ABB Relion REG670 Applications Manual Download Page 24

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Setting examples for IEC/UCA 61850-9-2LE and time

synchronization.................................................................... 692

IEC 61850 quality expander QUALEXP.................................... 697

LON communication protocol......................................................... 698

Application.................................................................................698
MULTICMDRCV and MULTICMDSND..................................... 700

Identification......................................................................... 700
Application............................................................................700
Setting guidelines................................................................. 700

SPA communication protocol......................................................... 700

Application.................................................................................700
Setting guidelines...................................................................... 701

IEC 60870-5-103 communication protocol..................................... 703

Application.................................................................................703

Functionality......................................................................... 703
Design.................................................................................. 704

Settings......................................................................................706

Settings for RS485 and optical serial communication.......... 707
Settings from PCM600......................................................... 708

Function and information types................................................. 710

DNP3 Communication protocol...................................................... 711

Application.................................................................................711

Section 21 Remote communication................................................713

Binary signal transfer......................................................................713

Identification.............................................................................. 713
Application.................................................................................713

Communication hardware solutions..................................... 714

Setting guidelines...................................................................... 715

Section 22 Security........................................................................ 719

Authority status ATHSTAT............................................................. 719

Application.................................................................................719

Self supervision with internal event list INTERRSIG...................... 719

Application.................................................................................719

Change lock CHNGLCK................................................................. 720

Application.................................................................................720

Denial of service SCHLCCH/RCHLCCH ....................................... 721

Application.................................................................................721
Setting guidelines...................................................................... 721

Section 23 Basic IED functions...................................................... 723

IED identifiers TERMINALID.......................................................... 723

Application.................................................................................723

Table of contents

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

Application manual

Summary of Contents for Relion REG670

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

Page 2: ......

Page 4: ...rms 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 b...

Page 5: ...roduct 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 equipme...

Page 6: ...d concerning electrical equipment for use within specified voltage limits Low voltage directive 2006 95 EC This conformity is the result of tests conducted by ABB in accordance with the product standa...

Page 7: ...D functions 55 Section 3 Configuration 57 Description of REG670 57 Introduction 57 Description of configuration A20 57 Description of configuration B30 58 Description of configuration C30 60 Section 4...

Page 8: ...ly earthed power systems 89 Example on how to connect a neutral point VT to the IED 90 Section 5 Local HMI 93 Display 94 LEDs 96 Keypad 97 Local HMI functionality 99 Protection and alarm indication 99...

Page 9: ...ntial protection 137 Application Examples 139 Summary and conclusions 146 High impedance differential protection single phase HZPDIF 148 Identification 148 Application 148 The basics of the high imped...

Page 10: ...dance protection 183 Full scheme distance measuring Mho characteristic ZMHPDIS 183 Identification 183 Application 183 Generator underimpedance protection application 183 Setting guidelines 183 Configu...

Page 11: ...of series compensation on protective IED of adjacent lines 239 Distance protection 240 Underreaching and overreaching schemes 241 Setting guidelines 247 General 247 Setting of zone 1 248 Setting of ov...

Page 12: ...Setting injection unit REX060 305 Connecting and setting voltage inputs 306 100 stator earth fault protection 307 Under impedance protection for generators and transformers ZGVPDIS 308 Identification...

Page 13: ...343 Switch onto fault logic 344 Settings for each step x 1 2 3 and 4 344 Transformer application example 347 Four step directional negative phase sequence overcurrent protection NS4PTOC 350 Identifica...

Page 14: ...synchronous generator AEGPVOC 393 Identification 393 Application 393 Setting guidelines 393 Voltage restrained time overcurrent protection VRPVOC 394 Identification 394 Application 395 Base quantitie...

Page 15: ...dance earthed systems 408 The following settings can be done for the two step overvoltage protection 408 Two step residual overvoltage protection ROV2PTOV 410 Identification 410 Application 410 Settin...

Page 16: ...ication 440 Setting guidelines 440 Frequency time accumulation protection function FTAQFVR 441 Identification 441 Application 441 Setting guidelines 443 Section 12 Multipurpose protection 445 General...

Page 17: ...465 Multipurpose filter SMAIHPAC 465 Identification 465 Application 465 Setting guidelines 466 Setting example 466 Section 14 Secondary system supervision 471 Current circuit supervision CCSSPVC 471...

Page 18: ...ler SCSWI 501 Switches SXCBR SXSWI 502 Proxy for signals from switching device via GOOSE XLNPROXY 503 Reservation function QCRSV and RESIN 506 Interaction between modules 508 Setting guidelines 510 Ba...

Page 19: ...als in double breaker arrangement 543 Signals in 1 1 2 breaker arrangement 544 Interlocking for double CB bay DB 545 Application 545 Configuration setting 546 Interlocking for 1 1 2 CB BH 547 Applicat...

Page 20: ...and or three phase tripping 601 Single two or three phase tripping 602 Lock out 602 Example of directional data 603 Blocking of the function block 605 Setting guidelines 605 Trip matrix logic TMAGAPC...

Page 21: ...ion 615 Application 615 Pulse integrator TIGAPC 616 Identification 616 Application 616 Setting guidelines 616 Elapsed time integrator with limit transgression and overflow supervision TEIGAPC 617 Iden...

Page 22: ...report DRPRDRE 643 Identification 643 Application 643 Setting guidelines 644 Recording times 647 Binary input signals 647 Analog input signals 648 Sub function parameters 648 Consideration 649 Logica...

Page 23: ...fication 676 Application 677 Setting guidelines 678 Merging unit 679 Application 679 Setting guidelines 680 Routes 680 Application 680 Setting guidelines 680 Section 20 Station communication 681 Commu...

Page 24: ...nction and information types 710 DNP3 Communication protocol 711 Application 711 Section 21 Remote communication 713 Binary signal transfer 713 Identification 713 Application 713 Communication hardwar...

Page 25: ...elines 727 Signal matrix for binary inputs SMBI 728 Application 728 Setting guidelines 728 Signal matrix for binary outputs SMBO 728 Application 728 Setting guidelines 728 Signal matrix for mA inputs...

Page 26: ...ce differential 754 Current transformer requirements for CTs according to other standards 757 Current transformers according to IEC 61869 2 class P PR757 Current transformers according to IEC 61869 2...

Page 27: ...calculating settings 1 2 Intended audience This manual addresses the protection and control engineer responsible for planning pre engineering and engineering The protection and control engineer must b...

Page 28: ...ure 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...

Page 29: ...l reference during the engineering phase installation and commissioning phase and during normal service The communication protocol manual describes the communication protocols supported by the IED The...

Page 30: ...RK 513 003 BEN Test system COMBITEST 1MRK 512 001 BEN Application guide Communication set up 1MRK 505 382 UEN 1 4 Document symbols and conventions 1 4 1 Symbols The electrical warning icon indicates t...

Page 31: ...le to save the changes in non volatile memory select Yes and press Parameter names are shown in italics For example the function can be enabled and disabled with the Operation setting Each function bl...

Page 32: ...MCALH ALMCALH ALTIM ALTIM ALTMS ALTMS ALTRK ALTRK BCZPDIF BCZPDIF BCZPDIF BCZSPDIF BCZSPDIF BCZSPDIF BCZTPDIF BCZTPDIF BCZTPDIF BDCGAPC SWSGGIO BBCSWI BDCGAPC BDZSGAPC BBS6LLN0 BDZSGAPC LLN0 BDZSGAPC...

Page 33: ...2 BUSPTRC BUSPTRC BUSPTRC_B3 BUSPTRC BUSPTRC BUSPTRC_B4 BUSPTRC BUSPTRC BUSPTRC_B5 BUSPTRC BUSPTRC BUSPTRC_B6 BUSPTRC BUSPTRC BUSPTRC_B7 BUSPTRC BUSPTRC BUSPTRC_B8 BUSPTRC BUSPTRC BUSPTRC_B9 BUSPTRC B...

Page 34: ...Z4 BZNPDIF BZNPDIF BZNPDIF_Z5 BZNPDIF BZNPDIF BZNPDIF_Z6 BZNPDIF BZNPDIF BZNSPDIF_A BZNSPDIF BZASGAPC BZASPDIF BZNSGAPC BZNSPDIF BZNSPDIF_B BZNSPDIF BZBSGAPC BZBSPDIF BZNSGAPC BZNSPDIF BZNTPDIF_A BZNT...

Page 35: ...EF2PTOC EF2LLN0 EF2PTRC EF2RDIR GEN2PHAR PH1PTOC EF2PTRC EF2RDIR GEN2PHAR PH1PTOC EF4PTOC EF4LLN0 EF4PTRC EF4RDIR GEN4PHAR PH1PTOC EF4PTRC EF4RDIR GEN4PHAR PH1PTOC EFPIOC EFPIOC EFPIOC EFRWPIOC EFRWPI...

