning calibration measurement and analysis in the ICT tool ...

Page 326: ...SI IEEE C37 2 device number 100 stator earth fault protection injection based STTIPHIZ Rse 64S 8 8 2 Application GUID ACF8F9DC 3A49 4F6E 9252 668BB5C228D0 v2 The 100 stator earth fault protection STTIPHIZ 64S is used to detect the ground faults in the stator windings of generators and motors STTIPHIZ 64S is applicable for generators connected to the power system through a unit transformer in a blo...

Page 327: ...ransformer and so on The protection function is fully operative in all operating conditions when stable measurements are achieved Both functions STTIPHIZ and ROV2PTOV shall be configured and shall operate in parallel in the same REG670 in order to perform the 100 stator earth fault protection function STTIPHIZ performs the earth fault protection based on the injection principle to protect the sect...

Page 328: ...159 High resistance generator grounding with a neutral point resistor There are some alternatives for connection of the neutral point resistor as shown in figure 160 low voltage neutral point resistor connected via a DT Section 8 1MRK 502 071 UUS A Impedance protection 322 Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 Application manual ...

Page 329: ...61 to limit the voltage to the injection equipment in case of ground fault at the generator terminal This voltage is often in the range 400 500 V As the open delta connection gives three times the zero sequence phase voltage this gives too high voltage at the injection point if the resistance is not divided as shown in the figure 161 By dividing the resistor in two parts it shall be ensured that m...

Page 330: ...r grounding via a grounded wye broken delta transformer It is also possible to make the injection via VT open delta connection as shown in figure 162 Section 8 1MRK 502 071 UUS A Impedance protection 324 Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 Application manual ...

Page 331: ...s will have very little contribution to the ground fault current as it has high resistance This injection principle can be used for applications with various generator system grounding methods It is therefore recommended to make the injection via the open delta VT on the terminal side in most applications 1MRK 502 071 UUS A Section 8 Impedance protection Generator protection REG670 2 2 ANSI and In...

Page 332: ...al point The injected voltage and current are connected to the measurement parts of REX060 The signals are amplified giving voltage signals for both the injected voltage and current adapted to analogue inputs of IED Frequency current and voltage gain are settable and stored in non volatile memory If value is outside range then the limited value will be stored Last stored settings are shown in disp...

Page 333: ...94696557FF33 v2 The SIM module of REX060 has two analog output channels that shall be connected to two voltage input channels of the IED If both stator and rotor protection are used there are two possible methods to perform the connection 1 The recommended connection requires four analog channels of the IED two IED voltage channels are used for the measured quantities for STTIPHIZ two more IED vol...

Page 334: ... to use a mixed connection that requires only two IED voltage channels for both ROTIPHIZ and STTIPHIZ REX060 outputs are connected in series This connection is not recommended and can be used only in applications where it is proved the possibility to use it The use of this connection leads to reduced performances of both ROTIPHIZ and STTIPHIZ Section 8 1MRK 502 071 UUS A Impedance protection 328 G...

Page 335: ...e processor block 8 8 3 3 100 stator earth fault protection GUID B4523E06 7D88 431F 87A6 909F83D1E253 v3 Operation to be set Enabled to activate the stator earth fault protection RTrip is the resistance level set directly in primary Ohms for activation of the trip function RAlarm is the resistance level set directly in primary Ohms for activation of the alarm function tAlarm is the time delay to a...

Page 336: ... as well as the first reference impedance RefR1 RefX1 are defined while performing the three steps of the calibration by ICT Injection Commissioning Tool The other 4 reference impedances RefR2 RefX2 RefR5 RefX5 are defined through the Commissioning tab of ICT according to the needs of the machine during the commissioning of the protection system ICT must be used for the calibration since this tool...

Page 337: ...orward and reverse direction The characteristic angle for all three zones is common and adjustable A load encroachment blinder feature is provided for zone 2 and zone 3 Protection designed to operate for below types of faults Faults in the generator generator terminal connections to the step up transformer and in the low voltage LV side of the generator step up transformer are 1 Phase to phase fau...

Page 338: ...3Rev Z2Rev Z1Rev R ohm X ohm B Typical setting of zones for under impedance relay IEC11000308 3 en vsd Zone3 Zone1 REG670 A Power system model Zone2 Y Y D Y IEC11000308 V3 EN US Section 8 1MRK 502 071 UUS A Impedance protection 332 Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 Application manual ...

Page 339: ...former are Sl No Phase to phase loop Voltage phasor Current phasor 1 A B VAB IAB 2 B C VBC IBC 3 C A VCA ICA VAB VBC VCA are three phase to phase voltages IAB IBC ICA are the three phase to phase currents For this application the zone 1 element is typically set to see 75 of the transformer impedance 8 9 2 3 Zone 2 operation GUID F9622D3F DDA1 451B A1C6 71F030725D25 v5 Zone 2 can be used to cover u...

Page 340: ...oad current in the machine leads due to which zone 2 element picks up resulting in misleading indications Zone 2 is not intended to operate for the generator winding ground faults The protection for generator winding ground fault is provided by sensitive ground fault relays that are time delayed To prevent such an operation the phase to ground measuring voltage is compensated with zero sequence vo...

Page 341: ... generating terminals the CTs might go in to saturation The problem is due to very long DC constant of the generators The persistent DC component of primary currents even if relatively small has a tendency to drive current transformers into saturation The ZGVPDIS under this condition might reset for some duration A reliable backup protection is provided under these conditions by providing an under...

Page 342: ... D824 4479 A03A 41EE034C9021 ANSI V1 EN US Equation 165 The LdAngle is a separate setting 8 9 2 8 External block signals GUID 8DDEDD52 37DC 4330 BE56 CBC37F0545AD v2 The under impedance function will have to be blocked in the event of PT fuse fail A BLKZ input for this purpose is provided Also a BLOCK input is provided Section 8 1MRK 502 071 UUS A Impedance protection 336 Generator protection REG6...

Page 343: ...orward reach in percentage It is recommended to set zone 1 forward reach to 75 of transformer impedance Z1Rev Zone 1 reverse reach in percentage It is recommended to set zone 1 reverse reach same as Z1Fwd tZ1 Zone 1 trip time delay in seconds Zone 2 Zone 2 in ZGVPDIS function has offset mho characteristic and it can evaluate three phase to phase impedance measuring loops or Enhanced reach loop OpM...

Page 344: ... slowest local backup for faults within zone 3 reach A safety margin of 100 ms should be considered 8 9 3 2 Load encroachment GUID EF64E2B4 2B84 421A B719 2DCA6883D21A v2 The settings involved in load encroachment feature are LdAngle Angle in degrees of load encroachment characteristics RLd Positive sequence resistance in per unit The procedure of calculating the settings for load encroachment con...

Page 345: ...04 1 en vsd ANSI11000304 V1 EN US Figure 167 Characteristics of load encroachment in R X plane 8 9 3 3 Under voltage seal in GUID 946B8F59 8609 4F93 B346 AE053F1C2F9C v2 Settings involved in under voltage seal in are OpMode27pickup Under voltage seal in feature is enabled using this setting and can be selected as Disabled or Z2pick up or Z3pick up If the under voltage seal in has to be 1MRK 502 07...

Page 346: ...current Thus the ground fault does not produce any damage in the generator Furthermore it will not affect the operation of a generating unit in any way However the existence of a single ground fault increases the electric stress at other points in the field circuit This means that the risk for a second ground fault at another point on the field winding has increased considerably A second ground fa...

Page 347: ...rs at constant amount of transmitted electric power The type of the fault Three phase faults are the most dangerous 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 bo...

Page 348: ...en connected to the network and can thus also cause the operation of the built in instantaneous overcurrent protection Common base IED values for primary current IBase primary voltage UBase and primary power SBase are set in the global base values for settings function GBASVAL GlobalBaseSel This is used to select GBASVAL function for reference of base values Operation Set the protection to On Off ...

Page 349: ...mum source impedance values for ZA and the maximum source impedance values for ZB in order to get the maximum through fault current from A to B ZA ZB ZL A B IED I fB Fault ANSI09000022 1 en vsd ANSI09000022 V1 EN US Figure 168 Through fault current from A to B IfB Then a fault in A has to be applied and the through fault current IfA has to be calculated Figure 169 In order to get the maximum throu...

Page 350: ...to be introduced An additional 20 is suggested due to the inaccuracy of the instrument transformers under transient conditions and inaccuracy in the system data The minimum primary setting Is for the instantaneous phase overcurrent protection is then min 1 3 s I I EQUATION79 V3 EN US Equation 169 The protection function can be used for the specific application only if this setting value is equal t...

Page 351: ...e 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 parallel line for the IED in Figure 171 will be with a fault at the C point with the C breaker open A fault in C has...

Page 352: ...mum setting Is for the instantaneous phase overcurrent protection 3 phase output is then Is 1 3 Imin EQUATION83 V2 EN US Equation 172 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 Pickup is given in percentage of the primary base current value IBase Th...

Page 353: ...rs motors and others Back up short circuit protection of power generators In many applications several steps with different current pickup levels and time delays are needed OC4PTOC 51_67 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 c...

Page 354: ... saturation of the transformer magnetic core during parts of the period There is a risk that inrush current will reach levels above the pick up current of the phase overcurrent protection The inrush current has a large 2nd harmonic content This can be used to avoid unwanted operation of the protection function Therefore OC4PTOC 51 67 has a possibility of 2nd harmonic restrain if the level of 2nd h...

Page 355: ...teristic angle set in degrees If the angle of the fault loop 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 172 NumPhSel 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...

Page 356: ...rating angle 3 Reverse 4 Forward 9 2 3 1 Settings for each step M12982 19 v10 x means step 1 2 3 and 4 DirModeSelx The directional mode of step x Possible settings are Disabled Non directional Forward Reverse Section 9 1MRK 502 071 UUS A Current protection 350 Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 Application manual ...

Page 357: ... level for step x given in of IB Ix Max and Ix Min should only be changed if remote setting of operation current level Ix is used The limits are used for decreasing the used range of the Ix setting 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...

Page 358: ...ry input signal ENMULTx enableMultiplier is activated the current operation level is increased by this setting constant Setting range 1 0 10 0 ANSI10000058 1 en vsdx Trip time Pickup current tx txMin ANSI10000058 V1 EN US Figure 173 Minimum pickup current and trip time for inverse time characteristics In order to fully comply with the definition of the curve the setting parameter txMin shall be se...

Page 359: ...t time reset and ANSI 3 current dependent reset time If the current dependent type is used settings pr tr and cr must be given tResetx Constant reset time delay in seconds for step x tPCrvx tACrvx tBCrvx tCCrvx These parameters are used by the customer to create the inverse time characteristic curve See equation 174 for the time characteristic equation For more information refer to Technical manua...

Page 360: ...ion operation The protection reset current must also be considered so that a short peak of overcurrent does not cause the operation of a protection even when the overcurrent has ceased This phenomenon is described in Figure 174 Pickup current Current I The IED does not reset Line phase current Time t Reset current ANSI09000146 en 1 vsd ANSI09000146 V1 EN US Figure 174 Pickup and reset current for ...

Page 361: ...e overcurrent protection The minimum fault current Iscmin to be detected by the protection must be calculated Taking this value as a base the highest pickup current setting can be written according to Equation 176 Ipu 0 7 Iscmin EQUATION1263 V2 EN US Equation 176 where 0 7 is a safety factor Iscmin is the smallest fault current to be detected by the overcurrent protection As a summary the pickup c...

Page 362: ...mary protection zone The operate time of the phase overcurrent protection has to be chosen so that the fault time is short enough that the protected equipment will not be destroyed due to thermal overload while at the same time selectivity is assured For overcurrent protection in a radial fed network the time setting can be chosen in a graphical way This is mostly used in the case of inverse time ...

Page 363: ...ween 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 Protection operation time 15 60 ms Protection resetting time 15 60 ms Breake...

Page 364: ...e 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 resetting time is t4 t3 To ensure that the ov...

Page 365: ...699 3 v5 In many applications when fault current is limited to a defined value by the object impedance an instantaneous ground fault protection can provide fast and selective tripping The Instantaneous residual overcurrent EFPIOC 50N 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 ...

Page 366: ...rrents 3I0 to the protection are calculated For a fault at the remote line end this fault current is IfB In this calculation the operational state with high source 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 ...

Page 367: ...Is is Is 1 3 Imin EQUATION285 V3 EN US Equation 181 In case of parallel lines with zero sequence mutual coupling a fault on the parallel line as shown in Figure 179 should be calculated ZA ZB ZL1 A B I M Fault IED ZL2 M C Line 1 Line 2 ANSI09000025_2_en vsd ANSI09000025 V2 EN US Figure 179 Two parallel lines Influence from parallel line to the through fault current IM The minimum theoretical curre...

Page 368: ... used The limits are used for decreasing the used range of the IN setting If IN is set outside IN Max and IN Min the closest of the limits to IN is used by the function If IN Max is smaller than IN Min the limits are swapped MultPU The set operate current can be changed by activation of the binary input MULTPU to the set factor MultPU 9 4 Directional residual overcurrent protection four steps EF4P...

Page 369: ... fault clearance the directional function can be necessary This can be the case for ground fault protection in meshed and effectively grounded transmission systems The directional residual overcurrent protection is also well suited to operate in teleprotection communication schemes which enables fast clearance of ground faults on transmission lines The directional function uses the polarizing quan...

Page 370: ...ime Therefore there is a possibility to give a setting of a multiplication factor INxMult to the residual current pick up level This multiplication factor is activated from a binary input signal MULTPUx to the function Power transformers can have a large inrush current when being energized This inrush current can produce residual current component The phenomenon is due to saturation of the transfo...

Page 371: ...BaseSel This is used to select GBASVAL function for reference of base values SeqTypeUPol This is used to select the type of voltage polarising quantity i e Zero seq and Neg seq for direction detection SeqTypeIPol This is used to select the type of current polarising quantity i e Zero seq and Neg seq for direction detection SeqTypeIDir This is used to select the type of operating current quantity i...

Page 372: ...tivity is required In such cases the polarizing voltage 3V0 can be below 1 and it is then necessary to use current polarizing or dual polarizing Multiply the required set current primary with the minimum impedance ZNpol and check that the percentage of the phase to ground voltage is definitely higher than 1 minimum 3V0 VPolMin setting as a verification RNPol XNPol The zero sequence source is set i...

Page 373: ...a declining residual current in the network as the inrush current is deviating between the phases There is a risk that the residual overcurrent function will give an unwanted trip The inrush current has a relatively large ratio of 2nd harmonic component This component can be used to create a restrain signal to prevent this unwanted function At current transformer saturation a false residual curren...

Page 374: ...ng The settings for the parallel transformer logic are described below BlkParTransf This is used to Enable blocking at energising of parallel transformers Use_PUValue Gives which current level should be used for the activation of the blocking signal This is given as one of the settings of the steps Step 1 2 3 4 Normally the step having the lowest operation current level should be set 9 4 3 4 Switc...

Page 375: ... the SOTF function is active after breaker closing The setting range is 0 000 60 000 s in step of 0 001 s The default setting is 1 000 s ActUndrTimeSel Describes the mode to activate the sensitive undertime function The function can be activated by Circuit breaker position change or Circuit breaker command tUnderTime Time delay for operation of the sensitive undertime function The setting range is...

Page 376: ...rent level for step x given in of IB INx Max and INx Min should only be changed if remote setting of operation current level INx is used The limits are used for decreasing the used range of the INx setting If INx is set outside INx Max and INx Min the closest of the limits to INx is used by the function If INx Max is smaller than INx Min the limits are swapped kx Time multiplier for the dependent ...

Page 377: ...g of the current setting value If a binary input signal MULTPUx 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 technical reference manual tResetx Constant reset time delay in s for step x HarmBlockx This is used to enable block of step x from 2nd harmonic ...

Page 378: ...idual current can be fed from the protected transformer winding or not The protected winding will feed ground fault residual current to ground faults in the connected power system The residual current fed from the transformer at external phase to ground faults is highly dependent on the total positive and zero sequence source impedances It is also dependent on the residual current distribution bet...

Page 379: ... inverse time delay and a lower current operation level Step 2 shall detect and clear transformer winding ground faults with low ground fault current that is faults close to the transformer winding neutral point If the current setting gap between step 1 and step 2 is large another step can be introduced with a current and time delay setting between the two described steps The transformer inrush cu...

Page 380: ...tive and zero sequence source impedances as well as the division of residual current in the network Ground fault current calculations are necessary for the setting Setting of step 1 SEMOD55591 35 v5 One requirement is that ground faults at the busbar where the transformer winding is connected shall be detected Therefore a fault calculation as shown in Figure 185 is made Section 9 1MRK 502 071 UUS ...

Page 381: ...s in the network a short delay is selected Normally a delay in the range 0 3 0 4 s is appropriate To assure selectivity to line faults tripped after a delay typically distance protection zone 2 of about 0 5 s the current setting must be set so high so that such faults does not cause unwanted step 1 trip Therefore a fault calculation as shown in Figure 186 is made 1MRK 502 071 UUS A Section 9 Curre...

Page 382: ...tep 1 can be chosen within the interval shown in equation 186 0fault2 step1 0fault1 3I lowmar I 3I highmar EQUATION1455 V2 EN US Equation 186 Where lowmar is a margin to assure selectivity typical 1 2 and highmar is a margin to assure fast fault clearance of busbar fault typical 1 2 Setting of step 2 SEMOD55591 57 v5 The setting of the sensitive step 2 is dependent of the chosen time delay Often a...

Page 383: ...053 V1 EN US 46I2 9 5 2 Application GUID 343023F8 AFE3 41C2 8440 1779DD7F5621 v2 Four step negative sequence overcurrent protection NS4PTOC 4612 is used in several applications in the power system Some applications are Ground fault and phase phase short circuit protection of feeders in effectively grounded distribution and subtransmission systems Normally these feeders have radial structure Back u...

Page 384: ...ng quantity Choice of time characteristics There are several types of time characteristics available such as definite time delay and different types of inverse time characteristics The selectivity between different overcurrent protections is normally enabled by co ordination between the operating time of the different protections To enable optimal co ordination all overcurrent relays to be co ordi...

Page 385: ... protection NS4PTOC 46I2 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 protection Operation Sets the protection to Enabled or Disabled Common base IED values for primary current IBase primary voltage VBase and primary power SBase are set in Global base values for settings function GBASVAL Global...

Page 386: ...ic The different characteristics are described in the Technical Reference Manual TRM Pickupx Operation negative sequence current level for step x given in of IBase 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 TDx Time multiplie...

Page 387: ...he delay timer can be made in different ways By choosing setting there are the following possibilities Curve name Instantaneous IEC Reset constant time ANSI Reset inverse time The different reset characteristics are described in the Technical Reference Manual TRM There are some restrictions regarding the choice of reset delay For the independent time delay characteristics the possible delay time s...

Page 388: ... s B TD i C ipickup æ ö ç ç ç æ ö ç ç è ø è ø EQUATION1722 V1 EN US Equation 187 Further description can be found in the Technical reference manual TRM tPRCrvx tTRCrvx tCRCrvx Parameters for customer creation of inverse reset time characteristic curve Further description can be found in the Technical Reference Manual 9 5 3 2 Common settings for all steps GUID A00A942B E760 42EE 8FEB F723426783F3 v...

Page 389: ...current level for directional comparison scheme The setting is given in of IBase The pickup forward or pickup reverse signals can be used in a communication scheme The appropriate signal must be configured to the communication scheme block 9 6 Sensitive directional residual overcurrent and power protection SDEPSDE 67N SEMOD171436 1 v4 1MRK 502 071 UUS A Section 9 Current protection Generator prote...