Page 36: ...LCCRPTRC LCNSPTOC LCNSPTOC LCNSPTOC LCNSPTOV LCNSPTOV LCNSPTOV LCP3PTOC LCP3PTOC LCP3PTOC LCP3PTUC LCP3PTUC LCP3PTUC LCPTTR LCPTTR LCPTTR LCZSPTOC LCZSPTOC LCZSPTOC LCZSPTOV LCZSPTOV LCZSPTOV LD0LLN0...

Page 37: ...2PTOV PH1PTRC OV2PTOV PH1PTRC PAPGAPC PAPGAPC PAPGAPC PCFCNT PCGGIO PCFCNT PH4SPTOC GEN4PHAR OCNDLLN0 PH1BPTOC PH1PTRC GEN4PHAR PH1BPTOC PH1PTRC PHPIOC PHPIOC PHPIOC PSLPSCH ZMRPSL PSLPSCH PSPPPAM PSP...

Page 38: ...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 T3...

Page 39: ...CH ZCPSCH ZCRWPSCH ZCRWPSCH ZCRWPSCH ZCVPSOF ZCVPSOF ZCVPSOF ZGVPDIS ZGVLLN0 PH1PTRC ZGVPDIS ZGVPTUV PH1PTRC ZGVPDIS ZGVPTUV ZMCAPDIS ZMCAPDIS ZMCAPDIS ZMCPDIS ZMCPDIS ZMCPDIS ZMFCPDIS ZMFCLLN0 PSFPDI...

Page 40: ...des Edition 2 logical nodes ZMRPDIS ZMRPDIS ZMRPDIS ZMRPSB ZMRPSB ZMRPSB ZSMGAPC ZSMGAPC ZSMGAPC Section 1 1MRK 502 071 UEN Introduction 34 Generator protection REG670 2 2 IEC and Injection equipment...

Page 41: ...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 tr...

Page 42: ...2LE process bus with up to eight merging units MU depending on the other functionality included in the IED This adaptive filtering is ensured by proper configuration and settings of all relevant pre...

Page 43: ...ents 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...

Page 44: ...2 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 Figu...

Page 45: ...P 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 Figure 3 Generator protection app...

Page 46: ...X060 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 Figure 4 Generator protection...

Page 47: ...N 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...

Page 48: ...50 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 M...

Page 49: ...STTI PHIZ 64S RSE ROTI PHIZ 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 Figure 7 Unit protection application with overall differ...

Page 50: ...e protection ZMHPDIS 21 Full scheme distance protection mho characteristic 0 4 3 3 3 ZDMRDIR 21D Directional impedance element for mho characteristic 0 2 1 1 1 ZMFPDIS 21 High speed distance protectio...

Page 51: ...failure protection 0 4 2 4 4 CCPDSC 52PD Pole discordance protection 0 4 2 4 4 GUPPDUP 37 Directional underpower protection 0 4 2 4 4 GOPPDOP 32 Directional overpower protection 0 4 2 4 4 NS2PTOC 46I...

Page 52: ...eneral current and voltage protection 0 9 6 6 6 General calculation SMAIHPAC Multipurpose filter 0 6 1 67 requires voltage 2 67N requires voltage 2 4 Control and monitoring functions IEC 61850 or func...

Page 53: ...nd 16 signals 4 4 4 4 I103CMD Function commands for IEC 60870 5 103 1 1 1 1 I103GENCMD Function commands generic for IEC 60870 5 103 50 50 50 50 I103POSCMD IED commands with position and select for IE...

Page 54: ...TIMERSET VSGAPC XOR Extension logic package see Table 6 0 1 FXDSIGN Fixed signal function block 1 1 1 1 B16I Boolean to integer conversion 16 bit 18 18 18 18 BTIGAPC Boolean to integer conversion wit...

Page 55: ...DC 6 ABC_BC 2 BH_CONN 2 BH_LINE_A 2 BH_LINE_B 2 DB_BUS_A 3 DB_BUS_B 3 DB_LINE 3 ABC_LINE 6 AB_TRAFO 4 SCSWI Switch controller 30 SXSWI Circuit switch 24 QCRSV Apparatus control 6 RESIN1 1 RESIN2 59 PO...

Page 56: ...ces AND 180 GATE 49 INV 180 LLD 49 OR 180 PULSETIMER 89 RSMEMORY 40 SLGAPC 74 SRMEMORY 130 TIMERSET 109 VSGAPC 120 XOR 89 IEC 61850 or function name ANSI Function description Generator REG670 Customiz...

Page 57: ...21 SSIML 71 Insulation supervision for liquid medium 3 3 3 3 SSCBR Circuit breaker condition monitoring 0 12 6 12 12 LOLSPTR 26 49 HS Transformer insulation loss of life monitoring 0 4 4 M21 4 M21 I1...

Page 58: ...DNP3 0 for EIA 485 communication protocol 1 1 1 1 CH1TCP CH2TCP CH3TCP CH4TCP DNP3 0 for TCP IP communication protocol 1 1 1 1 CHSEROPT DNP3 0 for TCP IP and EIA 485 communication protocol 1 1 1 1 MST...

Page 59: ...ocol 1 1 1 1 SECALARM Component for mapping security events on protocols such as DNP3 and IEC103 1 1 1 1 FSTACCS Field service tool access 1 1 1 1 IEC 61850 9 2 Process bus communication 8 merging uni...

Page 60: ...ve binary status from remote LDCM 6 3 3 6 3 3 6 3 3 6 3 3 LDCMRecBinS2_2M Receive binary status from LDCM 2Mbit 3 3 3 3 LDCMRecBinS3_2M Receive binary status from remote LDCM 2Mbit 3 3 3 3 Table 7 Num...

Page 61: ...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 SMAI12 Signal ma...

Page 62: ...Y5 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...

Page 63: ...Pole Slip protection function are optional REG670 A20 functional library includes additional functions which are not configured such as additional Overcurrent protection additional Multipurpose protec...

Page 64: ...V 60 Ud Q CBAY 3 Control GR PTTR 49R 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 ZDM RDIR 21D...

Page 65: ...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 R...

Page 66: ...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 C...

Page 67: ...onal library includes additional functions which are not configured such as additional Multipurpose protection functions Synchrocheck function second generator differential protection function and so...

Page 68: ...IF 87T 3Id I FUF SPVC U I C MSQI MET Isqi C MMXU MET I GS PTTR 49S 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 a...

Page 69: ...le information will be shown in relation to this analog input During testing and commissioning of the IED the reference channel can be changed to facilitate testing and service values reading The IED...

Page 70: ...rection 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 a...

Page 71: ...orrect setting is FromObject IEC05000753 IEC05 000753 1 en Origin al 1 vsd Is Is Ip Ip Ip IED IED IEC05000753 V2 EN Figure 12 Example how to set CTStarPoint parameters in the IED Figure 12 shows the n...

Page 72: ...Figure 13 Example how to set CTStarPoint parameters in the IED This example is similar to example 1 but here the transformer is feeding just one line and the line protection uses the same CT as the tr...

Page 73: ...rward 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 dir...

Page 74: ...input for transformer functions Set parameter CTStarPoint with Transformer as reference object Correct setting is ToObject Setting of current input for line functions Set parameter CTStarPoint with Li...

Page 75: ...and for all CT inputs marked with 2 in Figure 16 set CTStarPoint FromObject The second solution will be to use all connected bays as reference objects In that case for all CT inputs marked with 1 in F...

Page 76: ...h 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 Figure 17 Commonly used markings of CT terminals Where a is symbol and termina...

Page 77: ...xample on how to connect a star connected three phase CT set to the IED Figure 18 gives an example about the wiring of a star connected two phase CT set to the IED It gives an overview of the actions...

Page 78: ...ED 2 The current inputs are located in the TRM It shall be noted that for all these current inputs the following setting values shall be entered for the example shown in Figure 18 CTprim 600A CTsec 5A...

Page 79: ...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 input...

Page 80: ...meter CTStarPoint of the used current inputs on the TRM item 2 in Figure 19 and 18 CTprim 600A CTsec 5A CTStarPoint FromObject The ratio of the first two parameters is only used inside the IED The thi...

Page 81: ...e 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 ConnectionTyp...

Page 82: ...trol functions within the IED which are connected to this preprocessing function block in the configuration tool For this application most of the preprocessing settings can be left to the default valu...