Page 390: ...ce grounded networks The protection uses the residual power component 3I0 3V0 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 ...

Page 391: ...ctional residual power protection the operating quantity is elevated Therefore better possibility to detect ground faults In addition in low impedance grounded networks the inverse time characteristic gives better time selectivity in case of high zero resistive fault currents Phase currents Phase ground voltages IN VN ANSI13000013 1 en vsd ANSI13000013 V1 EN US Figure 189 Connection of SDEPSDE to ...

Page 392: ...rent will be calculated at the desired sensitivity fault resistance The complex neutral point voltage zero sequence can be calculated as phase 0 f 0 V V 3 R 1 Z EQUATION2020 ANSI V1 EN US Equation 188 Where Vphase is the phase voltage in the fault point before the fault Rf is the resistance to ground in the fault point and Z0 is the system zero sequence impedance to ground The fault current in the...

Page 393: ...the impedance Z0 can be calculated as n n c 0 c n n n c n n c 9R X X Z jX 3R j3X 3X X j3R 3X X EQUATION1947 V1 EN US Equation 192 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 grounding via a resistor giving higher ground fault current than the high impedance grounding The ...

Page 394: ... 0 f 3V 3I 2 Z Z 3 R EQUATION2023 ANSI V1 EN US Equation 193 Where Vphase 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...

Page 395: ...A S 3V 3I cos j EQUATION2028 ANSI V1 EN US Equation 198 0B prot 0B 0 B S 3V 3I cos j EQUATION2029 ANSI V1 EN US Equation 199 The angles φA and φB are the phase angles between the residual current and the residual voltage in the station compensated with the characteristic angle RCA The protection will use the power components in the characteristic angle direction for measurement and as base for the...

Page 396: ...h the setting OpModeSel the principle of directional function is chosen With OpModeSel set to 3I0cosfi the current component in the direction equal to the characteristic angleRCADir has the maximum sensitivity The characteristic for RCADir is equal to 0 is shown in Figure 191 3V0 Vref 3I0 RCA 0 ROA 90 ang 3I0 ang 3Vref 3I0 cos en06000648_ansi vsd Vref ANSI06000648 V1 EN US Figure 191 Characteristi...

Page 397: ...s measured When OpModeSel is set to 3I0 and fi the function will operate if the residual current is larger than the setting INDirPU and the residual current angle is within the sector RCADir ROADir The characteristic for this OpModeSel when RCADir 0 and ROADir 80 is shown in figure 193 1MRK 502 071 UUS A Section 9 Current protection Generator protection REG670 2 2 ANSI and Injection equipment REX0...

Page 398: ...he 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 ground faults correctly The setting shall be much shorter than the set trip delay In case of intermittent ground faults the fault current is intermittently dropping below the set value during consecutive cycles Therefore the definite timer should co...

Page 399: ...e 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 TDSN is the time multiplier The time delay will follow the following expression inv 0 0 TDSN Sref t 3I 3V cos measured j EQUATION2030 ANSI V1 EN US Equation 201 INDirPU is the pickup current level for the direction...

Page 400: ...s in Technical Manual 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 Pickup N EQUATION2031 ANSI V1 EN US Equation 202 tINNonDir is the definite time delay for the non directional ground fault current prote...

Page 401: ...nsequence of this the risk of internal phase to phase or phase to ground faults increases There might be hot spots within the transformer which degrades the paper insulation It might also cause bubbling in the transformer oil In stressed situations in the power system it can be required to overload transformers for a limited time This should be done without the above mentioned risks The thermal ov...

Page 402: ...sformer can be taken into service again Therefore the function will continue to estimate the heat content using a set cooling time constant Energizing of the transformer can be blocked until the heat content has reached a set level 9 7 3 Setting guideline M13250 3 v8 The parameters for the thermal overload protection two time constants TRPTTR 49 are set via the local HMI or Protection and Control ...

Page 403: ...out 2 5 hours for naturally cooled transformers and 1 5 hours for forced cooled transformers The time constant can be estimated from measurements of the oil temperature during a cooling sequence described in IEC 60076 7 It is assumed that the transformer is operated at a certain load level with a constant oil temperature steady state operation The oil temperature above the ambient temperature is D...

Page 404: ...e2 Alarm1 Heat content level for activation of the signal ALARM1 ALARM1 is set in of the trip heat content level Alarm2 Heat content level for activation of the output signal ALARM2 ALARM2 is set in of the trip heat content level LockoutReset Lockout release level of heat content to release the lockout signal When the thermal overload protection trips a lock out signal is activated This signal is ...

Page 405: ...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 50BF can also give a re trip This means that a second trip signal is sent to the protected circuit breaker The re trip function can be used to increase the proba...

Page 406: ...ipMode and FunctionMode RetripMode FunctionMode 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 ...

Page 407: ...rrents In order to detect breaker failure at single phase ground faults in these systems it is necessary to measure the residual current separately Also in effectively grounded systems the setting of the ground 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 gr...

Page 408: ...ip delay for multi phase faults Typical setting is 90 150 ms t3 Additional time delay to t2 for a second back up trip TRBU2 In some applications there might be a requirement to have separated 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 52FAIL from the circuit breaker This si...

Page 409: ...might give unwanted operation of sensitive ground fault protections in the power system It is therefore important to detect situations with pole discrepancy of circuit breakers When this is detected the breaker should be tripped directly Pole discordance protection CCPDSC 52PD will detect situation with deviating positions of the poles of the protected circuit breaker The protection has two differ...

Page 410: ...he current based pole discrepancy protection Can be set Disabled CB oper monitor Continuous monitor 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 CurrUnsymPU Unsymmetrical magnitude of lowest phase current compared to the highest set in ...

Page 411: ...rbines easily become overheated if the steam flow becomes too low or if the steam ceases to flow through the turbine Therefore turbo generators should have reverse power protection There are several contingencies that may cause reverse power break of a main steam pipe damage to one or more blades in the steam turbine or inadvertent closing of the main stop valves In the last case it is highly desi...

Page 412: ...and leaves may also block the trash gates A complete blockage of the intake may cause cavitations The risk for damages to hydro turbines can justify reverse power protection in unattended plants A hydro turbine that rotates in water with closed wicket gates will draw electric power from the rest of the power system This power will be about 10 of the rated power If there is only air in the hydro tu...

Page 413: ...ed Disabled Mode The voltage and current used for the power measurement The setting possibilities are shown in table 41 Table 41 Complex power calculation Set value Mode Formula used for complex power calculation A B C A A B B C C S V I V I V I EQUATION2055 ANSI V1 EN US Equation 206 Arone AB A BC C S V I V I EQUATION2056 ANSI V1 EN US Equation 207 PosSeq 3 PosSeq PosSeq S V I EQUATION2057 ANSI V1...

Page 414: ...SI V1 EN US Equation 214 The function has two stages that can be set independently With the parameter OpMode1 2 the function can be set Enabled Disabled The function gives trip if the power component in the direction defined by the setting Angle1 2 is smaller than the set pick up power value Power1 2 Section 9 1MRK 502 071 UUS A Current protection 408 Generator protection REG670 2 2 ANSI and Injec...

Page 415: ...ng class CT inputs into the IED are used N S 3 VBase IBase EQUATION2047 V1 EN US Equation 215 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 1MRK 502 071 UUS A Section 9 Current protecti...

Page 416: ...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 S TD S TD S Old Calculated 1 EQUATION1893 ANSI V1 EN US Equation 217 Where S is a new measured value to be used for the protection function Sold is the measured value given from the function in previous execution cycle SCalculated is the new calculated value in the pr...

Page 417: ...tional overpower protection GOPPDOP P 2 DOCUMENT172362 IMG158942 V2 EN US 32 9 11 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 ...

Page 418: ...ine rotates without steam supply the electric power consumption will be about 2 of rated power Even if the turbine rotates in vacuum it will soon become overheated and damaged The turbine overheats within minutes if the turbine loses the vacuum The critical time 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...

Page 419: ...and with overpower IED The underpower IED gives a higher margin and should provide better dependability On the other hand the risk for unwanted operation immediately after synchronization may be higher One should set the underpower 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 ...

Page 420: ...I EQUATION2042 V1 EN US Equation 223 C A C A CA S V I I EQUATION2043 V1 EN US Equation 224 A A A S 3 V I EQUATION2044 V1 EN US Equation 225 B B B S 3 V I EQUATION2045 V1 EN US Equation 226 C C C S 3 V I EQUATION2046 V1 EN US Equation 227 The function has two stages that can be set independently With the parameter OpMode1 2 the function can be set Enabled Disabled The function gives trip if the pow...

Page 421: ...tering class CT inputs into the IED are used N S 3 VBase IBase EQUATION2047 V1 EN US Equation 228 The setting Angle1 2 gives the characteristic angle giving maximum sensitivity of the power protection function The setting is given in degrees For active power the set angle should be 0 or 180 180 should be used for generator reverse power protection 1MRK 502 071 UUS A Section 9 Current protection Ge...

Page 422: ...pick up Hysteresis1 2 is given in p u of generator rated power according to equation 229 N S 3 VBase IBase EQUATION2047 V1 EN US Equation 229 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 Section 9 1MRK 502 071 UUS A Current protection 416 Generator protection REG670 2 2 ANSI and Injection equi...

Page 423: ...gComp5 IAngComp30 IAngComp100 The angle compensation is given as difference between current and voltage angle errors The values are given for operating points 5 30 and 100 of rated current voltage The values should be available from instrument transformer test protocols 9 12 Negativ sequence time overcurrent protection for machines NS2PTOC 46I2 GUID 25821361 229A 44BB A60F FC6DD9F4F140 v2 9 12 1 I...

Page 424: ...ce current NS2PTOC 46I2 also have a time delay characteristic which matches the heating characteristic of the generator I2 2t K as defined in standard where I2 is negative sequence current expressed in per unit of the rated generator current t is operating time in seconds K is a constant which depends of the generators size and design A wide range of I2 2t settings is available which provide the s...

Page 425: ...gative sequence current value in primary Amperes is available through the local HMI 9 12 2 2 Generator continuous unbalance current capability GUID 7C2DBEA9 4423 47DD 90FD 88F4AAD2E9A9 v3 During unbalanced loading negative sequence current flows in the stator winding Negative sequence current in the stator winding will induce double frequency current in the rotor surface and cause heating in almos...

Page 426: ...led generators For example a 500 MVA generator would have K 10 seconds and a 1600 MVA generator would have K 5 seconds Unbalanced short time negative sequence current I2 is expressed in per unit of rated generator current and time t in seconds en08000358 vsd IEC08000358 V1 EN US Figure 201 Short time unbalanced current capability of direct cooled generators Continuous I2 capability of generators i...

Page 427: ...ions will not usually detect this condition and the only protection is the negative sequence overcurrent protection Negative sequence currents in a generator may be caused by Unbalanced loads such as Single phase railroad load Unbalanced system faults such as Line to ground faults Double line to ground faults Line to line faults Open conductors includes Broken line conductors Malfunction of one po...

Page 428: ...tive sequence current once the pickup value is exceeded while inverse time delay characteristic do depend on the magnitude of the negative sequence current This means that inverse time delay is long for a small overcurrent and becomes progressively shorter as the magnitude of the negative sequence current increases Inverse time delay characteristic of the NS2PTOC 46I2 function is represented in th...

Page 429: ...pickup levels Current I2 1 and I2 2 of NS2PTOC 46I2 are freely settable over a range of 3 to 500 of rated generator current IBase The wide range of pickup setting is required in order to be able to protect generators of different types and sizes After pickup a certain hysteresis is used before resetting pickup levels For both steps the reset ratio is 0 97 9 12 3 3 Alarm function GUID 1B932D89 3233...

Page 430: ...tem and it can draw one to four per unit current depending upon the equivalent system impedance This high current may thermally damage the generator in a few seconds Accidental energizing protection for synchronous generator AEGPVOC 50AE monitors maximum phase current and maximum phase to phase voltage of the generator In its basis it is voltage supervised over current protection When generator vo...

Page 431: ... This voltage shall be lower than the lowest operation voltage The default value 50 is recommended tArm Time delay of voltage under the level Arm for activation The time delay shall be longer than the longest fault time at short circuits or phase ground faults in the network The default value 5s is recommended 59_Drop_out Voltage level given in of VBase for deactivation dearming of the accidental ...

Page 432: ...the fault and excitation system performance and characteristic So the fault current amplitude may decay with time A voltage restrained overcurrent relay can be set in order to remain in the picked up state in spite of the current decay and perform a backup trip in case of failure of the main protection The IED can be provided with a voltage restrained time overcurrent protection VRPVOC 51V The VRP...

Page 433: ... VRPVOC 51V function can be used in one of the following applications voltage controlled over current voltage restrained over current In both applications a seal in of the overcurrent function at under voltage can be included by configuration 9 14 2 3 Undervoltage seal in GUID 13BE02D3 1322 4075 859B 617CFF608657 v7 In the case of a generator with a static excitation system which receives its powe...

Page 434: ...ADD4 3DBA83581096 v2 9 14 3 1 Explanation of the setting parameters GUID 9B777E6D 602B 4214 9170 A44ED2D725BF v3 Operation Set to On in order to activate the function set to Off to switch off the complete function Pickup_Curr Operation phase current level given in of IBase Characterist Selection of time characteristic Definite time delay and different types of inverse time characteristics are avai...

Page 435: ... 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 pickup level of the overcurrent stage given in of Pickup_Curr when the voltage is lower than 25 of VBase so it defines the first point of the characteristic VD...

Page 436: ... time defined by the inverse time characteristic 7 If required set the minimum operating time for this curve by using the parameter t_MinTripDelay default value 0 05 s 8 Set PickupCurr to the value 185 9 Set VDepMode to Slope default value 10 Set VDepFact to the value 25 default value 11 Set VHighLimit to the value 100 default value All other settings can be left at the default values 9 14 3 3 Gen...

Page 437: ...vercurrent stage and the undervoltage stage shall be set in the following way 1 Set Operation to Enabled 2 Set GlobalBaseSel to the right value in order to select the Global Base Values Group with VBase and IBase equal to the rated phase to phase voltage and the rated phase current of the generator 3 Set StartCurr to the value 150 4 Set Characteristic to IEC Def Time 5 Set tDef_OC to 6000 00 s if ...

Page 438: ...rity and duration of the temperature excursion Excess temperature can also cause mechanical damage due to thermal expansion Temperature rise with in a generator for these conditions is primarily a function of I2R copper losses Because temperature increases with current it is logical to apply overcurrent elements with inverse time current characteristics The generator overcurrent applications are c...

Page 439: ... as bars and end rings are vulnerable to this damage Temperature rise within a generator for these conditions is primarily a function of I2R copper losses Because temperature increases with current it is logical to apply overcurrent elements with inverse time current characteristics The generator overcurrent applications are complicated by the complexity of generator thermal characteristics and th...

Page 440: ...sure that appropriate CT ratio for example 100 1 or 1000 5 is set on these three analogue inputs All settings will be given in a table format for both applications Table 45 100MVA machine application when LV side 1000 5 CT is used Parameter name Selected value Comment MeasurCurrent DC In order to measure directly rotor winding DC current IBase 810 Rated current of the field winding i e field curre...

Page 441: ...tor CT_Location HV_winding HV side 100 5 CT used for measurement VrLV 550 0 Rated LV side AC voltage in Volts VrHV 11 00 Rated HV side AC voltage in kV PhAngleShift 30 11 30 360 30 degree this provides 30 degrees anti clock wise phase angle shift across the excitation transformer Note that last three parameters from the table above must be properly set in order to have proper operation of the roto...

Page 442: ...436 ...

Page 443: ...system such as Malfunctioning of a voltage regulator or wrong settings under manual control symmetrical voltage decrease Overload symmetrical voltage decrease Short circuits often as phase to ground faults unsymmetrical voltage decrease UV2PTUV 27 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 als...

Page 444: ...rt circuits and ground faults Some applications and related setting guidelines for the voltage level are described in the following sections 10 1 3 1 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 set...

Page 445: ...teristicn This parameter gives the type of time delay to be used The setting can be Definite time Inverse Curve A Inverse Curve B Prog inv curve The selection is dependent on the protection application OpModen This parameter describes how many of the three measured voltages should be below the set level to give operation for step n The setting can be 1 out of 3 2 out of 3 or 3 out of 3 In most app...

Page 446: ... under voltage inverse time characteristic Description of this can be found in the Technical manual CrvSatn Tuning parameter that is used to compensate for the undesired discontinuity created when the denominator in the equation for the customer programmable curve is equal to zero For more information see the Technical manual IntBlkSeln This parameter can be set to Disabled Block of trip Block all...

Page 447: ...h measuring accuracy and hysteresis setting to allow applications to control reactive load OV2PTOV 59 is used to disconnect apparatuses like electric motors which will be damaged when subject to service under high voltage conditions It deals with high voltage conditions at power system frequency which can be caused by 1 Different kinds of faults where a too high voltage appears in a certain power ...

Page 448: ...vervoltages for some time but in case of large overvoltages the related equipment should be disconnected more rapidly Some applications and related setting guidelines for the voltage level are given below The hysteresis is for overvoltage functions very important to prevent that a transient voltage over set level is not sealed in due to a high hysteresis Typical values should be 0 5 10 2 3 1 Equip...

Page 449: ... to phase in primary kV This voltage is used as reference for voltage setting OV2PTOV 59 measures selectively phase to ground voltages or phase to phase voltage chosen by the setting ConnType The function will operate if the voltage gets lower than the set percentage of VBase When ConnType is set to PhN DFT or PhN RMS then the IED automatically divides set value for VBase by 3 When ConnType is set...

Page 450: ...rtant for example in case of protection of transformer that might be overexcited The time delay must be co ordinated with other automated actions in the system tResetn Reset time for step n if definite time delay is used given in s The default value is 25 ms tnMin Minimum operation time for inverse time characteristic for step n given in s For very high voltages the overvoltage function using inve...

Page 451: ...esidual overvoltage protection ROV2PTOV 59N is primarily used in high impedance grounded distribution networks mainly as a backup for the primary ground fault protection of the feeders and the transformer To increase the security for different ground fault related functions the residual overvoltage signal can be used as a release signal The residual voltage can be measured either at the transforme...

Page 452: ...n such as for motors generators reactors and transformersEquipment protection for transformers M13853 9 v8 High residual voltage indicates ground fault in the system perhaps in the component to which two step residual overvoltage protection ROV2PTOV 59N is connected For selectivity reasons to the primary protection for the faulted device ROV2PTOV 59N must trip the component with some time delay Th...

Page 453: ...mally set to operate for faults located at 5 percent or more from the stator neutral point with a time delay setting of 0 5 seconds Thus such function protects approximately 95 percent of the stator winding The function also covers the generator bus the low voltage winding of the unit transformer and the high voltage winding of the auxiliary transformer of the unit The function can be set so low b...

Page 454: ...ction ROV2PTOV 59N application 1 ROV2PTOV 59N is here connected to a voltage or distribution transformer located at generator star point 1 Due to such connection ROV2PTOV 59N measures the Uo voltage at the generator star point Due to such connection ROV2PTOV 59N measures the Vo voltage at the generator star point The maximum Vo voltage is present for a single phase to ground fault at the generator...

Page 455: ... and it has the maximum primary value 3VoMax 3 3 3 11 19 05 Vo V kV kV Max Ph Ph ANSIEQUATION2395 V1 EN US Equation 238 2 Three VT inputs are to be used in the IED The VT ratio should be set according to the VT ratio For this application the correct primary and secondary VT rating values are 11 kV and 110 V respectively 3 For the base value a generator rated phase to phase voltage is to be set Thu...

Page 456: ...s 10 3 3 4 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 5 High impedance grounded systems M13853 18 v10 In high impedance grounded systems ground faults cause a neutral voltage in the feeding transformer neutral Two step residual ...

Page 457: ...age collapse in that phase The other healthy phase will still have normal phase to ground voltage The residual sum will have the same value as the remaining phase to ground voltage which is shown in Figure 207 V_A V_B V_C V _ A F I L 1 F V_B V_C 3 V 0 ANSI07000189 1 en vsd ANSI07000189 V1 EN US Figure 207 Ground fault in Direct grounded system 1MRK 502 071 UUS A Section 10 Voltage protection Gener...

Page 458: ...igh impedance grounded system The measurement will be based on the neutral voltage displacement The setting parameters described below are identical for the two steps n step 1 and 2 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 tim...

Page 459: ... between different inverse time delayed undervoltage protections ACrvn BCrvn CCrvn DCrvn PCrvn Parameters for step n to set to create programmable undervoltage inverse time characteristic 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 ...

Page 460: ...the generator if the field current is not properly adjusted Loss 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 ne...

Page 461: ...ns to the normal value If a new period of overexcitation occurs after a short time interval the heating will start from a higher level therefore OEXPVPH 24 must have thermal memory A fixed cooling time constant is settable within a wide range The general experience is that the overexcitation characteristics for a number of power transformers are not in accordance with standard inverse time curves ...

Page 462: ...input can be used to block the operation for a limited time during special service conditions RESET OEXPVPH 24 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 e...

Page 463: ...e relation between rated voltage and rated frequency and set as a percentage factor Normal setting is around 108 110 depending of the capability curve for the transformer generator Pickup2 Operating level for the t_MinTripDelay definite time delay used at high overvoltages The operation is based on the relation between rated voltage and rated frequency and set as a percentage factor Normal setting...

Page 464: ...10 4 3 3 Service value report M6496 144 v4 A number of internal parameters are available as service values for use at commissioning and during service Remaining time to trip in seconds TMTOTRIP flux density VPERHZ internal thermal content in percentage of trip value THERMSTA The values are available at local HMI Substation SAsystem and PCM600 10 4 3 4 Setting example M6496 108 v5 Sufficient inform...

Page 465: ...ded up in five equal steps and the time delays t2 to t5 will be allocated to these values of overexcitation In this example each step will be 140 105 5 7 The setting of time delays t1 to t6 are listed in table 47 Table 47 Settings V f op Timer Time set s 105 t1 7200 max 112 t2 600 119 t3 60 126 t4 20 133 t5 8 140 t6 4 Information on the cooling time constant Tcool should be retrieved from the powe...

Page 466: ...MOD167723 2 v2 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Voltage differential protection VDCPTOV 60 10 5 2 Application SEMOD153893 5 v3 The Voltage differential protection VDCPTOV 60 functions can be used in some different applications Voltage unbalance protection for capacitor banks The voltage on the bus is supervised with the voltage in...

Page 467: ...ction has a block input BLOCK where a fuse failure supervision or MCB tripped can be connected to prevent problems if one fuse in the capacitor bank voltage transformer set has opened and not the other capacitor voltage is connected to input V2 It will also ensure that a fuse failure alarm is given instead of a Undervoltage or Differential voltage alarm and or tripping Fuse failure supervision SDD...

Page 468: ...se and SBase as applicable BlkDiffAtVLow The setting is to block the function when the voltages 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...

Page 469: ... expected to be acceptable V1Low The setting of the undervoltage level for the first voltage input is decided by this parameter The proposed default setting is 70 V2Low 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 paramete...

Page 470: ...fault can be disastrous Short circuit between the stator winding in the slots and stator core is the most common type of electrical fault in generators Medium and large generators normally have high impedance ground that is grounding via a neutral point resistor This resistor is dimensioned to give an ground fault current in the range 3 15 A at a solid ground fault directly at the generator high v...

Page 471: ...equivalent resistor on the low voltage side of the transformer Other types of system grounding of generator units such as direct grounding and isolated neutral are used but are quite rare In normal non faulted operation of the generating unit the neutral point voltage is close to zero and there is no zero sequence current flow in the generator When a phase to ground fault occurs the fundamental fr...

Page 472: ...shown in figure 213 and figure 214 Generator unit transformer 3V0 ANSI06000317_3_en vsd ANSI06000317 V3 EN US Figure 213 Broken delta voltage transformer measurement of 3V0 voltage Alternatively zero sequence current can be measured as shown in fig 215 Generator unit transformer V0 ANSI06000318_3_en vsd ANSI06000318 V3 EN US Figure 214 Neutral point voltage transformer measurement of neutral point...

Page 473: ...easurement In some power plants the connection of the neutral point resistor is made to the generator unit transformer neutral point This is often done if several generators are connected to the same bus The detection of ground fault can be made by current measurement as shown in figure 216 Generator unit transformer 3I0 IA IB IC ANSI06000320_3_en vsd ANSI06000320 V3 EN US Figure 216 Residual curr...

Page 474: ...rates some degree of 3rd harmonic voltages These voltages have the same phase angle in the three phases This means that there will be a harmonic voltage in the generator neutral during normal operation This component is used for detection of ground faults in the generator close to the neutral If the 3rd harmonic voltage generated in the generator is less than 0 8 V RMS secondary the 3rd harmonic b...

Page 475: ... the generator terminals The setting Beta gives the proportion of the 3rd harmonic voltage in the neutral point of the generator to be used as restrain quantity Beta must be set so that there is no risk of trip during normal non faulted operation of the generator On the other hand if Beta is set high this will limit the portion of the stator winding covered by the protection The default setting 3 ...

Page 476: ...otection The setting is given as of the rated phase to ground voltage A normal setting is in the range 5 10 VT3BlkLevel VT3BlkLevel gives a voltage level for the 3rd harmonic voltage level at the terminal side If this level is lower than the setting the function is blocked The setting is given as of the rated phase to ground voltage The setting is typically 1 t3rdH t3rdH gives the trip delay of th...

Page 477: ... such situations and provides an output signal suitable for load shedding generator boosting HVDC set point 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 81 is very sensitive and accurate and is used to alert operators t...

Page 478: ... for the equipment Power system protection by load shedding The setting has to be below the lowest occurring normal frequency and well above the lowest acceptable frequency for power stations or sensitive 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 s...

Page 479: ...operators that frequency has slightly deviated from the set point and that manual actions might be enough 11 2 3 Setting guidelines M14959 3 v7 All the frequency and voltage magnitude conditions in the system where SAPTOF 81 performs its functions must be considered The same also applies to the associated equipment its frequency and time characteristic There are two application areas for SAPTOF 81...

Page 480: ...Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Rate of change of frequency protection SAPFRC df dt SYMBOL N V1 EN US 81 11 3 2 Application M14966 3 v5 Rate of change of frequency protection SAPFRC 81 is applicable in all situations where reliable detection of change of the fundamental power system voltage frequency is needed SAPFRC 81 can be us...

Page 481: ...ominal level if the rate of change frequency is large with respect to sign The pickup value for SAPFRC 81 is set in Hz s All voltage magnitude related settings are made as a percentage of a settable base voltage which normally is set to the primary nominal voltage level phase phase of the power system or the high voltage equipment under consideration SAPFRC 81 is not instantaneous since the functi...

Page 482: ... of generation surplus while a lack of generation results in a drop of frequency The turbine blade is designed with its natural frequency adequately far from the rated speed or multiples of the rated speed of the turbine This design avoids the mechanical resonant condition which can lead to an increased mechanical stress on turbine blade If the ratio between the turbine resonant frequencies to the...

Page 483: ...ns The frequency limitations and their time restrictions for different types of turbines are similar in many aspects with steam turbine limitations Certain differences in design and applications may result in different protective requirements Therefore for different type of turbine systems different recommendations on the time restriction limits are specified by the manufacturer However the IEEE A...

Page 484: ...irement of continuous operation within the confines of their capability curves over the ranges of 5 in voltage and 2 in frequency Operation of the machine at rated power outside these voltage frequency limits lead to increased temperatures and reduction of insulation life 11 4 3 Setting guidelines GUID 62C6D764 CAF2 4C2F B91A EBC611987D72 v3 Among the generator protection functions the frequency t...

Page 485: ...above minimum load EnaVoltCheck set to Disable tCont to be coordinated to the grid requirements tAccLimit FreqHighLimit and FreqLowLimit setting is derived from the turbine manufacturer s operating requirements note that FreqLowLimit setting must always be lower than the set value of FreqHighLimit FTAQFVR 81A used to protect a generator Frequency during start up and shutdown is normally not calcul...

Page 486: ...480 ...

Page 487: ... 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 ground phase to phase residual or sequence voltage comp...

Page 488: ...ltage 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 it shall be once more noted that all these four protection elements measure one selected current quantity ...

Page 489: ...th minimum magnitude Phase angle will be set to 0 all the time 10 PhaseA PhaseB CVGAPC function will measure the current phasor internally calculated as the vector difference between the phase A current phasor and phase B current phasor VA VB 11 PhaseB PhaseC CVGAPC function will measure the current phasor internally calculated as the vector difference between the phase B current phasor and phase ...

Page 490: ...phase with minimum magnitude Phase angle will be set to 0 all the time 10 PhaseA PhaseB CVGAPC function will measure the voltage phasor internally calculated as the vector difference between the phase A voltage phasor and phase B voltage phasor VA VB 11 PhaseB PhaseC CVGAPC function will measure the voltage phasor internally calculated as the vector difference between the phase B voltage phasor an...

Page 491: ... from 1 to 9 as shown in table 49 2 rated phase to phase voltage of the protected object in primary kV when the measured Voltage Quantity is selected from 10 to 15 as shown in table 49 12 1 2 3 Application possibilities SEMOD53443 136 v2 Due to its flexibility the general current and voltage protection CVGAPC function can be used with appropriate settings and configuration in many different applic...

Page 492: ...ergizing of a generator which is at standstill or on turning gear causes it to behave and accelerate similarly to an induction motor The machine at this point essentially represents the subtransient reactance to the system and it can be expected to draw from one to four per unit current depending on the equivalent system impedance Machine terminal voltage can range from 20 to 70 of rated voltage a...

Page 493: ... overcurrent characteristic is selected the trip time of the stage will be the sum of the inverse time delay and the set definite time delay Thus if only the inverse time delay is required it is important to set the definite time delay for that stage to zero M13088 237 v3 The parameters for the general current and voltage protection function CVGAPC are set via the local HMI or Protection and Contr...

Page 494: ...t RCADir to value 65 degrees NegSeq current typically lags the inverted NegSeq voltage for this angle during the fault 7 Set ROADir to value 90 degree 8 Set LowVolt_VM to value 2 NegSeq voltage level above which the directional element will be enabled 9 Enable one overcurrent stage for example OC1 10 By parameter CurveType_OC1 select appropriate TOC IDMT or definite time delayed curve in accordanc...

Page 495: ... pickup signals from OC1 and OC2 elements shall be used to send forward and reverse signals to the remote end of the power line the available scheme communications function block within IED shall be used between multipurpose protection function and the communication equipment in order to insure proper conditioning of the above two pickup signals Furthermore the other built in UC OV and UV protecti...

Page 496: ...t changing the value for the operate time of the negative sequence inverse overcurrent IED op 2 NS r 2 TD t I x I 1 x æ ö ç è ø EQUATION1741 ANSI V1 EN US Equation 244 In order to achieve such protection functionality with one CVGAPC functions the following must be done 1 Connect three phase generator currents to one CVGAPC instance for example GF01 2 Set parameter CurrentInput to value NegSeq 3 S...

Page 497: ...r this particular example the following settings shall be entered to insure proper function operation 1 select negative sequence current as measuring quantity for this CVGAPC function 2 make sure that the base current value for the CVGAPC function is equal to the generator rated current 3 set TD_OC1 20 4 set A_OC1 1 0 072 204 0816 5 set B_OC1 0 0 C_OC1 0 0 and P_OC1 2 0 6 set PickupCurr_OC1 7 Prop...

Page 498: ... the IEC standard or TD 41 4 for the ANSI standard Im is the magnitude of the measured current Ir is the generator rated current This formula is applicable only when measured current for example positive sequence current exceeds a pre set value typically in the range from 105 to 125 of the generator rated current By defining parameter x equal to the per unit value for the desired pickup for the ov...

Page 499: ...248 is compared with the equation 249 for the inverse time characteristic of the OC1 step in it is obvious that if the following rules are followed 1 set TD equal to the IEC or ANSI standard generator capability value 2 set parameter A_OC1 equal to the value 1 x2 3 set parameter C_OC1 equal to the value 1 x2 4 set parameters B_OC1 0 0 and P_OC1 2 0 5 set PickupCurr_OC1 equal to the value x then th...

Page 500: ...ent restraint feature The following shall be done in order to insure proper operation of the function 1 Connect three phase currents from the protected object to one CVGAPC instance for example GF03 2 Set CurrentInput to value UnbalancePh 3 Set EnRestrainCurr to On 4 Set RestrCurrInput to MaxPh 5 Set RestrCurrCoeff to value 0 97 6 Set base current value to the rated current of the protected object...

Page 501: ... PosSeq for this setting parameter 4 Set base current value to the rated generator current primary amperes 5 Set base voltage value to the rated generator phase to phase voltage in kV 6 Enable one overcurrent step for example OC1 7 Select CurveType_OC1 to value ANSI Very inv 8 If required set minimum operating time for this curve by using parameter tMin_OC1 default value 0 05s 9 Set PickupCurr_OC1...

Page 502: ... angle 7 Set parameter ROADir to value 90 degree 8 Set parameter LowVolt_VM to value 5 9 Enable one overcurrent step for example OC1 10 Select parameter CurveType_OC1 to value IEC Def Time 11 Set parameter PickupCurr_OC1 to value 38 12 Set parameter tDef_OC1 to value 2 0s typical setting 13 Set parameter DirMode_OC1 to Forward 14 Set parameter DirPrinc_OC1 to IcosPhi V 15 Set parameter ActLowVolt1...

Page 503: ... 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 develop in the rotor during the period it is accelerating Although the rotor may be t...

Page 504: ...nction The overvoltage function will detect the situation when the generator is taken into operation and will disable the overcurrent function The overcurrent function will have a pick up value about 50 of the rated current of the generator The trip delay will be about 50 ms The inadvertent energization function is realized by means of the general current and voltage protection function CVGAPC The...

Page 505: ...used in this application EnRestrainCurr is set Disabled It can be set Enabled if the instance is used also for other protection functions 12 1 3 9 Settings for OC1 SEMOD158317 24 v3 Operation_OC1 The parameter Operation_OC1 is set Enabled to activate this function PickupCurr_OC1 The operate current level for OC1 is set by the parameter PickupCurr_OC1 The setting is made in of IBase The setting sho...

Page 506: ...t_OV1 The operate voltage level for OV1 is set by the parameter PickupVolt_OV1 The setting is made in of VBase The setting should be made so that the protection blocks the function at all situation of normal operation The setting is done as the lowest operate voltage level of the generator with an added margin The setting 85 can be used in most cases CurveType_OV1 The time delay of OV1 should be o...

Page 507: ...hosen ResCrvType_UV1 The reset time delay of UV1 should be delayed a short time so that the function is not blocked before operation of OC1 in case of inadvertent energizing of the generator The parameter ResCrvType_UV1 is set to Frozen timer tDef_UV1 The time delay is set in the parameter tDef_UV1 and is set so that the inadvertent energizing function is activated after some time when the generat...

Page 508: ...502 ...

Page 509: ...phases and the residual quantity the input samples from the TRM module which are coming at rate of 20 samples per fundamental 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 ...

Page 510: ...filter output can also be connected to the measurement function blocks such as CVMMXN Measurements CMMXU Phase current measurement VMMXU Phase phase voltage measurement etc in order to report the extracted phasor values to the supervisory system e g MicroSCADA The following figure shoes typical configuration connections required to utilize this filter in conjunction with multi purpose function as ...

Page 511: ...minimal subsynchronous current trip level was set at IS0 300 Amperes primary Solution First the IED configuration shall be arranged as shown in Figure 221 Then the settings for SMAI HPAC filter and multipurpose function shall be derived from existing relay settings in the following way The subsynchronous current frequency is calculated as follows 50 18 5 31 5 s f Hz Hz Hz EQUATION13000030 V1 EN US...

Page 512: ...teristics in the TRM p t A s B k i C in æ ö ç ç ç æ ö ç ç è ø è ø EQUATION13000031 V1 EN US Equation 252 In order to adapt to the previous relay characteristic the above equation can be re written in the following way 01 1 1 0 so s so t K I s T I I æ ö ç ç ç æ ö ç ç ç è ø è ø EQUATION13000032 V1 EN US Equation 253 Thus if the following rules are followed when multi purpose overcurrent stage one is...

Page 513: ...Curr Off RestrCurrInput PosSeq RestrCurrCoeff 0 00 RCADir 75 ROADir 75 LowVolt_VM 0 5 OC1 Setting Group1 Operation_OC1 On StartCurr_OC1 30 0 CurrMult_OC1 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 502 071 UUS A Section 13 System protection and control Generator ...

Page 514: ...508 ...

Page 515: ...d can be blocked and an alarm given In case of large 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 87 must be sensitive and have short operat...

Page 516: ...upervision FUFSPVC IP14556 1 v3 14 2 1 Identification M14869 1 v4 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Fuse failure supervision FUFSPVC 14 2 2 Application SEMOD113803 4 v10 Different protection functions within the protection IED operates on the basis of the measured voltage in the relay point Examples are impedance protection functio...

Page 517: ...cases where the line can have a weak infeed of zero sequence current this function shall be avoided A criterion based on delta current and delta voltage measurements can be added to the fuse failure supervision function in order to detect a three phase fuse failure This is beneficial for example during three phase transformer switching 14 2 3 Setting guidelines IP15000 1 v1 14 2 3 1 General M13683...

Page 518: ...r enables selecting interactions between the negative sequence and zero sequence algorithm In normal applications the OpModeSel is set to either V2I2 for selecting negative sequence algorithm or V0I0 for zero sequence based algorithm If system studies or field experiences shows that there is a risk that the fuse failure function will not be activated due to the system conditions the dependability ...

Page 519: ...ing to the setting GlobalBaseSel 14 2 3 4 Zero sequence based M13683 43 v8 The IED setting value 3V0PU is given in percentage of the base voltage VBase The setting of 3V0PU should not be set lower than the value that is calculated according to equation 256 100 3 0 3 0 3 VBase V PU V EQUATION1759 ANSI V4 EN US Equation 256 where 3V0 is the maximal zero sequence voltage during normal operation condi...

Page 520: ...tion of dU dt and ISetprim the primary current for operation of dI dt the setting of DVPU and DIPU will be given according to equation 258 and equation 259 DVPU VSet VBase prim 100 EQUATION1765 ANSI V2 EN US Equation 258 DIPU ISet IBase prim 100 ANSIEQUATION2385 V2 EN US Equation 259 The voltage thresholds VPPU is used to identify low voltage condition in the system Set VPPU below the minimum oper...

Page 521: ...pplication GUID AD63BF6C 0351 4E48 9FB2 9AB5CF0C521E v2 Some protection functions operate on the basis of measured voltage at the relay point Examples of such protection functions are distance protection function undervoltage function and energisation check function These functions might mal operate if there is an incorrect measured voltage due to fuse failure or other kind of faults in voltage me...