Page 83: ...IEC11000027 3 en vsdx SMAI2 BLOCK REVROT GRP2L1 GRP2L2 GRP2L3 GRP2N AI3P AI1 AI2 AI3 AI4 AIN IEC11000027 V3 EN Figure 21 Delta DAB connected three phase CT set 1MRK 502 071 UEN Section 4 Analog input...

Page 84: ...g 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...

Page 85: ...ype Ph Ph It is important to notice the references in SMAI As inputs at Ph Ph are expected to be L1L2 L2L3 respectively L3L1 we need to tilt 180 by setting ToObject 4 2 2 7 Example how to connect sing...

Page 86: ...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 functions within the IED which are co...

Page 87: ...ing minimum pickup of the function on the CT secondary side must always be verified It is strongly recommended that the minimum pickup of any instantaneous protection function e g differential restric...

Page 88: ...standard for open delta connected VTs d is the equivalent symbol and terminal marking used by IEC ANSI standard for phase to phase connected VTs It shall be noted that depending on national standard a...

Page 89: ...AI3P AI1 AI2 AI3 AI4 AIN IEC06000599 V4 EN Figure 25 A Three phase to earth connected VT L1 IED L2 132 2 110 2 kV V 1 3 2 132 2 110 2 kV V IEC16000140 1 en vsdx 4 SMAI2 BLOCK GRP2L1 GRP2L2 GRP2L1L2 G...

Page 90: ...lter the connected analog inputs and calculate fundamental frequency phasors for all input channels harmonic content for all input channels positive negative and zero sequence quantities by using the...

Page 91: ...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 V...

Page 92: ...e set as shown here ConnectionType Ph Ph UBase 13 8 kV If frequency tracking and compensation is required this feature is typically required only for IEDs installed in the generating stations then the...

Page 93: ...d Not Used SMAI2 BLOCK REVROT GRP2L1 GRP2L2 GRP2L3 GRP2N AI3P AI1 AI2 AI3 AI4 AIN IEC06000601 V4 EN Figure 28 Open delta connected VT in high impedance earthed power system 1MRK 502 071 UEN Section 4...

Page 94: ...nput 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...

Page 95: ...age 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 vol...

Page 96: ...d 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 pha...

Page 97: ...asurement available to the built in protection and control functions within the IED L1 L2 L3 IED 6 6 3 100 kV V R Uo IEC06000603 4 en vsdx Not Used Not Used Not Used Protected Object SMAI2 BLOCK REVRO...

Page 98: ...block 5 5 is a preprocessing block that has the task to digitally filter the connected analog inputs and calculate fundamental frequency phasors for all four input channels harmonic content for all f...

Page 99: ...man machine interface The LHMI of the IED contains the following elements Keypad Display LCD LED indicators Communication port for PCM600 1MRK 502 071 UEN Section 5 Local HMI Generator protection REG6...

Page 100: ...ew that is shown The display view is divided into four basic areas IEC15000270 1 en vsdx IEC15000270 V1 EN Figure 32 Display layout 1 Path 2 Content 3 Status 4 Scroll bar appears when needed The funct...

Page 101: ...ble IEC13000240 1 en vsd GUID 5157100F E8C0 4FAB B979 FD4A971475E3 V1 EN Figure 34 Indication LED panel The function button and indication LED panels are not visible at the same time Each panel is sho...

Page 102: ...y 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 but...

Page 103: ...ge 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 b...

Page 104: ...gation 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 Mu...

Page 105: ...operation Flashing Internal fault has occurred Table 11 Start LED yellow LED state Description Off Normal operation On A protection function has started and an indication message is displayed The star...

Page 106: ...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...

Page 107: ...een 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 Co...

Page 108: ...102...

Page 109: ...resses and specific settings for IEEE C37 118 as well as IEEE 1344 protocols 6 1 3 Operation principle The Figure 38 demonstrates the communication configuration diagram As can be seen the IED can sup...

Page 110: ...8 The communication configuration PMUCONF structure in the IED 6 1 3 1 Short guidance for use of TCP Port 7001 is used by the SPA on TCP IP field service tool If the port is used for any other protoco...

Page 111: ...u Diagnostics Communication PMU diagnostics PMUSTATUS 1 It is possible to turn off on the TCP data communication by sending a IEEE1344 or C37 118 command frame remotely from the client to the PMU cont...

Page 112: ...iable especially since commands are sent over TCP which performs request acknowledgment exchange to ensure that no data command in this case is lost However by setting the parameter SendCfgOnUDP x to...

Page 113: ...ostics on LHMI at Main menu Diagnostics Communication PMU diagnostics PMUSTATUS 1 Even if the parameter SendDataUDP x is set to Off it is still possible for the clients to connect on the TCP port and...

Page 114: ...gital report channels in BINARYREPORT1 3 and 4 trigger report channels in PMUREPORT function block Special rules shall be taken into account in PCM600 for Application Configuration and Parameter Setti...

Page 115: ...defined in IEEE C37 118 data frame format IEC140000120 2 en vsd IEC140000120 V2 EN Figure 41 Multiple instances of ANALOGREPORT blocks Figure 42 shows both instances of BINARYREPORT function blocks Th...

Page 116: ...plies with all the standard requirements with a specific attention to the Total Vector Error TVE requirement The TVE is calculated using the following equation 2 2 2 2 r r i i r i X n X X n X TVE X X...

Page 117: ...actory The calibration data is stored in the prepared area of the TRM EEProm The pre processor block is extended with calibration compensation and a new angle reference method based on timestamps The...

Page 118: ...ly the voltage phasor channels are used The phasor channel with a lower channel number is prioritized to the one with a higher channel number As a result the first voltage phasor is always the one del...

Page 119: ...e 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 fil...

Page 120: ...guration 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...

Page 121: ...nd 0 15 to 4915 5 Example 3 10000000000 AnalogXRange IECEQUATION2450 V1 EN The scale factor is calculated as follows 10000000000 2 0 305180 43 and 0 0 65535 5 scalefactor offset IECEQUATION2451 V1 EN...

Page 122: ...olation of rule 1 results in PMU applications not running at all The reason is the inconsistent cycle time For example in Figure 45 the SMAI block is updating its output every 3 ms while the PHASORREP...

Page 123: ...127 V2 EN Figure 47 An example of correct connection of SMAI and PHASORREPORT blocks in ACT Figure 48 shows an example of wrong connection of SMAI and PHASORREPORT blocks in ACT where the same SMAI bl...

Page 124: ...ck If 3PHSUM block is configured to use external DFT reference from SMAI reference block it shall only be connected to the same PHASORREPORT block instance as the one the SMAI reference block is conne...

Page 125: ...s in ACT IEC140000130 1 en vsd IEC140000130 V1 EN Figure 50 SMAI1 setting parameters example showing that SMAI3 is selected as the DFT reference DFTRefGrp3 1MRK 502 071 UEN Section 6 Wide area measure...

Page 126: ...locks in ACT If settingsfor PMUREPORTinstances PHASORREPORT1instances1and2above differ for SvcClass or ReportRate then the synchrophasor reported by PHASOR2 connection from PHASORREPORT1 instance 2 wi...

Page 127: ...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 Violat...

Page 128: ...allows uniquely identifying PMUs in a system that has more than 65535 PMUs The coding for the 16 bytes is left to the user for assignment PMUdataStreamIDCODE It refers to the 2 byte IDCODE field of t...

Page 129: ...ssage format Depends on the analog data type the size of ANALOG field can be 2 Integer or 4 Float bytes per IEEE C37 118 2 message More information is available under the section Scaling Factors for A...

Page 130: ...tag It refers to the method of time tagging used in the IED which is related to the phasor estimation and filtering technique The options are FirstSample MiddleSample and LastSample The time stamp of...

Page 131: ...lowing setting parameters where X is a number from 1 to 24 AnalogXRange This parameter defines a range between AnalogXRange and AnalogXRange for AnalogX value The range will be used by the IED to appl...

Page 132: ...126...

Page 133: ...ial 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 w...

Page 134: ...istics loads and operating conditions of the current transformers zero sequence currents that only flow on one side of the power transformer normal magnetizing currents magnetizing inrush currents ove...

Page 135: ...of information on the load tap changer position short circuit power of the systems and so on The second section of the restrain characteristic has an increased slope in order to deal with increased d...

Page 136: ...efault value of IdUnre 10pu which is typically acceptable for most of the standard power transformer applications In the following case this setting need to be changed accordingly For differential app...

Page 137: ...ined characteristic is defined by the settings 1 IdMin 2 EndSection1 3 EndSection2 4 SlopeSection2 5 SlopeSection3 7 1 3 2 Elimination of zero sequence currents A differential protection may operate u...