Page 522: ...CDD166 v2 The parameters for Fuse failure supervision VDSPVC are set via the local HMI or PCM600 GUID 0B298162 C939 47E4 A89B 7E6BD7BEBB2C v2 The voltage input type phase to phase or phase to neutral is selected using ConTypeMain and ConTypePilot parameters for main and pilot fuse groups respectively Section 14 1MRK 502 071 UUS A Secondary system supervision 516 Generator protection REG670 2 2 ANS...

Page 523: ...ase to phase voltage of measured fuse group the setting of Vdif Main block and Vdif Pilot alarm will be given according to equation 260 Vdif Main block or Vdif Pilot alarm SetPrim Base V V 100 ANSI13000279 V1 EN US Equation 260 VSetPrim is defined as phase to neutral or phase to phase voltage dependent of the selected ConTypeMain and ConTypePilot If ConTypeMain and ConTypePilot are set to Ph N tha...

Page 524: ...518 ...

Page 525: ... are satisfied in order to avoid stress on the network and its components The systems are defined as asynchronous when the frequency difference between bus and line is larger than an adjustable parameter If the frequency difference is less than this threshold value the system is defined to have a parallel circuit and the synchronism check function is used The synchronizing function measures the di...

Page 526: ... of slip frequency and required pre closing time The synchronizing function compensates for the measured slip frequency as well as the circuit breaker closing delay The phase angle advance is calculated continuously The calculation of the operation pulse sent in advance is using the measured SlipFrequency and the set tBreaker time To prevent incorrect closing pulses a maximum closing angle between...

Page 527: ...not require any synchronism check since the system is tied together by two phases SESRSYN 25 function block includes both the synchronism check function and the energizing function to allow closing when one side of the breaker is dead SESRSYN 25 function also includes a built in voltage selection scheme which allows adoption to various busbar arrangements en04000179_ansi vsd ANSI04000179 V1 EN US ...

Page 528: ...nce a highspeed auto reclosing takes place This can cause a power swing in the net and the phase angle difference may begin to oscillate Generally the frequency difference is the time derivative of the phase angle difference and will typically oscillate between positive and negative values When the circuit breaker needs to be closed by auto reclosing after fault clearance some frequency difference...

Page 529: ... connection of disconnected lines and buses to energized buses and lines The energizing check function measures the bus and line voltages and compares them to both high and low threshold values The output is given only when the actual measured conditions match the set conditions Figure 225 shows two substations where one 1 is energized and the other 2 is not energized The line between CB A and CB ...

Page 530: ...ay the equipment is considered non energized Dead if the voltage is below the set value for VDeadBusEnerg or VDeadLineEnerg 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 extinguishing capacitors in the circuit breakers This voltage can be as high as 50 or more of the b...

Page 531: ...lso be used if a three phase voltage is present The signal BLKV 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 25 function is blocked The VB1OK VB2OK and VB1FF VB2FF inputs are related to the busbar voltage and the VL1OK VL2OK and VL1FF VL2FF inputs are rela...

Page 532: ...different parameter settings Below are some examples of how different arrangements are connected to the IED analog inputs and to the function block SESRSYN 25 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 ti...

Page 533: ...DVCLS VDIFFME FRDIFFME PHDIFFME Vbus VLine MODEAEN MODEMEN ANSI10000093 V1 EN US Figure 227 Connection of SESRSYN 25 function block in a single busbar arrangement Figure 227 illustrates connection principles for a single busbar For the SESRSYN 25 function there is one voltage transformer on each side of the circuit breaker The voltage transformer circuit connections are straightforward no special ...

Page 534: ... FRDIFFM PHDIFFM INADVCLS VDIFFME FRDIFFME PHDIFFME Vbus VLine MODEAEN MODEMEN ANSI10000094 V1 EN US Figure 228 Connection of SESRSYN 25 function block in a single breaker double busbar arrangement with external voltage selection In this type of arrangement no internal voltage selection is required The voltage selection is made by external relays typically connected according to figure 228 Suitabl...

Page 535: ...KSC VDIFFSC FRDIFFA PHDIFFA FRDIFFM PHDIFFM INADVCLS VDIFFME FRDIFFME PHDIFFME Vbus VLine MODEAEN MODEMEN ANSI10000095 V1 EN US Figure 229 Connection of the SESRSYN function block in a single breaker double busbar arrangement with internal voltage selection When internal voltage selection is needed the voltage transformer circuit connections are made according to figure 229 The voltage from the bu...

Page 536: ...DIFFM INADVCLS VDIFFME FRDIFFME PHDIFFME Vbus VLine MODEAEN MODEMEN SESRSYN 25 V3PB1 V3PB2 V3PL1 V3PL2 BLOCK BLKSYNCH BLKSC BLKENERG BUS1_OP BUS1_CL BUS2_OP BUS2_CL LINE1_OP LINE1_CL LINE2_OP LINE2_CL VB1OK VB1FF VB2OK VB2FF VL1OK VL1FF VL2OK VL2FF STARTSYN TSTSYNCH TSTSC TSTENERG AENMODE MENMODE SYNOK AUTOSYOK AUTOENOK MANSYOK MANENOK TSTSYNOK TSTAUTSY TSTMANSY TSTENOK VSELFAIL B1SEL B2SEL L1SEL ...

Page 537: ... half M12330 3 v8 Figure 231 describes a breaker and a half arrangement with three SESRSYN functions in the same IED each of them handling voltage selection for WA1_QA1 TIE_QA1 and WA2_QA1 breakers respectively The voltage from busbar 1 VT is connected to V3PB1 on all three function blocks and the voltage from busbar 2 VT is connected to V3PB2 on all three function blocks The voltage from line1 VT...

Page 538: ...M PHDIFFM INADVCLS VDIFFME FRDIFFME PHDIFFME Vbus VLine MODEAEN MODEMEN SESRSYN 25 V3PB1 V3PB2 V3PL1 V3PL2 BLOCK BLKSYNCH BLKSC BLKENERG BUS1_OP BUS1_CL BUS2_OP BUS2_CL LINE1_OP LINE1_CL LINE2_OP LINE2_CL VB1OK VB1FF VB2OK VB2FF VL1OK VL1FF VL2OK VL2FF STARTSYN TSTSYNCH TSTSC TSTENERG AENMODE MENMODE SYNOK AUTOSYOK AUTOENOK MANSYOK MANENOK TSTSYNOK TSTAUTSY TSTMANSY TSTENOK VSELFAIL B1SEL B2SEL L1...

Page 539: ..._QA1 breaker and belonging disconnectors BUS2_OP CL Position of WA2_QA1 breaker and belonging disconnectors LINE1_OP CL Position of LINE1_QB9 disconnector LINE2_OP CL Position of LINE2_QB9 disconnector VB1OK FF Supervision of WA1_MCB fuse VB2OK FF Supervision of WA2_MCB fuse VL1OK FF Supervision of LINE1_MCB fuse VL2OK FF Supervision of LINE2_MCB fuse Setting CBConfig Tie CB WA2_QA1 BUS1_OP CL Pos...

Page 540: ... divided into four different setting groups General Synchronizing Synchrocheck and Energizingcheck General settings Operation The operation mode can be set Enabled or Disabled The setting Disabled disables the whole function GblBaseSelBus and GblBaseSelLine These configuration settings are used for selecting one of twelve GBASVAL functions which then is used as base value reference voltage for bus...

Page 541: ...ode and the output signal depends on the input conditions VHighBusSynch and VHighLineSynch The voltage level settings shall be chosen in relation to the bus line network voltage The threshold voltages VHighBusSynch and VHighLineSynch 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 VDiffSynch Setting of the voltage diff...

Page 542: ...hich synchronizing is accepted To minimize the moment stress when synchronizing 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 conf...

Page 543: ...oltages VDiffSC The setting for voltage difference between line and bus in p u This setting in p u is defined as V Bus GblBaseSelBus V Line GblBaseSelLine A normal setting 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...

Page 544: ...ings can be used for automatic and manual closing of the circuit breaker The settings for each of them are Disabled the energizing function is disabled DLLB Dead Line Live Bus the line voltage is below set value of VDeadLineEnerg and the bus voltage is above set value of VLIveBusEnerg DBLL Dead Bus Live Line the bus voltage is below set value of VDeadBusEnerg and the line voltage is above set valu...

Page 545: ...rg The purpose of the timer delay settings tAutoEnerg and tManEnerg is to ensure that the dead side remains de energized and that the condition is not due to a temporary interference Should the conditions not persist for the specified time the delay timer is reset and the procedure is restarted when the conditions are fulfilled again Circuit breaker closing is thus not permitted until the energizi...

Page 546: ...S Figure 232 Overview of the apparatus control functions Features in the apparatus control function Operation of primary apparatuses Select Execute principle to give high security Selection and reservation function to prevent simultaneous operation Selection and supervision of operator place Command supervision Block deblock of operation Block deblock of updating of position indications Substituti...

Page 547: ...SV also are included in the apparatus control function The application description for all these functions can be found below The function SCILO in the Figure 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 ...

Page 548: ... QCBAY 152 ANSI05000116 V1 EN US Figure 233 Signal flow between apparatus control function blocks when all functions are situated within the IED Section 15 1MRK 502 071 UUS A Control 542 Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 Application manual ...

Page 549: ...CV XLNPROXY QA1 QB1 QB9 GOOSEover process bus IEC16000070 1 EN vsdx IEC16000070 V1 EN US Figure 234 Signal flow between apparatus control functions with XCBR and XSWI located in a breaker IED 1MRK 502 071 UUS A Section 15 Control Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 543 Application manual ...

Page 550: ...or each PSTO value are shown in Table 52 Table 52 Accepted originator categories for each PSTO Permitted Source To Operate Originator orCat 0 Off 4 5 6 1 Local 1 4 5 6 2 Remote 2 3 4 5 6 3 Faulty 4 5 6 4 Not in use 4 5 6 5 All 1 2 3 4 5 6 6 Station 2 4 5 6 7 Remote 3 4 5 6 PSTO All then it is no priority between operator places All operator places are allowed to operate According to IEC 61850 stan...

Page 551: ...ocal or from remote For IEC 61850 8 1 communication the Bay Control function can be set to discriminate between commands with orCat station and remote 2 and 3 The selection is then done through the IEC 61850 8 1 edition 2 command LocSta QCBAY also provides blocking functions that can be distributed to different apparatuses within the bay There are two different blocking alternatives Blocking of up...

Page 552: ...sequence is cancelled In the case when there are three one phase switches SXCBR connected to the switch controller function the switch controller will merge the position of the three switches to the resulting three phase position In case of a pole discrepancy situation that is the positions of the one phase switches are not equal for a time longer than a settable time an error signal will be given...

Page 553: ...ory functionality 15 2 1 4 Proxy for signals from switching device via GOOSE XLNPROXY GUID 2DA1E47C 5A9A 4C53 8D60 7B1729EF6B90 v1 The purpose of the proxy for signals from switching device via GOOSE XLNPROXY is to give the same internal representation of the position status and control response for a switch modeled in a breaker IED as if represented by a SXCBR or SXSWI function The command respon...

Page 554: ...tion with XLNPROXY and GOOSEXLNRCV where all the IEC 61850 modelled data is used including selection Section 15 1MRK 502 071 UUS A Control 548 Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 Application manual ...

Page 555: ... 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 failed and the cause o...

Page 556: ...t are used for the CBOpCap data of a XCBR respectively SwOpCap for a XSWI The interpretation for the command following is controlled through the setting SwitchType 15 2 1 5 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 c...

Page 557: ... 60 instances are available The received signals are either the request for reservation from another bay or the acknowledgment from each bay respectively which have received a request from this bay Also the information of valid transmission over the station bus must be received en 05000117 _ansi vsd IED IED From other SCSWI in the bay To other SCSWI in the bay 3 Station bus 3 RESIN EXCH _OUT EXCH ...

Page 558: ...t 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 240 Application principle for an alternative reservation solution 15 2 2 Interaction between modules M16626 3 v8 A typical bay with apparatus control function...

Page 559: ...e Autorecloser SMBRREC 79 consists of the facilities to automatically close a tripped breaker with respect to a number of configurable conditions The logical node Interlocking SCILO 3 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 3 The Synchronism energizing ch...

Page 560: ...king QCRSV Reservation Res req Res granted GAPC Generic Automatic Process Control Open 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 Sectio...

Page 561: ... SCILO SCILO Synchrocheck OK QCRSV Reservation Res req Res granted GAPC Generic Automatic Process Control Open Close Open Close Enable close Enable open Open rel Close rel Open rel SMPPTRC Trip logic Position Enable open Enable close Pos from other bays I O Open cmd Close cmd Interlocking Interlocking ANSI05000120 V2 EN US Figure 241 Example overview of the interactions between functions in a typi...

Page 562: ...e default for control of circuit breakers disconnectors and grounding switches the control model is set to SBO Enh Select Before Operate with enhanced security When the operation shall be performed in one step and no monitoring of the result of the command is desired the model direct control with normal security is used At control with enhanced security there is an additional supervision of the st...

Page 563: ...is the allowed time to have discrepancy between the poles at control of three single phase breakers At discrepancy an output signal is activated to be used for trip or alarm and during a command the control function is reset and a cause code is given SuppressMidPos when On suppresses the mid position during the time tIntermediate of the connected switches The parameter InterlockCheck decides if in...

Page 564: ... operating capability CbOpCap Switch operating capability SwOpCap 1 None None 2 Open Open 3 Close Open Close 4 Open Close Open Close and Open 5 Close Open Close Open Larger values handled as 4 both Close and Open 6 Open Close Open Close Open 7 more 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 expire...

Page 565: ...o ensure that energizing is always from one side for example the high voltage side of a transformer This section only deals with the first point and only with restrictions caused by switching devices other than the one to be controlled This means that switch interlock because of device alarms is not included in this section Disconnectors and grounding switches have a limited switching capacity Dis...

Page 566: ...f disconnectors may be up to 10 seconds Should both indications stay low for a longer period the position indication will be interpreted as unknown If both indications stay high something is wrong and the state is again treated as unknown In both cases an alarm is sent to the operator Indications from position sensors shall be self checked and system faults indicated by a fault signal In the inter...

Page 567: ...A2 B WA7 C 789 en04000478_ansi vsd 152 ANSI04000478 V1 EN US Figure 242 Switchyard layout ABC_LINE 3 M13560 4 v5 The signals from other bays connected to the module ABC_LINE 3 are described below 15 3 2 2 Signals from bypass busbar M13560 6 v5 To derive the signals Signal BB7_D_OP All line disconnectors on bypass WA7 except in the own bay are open VP_BB7_D The switch status of disconnectors on byp...

Page 568: ...9OPTR bay n 1 VP789TR bay 1 VP789TR bay 2 VP789TR bay n 1 EXDU_BPB bay 1 EXDU_BPB bay 2 EXDU_BPB bay n 1 ANSI04000477 V1 EN US Figure 243 Signals from bypass busbar in line bay n 15 3 2 3 Signals from bus coupler M13560 31 v4 If the busbar is divided by bus section disconnectors into bus sections the busbar busbar connection could exist via the bus section disconnector and bus coupler within the o...

Page 569: ...sion error from any bus coupler bay BC These signals from each bus coupler bay ABC_BC are needed Signal BC12CLTR A bus coupler connection through the own bus coupler exists between busbar WA1 and WA2 BC17OPTR No bus coupler connection through the own bus coupler between busbar WA1 and WA7 BC17CLTR A bus coupler connection through the own bus coupler exists between busbar WA1 and WA7 BC27OPTR No bu...

Page 570: ...bus section coupler bay A1A2_BS rather than the bus section disconnector bay A1A2_DC must be used For B1B2_BS corresponding signals from busbar B are used The same type of module A1A2_BS is used for different busbars that is for both bus section circuit breakers A1A2_BS and B1B2_BS Signal S1S2OPTR No bus section coupler connection between bus sections 1 and 2 S1S2CLTR A bus section coupler connect...

Page 571: ...7TR sect 2 EXDU_BC sect 1 EXDU_DC A1A2 EXDU_DC B1B2 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_ansi vsd AND AND AND OR AND AND OR AND OR AND AND ANSI04000480 V1 EN US Figure 245 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 sec...

Page 572: ...P 1 BC_17_CL 0 BC_27_OP 1 BC_27_CL 0 EXDU_BPB 1 VP_BB7_D 1 VP_BC_17 1 VP_BC_27 1 If there is no second busbar WA2 and therefore no 289 disconnector then the interlocking for 289 is not used The state for 289 2189G 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 289_OP 1 289_CL 0 2189G_OP 1 218...

Page 573: ... 2 Configuration M13553 138 v4 The signals from the other bays connected to the bus coupler module ABC_BC are described below 15 3 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...

Page 574: ...e 247 Signals from any bays in bus coupler bay n If the busbar is divided by bus section disconnectors into bus sections the signals BBTR are connected in parallel if both bus section disconnectors are closed So for the basic project specific logic for BBTR above add this logic Section 1 Section 2 A1A2_DC BS B1B2_DC BS ABC_LINE ABC_BC ABC_LINE ABC_BC WA1 A1 WA2 B1 WA7 C C B2 A2 en04000482_ansi vsd...

Page 575: ...usbars that is for both bus section circuit breakers A1A2_BS and B1B2_BS Signal S1S2OPTR No bus section coupler connection between bus sections 1 and 2 VPS1S2TR The switch status of bus section coupler BS is valid EXDU_BS No transmission error from the bay that contains the above information For a bus coupler bay in section 1 these conditions are valid en04000483_ansi vsd AND VP_BBTR EXDU_12 AND B...

Page 576: ... from each bus coupler bay ABC_BC except the own bay are needed Signal BC12CLTR A bus coupler connection through the own bus coupler exists 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 each bus section disconnector bay A1A2_DC are also needed For B1B2_DC corresponding signal...

Page 577: ...i vsd AND AND DCCLTR A1A2 DCCLTR B1B2 BC12CLTR sect 2 VPDCTR A1A2 VPDCTR B1B2 VPBC12TR sect 2 EXDU_DC A1A2 EXDU_DC B1B2 EXDU_BC sect 2 ANSI04000485 V1 EN US Figure 251 Signals to a bus coupler bay in section 1 from a bus coupler bay in another 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 3 3 5 Configuration s...

Page 578: ... VP_BBTR 1 15 3 4 Interlocking for transformer bay AB_TRAFO 3 IP14149 1 v2 15 3 4 1 Application M13567 3 v7 The interlocking for transformer bay AB_TRAFO 3 function is used for a transformer bay connected to a double busbar arrangement according to figure 252 The function is used when there is no disconnector between circuit breaker and transformer Otherwise the interlocking for line bay ABC_LINE ...

Page 579: ...s connected to the module AB_TRAFO are described below 15 3 4 2 Signals from bus coupler M13566 6 v4 If the busbar is divided by bus section disconnectors into bus sections the busbar busbar connection could exist via the bus section disconnector and bus coupler within the other bus section 1MRK 502 071 UUS A Section 15 Control Generator protection REG670 2 2 ANSI and Injection equipment REX060 RE...

Page 580: ...EXDU_BC No transmission error from bus coupler bay BC The logic is identical to the double busbar configuration Signals from bus coupler 15 3 4 3 Configuration setting M13566 22 v5 If there are no second busbar B and therefore no 289 disconnector then the interlocking for 289 is not used The state for 289 2189G BC_12 are set to open by setting the appropriate module inputs as follows In the functi...

Page 581: ...circuit breaker WA1 A1 289 489G 189 389G WA2 A2 en04000516_ansi vsd 289G 189G A1A2_BS 152 ANSI04000516 V1 EN US Figure 254 Switchyard layout A1A2_BS 3 M15111 4 v3 The signals from other bays connected to the module A1A2_BS are described below 15 3 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 breakers are closed...

Page 582: ...us coupler bay ABC_BC are needed Signal 1289OPTR 189 or 289 or both are open VP1289TR The switch status of 189 and 289 are valid EXDU_12 No transmission error from the bay that contains the above information 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 i...

Page 583: ...12OPTR sect 2 1289OPTR bay 1 sect 1 1289OPTR bay n sect 1 BBTR_OP VP_BBTR EXDU_12 OR AND OR AND AND AND VPS1S2TR B1B2 VPBC12TR sect 1 VP1289TR bay 1 sect 2 VP1289TR bay n sect 1 VPBC12TR sect 2 VP1289TR bay 1 sect 1 VP1289TR bay n sect 1 AND 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 ANSI04000490 V1 EN US Figure 25...

Page 584: ... EXDU_12 bay n sect 2 EXDU_12 bay 1 sect 1 EXDU_12 bay n sect 1 EXDU_BS A1A2 EXDU_BC sect 1 EXDU_BC sect 2 ANSI04000491 V1 EN US Figure 257 Signals from any bays for a bus section circuit breaker between sections B1 and B2 15 3 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 152 open circuit breaker is n...

Page 585: ... 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 en04000493_ansi...

Page 586: ...above information If 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 ...

Page 587: ...ese conditions from the A2 busbar section are valid en04000495_ansi vsd 189OPTR bay 1 sect A2 S2DC_OP VPS2_DC EXDU_BB 189OPTR bay n sect A2 VP189TR bay 1 sect A2 VP189TR bay n sect A2 VPDCTR A2 A3 EXDU_BB bay n sect A2 AND DCOPTR A2 A3 EXDU_BB bay 1 sect A2 EXDU_DC A2 A3 AND AND ANSI04000495 V1 EN US Figure 261 Signals from any bays in section A2 to a bus section disconnector For a bus section dis...

Page 588: ... 289OPTR 22089OTR bay n sect B2 VP289TR V22089TR bay 1 sect B2 VP289TR V22089TR bay n sect B2 VPDCTR B2 B3 EXDU_BB bay n sect B2 AND DCOPTR B2 B3 EXDU_BB bay 1 sect B2 EXDU_DC B2 B3 AND AND ANSI04000497 V1 EN US Figure 263 Signals from any bays in section B2 to a bus section disconnector 15 3 6 3 Signals in double breaker arrangement M13542 80 v5 If the busbar is divided by bus section disconnecto...

Page 589: ...section 1 is valid VPS2_DC The switch status of all disconnectors on bus section 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 189OPTR 189 is open 289OPTR 289 is open VP189TR The switch status of 189 is valid VP289TR The switch status of 289 is valid EXDU_DB No transmission...

Page 590: ...e A2 busbar section are valid en04000500_ansi vsd 189OPTR bay 1 sect A2 S2DC_OP VPS2_DC EXDU_BB AND 189OPTR bay n sect A2 VP189TR bay 1 sect A2 VP189TR bay n sect A2 EXDU_DB bay 1 sect A2 EXDU_DB bay n sect A2 AND AND ANSI04000500 V1 EN US Figure 266 Signals from double breaker bays in section A2 to a bus section disconnector For a bus section disconnector these conditions from the B1 busbar secti...

Page 591: ... sect B2 EXDU_DB bay n sect B2 AND AND ANSI04000502 V1 EN US Figure 268 Signals from double breaker bays in section B2 to a bus section disconnector 15 3 6 4 Signals in breaker and a half 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 592: ... status of disconnectors on bus section 2 is valid EXDU_BB No transmission error from breaker and a half BH that contains the above information 15 3 7 Interlocking for busbar grounding switch BB_ES 3 IP14164 1 v4 15 3 7 1 Application M15015 3 v7 The interlocking for busbar grounding switch BB_ES 3 function is used for one busbar grounding switch on any busbar parts according to figure 270 89G en04...

Page 593: ...line bay ABC_LINE each transformer bay AB_TRAFO and each bus coupler bay ABC_BC are needed Signal 189OPTR 189 is open 289OPTR 289 is open AB_TRAFO ABC_LINE 22089OTR 289 and 2089 are open ABC_BC 789OPTR 789 is open VP189TR The switch status of 189 is valid VP289TR The switch status of 289 is valid V22089TR The switch status of 289and 2089 is valid VP789TR The switch status of 789 is valid EXDU_BB N...

Page 594: ...open 289OPTR 289 is open VP189TR The switch status of 189 is valid VP289TR The switch status of 289 is valid EXDU_BS No transmission error from the bay BS bus section coupler bay that contains the above information For a busbar grounding switch these conditions from the A1 busbar section are valid en04000506_ansi vsd 189OPTR bay 1 sect A1 BB_DC_OP VP_BB_DC EXDU_BB 189OPTR bay n sect A1 VP189TR bay...

Page 595: ...EXDU_BB bay 1 sect A2 EXDU_DC A1 A2 AND AND ANSI04000507 V1 EN US Figure 273 Signals from any bays in section A2 to a busbar grounding switch in the same section For a busbar grounding switch these conditions from the B1 busbar section are valid 1MRK 502 071 UUS A Section 15 Control Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 589 Application manual ...

Page 596: ...grounding switch these conditions from the B2 busbar section are valid 289OPTR 22089OTR bay 1 sect B2 BB_DC_OP VP_BB_DC EXDU_BB en04000509_ansi vsd 289OPTR 22089OTR bay n sect B2 VP289TR V22089TR bay 1 sect B2 VP289TR V22089TR bay n sect B2 VPDCTR B1 B2 EXDU_BB bay n sect B2 AND DCOPTR B1 B2 EXDU_BB bay 1 sect B2 EXDU_DC B1 B2 AND AND ANSI04000509 V1 EN US Figure 275 Signals from any bays in secti...

Page 597: ...pen en04000511_ansi vsd Section 1 Section 2 A1A2_DC BS B1B2_DC BS BB_ES BB_ES DB_BUS WA1 A1 WA2 B1 B2 A2 DB_BUS ANSI04000511 V1 EN US Figure 277 Busbars divided by bus section disconnectors circuit breakers To derive the signals Signal BB_DC_OP All disconnectors of this part of the busbar are open VP_BB_DC The switch status of all disconnectors on this part of the busbar are valid EXDU_BB No trans...

Page 598: ...on Signals in single breaker arrangement 15 3 7 4 Signals in breaker and a half arrangement M15053 123 v4 The busbar grounding switch is only allowed to operate if all disconnectors of the bus section are open en04000512_ansi vsd Section 1 Section 2 A1A2_DC BS B1B2_DC BS BB_ES BB_ES BH_LINE WA1 A1 WA2 B1 B2 A2 BH_LINE ANSI04000512 V1 EN US Figure 278 Busbars divided by bus section disconnectors ci...

Page 599: ...y are defined DB_BUS_A 3 handles the circuit breaker QA1 that is connected to busbar WA1 and the disconnectors and grounding switches of this section DB_BUS_B 3 handles the circuit breaker QA2 that is connected to busbar WA2 and the disconnectors and grounding switches of this section M13584 4 v4 For a double circuit breaker bay the modules DB_BUS_A DB_LINE and DB_BUS_B must be used 15 3 8 2 Confi...

Page 600: ...ing inputs as follows VOLT_OFF 1 VOLT_ON 0 15 3 9 Interlocking for breaker and a half diameter BH 3 IP14173 1 v3 15 3 9 1 Application M13570 3 v6 The interlocking for breaker and a half diameter BH_CONN 3 BH_LINE_A 3 BH_LINE_B 3 functions are used for lines connected to a breaker and a half diameter according to figure 280 Section 15 1MRK 502 071 UUS A Control 594 Generator protection REG670 2 2 A...

Page 601: ...on between the two lines of the diameter in the breaker and a half switchyard layout M13569 4 v4 For a breaker and a half arrangement the modules BH_LINE_A BH_CONN and BH_LINE_B must be used 15 3 9 2 Configuration setting M13569 6 v5 For application without 989 and 989G just set the appropriate inputs to open state and disregard the outputs In the functional block diagram 0 and 1 are designated 0 ...

Page 602: ... the secondary side of the power transformer The control method is based on a step by step principle which means that a control pulse one at a time will be issued to the tap changer mechanism to move it one position up or down The length of the control pulse can be set within a wide range to accommodate different types of tap changer mechanisms The pulse is generated whenever the measured voltage ...

Page 603: ...ide side of a power transformer within given limits around a set target voltage A raise or lower command is generated whenever the measured voltage for a given period of time deviates from the set target value by more than the preset deadband value degree of insensitivity A time delay inverse or definite time is set to avoid unnecessary operation during shorter voltage deviations from the target v...

Page 604: ...ock has three inputs I3P1 I3P2 and V3P2 corresponding to HV current LV current and LV voltage respectively These analog quantities are fed to the IED via the transformer input module the Analog to Digital Converter and thereafter a Pre Processing Block In the Pre Processing Block a great number of quantities for example phase to phase analog values sequence values max value in a three phase group ...

Page 605: ...locks the load tap changer in case of over current above harmful levels The voltage measurement on the LV side can be made single phase ground However it shall be remembered that this can only be used in solidly grounded systems as the measured phase ground voltage can increase with as much as a factor 3 in case of ground faults in a non solidly grounded system The analog input signals are normall...

Page 606: ... 2 en vsd D D V V DVin DVin ANSI06000489 V2 EN US Figure 282 Control actions on a voltage scale During normal operating conditions the busbar voltage VB stays within the outer deadband interval between V1 and V2 in figure 282 In that case no actions will be taken by TR1ATCC 90 However if VB becomes smaller than V1 or greater than V2 an appropriate raise or lower timer will start The timer will run...

Page 607: ...and is initiated The purpose of the time delay is to prevent unnecessary load tap changer operations caused by temporary voltage fluctuations and to coordinate load tap changer operations in radial networks in order to limit the number of load tap changer operations This can be done by setting a longer time delay closer to the consumer and shorter time delays higher up in the system The first time...

Page 608: ...180 seconds settings for t1 and 10 seconds for tMin t1 180 t1 150 t1 120 t1 90 t1 60 t1 30 IEC06000488_2_en vsd IEC06000488 V2 EN US Figure 283 Inverse time characteristic for TR1ATCC 90 and TR8ATCC 90 The second time delay t2 will be used for consecutive commands commands in the same direction as the first command It can have a definite or inverse time characteristic according to the setting t2Us...

Page 609: ... OperationLDC When it is enabled the voltage VL will be used by the Automatic voltage control for tap changer function TR1ATCC 90 for single control and TR8ATCC 90 for parallel control for voltage regulation instead of VB However TR1ATCC 90 or TR8ATCC 90 will still perform the following two checks 1 The magnitude of the measured busbar voltageVB shall be within the security range setting Vmin and ...

Page 610: ...ntrol TR1ATCC 90 and parallel control TR8ATCC 90 1 Automatic load voltage adjustment proportional to the load current 2 Constant load voltage adjustment with four different preset values In the first case the voltage adjustment is dependent on the load and maximum voltage adjustment should be obtained at rated load of the transformer In the second case a voltage adjustment of the set point voltage...

Page 611: ...C x Automatic control of parallel transformers SEMOD159053 135 v5 Control of parallel transformers means control of two or more power transformers connected to the same busbar on the LV side and in most cases also on the HV side Special measures must be taken in order to avoid a runaway situation where the tap changers on the parallel transformers gradually diverge and end up in opposite end posit...

Page 612: ...accordance with the principles for Automatic voltage control Selection of the master is made by activating the binary input FORCMAST in TR8ATCC 90 function block for one of the transformers in the group The followers can act in two alternative ways depending on the setting of the parameter MFMode When this setting is Follow Cmd raise and lower commands VRAISE and VLOWER generated by the master wil...

Page 613: ...nce method SEMOD159053 145 v4 Consider Figure 286 with two parallel transformers with equal rated data and similar tap changers The tap positions will diverge and finally end up in a runaway tap situation if no measures to avoid this are taken Load T1 IL T2 VB VL IT1 IT2 en06000486_ansi vsd ANSI06000486 V1 EN US Figure 286 Parallel transformers with equal rated data In the reverse reactance method...

Page 614: ... whereas the line voltage drop compensation in figure 284 gave a voltage drop along a line from the busbar voltage VB to a load point voltage VL the line voltage drop compensation in figure 287 gives a voltage increase actually by adjusting the ratio XL RL with respect to the power factor the length of the vector VL will be approximately equal to the length of VB from VB up towards the transformer...

Page 615: ...ntly when the busbar voltage increases T1 will be the one to tap down and when the busbar voltage decreases T2 will be the one to tap up The overall performance will then be that the runaway tap situation will be avoided and that the circulating current will be minimized Parallel control with the circulating current method SEMOD159053 159 v5 Two transformers with different turns ratio connected to...

Page 616: ... each IED instead of VB for the voltage regulation thus assuring that the same value is used by all TR8ATCC functions and thereby avoiding that one erroneous measurement in one transformer could upset the voltage regulation At the same time supervision of the VT mismatch is also performed This works such that if a measured voltage VB differs from VBmean with more than a preset value setting parame...

Page 617: ... voltage will then be compared with the set voltage VSet A steady deviation which is outside the outer deadband will result in VLOWER or VRAISE being initiated alternatively In this way the overall control action will always be correct since the position of a tap changer is directly proportional to the transformer no load voltage The sequence resets when VBmean is inside the inner deadband at the ...

Page 618: ...ontrol TR8ATCC 90 will select the transformer with the greatest voltage deviation Vdi to tap first That transformer will then start timing and after time delay t1 the appropriate VRAISE or VLOWER command will be initiated If now further tapping is required to bring the busbar voltage inside VDeadbandInner the process will be repeated and the transformer with the then greatest value of Vdi amongst ...

Page 619: ...r within the deadband of the busbar voltage Homing operation with the master follower method SEMOD159053 216 v3 If one or more follower has its LV circuit breaker open and its HV circuit breaker closed and if OperHoming Enabled this follower continues to follow the master just as it would have made with the LV circuit breaker closed On the other hand if the LV circuit breaker of the master opens a...

Page 620: ...nd the master is put in manual control with the followers still in parallel master follower control In this situation the followers will continue to follow the master the same way as when it is in automatic control If one follower in a master follower parallel group is put in manual mode still with the setting OperationAdaptEnabled the rest of the group will continue in automatic master follower c...

Page 621: ...T1 IL T2 Icc T2 I cc T1 VB VL IT1 IT2 IC I T2 I C Load T1 IL T2 Icc T2 Icc T1 VB VL IT1 IT2 IT2 IT1 IT1 IC en06000512_ansi vsd ANSI06000512 V1 EN US Figure 289 Capacitor bank on the LV side From figure 289 it is obvious that the two different connections of the capacitor banks are completely the same regarding the currents in the primary network However the CT measured currents for the transformer...

Page 622: ...ing of three steps in a capacitor bank in one bay Power monitoring SEMOD159053 251 v4 The level with sign of active and reactive power flow through the transformer can be monitored This function can be utilized for different purposes for example to block the voltage control function when active power is flowing from the LV side to the HV side or to initiate switching of reactive power compensation...

Page 623: ...llel control In a simple case when only the switchgear in the transformer bays needs to be considered there is a built in function in TR8ATCC 90 block that can provide information on whether a transformer is connected to the parallel group or not This is made by connecting the transformer CB auxiliary contact status to TR8ATCC 90 function block input DISC which can be made via a binary input or vi...

Page 624: ...e control functions working in parallel according to the current station configuration When the parallel voltage control function detects that no other transformers work in parallel it will behave as a single voltage control function in automatic mode Exchange of information between TR8ATCC functions SEMOD159053 267 v6 Each transformer in a parallel group needs an Automatic voltage control for tap...

Page 625: ... in the master follower parallel control mode termReadyForMSF Activated when the transformer is ready for master follower parallel control mode raiseVoltageOut Order from the master to the followers to tap up lowerVoltageOut Order from the master to the followers to tap down Table 57 Analog signals Signal Explanation voltageBusbar Measured busbar voltage for this transformer ownLoadCurrim Measured...

Page 626: ...tting in each TR8ATCC T1RXOP Off On T8RXOP Off On This setting determines from which of the other transformer individuals that data shall be received Settings in the three TR8ATCC blocks for the transformers in figure 291 would then be according to the table 58 Table 58 Setting of TxRXOP TrfId T1 T1RXOP Off T2RXOP On T3RXOP On T4RXOP Off T5RXOP Off T6RXOP Off T7RXOP Off T8RXOP Off TrfId T2 T1RXOP ...

Page 627: ...m will be initiated or further VRAISE commands will be blocked If permitted by setting in PST configuration Fast Step Down FSD of the tap changer will be initiated in order to re enter the voltage into the range Vmin VB Vmax The FSD function is blocked when the lowest voltage tap position is reached The time delay for the FSD function is separately set The output VHIGH will be activated as long as...

Page 628: ...eter tRevAct and the output signal REVACBLK will be set The reversed action feature can be turned off on with the setting parameter OperationRA CmdErrBk manually reset Alarm Auto Block Auto Man Block Typical operating time for a tap changer mechanism is around 3 8 seconds Therefore the function should wait for a position change before a new command is issued The command error signal CMDERRAL on th...

Page 629: ...depending on the actual parameter setting In correct operation the TCINPROG shall appear during the VRAISE VLOWER output pulse and disappear before the tTCTimeout time has elapsed This error condition can be reset by the input RESETERR on TCMYLTC 84 function block or alternatively by changing control mode of TR1ATCC 90 or TR8ATCC 90 function to Manual and then back to Automatic Table continues on ...

Page 630: ...or negative mA values Indication of hardware fault on BIM or MIM module Supervision of the input hardware module is provided by connecting the corresponding error signal to the INERR input input module error or BIERR on TCMYLTC or TCLYLTC 84 function block Interruption of communication with the tap changer The outputs POSERRAL and AUTOBLK or TOTBLK will be set This error condition can be reset by ...

Page 631: ...1ATCC 90 or TR8ATCC 90 function can be blocked for automatic control via the setting parameter AutoBlock which can be set Enabled Disabled from the local HMI or PST The output AUTOBLK will be set TR1ATCC 90 or TR8ATCC 90 blockings that can be made via input signals in the function block are listed in table 61 Table 61 Blocking via binary inputs Input name Activation Description BLOCK manually rese...

Page 632: ...LV circuit breaker is closed or not The outputs TRFDISC MFERR and AUTOBLK will be activated The followers will also be blocked by mutual blocking in this situation Blocking will be removed when the transformer is reconnected input signal DISC set back to zero One transformer in a parallel group switched to manual control automatically reset Auto Block When the setting OperationAdapt is Disabled au...

Page 633: ...ignal to the master This will prevent a situation where the rest of the group otherwise would be able to tap away from the blocked individual and that way cause high circulating currents Thus when a follower is blocked it broadcasts a mutual block on the horizontal communication The master picks up this message and blocks its automatic operation as well Besides the conditions listed above for mutu...

Page 634: ...ght timing data is set it may then happen that TR1ATCC 90 or TR8ATCC 90 becomes totally blocked or blocked in auto mode because of incorrect settings In this situation it is recommended to temporarily set these types of blockings to alarm instead until the commissioning of all main items are working as expected Tap Changer position measurement and monitoring SEMOD159053 337 v1 Tap changer extreme ...

Page 635: ...sition reached making the signal tap change in progress disappear from the tap changer and a new position reported f The new tap position available in TCMYLTC 84 or TCLYLTC 84 g Fixed extension 2 sec of TCINPROG made internally in TCMYLTC 84 or TCLYLTC 84 function h Safety margin to avoid that TCINPROG extends beyond tTCTimeout The first use is to reset the Automatic voltage control for tap change...