Page 138: ...se of heavy internal faults even if the current transformers are saturated Both these restraint methods are used by the IED The second harmonic restraint function has a settable level If the ratio of...

Page 139: ...are due to a fault On the other hand in order to guarantee a good sensitivity of the internal external fault discriminator the value of this minimum limit must not be too high Therefore this limit va...

Page 140: ...50 Hz system for all more severe internal faults Even for heavy internal faults with severely saturated current transformers this differential protection operates well below one cycle since the harmo...

Page 141: ...ghest no load voltage for that winding is obtained for example position with maximum number of turns Parameter StepSizeOLTC1 defines the voltage change per OLTC1 step for example 1 5 The above paramet...

Page 142: ...y OpenCTIN Open CT in CT group inputs 1 for input 1 and 2 for input 2 OpenCTPH Open CT with phase information 1 for phase L1 2 for phase L2 3 for phase L3 7 1 3 10 Switch onto fault feature The Transf...

Page 143: ...e reference windings However the IED can also be used in applications where some of the main CTs are connected in delta In such cases the ratio for the main CT connected in delta shall be intentionall...

Page 144: ...If star connected main CTs have their star point away from the protected transformer this parameter should be set FromObject For delta DAC connected main CTs secondary currents fed to the IED are incr...

Page 145: ...rential protection solutions will be presented First solution will be with all main CTs star connected Second solution will be with delta connected main CT on Y that is star connected sides of the pro...

Page 146: ...e HV currents are rotated by 30 in clockwise direction Thus the DAC delta CT connection must be used for 69 kV CTs in order to put 69 kV 12 5 kV currents in phase To ensure proper application of the I...

Page 147: ...of the Transformer differential protection function see table 17 Table 17 General settings of the differential protection function Setting parameter Select value for solution 1 star connected CT Sele...

Page 148: ...BY CT 1500 5 Star CT 400 5 Star 60 MVA 115 24 9 kV Dyn1 DABY en06000555 vsd IEC06000555 V1 EN Figure 56 Two differential protection solutions for delta star connected power transformer For this partic...

Page 149: ...for the LV side CTs CT input channels used for the LV side CTs Setting parameter Selected value for Solution 1 star connected CT Selected value for Solution 2 delta connected CT CTprim 1500 1500 866...

Page 150: ...transformer with load tap changer and tertiary not loaded delta winding Single line diagrams for two possible solutions for such type of power transformer with all relevant application data are given...

Page 151: ...ow they are star red that is earthed towards or away from the protected transformer 5 Enter the following settings for all three CT input channels used for the HV side CTs see table 20 Table 20 CT inp...

Page 152: ...ero sequence current is already removed by connecting main CTs in delta 7 1 4 4 Summary and conclusions The IED can be used for differential protection of three phase power transformers with main CTs...

Page 153: ...m Required delta CT connection type on star side of the protected power transformer and internal vector group setting in the IED YNd1 Y IEC06000559 V1 EN DAC Yy0 Dyn1 Y IEC06000560 V1 EN DAB Yy0 YNd11...

Page 154: ...actor differential protection Busbar differential protection Autotransformer differential protection for common and serial windings only T feeder differential protection Capacitor differential protect...

Page 155: ...3 Id 3 Id G 3 Id IEC05000163 4 en vsd IEC05000163 V4 EN 1MRK 502 071 UEN Section 7 Differential protection Generator protection REG670 2 2 IEC and Injection equipment REX060 REX061 REX062 149 Applica...

Page 156: ...ough 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 ca...

Page 157: ...ons are made with the worst situations in mind and a minimum operating voltage UR is calculated according to equation 21 max UR IF Rct Rl EQUATION1531 V1 EN Equation 21 where IFmax is the maximum thro...

Page 158: ...A 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 U Trip and SeriesResitor values The CT input...

Page 159: ...s must be checked after calculation of U Trip When the R value has been selected and the U Trip value has been set the sensitivity of the scheme IP can be calculated The IED sensitivity is decided by...

Page 160: ...00 W Preferable the U Trip2 SeriesResistor should always be lower than 200 W to allow continuous activation during testing If this value is exceeded testing should be done with a transient faults Sect...

Page 161: ...R Protected Object IEC05000427 2 en vsd IEC05000427 V2 EN Figure 60 The high impedance principle for one phase with two current transformer inputs 1MRK 502 071 UEN Section 7 Differential protection Ge...

Page 162: ...ase high impedance differential protection Typical CT connections for three phase high impedance differential protection scheme are shown in figure 61 L1 A L2 B L3 C Protected Object CT 1200 1 Star Wy...

Page 163: ...resistor set The star point 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 hi...

Page 164: ...bilizing resistor and metrosil Protective earth 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 t...

Page 165: ...hat 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 chosen such that both U Alarm SeriesResistor...

Page 166: ...vsd IEC05000739 V2 EN Figure 63 The protection scheme utilizing the high impedance function for the T feeder Section 7 1MRK 502 071 UEN Differential protection 160 Generator protection REG670 2 2 IEC...

Page 167: ...T Class 20 VA 5P20 Secondary resistance 6 2 ohms Cable loop resistance 100 m 2 5 mm2 one way gives 2 0 8 ohm at 75 C Max fault current Equal to switchgear rated fault current 40 kA Calculation EQUATIO...

Page 168: ...clearly be seen that the sensitivity is not so much influenced by the selected voltage level so a sufficient margin should be used The selection of the stabilizing resistor and the level of the magnet...

Page 169: ...imum 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 t...

Page 170: ...the table of selected resistances the required series stabilizing resistor value to use Since this application requires good sensitivity select SeriesResistor 300 ohm which gives an IED current of 100...

Page 171: ...IEC05000177 V2 EN Figure 65 Application of HZPDIF function as a restricted earth fault protection for a star connected winding of an YNd transformer Setting example It is strongly recommended to use t...

Page 172: ...tion 31 which is acceptable as it gives around 10 minimum operating current IP approx A 300 5 40 0 5 0 4 20 60 10 33 3 EQUATION1221 V2 EN Equation 31 The magnetizing current is taken from the magnetiz...

Page 173: ...vate an external shorting of the differential circuit avoiding continuous high voltage in the circuit A time delay of a few seconds is used before the shorting and alarm are activated Auxiliary relays...

Page 174: ...latively small fault current The fault current fed from the generator itself can also be limited due to low excitation of the generator This is normally the case at running up of the generator before...

Page 175: ...al 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 preproce...

Page 176: ...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 adj...

Page 177: ...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 curre...

Page 178: ...erential 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 IMinNegS...

Page 179: ...d 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 featur...

Page 180: ...ration 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 End...

Page 181: ...er transformer winding can be obtained in solidly earthed or low impedance earthed networks by the restricted earth fault protection The only requirement is that the power transformer winding is conne...

Page 182: ...transformer winding for all faults involving earth 7 4 2 1 Transformer winding solidly earthed The most common application is on a solidly earthed transformer winding The connection is shown in Figur...

Page 183: ...onnection for this application is shown in figure 73 REFPDIF 1 I3PW1CT1 I3P IdN I Protected winding W1 I3PW2CT1 I3P IdN I REFPDIF 2 Protected winding W2 Earthing transformer IEC09000110 4 EN vsd IEC09...

Page 184: ...transformer REFPDIF I3PW1CT1 I3P IdN I I3PW2CT1 HV W1 LV W2 IEC09000111 4 EN V2 EN Figure 74 Connection of restricted earth fault low impedance function REFPDIF for an autotransformer solidly earthed...

Page 185: ...orner arrangements have two sets of current transformers on the phase side The restricted earth fault protection low impedance function REFPDIF has inputs to allow two current inputs from each side of...

Page 186: ...ways 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 earthing can be freely selected...

Page 187: ...e function REFPDIF are set via the local HMI or PCM600 Common base IED values for primary current IBase primary voltage UBase and primary power SBase are set in a Global base values for settings funct...

Page 188: ...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 CTFactorSec1 See setting C...

Page 189: ...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 S...

Page 190: ...tings Full scheme distance measuring Mho characteristic ZMHPDIS used as an under impedance function shall be set for the application example shown in figure 78 Section 8 1MRK 502 071 UEN Impedance pro...

Page 191: ...8 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 Calculate the step...

Page 192: ...delay shall be entered accordingly Parameter ZPP shall be set to 0 260 Parameter ZrevPP shall be set to 0 260 Parameter tPP shall be set to 1 0000s Parameter ZAngPP shall be set to default value 85 D...

Page 193: ...ation description below only if VT and CT of the line feeder are wired to REG670 8 2 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device numb...