Page 636: ... SEMOD159053 361 v4 Hunting detection is provided in order to generate an alarm when the voltage control gives an abnormal number of commands or abnormal sequence of commands within a pre defined period of time There are three hunting functions 1 The Automatic voltage control for tap changer function TR1ATCC 90 for single control and TR8ATCC 90 for parallel control will activate the output signal ...

Page 637: ...r is issued It is therefore necessary to check that the IED internal time is correct before these counters are reset The counter value can be reset on the local HMI under Main menu Reset Reset counters TransformerTapControl YLTC 84 TCMYLTC 1 or TCLYLTC 1 Reset Counter and ResetCLCounter Both counters and their last reset dates are shown on the local HMI as service values under Main menu Test Funct...

Page 638: ...y of the three phase currents on the HV side has exceeded Iblock MFPosDiffBk Selection of action to be taken in case the tap difference between a follower and the master is greater than MFPosDiffLim OVPartBk Selection of action to be taken in case the busbar voltage VB exceeds Vmax RevActPartBk Selection of action to be taken in case Reverse Action has been activated TapChgBk Selection of action t...

Page 639: ...ontrol function TR1ATCC 90 for single control and TR8ATCC 90 for parallel control is blocked for automatic control Operation FSDMode This setting enables disables the fast step down function Enabling can be for automatic and manual control or for only automatic control alternatively tFSD Time delay to be used for the fast step down tapping Voltage UseCmdUSet This setting enabled makes it possible ...

Page 640: ...of time characteristic definite or inverse for t2 t2 Time delay for consecutive raise lower commands In the circulating current method the second third etc commands are all executed with time delay t2 independently of which transformer in the parallel group that is tapping In the master follower method with the follow tap option the master is executing the second third etc commands with time delay...

Page 641: ...er controlled in a parallel group with the reverse reactance method and with no circulation for example assume two equal transformers on the same tap position The load current lags the busbar voltage VB with the power factor j and the argument of the impedance Rline and Xline is designated j1 VB jIT Xline VL Xline Rline Zline IT IT Rline j j1 j2 DV en06000626_ansi vsd ANSI06000626 V1 EN US Figure ...

Page 642: ...ect regulation an adjustment to a value of j2 slightly less than 90 2 4 less can be made The effect of changing power factor of the load will be that j2 will no longer be close to 90 resulting in VL being smaller or greater than VB if the ratio Rline Xline is not adjusted Figure 294 shows an example of this where the settings of Rline and Xline for j 11 from figure 293 has been applied with a diff...

Page 643: ...er with no or only a small difference in tap position but the voltage regulation as such will be more sensitive to a deviation from the anticipated power factor A too high setting of Xline can cause a hunting situation as the transformers will then be prone to over react on deviations from the target value There is no rule for the setting of Xline such that an optimal balance between control respo...

Page 644: ...f VBase and it is proportional to the load current with the set value reached at the nominal current I2Base RevAct OperationRA This setting enables disables the reverse action partial blocking function tRevAct After the reverse action has picked up this time setting gives the time during which the partial blocking is active RevActLim Current threshold for the reverse action activation This is just...

Page 645: ...s to the right of the setting Reference is made to figure 290 for definition of forward and reverse direction of power through the transformer en06000634_2_en vsd P P IEC06000634 V2 EN US Figure 295 Setting of a negative value for P P When the active power falls below the value given by this setting the output PLTREV will be activated after the time delay tPower It shall be noticed that the settin...

Page 646: ...exceeds CircCurrLimit CircCurrLimit Pick up value for the circulating current blocking function The setting is made in percent of I2Base tCircCurr Time delay for the circulating current blocking function Comp When parallel operation with the circulating current method is used this setting increases or decreases the influence of the circulating current on the regulation If the transformers are conn...

Page 647: ...t method as well for parallel control with the master follower method VTmismatch Setting of the level for activation of the output VTALARM in case the voltage measurement in one transformer bay deviates to the mean value of all voltage measurements in the parallel group tVTmismatch Time delay for activation of the output VTALARM T1RXOP T8RXOP This setting is set Enabled for every transformer that ...

Page 648: ...actor gives the weighting of the deviation with respect to the load current InitCLCounter The ContactLife counter monitors the remaining number of operations decremental counter The setting InitCLCounter then gives the start value for the counter that is the total number of operations at rated load that the tap changer is designed for EnabTapCmd This setting enables disables the lower and raise co...

Page 649: ...and DOWN one blocking input BLOCK and one operator position input PSTO SLGAPC can be activated both from the local HMI and from external sources switches via the IED binary inputs It also allows the operation from remote like the station computer SWPOSN is an integer value output giving the actual output number Since the number of positions of the switch can be established by settings see below on...

Page 650: ...ch VSGAPC function is a multipurpose function used in the configuration tool in PCM600 for a variety of applications as a general purpose switch VSGAPC can be used for both acquiring an external switch position through the IPOS1 and the IPOS2 inputs and represent it through the single line diagram symbols or use it in the configuration through the outputs POS1 and POS2 as well as a command functio...

Page 651: ...ram SLD this function block has two control modes settable through CtlModel Dir Norm and SBO Enh 15 7 Generic communication function for Double Point indication DPGAPC SEMOD55384 1 v4 15 7 1 Identification GUID E16EA78F 6DF9 4B37 A92D 5C09827E2297 v3 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Generic communication function for Double Point ...

Page 652: ...t 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 be updated as the time when DPGAPC function detects the change Refer to Table 63 for the description of the input output relationship in terms of the value and t...

Page 653: ...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 v6 The parameters for the single point generic control 8 signals SPC8GAPC function are set via the local HMI or PCM600 Operation turning the func...

Page 654: ...UTOBITS output point send a control 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 b...

Page 655: ...uit to control a high voltage apparatus This type of command control is normally carried out by sending a pulse to the binary outputs of the IED Figure 298 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 AND User defined conditions Synchro check Configuration logic circu...

Page 656: ...ons Configuration logic circuits en04000208_ansi vsd AND ANSI04000208 V2 EN US Figure 300 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 502 071 UUS A Control 650 Generator protection REG670 2...

Page 657: ... 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 1MRK 502 071 UU...

Page 658: ...652 ...

Page 659: ...lts and three pole tripping for multi phase and evolving faults 1p 3p operating mode Single pole tripping for single pole faults two pole tripping for two pole faults and three pole tripping for three pole faults 1p 2p 3p operating mode The logic also issues a three pole tripping command when phase selection within the operating protection functions is not possible or when external conditions requ...

Page 660: ...t the output TRIP to the binary outputs on the IO board This signal can also be used for other purposes internally in the IED An example could be the starting of breaker failure protection The three outputs TR_A TR_B TR_C will always be activated at every trip and can be utilized on individual trip outputs if single pole operating devices are available on the circuit breaker even when a three pole...

Page 661: ...hieve the tripping on the respective single pole trip outputs TR_A TR_B and TR_C 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 pole tripping schemes are used a single phase autoreclosing attempt is expected to follow For cases where the auto...

Page 662: ...ple time delayed overcurrent protection OR To prepare 3 phase trip for any trip signal SMBRREC PREP3P TR3P STN ANSI05000545 6 en vsdx ANSI05000545 V6 EN US Figure 302 The trip logic function SMPPTRC 94 used for single pole tripping application 16 1 2 3 Single two or three pole tripping M14828 15 v5 The single two three pole tripping mode provides single pole tripping for single phase faults two po...

Page 663: ... SETLKOUT The setting AutoLock Disabled means that the internal trip will not activate lock out so only initiation of the 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 16 1 2 5 Example...

Page 664: ... 2 en vsdx SMPPTRC 94 BLOCK BLKLKOUT TRINP_3P TRINP_A TRINP_B TRINP_C PS_A PS_B PS_C 1PTRZ 1PTRGF P3PTR SETLKOUT RSTLKOUT CND TRIP TR_A TR_B TR_C TR1P TR2P TR3P CLLKOUT BFI_3P BFI_A BFI_B BFI_C STN FW REV ANSI16000180 V2 EN US Figure 303 Example of the connection of directional start logic The Start Matrix SMAGAPC merges start and directional output signals from different application functions and...

Page 665: ...r lock out Disabled only activates the closing circuit lock out output Enabled activates the closing circuit lock out output and latches the TRIP related outputs The normal selection is Disabled AutoLock Sets the scheme for lock out Disabled only activates lock out through the input SETLKOUT Enabled additionally allows lock out activation via the trip inputs The normal selection is Disabled tTripM...

Page 666: ...ry minimum duration of the trip pulse to the circuit breaker trip coils OnDelay Used to prevent output signals to be given for spurious inputs Normally set to 0 or a low value OffDelay Defines a delay of the reset of the outputs after the activation conditions no longer are fulfilled It is only used in Steady mode When used for direct tripping of circuit breaker s the off delay time shall be set t...

Page 667: ... group warning WRNCALH 16 4 1 1 Application GUID FC0DBB7B FF86 44BF 83D6 DDF120A176DE v1 Group warning logic function WRNCALH is used to route warning signals to LEDs and or output contacts on the IED WRNCALH output signal WARNING and the physical outputs allows the user to adapt the warning signal to physical tripping outputs according to the specific application needs 16 4 1 2 Setting guidelines...

Page 668: ...d the quality of signals They have the suffix QT at the end of their function block name for example SRMEMORYQT 16 6 1 Application GUID F5D6F065 441B 4296 AC56 F4DC1F5487E3 v3 A set of standard logic blocks like AND OR etc and timers are available for adapting the IED configuration to the specific application needs Additional logic blocks that beside the normal logical function have the capability...

Page 669: ...designation of the function block and the cycle time see example below IEC09000695_2_en vsd IEC09000695 V2 EN US Figure 304 Example designation serial execution number and cycle time for logic function IEC09000310 2 en vsd IEC09000310 V2 EN US Figure 305 Example designation serial execution number and cycle time for logic function that also propagates timestamp and quality of input signals The exe...

Page 670: ...gnals function FXDSIGN has nine pre set fixed signals that can be used in the configuration of an IED either for forcing the unused inputs in other function blocks to a certain level value or for creating certain logic Boolean integer floating point string types of signals are available One FXDSIGN function block is included in all IEDs Example for use of GRP_OFF signal in FXDSIGN The Restricted e...

Page 671: ... GRP_OFF signal in FXDSIGN function block I3PW1CT1 I3PW2CT1 I3P REFPDIF 87N ANSI11000084_1_en vsd GRP_OFF FXDSIGN ANSI11000084 V1 EN US Figure 307 REFPDIF 87N function inputs for normal transformer application 16 8 Boolean 16 to Integer conversion B16I SEMOD175715 1 v1 16 8 1 Identification SEMOD175721 2 v2 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 devi...

Page 672: ...ds to that integer 65535 is available on the output OUT B16I function is designed for receiving up to 16 booleans input locally If the BLOCK input is activated it will freeze the output at the last value Values of each of the different OUTx from function block B16I for 1 x 16 The sum of the value on each INx corresponds to the integer presented on the output OUT on the function block B16I Name of ...

Page 673: ...esents a value according to the table below from 0 to 32768 This follows the general formula INx 2x 1 where 1 x 16 The sum of all the values on the activated INx will be available on the output OUT as a sum of the values of all the inputs INx that are activated OUT is an integer When all INx where 1 x 16 are activated that is Boolean 1 it corresponds to that integer 65535 is available on the outpu...

Page 674: ... 16 10 Integer to Boolean 16 conversion IB16 SEMOD158367 1 v2 16 10 1 Identification SEMOD167941 2 v2 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Integer to boolean 16 conversion IB16 16 10 2 Application SEMOD158499 5 v4 Integer to boolean 16 conversion function IB16 is used to transform an integer into a set of 16 binary logical signals It ...

Page 675: ...escription 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 9 256 0 IN10 BOOLEAN 0 Input 10 512 0 IN11 BOOLEAN 0 Input 11 1024 0 IN12 BOOLEAN 0 Input 12 2048 0 IN13 BOOLEAN...

Page 676: ...nction ITBGAPC will transfer an integer with a value between 0 to 65535 communicated via IEC 61850 and connected to the ITBGAPC function block to a combination of activated outputs OUTx where 1 x 16 The values of the different OUTx are according to the Table 64 If the BLOCK input is activated it freezes the logical outputs at the last value Table 64 Output signals Name of OUTx Type Description Val...

Page 677: ...ion TIGAPC is intended for applications where there is a need for a integration of a pulsed signal For example the pulses from the pickup output of certain functions like reverse power loss of excitation and pole slip Some applications may require the integration of the pickup output of those functions to perform the trip 16 12 3 Setting guidelines GUID FD076D19 B803 4BBB 8320 62CFEEFB677A v2 The ...

Page 678: ...is fixed to 999999 9 seconds 16 13 3 Setting guidelines GUID 2911D624 87D5 4427 BB2F E0D1072394FA v3 The settings tAlarm and tWarning are user settable limits defined in seconds The achievable resolution of the settings depends on the level of the values defined A resolution of 10 ms can be achieved when the settings are defined within the range 1 00 second tAlarm 99 999 99 seconds 1 00 second tWa...

Page 679: ... 109 Setting procedure on the IED EnaAbs This setting is used to select the comparison type between signed and absolute values Absolute Comparison is performed on absolute values of input and reference values Signed Comparison is performed on signed values of input and reference values RefSource This setting is used to select the reference source between input and setting for comparison Input REF ...

Page 680: ...E846 5A15 4C2C 91A2 F81A74034E81 v1 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Comparator for real inputs REALCOMP Real 16 15 2 Application GUID 5F7B1683 9799 4D27 B333 B184F8861A5B v1 The function gives the possibility to monitor the level of real values in the system relative to each other or to a fixed value It is a basic arithmetic func...

Page 681: ...etting RefSource is selected as SetValue It has 5 unit selections and they are Milli Unity Kilo Mega and Giga EqualBandHigh This setting is used to set the equal condition high band limit in of reference value This high band limit will act as reset limit for INHIGH output when INHIGH EqualBandLow This setting is used to set the equal condition low band limit in of reference value This low band lim...

Page 682: ... crosses below 95 kA If the comparison should be done between two current magnitudes then those current signals need to be connected to function inputs INPUT and REF Then the settings should be adjusted as below EnaAbs Absolute RefSource Input REF EqualBandHigh 5 0 of reference value EqualBandLow 5 0 of reference value Section 16 1MRK 502 071 UUS A Logic 676 Generator protection REG670 2 2 ANSI an...

Page 683: ...RR V1 EN US Phase current measurement CMMXU I SYMBOL SS V1 EN US Phase phase voltage measurement VMMXU U SYMBOL UU V1 EN US Current sequence component measurement CMSQI I1 I2 I0 SYMBOL VV V1 EN US Voltage sequence component measurement VMSQI U1 U2 U0 SYMBOL TT V1 EN US Phase neutral voltage measurement VNMMXU U SYMBOL UU V1 EN US 1MRK 502 071 UUS A Section 17 Monitoring Generator protection REG670...

Page 684: ...n The available measured values from an IED are depending on the actual hardware TRM and the logic configuration made in PCM600 All measured values can be supervised with four settable limits that is low low limit low limit high limit and high high limit A zero clamping reduction is also supported that is the measured value below a settable limit is forced to zero which reduces the impact of noise...

Page 685: ...VMSQI provide sequence component quantities I sequence currents positive zero negative sequence magnitude and angle V sequence voltages positive zero and negative sequence magnitude and angle 17 1 3 Zero clamping GUID 8DABC3F5 6615 493C B839 A5C557A2FAE8 v4 Measuring functions CVMMXN CMMXU VMMXU and VNMMXU have no interconnections regarding any settings or parameters Zero clampings are also handle...

Page 686: ... the logic configuration made in PCM600 The parameters for the Measurement functions CVMMXN CMMXU VMMXU CMSQI VMSQI VNMMXU are set via the local HMI or PCM600 GlobalBaseSel Selects the global base value group used by the function to define IBase VBase and SBase as applicable Operation Disabled Enabled Every function instance CVMMXN CMMXU VMMXU CMSQI VMSQI VNMMXU can be taken in operation Enabled o...

Page 687: ...00 IAngCompY Angle compensation to calibrate angle measurements at Y of In where Y is equal to 5 30 or 100 The following general settings can be set for the Phase phase voltage measurement VMMXU VMagCompY Amplitude compensation to calibrate voltage measurements at Y of Vn where Y is equal to 5 30 or 100 VAngCompY Angle compensation to calibrate angle measurements at Y of Vn where Y is equal to 5 3...

Page 688: ...gh limit Set as of YBase Y is SBase for S P Q UBase for Voltage measurement and IBase for current measurement XLowLim Low limit Set as of YBase Y is SBase for S P Q UBase for Voltage measurement and IBase for current measurement XLowLowLim Low low limit Set as of YBase Y is SBase for S P Q UBase for Voltage measurement and IBase for current measurement XLimHyst Hysteresis value in of range and is ...

Page 689: ...asurement function CVMMXN are provided Measurement function CVMMXN application for a OHL Measurement function CVMMXN application on the secondary side of a transformer Measurement function CVMMXN application for a generator For each of them detail explanation and final list of selected setting parameters values will be provided The available measured values of an IED are depending on the actual ha...

Page 690: ...re 309 it is necessary to do the following 1 Set correctly CT and VT data and phase angle reference channel PhaseAngleRef using PCM600 for analog input channels 2 Connect in PCM600 measurement function to three phase CT and VT inputs 3 Set under General settings parameters for the Measurement function general settings as shown in table 65 level supervision of active power as shown in table 66 cali...

Page 691: ...age 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 VBase 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 current level in A 1000 Set rated primary CT current used for OHL SBase set in Global bas...

Page 692: ...omp5 Magnitude factor to calibrate current at 5 of In 0 00 IMagComp30 Magnitude factor to calibrate current at 30 of In 0 00 IMagComp100 Magnitude factor to calibrate current at 100 of In 0 00 VAmpComp5 Magnitude factor to calibrate voltage at 5 of Vn 0 00 VMagComp30 Magnitude factor to calibrate voltage at 30 of Vn 0 00 VMagComp100 Magnitude factor to calibrate voltage at 100 of Vn 0 00 IAngComp5...

Page 693: ...necessary to do the following 1 Set correctly all CT and VT and phase angle reference channel PhaseAngleRef 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 68 1MRK 502 071 UUS A Section 17 Monitoring Generator protection REG670 2 2 ANSI and Inj...

Page 694: ...L1L2 phase to phase voltage is available k Low pass filter coefficient for power measurement V and I 0 00 Typically no additional filtering is required VGenZeroDb Zero point clamping in of Vbase 25 Set minimum voltage level to 25 IGenZeroDb Zero point clamping in of Ibase 3 Set minimum current level to 3 VBase set in Global base Base setting for voltage level in kV 35 00 Set LV side rated phase to...

Page 695: ...necessary to do the following 1 Set correctly all CT and VT data and phase angle reference channel PhaseAngleRef using PCM600 for analog input channels 2 Connect in PCM600 measurement function to the generator CT VT inputs 3 Set the setting parameters for relevant Measurement function as shown in the following table 1MRK 502 071 UUS A Section 17 Monitoring Generator protection REG670 2 2 ANSI and ...

Page 696: ...t generator rated phase to phase voltage IBase set in Global base Base setting for current level in A 3690 Set generator rated current 17 2 Gas medium supervision SSIMG 63 GUID 358AD8F8 AE06 4AEA 9969 46E5299D5B4B v3 17 2 1 Identification GUID AD96C26E C3E5 4B21 9ED6 12E540954AC3 v4 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Insulation gas ...