Page 194: ...hout any impedance between the transformer neutral and earth IEC05000215 V2 EN Figure 80 Solidly earthed network The earth fault current is as high or even higher than the short circuit current The se...

Page 195: ...st fundamental frequency voltage on one of the healthy phases at single phase to earth fault Upn is the phase to earth fundamental frequency voltage before fault Another definition for effectively ear...

Page 196: ...the healthy phases will get a magnitude of 3 times the phase voltage during the fault The zero sequence voltage 3U0 will have the same magnitude in different places in the network due to low voltage d...

Page 197: ...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 gu...

Page 198: ...impedance within the characteristic would cause an unwanted trip The traditional way of avoiding this situation is to set the distance zone resistive reach with a security margin to the minimum load...

Page 199: ...urce impedance see table 25 Table 25 Definition of short and very short line Line category Un Un 110 kV 500 kV Very short line 1 1 5 5 km 5 25 km Short line 5 5 11 km 25 50 km The IED s ability to set...

Page 200: ...pling General Introduction of parallel lines in the network is increasing due to difficulties to get necessary land to build new lines Parallel lines introduce an error in the measurement due to the m...

Page 201: ...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 line...

Page 202: ...e double circuit parallel operating line with a single phase to earth fault at the remote busbar When mutual coupling is introduced the voltage at the relay point A will be changed according to equati...

Page 203: ...L EQUATION1279 V3 EN Equation 45 Simplification of equation 45 solving it for 3I0p and substitution of the result into equation 44 gives that the voltage can be drawn as U p ZI I K I K I p p A L ph N...

Page 204: ...the equivalent zero sequence impedance is equal to Z0 Z0m in parallel with Z0 Z0m Z0 Z0m Z0m which is equal to equation 48 2 2 0 0 om E Z Z Z Z EQUATION2002 V4 EN Equation 48 The influence on the dist...

Page 205: ...s bar can be simplified to the circuit shown in figure 88 The line zero sequence mutual impedance does not influence the measurement of the distance protection in a faulty circuit This means that the...

Page 206: ...EN Equation 53 The real component of the KU factor is equal to equation 54 Re Re Re Im K A X A A u m 1 0 2 2 2 EQUATION1287 V3 EN Equation 54 The imaginary component of the same factor is equal to equ...

Page 207: ...Trf CT A C C TF 2 1 2 DOCUMENT11524 IMG3510 V3 EN Equation 57 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 sta...

Page 208: ...selectivity conflicts Careful fault calculations are necessary to determine suitable settings and selection of proper scheme communication Fault resistance The performance of distance protection for...

Page 209: ...2 Setting of zone 1 The different errors mentioned earlier usually require a limitation of the underreaching zone normally zone 1 to 75 90 of the protected line In case of parallel lines consider the...

Page 210: ...der all conditions The requirement that the zone 2 shall not reach more than 80 of the shortest adjacent line at remote end is highlighted in the example below If a fault occurs at point F see figure...

Page 211: ...ver influence of mutual impedance has to be taken into account Parallel line in service setting of zone 2 Overreaching zones in general zones 2 and 3 must overreach the protected circuit in all cases...

Page 212: ...es of the corresponding zone zero sequence resistance and reactance equal to R0E R0 1 Xm0 2 R0 2 X0 2 EQUATION561 V1 EN Equation 66 X0E X0 1 Xm0 2 R0 2 X0 2 EQUATION562 V1 EN Equation 67 8 2 3 6 Setti...

Page 213: ...t as much as is needed from a zone reach point of view As with the settings RLdFw and RLdRv 2 XLd is representing a per phase load impedance of a symmetrical star coupled representation For a symmetri...

Page 214: ...ld be considered To avoid load encroachment for the phase to earth measuring elements the set resistive reach of any distance protection zone must be less than 80 of the minimum load impedance 0 8 loa...

Page 215: ...RLdRv 4 or the lines defined by ArgLd So it is necessary to consider some margin It is recommended to set RLdFw and RLdRv to 90 of the per phase resistance that corresponds to maximum load min 0 9 lo...

Page 216: ...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...

Page 217: ...ectional 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...

Page 218: ...mponent 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 opti...

Page 219: ...opriate like in the case of simultaneous faults two earth faults at the same time one each on the two circuits of a double line One specific situation where the INReleasePE setting should be altered i...

Page 220: ...stem earthing The type of system earthing plays an important role when designing the protection system Some hints with respect to distance protection are highlighted below Solidly earthed networks In...

Page 221: ...ection function s that can carry out the fault clearance in those cases Effectively earthed networks A network is defined as effectively earthed if the earth fault factor fe is less than 1 4 The earth...

Page 222: ...a separate high sensitive earth fault protection is necessary to carry out the fault clearance for single phase to earth fault 8 3 2 2 Fault infeed from remote end All transmission and most sub trans...

Page 223: ...tion 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 faul...

Page 224: ...of short and very short line Line category Un Un 110 kV 500 kV Very short line 1 1 5 5 km 5 25 km Short line 5 5 11 km 25 50 km The IED s ability to set resistive and reactive reach independent for p...

Page 225: ...km 450 km Very long lines 99 km 450 km The IED s ability to set resistive and reactive reach independent for positive and zero sequence fault loops and individual fault resistance settings for phase...

Page 226: ...rhead lines This type of mutual coupling is not so common although it exists and is not treated any further in this manual For each type of network class there are three different topologies the paral...

Page 227: ...for normal lines without mutual coupling according to equation 41 Z U I I Z Z Z U I I K ph ph ph ph N 3 3 3 0 0 1 1 0 IECEQUATION1275 V2 EN Equation 87 Where Uph is phase to earth voltage at the relay...

Page 228: ...rement 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 comp...

Page 229: ...duce 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...

Page 230: ...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 re...

Page 231: ...ion zone is reduced if due to operating conditions the equivalent zero sequence impedance is set according to the conditions when the parallel system is out of operation and earthed at both ends A B C...

Page 232: ...Re Im m U A X K A A EQUATION1288 V2 EN Equation 101 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...

Page 233: ...ivided by the IED current For the IED at C the impedance on the high voltage side U1 has to be transferred to the measuring voltage level by the transformer ratio Another complication that might occur...

Page 234: ...rease loadability of transmission corridors The principle is based on compensation of distributed line reactanceby insertionof seriescapacitor SC Thegeneratedreactivepowerprovided by the capacitor is...

Page 235: ...ch is defined according to equation 105 The effect of series compensation is in this particular case obvious and self explanatory C C Line X K X EQUATION1895 V1 EN Equation 105 A typical 500 km long 5...

Page 236: ...from 20 to 70 percent Transmission capability increases of more than two times can be obtained in practice IEC06000592 2 en vsd 0 0 1 0 2 0 3 0 4 0 5 0 6 0 7 1 1 5 2 2 5 3 3 5 Degree of series compens...

Page 237: ...or included in circuit between the IED point and the fault position The fault current IF see figure 111 is increased due to the series capacitor generally decreases total impedance between the sources...

Page 238: ...ferent protections 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 prote...

Page 239: ...es 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...

Page 240: ...reasing 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 Dire...

Page 241: ...Distance IEDs are exposed especially to voltage inversion for close in reverse faults which decreases the security The effect of negative apparent reactance must be studied seriously in case of revers...

Page 242: ...sed on capacitor bank spark gap or MOV and SC location on protected power line en06000612 vsd EA 0 33 50 66 KC 80 33 33 50 Z 100 80 IEC06000612 V1 EN Figure 115 Typical locations of capacitor banks on...

Page 243: ...pensation 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...

Page 244: ...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 c...

Page 245: ...LF C 1 EQUATION1912 V2 EN Equation 114 0 1 LB C B LF A B X X U X I I EQUATION1913 V1 EN Equation 115 Equation 114 indicates the fact that the infeed current IA increases the apparent value of capaciti...

Page 246: ...the same time caused a lot of challenges to protection society especially when it comes to directional measurement and transient overreach Distance IED in fact does not measure impedance or quotient b...

Page 247: ...Zone 1 is often set to 1 11 12 Z S C X K X X X EQUATION1914 V1 EN Equation 116 Here KS is a safety factor presented graphically in figure 121 which covers for possible overreaching due to low frequenc...

Page 248: ...e of overreach which can be considered as a disadvantage from a security point of view en06000620 vsd X11 X12 jXC A B DA DB Permissive Zone A Permissive Zone B IEC06000620 V1 EN Figure 122 Permissive...

Page 249: ...ion must be delayed until the gap flashing has taken place If the delay is not acceptable some directional comparison must also be added to the protection of all adjacent power lines As stated above a...