Page 697: ... 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 for the pressure alar...

Page 698: ...n 17 3 3 Setting guidelines GUID 0C8E498B 2A65 44ED 91D6 53EC72F49222 v2 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 transformer LevelLOLimit This is use...

Page 699: ...itoring SSCBR 17 4 2 Application GUID 45572680 3A39 4B3C 8639 4E4C5A95AA26 v9 The circuit breaker maintenance is usually based on regular time intervals or the number of operations performed This has some disadvantages because there could be a number of abnormal operations or few operations with high level currents within the predetermined maintenance interval Hence condition based maintenance sch...

Page 700: ...aker operates the circuit breaker life reduces due to wear The wear in a breaker depends on the interrupted current For breaker maintenance or replacement at the right time the remaining life of the breaker must be estimated The remaining life of a breaker can be estimated using the maintenance curve provided by the circuit breaker manufacturer Circuit breaker manufacturers provide the number of m...

Page 701: ...valent to 10000 900 11 operations at the rated current It is assumed that prior to tripping the remaining life of a breaker is 10000 operations Remaining life calculation for three different interrupted current conditions is explained below Breaker interrupts at and below the rated operating current that is 2 kA the remaining life of the CB is decreased by 1 operation and therefore 9999 operations...

Page 702: ...intenance 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 oil sampling for dielectric testing in case of an oil circuit breaker Circuit breaker operation monitoring By monitoring the activity of the number of operations it is possible to calculate the number of...

Page 703: ... Operation Enabled or Disabled IBase Base phase current in primary A This current is used as reference for current settings OpenTimeCorr Correction factor for circuit breaker opening travel time CloseTimeCorr Correction factor for circuit breaker closing travel time tTrOpenAlm Setting of alarm level for opening travel time tTrCloseAlm Setting of alarm level for closing travel time OperAlmLevel Ala...

Page 704: ...output and start of main contact separation 17 5 Event function EVENT IP14590 1 v2 17 5 1 Identification SEMOD167950 2 v2 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Event function EVENT S00946 V1 EN US 17 5 2 Application M12805 6 v11 When using a Substation Automation system with LON or SPA communication time tagged events can be sent at ch...

Page 705: ...to be set by the user LONChannelMask or SPAChannelMask M12811 15 v2 Definition of which part of the event function block that shall generate events Disabled Channel 1 8 Channel 9 16 Channel 1 16 MinRepIntVal 1 16 M12811 29 v3 A time interval between cyclic events can be set individually for each input channel This can be set between 0 s to 3600 s in steps of 1 s It should normally be set to 0 that...

Page 706: ...g 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 10 internal derived analog signals and 352 binary signals Disturbance report function is a common name for several functions Indications IND Event recorder ER Seq...

Page 707: ...in all functions that is Disturbance recorder DR Event recorder ER Indication IND Trip value recorder TVR and Sequential of events SOE function User defined names of binary and analog input signals is set using PCM600 The analog and binary signals appear with their user defined names The name is used in all related functions Disturbance recorder DR Event recorder ER Indication IND Trip value recor...

Page 708: ...also influences the sub functions 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 Table continues on next page Section...

Page 709: ...get a number 0 to 999 which is used as identifier local HMI disturbance handling tool and IEC 61850 An alternative recording identification is date time and sequence number The sequence number is automatically increased by one for each new recording and is reset to zero at midnight The maximum number of recordings stored in the IED is 100 The oldest recording will be overwritten when a new recordi...

Page 710: ...rt function does not automatically respond to any new trig condition during a recording after all signals set as trigger signals have been reset However under certain circumstances the fault condition may reoccur during the post fault recording for instance by automatic reclosing to a still faulty power line In order to capture the new disturbance it is possible to allow retriggering PostRetrig En...

Page 711: ...ure the signals For retrieving remote data from LDCM module the Disturbance report function should be connected to a 8 ms SMAI function block if this is the only intended use for the remote data The analog trigger of Disturbance report is not affected if analog input M is to be included in the disturbance recording or not OperationM Enabled Disabled If OperationM Disabled no waveform samples will ...

Page 712: ...B0D40F6D 3CE4 4FF3 81B4 B453FDD389CB v1 SetInfoInDrep Parameter used to enable or disable the settings information in disturbance header Event recorder M12179 444 v4 Event recorder ER function has no dedicated parameters Trip value recorder M12179 442 v3 ZeroAngleRef The parameter defines which analog signal that will be used as phase angle reference for all other analog input signals This signal ...

Page 713: ...should be used with great care since unfortunate settings will cause enormously number of recordings If nevertheless analog input triggering is used chose settings by a sufficient margin from normal operation values Phase voltages are not recommended for trigging There is a risk of flash wear out if the disturbance report triggers too often Remember that values of parameters set elsewhere are link...

Page 714: ...09000732 V1 EN US Figure 314 BINSTATREP logical diagram 17 7 3 Setting guidelines GUID BBDA6900 4C1A 4A7C AEA5 3C49C2749254 v2 The pulse time t is the only setting for the Logical signal status report BINSTATREP Each output can be set or reset individually but the pulse time will be the same for all outputs in the entire BINSTATREP function 17 8 Limit counter L4UFCNT GUID 22E141DB 38B3 462C B031 7...

Page 715: ...s case periodic pulses will be generated at multiple overflow of the function 17 8 3 Setting guidelines GUID 5AECCDBC 7385 4D9F 940C 9D4A0E59B106 v1 GUID DA5DA8D7 4821 4BFB 86CC 28658E376270 v1 The parameters for Limit counter L4UFCNT are set via the local HMI or PCM600 17 9 Running hour meter TEILGAPC 17 9 1 Identification GUID 3F9EF4FA 74FA 4D1D 88A0 E948B722B64F v1 Function Description IEC 6185...

Page 716: ... v1 A typical power transformer is composed of Laminated steel core with copper or aluminium windings Solid refined paper insulation Highly refined mineral oil as insulating and cooling medium for the entire transformer The oil is cooled by a separate cooling system using air or water The core windings and insulation have specific thermal capabilities Losses in the winding and core can cause tempe...

Page 717: ... the nameplate rating Leakage flux density short circuit force and high electric stress on the insulation increases once size of the transformer increases Hence determination of hot spot temperature becomes more complex Therefore large transformers are more vulnerable than the smaller ones Consequences of transformer failures are more severe for larger sizes than for smaller ones As per IEC 60076 ...

Page 718: ...om of winding Height of transformer Average oil g H g x Top of winding IEC15000440 1 en vsdx IEC15000440 V1 EN US Figure 315 Thermal diagram Winding hot spot temperature depends on the oil temperature inside the winding load losses in the winding cooling type and ambient temperature For most transformers in service oil temperature inside a winding is difficult to measure On the other hand top oil ...

Page 719: ...operating temperatures see Figure 316 The four types of loading are Normal life expectancy Normal life expectancy loading The transformer loading is continuous at rated output when operated under usual conditions Sacrifice of life expectancy Planned loading beyond nameplate Restricted to transformers that do not carry a continuous steady load and it is a normal planned repetitive load Long time em...

Page 720: ...mple Impact of the increased currents and temperature leads to premature transformer failure and this may have an immediate short term effect or a cumulative long term effect Short term effect Reduction in dielectric strength due to the possible presence of gas bubbles which leads to super saturation of the oil and reduction in short circuit strength Long term effect Continuous deterioration of th...

Page 721: ...r insulation life function LOLSPTR 26 49HS are set via the local HMI or PCM600 Minimum information about the transformer parameters which are required to decide the transformer insulation life are 1 Top oil temperature rise over ambient temperature at rated load 2 Average conductor temperature rise over ambient temperature at rated load 3 Winding hot spot temperature rise over ambient temperature ...

Page 722: ...If the transformer rating is less than 0 833 MVA the function considers this as a distribution transformer If the transformer rating is less than 33 3 MVA it is considered as a medium power transformer If the transformer rating is above 33 3 MVA it is considered as a larger power transformer NoOfWindings This setting is used to set the number of windings in the transformer The options are Three wi...

Page 723: ...onverted into C for calculation Once the calculations are done the outputs in C are converted into F C The temperature unit will be selected as C All temperature inputs will be taken as they are and the output is given in C GUID 4D6F8802 AFCC 4277 8844 A87A98A5F2C8 v1 LOLSPTR 26 49HS can work with n 1 winding CT availability that is if the given transformer has three windings and it has CTs only i...

Page 724: ...EEE or IEC standard as selected for the temperature calculations User defined Oil time constant is provided by the user through setting The value may be given by the transformer manufacturer Calculated Oil time constant is calculated by the function based on the transformer parameters given by the user OilTimeConst This setting is used to get the oil time constant from the user and this will be us...

Page 725: ... from the IEEE or IEC standard as selected for the temperature calculations User defined Winding time constant is provided by the user through setting The value may be given by the transformer manufacturer Calculated Winding time constant is calculated by the function based on the transformer parameters given by the user WdgTimeConst1 This setting is used to get the winding time constant for windi...

Page 726: ...to set the mass of the winding 3 GUID 8A9D8886 8EE5 4B02 80B8 BDDA95164BFF v1 Loss ratios at different tap positions are required for the calculation of top oil temperature especially when the transformer is using online tap changer This loss ratio is the ratio between load losses to no load loss It may vary from 6 7 for distribution transformer and 4 8 for power transformer Normally it varies fro...

Page 727: ...ugust month average ambient temperature SepAmbTmp This setting is used to set the September month average ambient temperature OctAmbTmp This setting is used to set the October month average ambient temperature NovAmbTmp This setting is used to set the November month average ambient temperature DecAmbTmp This setting is used to set the December month average ambient temperature GUID F6960AEE E0F9 4...

Page 728: ...his setting is used to set the RMS value of the current which is applied during the type test in A for winding 3 GUID 6CB4E94E 1DC9 46DB ADC0 F86922A8D611 v1 The following settings are required to perform the insulation loss of life calculation EnaAgeCalc This setting is used to enable or disable the transformer insulation loss of life calculation It has the following options Enable Transformer in...

Page 729: ...ing is used to set the time interval for updating the transformer insulation loss of life calculation outputs LOLINDAY and LOLINYRS It can be selected as 1 hour 2 hour 4 hour 8 hour 12 hour 24 hour depending on user requirement GUID B170CF21 839E 4246 A607 55A8999FAD07 v1 Two settable warning levels are available for hot spot temperature with separate outputs If warning level exceeds for the set t...

Page 730: ...ng time constant For example if the winding time constant is 420 sec this setting can be 400 sec tDelayToAlarm2 This setting is used to set the time delay for the level 2 hot spot temperature alarm This should be less than time setting in tDelayToAlarm1 17 10 3 Setting example 17 10 3 1 Transformer Rated Data GUID B3AE440F CC5E 4742 9483 8D6448A476C8 v1 Table 72 Transformer Rated Data Parameter Va...

Page 731: ...determination of current on which the load factor needs to be calculated Maximum TempeUnitMode Select the unit of temperature should be used in the function C AvailableCT Select the available CT connections on the windings All windings RatedVoltageW1 Set the winding 1 rated nominal voltage 415 0 kV RatedVoltageW2 Set the winding 2 rated nominal voltage 230 0 kV RatedVoltageW3 Set the winding 3 rat...

Page 732: ... MW WdgTmConstMode Select the transformer winding time constant mode of input to the function Standard WdgTimeConst1 Set the transformer winding time constant for the winding 1 when the winding time constant mode is selected as User defined 420 0 sec WdgTimeConst2 Set the transformer winding time constant for the winding 2 when the winding time constant mode is selected as User defined 420 0 sec W...

Page 733: ... calculation of ratio loss at the given tap position 3 0 RLHighRated Set the loss ratio at principal tapping 1 position for the calculation of ratio loss at the given tap position 5 0 RLMaxTap Set the loss ratio at maximum tapping position where maximum voltage is possible for the calculation of ratio loss at the given tap position 8 0 RLMinTap Set the loss ratio at minimum tapping position where ...

Page 734: ...p Set the September month average ambient temperature for the calculation of top oil temperature when ambient temperature sensor failure absence 30 C OctAmbTmp Set the October month average ambient temperature for the calculation of top oil temperature when ambient temperature sensor failure absence 30 C NovAmbTmp Set the November month average ambient temperature for the calculation of top oil te...

Page 735: ...sulation loss of life calculation Enable InitialLife Set the initial loss of insulation life 0 0 Hours ExpectedLife Set the expected life of the transformer 1 80 000 Hours AgeingRateMeth Select the ageing rate method of calculation IEC ThermalUpgrade Select the transformer insulation paper type Upgraded TimeToUpdate Set the time interval for the update of loss of life outputs 1 Hour WrnHPTmpLev1 S...

Page 736: ...730 ...

Page 737: ...s to the 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 ...

Page 738: ...he inputs on the same board used for pulse counting 18 2 Function for energy calculation and demand handling ETPMMTR SEMOD153638 1 v2 18 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 18 2 2 Application SEMOD175546 4 v5 Energy calculation and ...

Page 739: ...ulse 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 then is calcul...

Page 740: ... 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 direction ...

Page 741: ...front port and access point 1 The settings for the access points are configured using the Ethernet configuration 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 b...

Page 742: ...protocol chapters To increase security it is recommended to uncheck protocols that are not used on the access point The default gateway can be selected by entering the IP address in Default gateway The default gateway is the router that is used to communicate with the devices in the other subnetwork By default this is set to 0 0 0 0 which means that no default gateway is selected ECT validates the...

Page 743: ... Dynamic access point diagnostic RCHLCCH is used to supervise and assure redundant Ethernet communication over two channels This will secure data transfer even though one communication channel might not be available for some reason Parallel Redundancy Protocol PRP and High availability Seamless Redundancy HSR provides redundant communication over station bus running the available communication pro...

Page 744: ... AP1 PhyPortA PhyPortB Switch B Device 1 Device 2 Device 3 Device 4 IEC09000758 V4 EN US Figure 318 Parallel Redundancy Protocol PRP Section 19 1MRK 502 071 UUS A Ethernet based communication 738 Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 Application manual ...

Page 745: ... 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 into operation the writ...

Page 746: ...e 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 transducers and yet o...

Page 747: ...ork as the default gateway The route specifies that when a package is sent to the destination device it should be sent through the selected router If no route is specified the source device will not find the destination device 19 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 s...

Page 748: ...n Destination subnet mask specifies the subnetwork mask of the destination Section 19 1MRK 502 071 UUS A Ethernet based communication 742 Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 Application manual ...

Page 749: ...wo or more intelligent electronic devices IEDs from one or several vendors to exchange information and to use it in the performance of their functions and for correct co operation GOOSE Generic Object Oriented Substation Event which is a part of IEC 61850 8 1 standard allows the IEDs to communicate state and control information amongst themselves using a publish subscribe mechanism That is upon de...

Page 750: ...2 IED 3 IED 1 IED 2 IED 3 IED 1 IED 2 IED 3 IEC09000135 V1 EN US Figure 322 SA system with IEC 61850 8 1 M16925 3 v4 Figure323 shows the GOOSE peer to peer communication Section 20 1MRK 502 071 UUS A Station communication 744 Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 Application manual ...

Page 751: ...k selection is done with the Ethernet Configuration Tool ECT in PCM600 20 2 3 Horizontal communication via GOOSE 20 2 3 1 Sending data GUID 9888ECAD 8221 4B31 A443 EB1E3A9022C4 v1 In addition to the data object and data attributes of the logical nodes it is possible to send the outputs of the function blocks using the generic communication blocks The outputs of this function can be set in a datase...

Page 752: ...ion for Measured Value MVGAPC function allows the user to choose a deadband and a zero deadband for the monitored signal Values within the zero deadband are considered as zero The high and low limit settings provides limits for the high high high normal low and low low ranges of the measured value The actual range of the measured value is shown on the range output of MVGAPC function block When a M...

Page 753: ...he figure below the GOOSESPRCV is used to receive the status of the bay reservation The validity of the received data is used in additional logic to guarantee that the value has good quality before operation on that bay GOOSESPRCV Block Spout DataValid CommValid Test AND AND Input1 out Input2 Noput Input3 Input4 Input1 out Input2 Noput Input3 Input4 Ext_Res_OK_To_Operate IEC16000082 1 en vsd IEC16...

Page 754: ...rator s workplace from the control 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 fibre optic LON bus is implemented using either glass core or plastic core fibre optic cables Table 74 Specification of the fibre optic connectors Glass fibre Plastic fibre Cable connector ST connector snap in connector Cabl...

Page 755: ...plication library LIB520 is required The HV Control 670 software module is included in the LIB520 high voltage process package which is a part of the Application Software Library in MicroSCADA applications The HV Control 670 software module is used for control functions in the IEDs The module contains a process picture dialogues and a tool to generate a process database for the control application...

Page 756: ...vides two function blocks enabling several IEDs to send and receive signals via the interbay bus The sending function block MULTICMDSND takes 16 binary inputs LON enables these to be transmitted to the equivalent receiving function block MULTICMDRCV which has 16 binary outputs 20 3 2 3 Setting guidelines SEMOD119915 1 v1 Settings M14789 4 v3 The parameters for the multiple command function are set...

Page 757: ...y if the PC is located in the substation via a telephone modem through a telephone network with ITU former CCITT characteristics or via a LAN WAN connection glass 1000 m according to optical budget plastic 25 m inside cubicle according to optical budget Functionality SEMOD115767 25 v2 The SPA protocol V2 5 is an ASCII based protocol for serial communication The communication is based on a master s...

Page 758: ...899 as long as the slave number is unique within the used SPA loop BaudRate communication speed can be set between 300 38400 baud BaudRate should be the same for the whole station although different communication speeds in a loop are possible If different communication speeds are used in the same fibre optical loop or RS485 network take this into account when making the communication setup in the ...

Page 759: ... a Personal Computer PC or a Remote Terminal Unit RTU connected to the Communication and processing module the only hardware needed is optical fibres and an opto electrical converter for the PC RTU or a RS 485 connection depending on the used IED communication interface 20 5 1 1 Functionality M17109 38 v3 IEC 60870 5 103 is an unbalanced master slave protocol for coded bit serial communication exc...

Page 760: ...ter PC or a Remote Terminal Unit RTU in the station using the SPA IEC port the only hardware needed is Optical fibres glass plastic Opto electrical converter for the PC RTU PC RTU Commands M17109 62 v4 The commands defined in the IEC 60870 5 103 protocol are represented in dedicated function blocks These blocks have output signals for all available commands according to the protocol For more infor...

Page 761: ... Fault location M17109 108 v1 The fault location is expressed in reactive ohms In relation to the line length in reactive ohms it gives the distance to the fault in percent The data is available and reported 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 signa...

Page 762: ...fic IEC 60870 5 103 protocol parameters are configured under Main menu 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 th...

Page 763: ...ed by BSW The most recent value is the latest value 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 ti...

Page 764: ...r can be set to any value between 0 and 255 To get INF and FUN for the recorded binary signals there are parameters 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 A...

Page 765: ...Private range 32 87 Private range 33 88 Private range 34 89 Private range 35 90 Private range 36 91 Private range 37 92 Private range 38 93 Private range 39 94 Private range 40 95 Private range 20 5 3 Function and information types M17109 145 v6 Product type IEC103mainFunType value Comment REL 128 Compatible range REC 242 Private range use default RED 192 Compatible range RET 176 Compatible range ...