Page 250: ...by the distance protection As soon as the spark gap has flashed the situation for protection will be as for an ordinary fault However a good protection system should be able to operate correctly befor...

Page 251: ...hase fault The condition for a negative current in case of an earth fault can be written as follows 1_ 1 0 _ 1 0 _ 1_ 3 2 2 C L L S S X X X X X EQUATION1920 V1 EN Equation 125 All designations relates...

Page 252: ...eration of distance protection for external evolving faults when one circuit has already been disconnected in one phase and runs non symmetrical during dead time of single pole autoreclosing cycle All...

Page 253: ...ies will be accentuated because the ratio of mutual impedance against self impedance will be much higher than for a non compensated line If non unit protection is to be used in a directional compariso...

Page 254: ...crease the reach of the overreaching zone to at least 120 of the protected line The zone 2 reach can be even higher if the fault infeed from adjacent lines at the remote end is considerably higher tha...

Page 255: ...r the telecommunication purposes Consider the possible enlarging factor that might exist due to fault infeed from adjacent lines The equation can be used to calculate the reach in reverse direction wh...

Page 256: ...e zone ZMFCPDIS characteristic in forward and reverse direction makes it possible to optimize the settings in order to maximize dependability and security for independent zone1 Due to the sub harmonic...

Page 257: ...st degree of compensation will occur at three phase fault and therefore the calculation need only to be performed for three phase faults The compensation degree in earth return path is different than...

Page 258: ...ne 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 For protecti...

Page 259: ...ieved by the communication scheme With the reduced reach of the under reaching zones not providing effective protection for all faults along the length of the line it becomes essential to provide over...

Page 260: ...ion Parallel line applications the zone reach can be set to 85 of the protected line However influence of mutual impedance has to be taken into account Parallel line in service setting of zone 2 Overr...

Page 261: ...1 Xm0 2 R0 2 X0 2 EQUATION561 V1 EN Equation 134 X0E X0 1 Xm0 2 R0 2 X0 2 EQUATION562 V1 EN Equation 135 8 3 4 7 Setting of reach in resistive direction Set the resistive reach R1 independently for e...

Page 262: ...t needed that is when the load is not encroaching on the distance zones Always define the load encroachment boundary according to the actual load or in consideration of how far the phase selection mus...

Page 263: ...n is applicable only when the loop characteristic angle for the single phase to earth faults is more than three times as large as the maximum expected load impedance angle For the case when the loop c...

Page 264: ...es defined by RLdFw and RLdRv 9 or the lines defined by ArgLd So it is necessary to consider some margin It is recommended to set RLdFw and RLdRv to 90 of the per phase resistance that corresponds to...

Page 265: ...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...

Page 266: ...direction out on the protected line IEC05000182 2 en vsdx R X R X R X Non directional Forward Reverse IEC05000182 V2 EN Figure 133 Directional operating modes of the distance measuring zones 3 to 5 t...

Page 267: ...rmer is fully magnetic INReleasePE This setting opens up an opportunity to enable phase to earth measurement for phase to phase earth faults It determines the level of residual current 3I0 above which...

Page 268: ...em cannot be maintained In such a case the generator loses the synchronism pole slip to the external power system The situation with pole slip of a generator can be caused by different reasons A short...

Page 269: ...the oscillations will increase until the angular stability is lost At the moment of pole slip there will be a centre of this pole slip which is equivalentwith distanceprotectionimpedancemeasurementof...

Page 270: ...he pole slip For this fault the under excitation protection and PSPPPAM function will give mutual redundancy The operation of a generator having pole slip will give risk of damages to the generator bl...

Page 271: ...delines GlobalBaseSel Selects the global base value group used by the function to define IBase UBase and SBase as applicable Operation With the parameter Operation the function can be set On or Off Me...

Page 272: ...XT and the equivalent impedance of the external system ZS The impedance is given in of the base impedance according to equation 150 3 Base UBase Z IBase EQUATION1883 V1 EN Equation 150 The ImpedanceZ...

Page 273: ...e 1 that is the node of the pole slip is within the generator transformer block The default value 1 is recommended to minimize the stress on the generator and turbine at out of step conditions N2Limit...

Page 274: ...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 50...

Page 275: ...160 j ZB j pu pu EQUATION1964 V1 EN Equation 155 Set ZB to 0 2 This corresponds to 2 20 0 0125 0 125 0 126 84 160 j ZC j pu pu EQUATION1966 V1 EN Equation 156 Set ZC to 0 13 and AnglePhi to 88 The war...

Page 276: ...e it is recommended to set this parameter to 90 to assure limited stress for the circuit breaker In a power system it is desirable to split the system into predefined parts in case of pole slip The pr...

Page 277: ...ork zone 2 ZC ZA ZB en07000017 vsd IEC07000017 V1 EN Figure 140 Generator application of pole slip protection If the apparent impedance crosses the impedance line ZB ZA this is the detected criterion...

Page 278: ...e forward direction ZB The generator transient reactance ZC The block transformer reactance AnglePhi The impedance phase angle Use the following generator data UBase 20 kV SBase set to 200 MVA Xd 25 U...

Page 279: ...A Z transf Zsc network j j j ohm EQUATION1970 V1 EN Equation 160 This corresponds to 0 38 0 19 0 19 90 2 0 j ZA j pu pu EQUATION1971 V1 EN Equation 161 Set ZA to 0 19 2 20 0 25 0 5 200 d ZB jX j j ohm...

Page 280: ...Zload R X en07000016 vsd IEC07000016 V1 EN Figure 142 Simplified figure to derive StartAngle 0 0 arctan arctan arctan arctan 7 1 5 4 0 25 0 19 13 2 2 ZB ZA angleStart Zload Zload EQUATION1977 V2 EN E...

Page 281: ...phase fault electrically close to the generator no active power can be delivered Almost all mechanical power from the turbine is under this condition used to accelerate the moving parts that is the ro...

Page 282: ...er 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 point...

Page 283: ...loses synchronism Generator operates in asynchronous mode at speeds nominal IEC10000108 2 en vsd IEC10000108 V2 EN Figure 144 Stable and unstable case For the fault clearing time tcl 200 ms the gener...

Page 284: ...se Uline 230 kV Xline km 0 4289 km Rline km 0 0659 km Unom 230 kV SC level 5000 MVA SC current 12 551 A 84 289 Ze 10 5801 1 st step in calculation ZBase 0 9522 generator Xd 0 2960 0 952 0 282 Rs 0 002...

Page 285: ...mer ZBase 0 6348 must be used when the power transformer reactance and resistance are transformed For the synchronous machines as the generator in Table 29 the transient reactance Xd shall be used Thi...

Page 286: ...terval specified by tReset since the previous one the function is reset All outputs are set to 0 FALSE If no pole slip at all is detected under interval of time specified by tReset since the start sig...

Page 287: ...a generator protection scheme InvertCTCurr If the currents fed to the Out of step protection are measured on the protected generator neutral side LV side then inversion is not necessary InvertCTCurr O...

Page 288: ...er system and Enet is an infinite voltage source representing the lumped sum of the generators in the system The active power out from the generator can be formulated according to equation 168 sin net...

Page 289: ...To prevent damages to the generator block the 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...

Page 290: ...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 Section 8 1MRK 502 071 UEN Impedance p...

Page 291: ...d 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...

Page 292: ...m is equivalent with a circle in the impedance plane LEXPDIS in the IED is realised by two impedance circles and a directional restraint possibility as shown in figure 150 Section 8 1MRK 502 071 UEN I...

Page 293: ...erator 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 f...

Page 294: ...the fast Z1 and slow Z2 zone The impedances are given in pu of the base impedance calculated according to equation 171 IBase UBase ZBase 3 EQUATION1776 V1 EN Equation 171 XoffsetZ1 and XoffsetZ2 offs...

Page 295: ...rSuperv The directional restrain characteristic allows impedance setting with positive X value without the risk of unwanted operation of the under excitation function To enable the directional restrai...

Page 296: ...0 identification IEC 60617 identification ANSI IEEE C37 2 device number Sensitive rotor earth fault protection injection based ROTIPHIZ Rre 64R 8 7 2 Application The sensitive rotor earth fault protec...

Page 297: ...ystem earth faults on the AC side of the excitation rectifier The measuring principle used is not influenced by the generator operating mode and is fully functional even with the generator at standsti...

Page 298: ...ue 113 Hz in 50 Hz systems and 137 Hz in 60 Hz systems Rseries is a resistance in the REX061 unit used to protect against overvoltage to the injection unit Such overvoltages can occur if the unit is f...

Page 299: ...nal 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...

Page 300: ...r ROTIPHIZ is installation dependent because harmonics in static excitation system large variation of the ambient temperature and variation of rotor capacitance and conductance to ground between stand...

Page 301: ...ter button or alternatively recover to the last stored gain by the Clear button Rotor gain factor for both voltage and current is dependent on the highest voltage that may occur at the injection point...

Page 302: ...V1 EN Figure 156 Separate analog inputs for stator STTIPHIZ and rotor ROTIPHIZ protection 2 It is possible to use a mixed connection that requires only two IED voltage channels for both ROTIPHIZ and...

Page 303: ...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 impo...

Page 304: ...0 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 t...

Page 305: ...64S 8 8 2 Application The 100 stator earth fault protection STTIPHIZ is used to detect the earth faults in the stator windings of generators and motors STTIPHIZ is applicable for generators connected...

Page 306: ...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...

Page 307: ...High resistance generator earthing 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 con...

Page 308: ...to limit the voltage to the injection equipment in case of earth 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 se...

Page 309: ...earthing 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 1MRK 502 071 UEN Section 8 Impedance protection Gene...

Page 310: ...e used for applications with various generator system earthing methods It is therefore recommended to make the injection via the open delta VT on the terminal side in most applications Accuracy for ST...

Page 311: ...volatile memory If value is outside range then the limited value will be stored Last stored settings are shown in display Table 32 Necessary settings for REX060 Setting Range System frequency 50 60 Hz...

Page 312: ...1 9 8 8 9 11 10 11 10 X81 STATOR MODULE SIM ROTOR MODULE RIM IED VOLTAGE MEASURE U VOLTAGE MEASURE U CURRENT MEASURE U CURRENT MEASURE U IEC11000209 1 en vsd IEC11000209 V1 EN Figure 163 Separate anal...

Page 313: ...peration to be set On 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 di...

Page 314: ...ce 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...

Page 315: ...nd 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 ste...

Page 316: ...nes for under impedance relay IEC11000308 3 en vsd Zone3 Zone1 REG670 A Power system model Zone2 Y Y D Y IEC11000308 V3 EN Figure 165 Zone characteristics and typical power system model Section 8 1MRK...

Page 317: ...rrents For this application the zone 1 element is typically set to see 75 of the transformer impedance 8 9 2 3 Zone 2 operation Zone 2 can be used to cover up to the HV side of the transformer and the...

Page 318: ...the phase distance relays on the transmission lines connected to the generating substation bus It is normally set to about 80 of the load impedance considering maximum short time overload on the gener...

Page 319: ...into mho characteristics during heavy load conditions Hence zone 2 and zone 3 are provided with load encroachment blinder feature which is to be enabled by the user This feature measures the impedanc...

Page 320: ...he common characteristic angle for all the three zone distance elements IMinOp The minimum operating current in IBase Zone 1 ZGVPDIS function has an offset mho characteristic and it can evaluate three...

Page 321: ...nce considering maximum short time over load of the generator Z3Rev Zone 3 reverse reach in percentage It is recommended to give limited reverse reach to ensure operation for close in faults and to mi...

Page 322: ...expmax is the maximum exporting active power Umin is the minimum voltage for which Pexpmax occurs 0 8 is the security factor to ensure that the setting of RLd can be lesser than the calculated minimal...

Page 323: ...t on the field winding will cause only a very small fault current Thus the earth fault does not produce any damage in the generator Furthermore it will not affect the operation of a generating unit in...

Page 324: ...318...

Page 325: ...d 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 pha...

Page 326: ...on to On Off OpMode This parameter can be set to 2 out of 3 or 1 out of 3 The setting controls the minimum number of phase currents that must be larger than the set operate current IP for operation No...

Page 327: ...000023 V1 EN Figure 169 Through fault current from B to A IfA The IED must not trip for any of the two through fault currents Hence the minimum theoretical current setting Imin will be Imin MAX IfA If...

Page 328: ...e protected line has to be considered One example is given in Figure 171 where the two lines are connected to the same busbars In this case the influence of the induced fault current from the faulty l...

Page 329: ...he minimum setting Is for the instantaneous phase overcurrent protection 3 phase output is then Is 1 3 Imin EQUATION83 V2 EN Equation 179 The protection function can be used for the specific applicati...

Page 330: ...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 mos...

Page 331: ...2nd harmonic restrain if the level of 2nd harmonic current reaches a value above a set percent of the fundamental current The phase overcurrent protection is often used as a protection for two and th...

Page 332: ...on shown in Figure 172 StartPhSel Number of phases with high current required for operation The setting possibilities are 1 out of 3 2 out of 3 and 3 out of 3 The default setting is 1 out of 3 IMinOpP...

Page 333: ...1 2 3 and 4 DirModex The directional mode of step x Possible settings are Off Non directional Forward Reverse Characteristx Selection of time characteristic for step x Definite time delay and differe...

Page 334: ...side Ix Max and Ix Min the closest of the limits to Ix is used by the function If Ix Max is smaller than Ix Min the limits are swapped tx Definite time delay for step x The definite time tx is added t...

Page 335: ...ly with the definition of the curve the setting parameter txMin shall be set to a value equal to the operating time of the selected inverse curve for twenty times the set current pickup value Note tha...

Page 336: ...x These parameters are used by the customer to create the inverse reset time characteristic curve For more information refer to Technical manual HarmRestrainx Enables the block of step x from the harm...

Page 337: ...t cases the setting values are updated once every five years or less often Investigate the maximum load current that the equipment on the line can withstand Study components such as line conductors cu...

Page 338: ...ent The lowest current setting of the fastest stage can be written according to max 1 2 t sc high I k I EQUATION1265 V1 EN Equation 185 where 1 2 is a safety factor kt is a factor that takes care of t...

Page 339: ...me 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...

Page 340: ...nt 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 t...

Page 341: ...e by the object impedance an instantaneous earth fault protection can provide fast and selective tripping The Instantaneous residual overcurrent EFPIOC which can operate in 15 ms 50 Hz nominal system...

Page 342: ...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 Z...

Page 343: ...A B I M Fault IED ZL2 M C Line 1 Line 2 IEC09000025 V1 EN Figure 179 Two parallel lines Influence from parallel line to the through fault current IM The minimum theoretical current setting Imin will...

Page 344: ...Min the limits are swapped StValMult The set operate current can be changed by activation of the binary input ENMULT to the set factor StValMult 9 4 Directional residual overcurrent protection four s...

Page 345: ...teleprotection communication schemes which enables fast clearance of earth faults on transmission lines The directional function uses the polarizing quantity as decided by setting Voltage polarizing...

Page 346: ...rts of the cycle There is a risk that inrush current will give a residual current that reaches level above the operating current of the residual overcurrent protection The inrush current has a large s...

Page 347: ...Common settings for all steps AngleRCA Relay characteristic angle given in degree This angle is defined as shown in Figure 180 The angle is defined positive when the residual current lags the referenc...

Page 348: ...is not greater than 3U0 If so there is a risk for incorrect operation for faults in the reverse direction IPolMin is the minimum earth fault current accepted for directional evaluation For smaller cur...

Page 349: ...sformer Therefore we will have high 2nd harmonic current initially After a short period this current will however be small and the normal 2nd harmonic blocking will reset en05000136 vsd Power System I...

Page 350: ...nder Time SOTF Under Time ActivationSOTF This setting will select the signal to activate SOTF function CB position open CB position closed CB close command StepForSOTF If this parameter is set on step...

Page 351: ...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 t...

Page 352: ...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 technica...

Page 353: ...mpedance An example of this application is shown in Figure 183 IN alt Three phase CT summated Single CT YN D or YN Y transformer en05000490 vsd IEC05000490 V1 EN Figure 183 Residual overcurrent protec...

Page 354: ...pplication is as shown in Figure 184 IN Three phase CT summated Y Y Y D or D Y transformer en05000491 vsd IEC05000491 V1 EN Figure 184 Residual overcurrent protection application on an isolated transf...

Page 355: ...riate 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...

Page 356: ...sformer winding close to the neutral point values down to the minimum setting possibilities can be chosen However one must consider zero sequence currents that can occur during normal operation of the...

Page 357: ...rance the directional function can be necessary This can be the case for unsymmetrical fault protection in meshed and effectively earthed transmission systems The directional negative sequence overcur...

Page 358: ...om a binary input signal ENMULTx to the function 9 5 3 Setting guidelines The parameters for Four step negative sequence overcurrent protection NS4PTOC are set via the local HMI or Protection and Cont...

Page 359: ...l Inverse IEC Very Inverse IEC Inverse IEC Extremely Inverse IEC Short Time Inverse IEC Long Time Inverse IEC Definite Time User Programmable ASEA RI RXIDG logarithmic The different characteristics ar...