Page 766: ...o no 11 Local operation Glass or plastic fibre 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 20 6 DNP3 Communication protocol 20 6 1 Application GUID EF1F0C38 9FF6 4683 8B10 AAA372D42185 v1 For more information on the ...

Page 767: ...eprotection schemes and for direct transfer trips In addition to this there are application possibilities for example blocking enabling functionality in the remote substation changing setting group in the remote IED depending on the switching situation in the local substation and so on If equipped with a 64kbit s LDCM module the IED can be configured to send either 192 binary signals or 3 analog a...

Page 768: ...nected to the protection function together with 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 ...

Page 769: ...mple PDH Telecom Network Multiplexer Multiplexer en05000527 2 vsd Converting optical to galvanic G 703 IEC05000527 V2 EN US Figure 331 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 fibre of max 3 km 2 mile length The IEEE ANSI C37 94 protocol is always used between LDCM a...

Page 770: ... for slot 306 set TerminalNo to 3 and RemoteTermNo to 4 In multiterminal current differential applications with 4 LDCMs in each IED up to 20 unique addresses must be set A unique 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 i...

Page 771: ...se the telecommunication system provides the clock master OptoPower has two settings LowPower is used for fibres 0 1 km 0 6 mile and HighPower for fibres 1 km 0 6 mile ComAlarmDel defines the time delay for communication failure alarm In communication systems route switching can sometimes cause interruptions with a duration of up to 50 ms Too short a time delay can thus cause nuisance alarms ComAl...

Page 772: ...backup channel The redundant channel takes the CT group setting of the main channel RemAinLatency corresponds to LocAinLatency set in the remote IED AnalogLatency specifies the time delay number of samples between actual sampling and the time the sample reaches LDCM The value is set to 2 when transmitting analog data When a merging unit according to IEC 61850 9 2 is used instead of the TRM this pa...

Page 773: ...rom another LDCM receiver This is used when the analog signals for the LDCM transmitter is connected to the receiver of another LDCM 1MRK 502 071 UUS A Section 21 Remote communication Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 767 Application manual ...

Page 774: ...768 ...

Page 775: ...ave many functions included The 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 eve...

Page 776: ...Monitoring Tool The PC can either be connected to the front port or to the port at the back of the IED 22 3 Change lock CHNGLCK GUID B48775D0 ACF0 49C6 A7F6 69AF37F1C68F v1 22 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 p...

Page 777: ...ation would occur in spite of these precautions then please contact the local ABB representative for remedial action 22 4 Denial of service SCHLCCH RCHLCCH 22 4 1 Application GUID 64F4D905 9F73 4073 B8F6 8D373155316A v5 The denial of service functionality is designed to limit the CPU load that can be produced by Ethernet network traffic on the IED The communication facilities must not be allowed t...

Page 778: ...dundant communication LinkStatus indicates the Ethernet link status for the front port 22 4 2 Setting guidelines GUID CE3344E8 539B 47E0 9C19 8239988BDBCF v2 The function does not have any parameters available in the local HMI or PCM600 Section 22 1MRK 502 071 UUS A Security 772 Generator protection REG670 2 2 ANSI and Injection equipment REX060 REX061 REX062 Application manual ...

Page 779: ...D78786E6 C34A 4E63 9D1E 0582C8F1F7E1 v8 Product information contains unchangeable 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 ProductVer ProductDef FirmwareVer SerialNo OrderingNo ProductionDate IEDProdType This information is very helpful...

Page 780: ...s 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 the manufactured pro...

Page 781: ...he measured value expander block function 23 4 Parameter setting groups IP1745 1 v1 23 4 1 Application M12007 6 v9 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 ...

Page 782: ...meter MAXSETGR defines the maximum number of setting groups in use to switch between Only the selected number of setting groups will be available in the Parameter Setting tool PST for activation with the ActiveGroup function block 23 5 Rated system frequency PRIMVAL IP15064 1 v2 23 5 1 Identification GUID B8B3535D 227B 4151 9E98 BEB85F4D54DE v1 Function description IEC 61850 identification IEC 606...

Page 783: ... DFT block InternalDFT Ref DFTRefGrp1 or External DFT ref FreqMeasMinVal The minimum value of the voltage for which the frequency is calculated expressed as percent of VBasebase voltage setting for each instance x GlobalBaseSel Selects the global base value group used by the function to define IBase VBase and SBase 23 7 Global base values GBASVAL GUID 2FDB0A2C 10FE 4954 B6E4 9DA2EEEF1668 v1 23 7 1...

Page 784: ...able functions throughout the IED SBase Standard apparent power value to be used as a base value for applicable functions throughout the IED typically SBase 3 VBase IBase 23 8 Signal matrix for binary inputs SMBI SEMOD55793 1 v2 23 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 Matri...

Page 785: ...in the Signal Matrix tool 23 10 Signal matrix for mA inputs SMMI SEMOD55233 1 v2 23 10 1 Application SEMOD55237 5 v2 The Signal matrix for mA inputs function SMMI is used within the Application Configuration tool in direct relation with the Signal Matrix tool SMMI represents the way milliamp mA inputs are brought in for one IED configuration 23 10 2 Setting guidelines SEMOD55247 5 v2 There are no ...

Page 786: ...id frequency values MinValFreqMeas is set as of VBase 3 If SMAI setting ConnectionType is Ph Ph at least two of the inputs GRPx_A GRPx_B and GRPx_C where 1 x 12 must be connected in order to calculate the positive sequence voltage Note that phase to phase inputs shall always be connected as follows A B to GRPxA B C to GRPxB C A to GRPxC If SMAI setting ConnectionType is Ph N all three inputs GRPx_...

Page 787: ...ing guidelines GUID C8D6C88B 87C6 44C1 804B CF1594365EE6 v8 The parameters for the signal matrix for analog inputs SMAI functions are set via the local HMI or PCM600 Every SMAI function block can receive four analog signals three phases and one neutral value either voltage or current SMAI outputs give information about every aspect of the 3ph analog signals acquired phase angle RMS value frequency...

Page 788: ...IBase VBase and SBase MinValFreqMeas The minimum value of the voltage for which the frequency is calculated expressed as percent of VBase for each instance n Settings DFTRefExtOut and DFTReference shall be set to default value InternalDFTRef if no VT inputs are available Even if the user sets the AnalogInputType of a SMAI block to Current the MinValFreqMeas is still visible However using the curre...

Page 789: ...9 SMAI10 22 10 SMAI11 23 11 SMAI12 24 12 Task time group 2 SMAI instance 3 phase group SMAI1 25 1 SMAI2 26 2 SMAI3 27 3 SMAI4 28 4 SMAI5 29 5 SMAI6 30 6 SMAI7 31 7 SMAI8 32 8 SMAI9 33 9 SMAI10 34 10 SMAI11 35 11 SMAI12 36 12 Task time group 3 AdDFTRefCh7 AdDFTRefCh4 IEC07000197 V2 EN US Figure 333 Twelve SMAI instances are grouped within one task time SMAI blocks are available in three different t...

Page 790: ...r using an instance in task time group 1 as DFT reference Assume instance SMAI7 7 in task time group 1 has been selected in the configuration to control the frequency tracking Observe that the selected reference instance i e frequency tracking master must be a voltage type Observe that positive sequence voltage is used for the frequency tracking feature For task time group 1 this gives the followi...

Page 791: ...all instances Observe that the selected reference instance i e frequency tracking master must be a voltage type Observe that positive sequence voltage is used for the frequency tracking feature For task time group 1 this gives the following settings see Figure 333 for numbering SMAI1 1 SMAI12 12 DFTReference ExternalDFTRef to use DFTSPFC input as reference SMAI4 16 For task time group 2 this gives...

Page 792: ...0 client The possible values of IEC 61850 Mod are described in Communication protocol manual IEC 61850 Edition 1 and Edition 2 To be able to set the IEC 61850 Mod the parameter remotely the PST setting RemoteModControl may not be set to Off The possible values are Off Maintenance or All levels The Off value denies all access to data object Mod from remote Maintenance requires that the category of ...

Page 793: ...IEC 61850 link data are blocked by the LN Only process related outputs on LNs related to primary equipment are blocked If there is an XCBR the outputs EXC_Open and EXC_Close are blocked When the Beh of a component is set to Blocked all control commands with a test bit are accepted Outputs to the process via a non IEC 61850 link data are blocked by the LN In addition the components can be blocked w...

Page 794: ...be compared and evaluated In the IED the internal time can be synchronized from the following sources BIN Binary Minute Pulse DNP GPS IEC103 SNTP IRIG B SPA LON PPS IEEE 1588 PTP For IEDs using PMU functionality only PTP GPS or IRIG B or a combination of both GPS and IRIG B is allowed For IEDs using IEC UCA 61850 9 2LE in mixed mode a time synchronization from an external clock is recommended to t...

Page 795: ... its profile IEC IEEE 61850 9 3 for power utility automation is a synchronization method that can be used to maintain a common time within a station This time can be synchronized to the global time using for instance a GPS receiver If PTP is enabled on the IEDs and the switches that connect the station are compatible with IEEE 1588 the station will become synchronized to one common time with an ac...

Page 796: ...oarseSyncSrc which can have the following values Disabled 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 system time can be set manually either via the local HMI or via any of the communication ports The time synchronization fine tunes the clock seconds and millise...

Page 797: ...he 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 336 Enabling PTP in ECT The PTP VLAN tag must have the same value in stati...

Page 798: ...ns a GTM card which has a PPS output that is used to synchronize merging units that are not PTP compliant As a side effect the GTM contains a GPS receiver and the REL acts as a backup of the GPS on the station bus On all access points the PTP parameter is ON On the REL the parameter FineSyncSource under Configuration Time Synchronization TIMESYNCHGEN 1 General is set to GPS if there is a GPS anten...

Page 799: ...rent classes and standards In principle there are three different types of protection CTs These 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 Rem...

Page 800: ...e for example protection classes TPX P PX according to IEC class C K according to ANSI IEEE and with an iron core material new material typically new alloy based magnetic materials that gives 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 wit...

Page 801: ...ent limiting secondary e m f Eal according to the IEC 61869 2 standard is used to specify the CT requirements for the IED The requirements are also specified according to other standards 24 1 2 Conditions M11610 3 v1 M11610 4 v4 The requirements are a result of investigations performed in our network simulator The current transformer models are representative for current transformers of high reman...

Page 802: ...the maximum fault current for faults in different positions Maximum fault current will occur for three phase faults or single phase to ground faults The current for a single phase to ground fault will exceed the current for a three phase fault when the zero sequence impedance in the total fault loop is less than the positive sequence impedance When calculating the current transformer requirements ...

Page 803: ...sitive setting of a sensitive residual overcurrent protection If a very sensitive setting of this function will be used it is recommended that the current transformer should have an accuracy class which have an current error at rated primary current that is less than 1 for example 5P If current transformers with less accuracy are used it is advisable to check the actual unwanted residual current d...

Page 804: ...t have a rated equivalent limiting secondary e m f Eal that is larger than or equal to the maximum of the required rated equivalent limiting secondary e m f EalreqRat and EalreqExt below 30 NG al alreqRat sr ct w addbu pr I E E I R R R I EQUATION2525 V2 EN US Equation 273 2 tf al alreqExt sr ct w addbu pr I E E I R R R I EQUATION2526 V2 EN US Equation 274 where ING The rated primary current of the...

Page 805: ...ression w R I A r W EQUATION2527 V1 EN US Equation 275 In our example the single length of the secondary wire is 300 m both to CT1 and CT2 The cross section area is 2 5 mm2 The resistivity for cupper at 75 C is 0 021 Ω m2 m With this value 300 0 021 2 5 2 5 r W w R I A EQUATION2528 V2 EN US Equation 276 The total additional burden in our example is 0 3 Ω for both CTs Calculation example 1 GUID D92...

Page 806: ... resistance Rct 5 Ω The rated burden W b 2 sr 15 15 R 15 1 I EQUATION2529 V2 EN US Equation 277 CT2 4000 1 A class PX the rated knee point e m f Ek 200 V Rct 5 Ω From the data the Eal can be calculated CT1 al sr ct b E ALF I R R 10 1 5 15 200 V EQUATION2530 V2 EN US Equation 278 where ALF is the CT accuracy limit factor CT2 Section 24 1MRK 502 071 UUS A Requirements 800 Generator protection REG670...

Page 807: ...lreqExt below NG al alreqRat sr ct w addbu pr I 3250 E E 30 I R R R 30 1 5 2 5 0 3 190 V I 4000 EQUATION2534 V2 EN US Equation 282 tf al alreqExt sr ct w addbu pr I 13000 E E 2 I R R R 2 1 5 2 5 0 3 51V I 4000 EQUATION2535 V2 EN US Equation 283 In this application we can see that the CTs must have a rated equivalent secondary e m f Eal that is equal or larger than 190 V As the existing CT1 has Eal...

Page 808: ...R R 2 5 0 3 2 8 EQUATION2536 V2 EN US Equation 286 It is often economical favorable to specify a low rated burden and a higher overcurrent factor instead of vice versa In our case it can be suitable to decide the rated burden to Rb 5 Ω 5 VA Now we can assume the CT secondary winding resistance to be 60 of Rb Rct 3 Ω We can now calculate the required secondary e m f according to equation 273 and 27...

Page 809: ...possible to have an actual burden more than 2 8 Ω and still fulfil the CT requirements It is of course also possible to specify the CT according to other classes For example a CT with the following data will also fulfil the requirements Class PX RCT 3 Ω and the knee point e m f k al E 0 8 E 0 8 142 114 V EQUATION2541 V2 EN US Equation 291 As an alternative it can be suitable to provide the CT manu...

Page 810: ... E 2 I R R I I æ ö ç è ø EQUATION1673 V1 EN US Equation 296 where Irt The rated primary current of the power transformer A Itf Maximum primary fundamental frequency current that passes two main CTs and the power transformer A Ipr The rated primary CT current A Isr The rated secondary CT current A In The nominal current of the protection IED A Rct The secondary resistance of the CT W RL The resista...

Page 811: ...77 V1 EN US Equation 298 where Iop The primary operate value A Ipr The rated primary CT current A Isr The rated secondary CT current A In The nominal current of the protection IED A Rct The secondary resistance of the CT W RL The resistance of the secondary cable and additional load W The loop resistance containing the phase and neutral wires must be used for faults in solidly grounded systems The...

Page 812: ...tral A Ipr The rated primary CT current A Isr The rated secondary CT current A Ir The rated current of the protection IED A Rct The secondary resistance of the CT Ω RL The resistance of the secondary wire and additional load Ω The loop resistance containing the phase and neutral wires shall be used SR The burden of a REx670 current input channel VA SR 0 020 VA channel for IR 1 A and SR 0 150 VA ch...

Page 813: ...nt A Ir The rated current of the protection IED A Rct The secondary resistance of the CT Ω RL The resistance of the secondary wire and additional load Ω The loop resistance containing the phase and neutral wires shall be used SR The burden of a REx670 current input channel VA SR 0 020 VA channel for Ir 1 A and SR 0 150 VA channel for Ir 5 A In case of three individual CTs connected in parallel Hol...

Page 814: ...e cases with summation of zero sequence currents from more than one CT the phase side CTs must fulfill the Requirement 304 below 2 sr R al alreq f ct L pr r I S E E I R R I I æ ö ç è ø EQUATION2242 V2 EN US Equation 304 Where If Maximum primary fundamental frequency three phase fault current that passes the CTs A RL The resistance of the secondary wire and additional load Ω The loop resistance con...

Page 815: ... is not possible to give a general relation between the Eknee and the Eal but normally the Eknee is approximately 80 of the Eal Therefore the CTs according to class PX PXR X and TPS must have a rated knee point e m f Eknee that fulfills the following 1 Old Calculated S TD S TD S EQUATION1893 ANSI V1 EN US Equation 306 24 1 7 3 Current transformers according to ANSI IEEE M11623 22 v6 Current transf...

Page 816: ...EE must have a knee point voltage VkneeANSI that fulfills the following kneeANSI alreq V 0 75 maximum of E EQUATION2101 V2 EN US Equation 309 The following guide may also be referred for some more application aspects of ANSI class CTs IEEE C37 110 2007 IEEE Guide for the Application of Current Transformers Used for Protective Relaying Purposes 24 2 Voltage transformer requirements M11608 3 v5 The ...

Page 817: ...rver in a redundant configuration is not recommended 24 4 PTP requirements GUID 741CC863 D760 49D6 85B2 AFECA222A8C3 v1 For PTP to perform properly the Ethernet equipment that is used needs to be compliant with IEEE1588 The clocks used must follow the IEEE1588 standard BMC Best Master Algorithm and shall for instance not claim class 7 for a longer time than it can guarantee 1us absolute accuracy 2...

Page 818: ...red etc Format No CRC check Synchronization in PDH systems connected to SDH systems Independent synchronization asynchronous mapping The actual SDH port must be set to allow transmission of the master clock from the PDH system via the SDH system in transparent mode Maximum clock deviation 50 ppm nominal 100 ppm operational Jitter and Wander according to ITU T G 823 and G 825 Buffer memory 100 μs F...

Page 819: ... American Wire Gauge standard BBP Busbar protection BFOC 2 5 Bayonet fibre 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...

Page 820: ... Format for Transient Data Exchange format for Disturbance 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 red...

Page 821: ...onic Industries Association EMC Electromagnetic compatibility EMF Electromotive force EMI Electromagnetic interference EnFP End fault protection EPA Enhanced performance architecture ESD Electrostatic discharge F SMA Type of optical fibre 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...

Page 822: ...ne interface HSAR High speed autoreclosing HSR High availability Seamless Redundancy HV High voltage HVDC High voltage direct current ICT Installation and Commissioning Tool for injection based protection in REG670 IDBS Integrating deadband supervision IEC International Electrical Committee IEC 60044 6 IEC Standard Instrument transformers Part 6 Requirements for protective current transformers for...

Page 823: ...e is sometimes defined as an item of information that is representative of a type In the same way an instance of a function in the IED is representative of a type of function IP 1 Internet protocol The network layer for the TCP IP protocol suite widely used on Ethernet networks IP is a connectionless best effort packet switching protocol It provides packet routing fragmentation and reassembly thro...

Page 824: ...l module OCO cycle Open close open cycle OCP Overcurrent protection OEM Optical Ethernet module OLTC On load tap changer OTEV Disturbance data recording initiated by other event than start pick up OV Overvoltage Overreach A term used to describe how the relay behaves during a fault condition For example a distance relay is overreaching when the impedance presented to it is smaller than the apparen...

Page 825: ...c angle RISC Reduced instruction set computer RMS value Root mean square value RS422 A balanced serial interface for the transmission of digital data in point to point connections RS485 Serial link according to EIA standard RS485 RTC Real time clock RTU Remote terminal unit SA Substation Automation SBO Select before operate SC Switch or push button to close SCL Short circuit location SCS Station c...

Page 826: ...ip coil TCS Trip circuit supervision TCP Transmission control protocol The most common transport layer protocol used on Ethernet and the Internet TCP IP Transmission control protocol over Internet Protocol The de facto standard Ethernet protocols incorporated into 4 2BSD Unix TCP IP was developed by DARPA for Internet working and encompasses both network layer and transport layer protocols While T...

Page 827: ... Atomic Time TAI by the addition of a whole number of leap seconds to synchronize it with Universal Time 1 UT1 thus allowing for the eccentricity of the Earth s orbit the rotational axis tilt 23 5 degrees but still showing the Earth s irregular rotation on which UT1 is based The Coordinated Universal Time is expressed using a 24 hour clock and uses the Gregorian calendar It is used for aeroplane a...

Page 828: ...822 ...

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Page 830: ... 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 502 071 UUS ...

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