Page 360: ...ep can never be shorter than the setting IMinx Operate time Current tx txMin IEC10000058 IEC10000058 V2 EN Figure 187 Minimum operate current and operation time for inverse time characteristics ResetT...

Page 361: ...Crvx Parameters for programmable inverse time characteristic curve The time characteristic equation is according to equation 192 p A t s B k i C in EQUATION1189 V1 EN Equation 194 Further description...

Page 362: ...residual current level for directional comparison scheme The setting is given in of IBase The start forward or start reverse signals can be used in a communication scheme The appropriate signal must b...

Page 363: ...acteristic 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 r...

Page 364: ...functionality uses true 3I0 i e sum of GRPxL1 GRPxL2 and GRPxL3 For 3I0 to be calculated connection is needed to all three phase inputs Directional and power functionality uses IN and UN If a connect...

Page 365: ...the fault point can be calculated as phase j 0 0 f 3 U I 3I Z 3 R EQUATION1944 V1 EN Equation 196 The impedance Z0 is dependent on the system earthing In an isolated system without neutral point appar...

Page 366: ...uation 199 Where Xn is the reactance of the Petersen coil If the Petersen coil is well tuned we have 3Xn Xc In this case the impedance Z0 will be Z0 3Rn Now consider a system with an earthing via a re...

Page 367: ...Uphase is the phase voltage in the fault point before the fault Z1 is the total positive sequence impedance to the fault point Z1 Zsc ZT 1 ZlineAB 1 ZlineBC 1 Z0 is the total zero sequence impedance t...

Page 368: ...e delay The inverse time delay is defined as 0 0 inv 0 0 kSN 3I 3U cos reference t 3I 3U cos measured j j EQUATION1942 V2 EN Equation 207 The function can be set On Off with the setting of Operation C...

Page 369: ...shown in Figure 192 IEC06000649_3_en vsd ref U 90 90 RCADir ROADir 0 3I 0 3 I cos 0 3 ref ang I ang U 0 3U IEC06000649 V3 EN Figure 192 Characteristic for RCADir equal to 90 When OpMode is set to 3U0...

Page 370: ...residual current protection tReset is the time delay before the definite timer gets reset given in s With a tReset time of few cycles there is an increased possibility to clear intermittent earth faul...

Page 371: ...r is chosen the delay time is dependent on two setting parameters SRef is the reference residual power given in of SBase kSN is the time multiplier The time delay will follow the following expression...

Page 372: ...rs for customer creation of inverse time characteristic curve Curve type 17 The time characteristic equation is p A t s B InMult i C in EQUATION1958 V1 EN Equation 209 tINNonDir is the definite time d...

Page 373: ...e load level of a power transformer is highly dependent on the cooling system of the transformer There are two main principles OA The air is naturally circulated to the coolers without fans and the oi...

Page 374: ...give a setting corresponding to the rated current of the transformer winding IRefMult If a binary input ENMULT is activated the reference current value can be multiplied by the factor IRefMult The ac...

Page 375: ...assumed that the forced cooling is activated while it is deactivated at low current The setting of the parameters below enables automatic adjustment of the time constant Tau1High Multiplication facto...

Page 376: ...mperature can be higher than the ambient temperature The start point given in the setting will prevent risk of no trip at overtemperature during the first moments after activation ThetaInit is set in...

Page 377: ...s parameter can be set Current or Contact This states the way the detection of failure of the breaker is performed In the mode current the current measurement is used for the detection In the mode Con...

Page 378: ...act operation means back up trip is done when circuit breaker is closed breaker position is used IP Current level for detection of breaker failure set in of IBase This parameter should be set so that...

Page 379: ...the maximum opening time for the circuit breaker tBFP_reset is the maximum time for breaker failure protection to detect correct breaker function the current criteria reset tmargin is a safety margin...

Page 380: ...e Trip pulse duration This setting must be larger than the critical impulse time of circuit breakers to be tripped from the breaker failure protection Typical setting is 200 ms 9 9 Pole discordance pr...

Page 381: ...om CB is chosen the logic to detect pole discordance is made in the vicinity to the breaker auxiliary contacts and only one signal is connected to the pole discordance function If the Pole pos aux con...

Page 382: ...Steam turbines easily become overheated if the steam flow becomes too low or if the steam ceases to flow through the turbine Therefore turbo generators should have reverse power protection There are s...

Page 383: ...s 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 h...

Page 384: ...he power measurement The setting possibilities are shown in table 41 Table 41 Complex power calculation Set value Mode Formula used for complex power calculation L1 L2 L3 1 1 2 2 3 3 L L L L L L S U I...

Page 385: ...ection defined by the setting Angle1 2 is smaller than the set pick up power value Power1 2 Operate Angle1 2 Power1 2 P Q en06000441 vsd IEC06000441 V1 EN Figure 196 Underpower mode The setting Power1...

Page 386: ...ow forward power the set angle should be 0 in the underpower function TripDelay1 2 is set in seconds to give the time delay for trip of the stage after pick up Hysteresis1 2 is given in p u of generat...

Page 387: ...omp100 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 avail...

Page 388: ...n would cause an acceleration of the turbine generator at all routine shutdowns This should have caused overspeed and high centrifugal stresses When the steam ceases to flow through a turbine the cool...

Page 389: ...verse power during commissioning Gas turbines usually do not require reverse power protection Figure 198 illustrates the reverse power protection with underpower IED and with overpower IED The underpo...

Page 390: ...2 3 L L L L S U I I EQUATION1701 V1 EN Equation 230 L3L1 3 1 3 1 L L L L S U I I EQUATION1702 V1 EN Equation 231 L1 1 1 3 L L S U I EQUATION1703 V1 EN Equation 232 L2 2 2 3 L L S U I EQUATION1704 V1...

Page 391: ...etering class CT inputs into the IED are used 3 N S UBase IBase EQUATION1708 V1 EN Equation 235 The setting Angle1 2 gives the characteristic angle giving maximum sensitivity of the power protection f...

Page 392: ...power will be Power1 2 Hysteresis1 2 The possibility to have low pass filtering of the measured power can be made as shown in the formula 1 Old Calculated S k S k S EQUATION1893 V1 EN Equation 237 Wh...

Page 393: ...ation ANSI IEEE C37 2 device number Negative sequence time overcurrent protection for machines NS2PTOC 2I2 46I2 9 12 2 Application Negative sequence overcurrent protection for machines NS2PTOC is inte...

Page 394: ...es are available Two steps independently adjustable with separate tripping outputs Sensitive protection capable of detecting and tripping for negative sequence currents down to 3 of rated generator cu...

Page 395: ...unbalanced fault capability expressed in terms of rotor heating criterion 2 2 I t K is shown below in Table 43 Table 43 ANSI requirements for unbalanced faults on synchronous machines Types of Synchr...

Page 396: ...in the table above that the continuous negative sequence current capability of the generator is in range of 5 to 10 of the rated generator current During an open conductor or open generator breaker po...

Page 397: ...lected by setting CurveType1 as follows CurveType1 Definite CurveType1 Inverse Definite time delay 1 is independent of the magnitude of the negative sequence current once the start value is exceeded w...

Page 398: ...a range of 3 to 500 of rated generator current IBase The wide range of start setting is required in order to be able to protect generators of different types and sizes After start a certain hysteresis...

Page 399: ...in a few seconds Accidental energizing protection for synchronous generator AEGPVOC monitors maximum phase current and maximum phase to phase voltage of the generator In its basis it is voltage superv...

Page 400: ...The time delay shall be longer than the longest fault time at short circuits or phase earth faults in the network The default value 5s is recommended DisarmU Voltage level given in of UBase for deact...

Page 401: ...OC function module has two independent protection each consisting of One overcurrent step with the following built in features Selectable definite time delay or Inverse Time IDMT characteristic Voltag...

Page 402: ...current may drop below the generator rated current after 0 5 1 s Also for generators with an excitation system not fed from the generator terminals a fault can occur when the automatic voltage regulat...

Page 403: ...f the rated voltage of the generator tDef_UV Definite time delay Since it is related to a backup protection function a long time delay for example 0 5 s or more is typically used Note that the value s...

Page 404: ...phase voltage and the rated phase current of the generator 3 Connect three phase generator currents and voltages to VRPVOC in the application configuration 4 Select Characterist to match the type of...

Page 405: ...he undervoltage stage shall be set in the following way 1 Set Operation to On 2 Set GlobalBaseSel to the right value in order to select the Global Base Values Group with UBase and IBase equal to the r...

Page 406: ...teristics and the time varying nature of current experienced during starting and when the generator drives a time varying load The generator stator overload function GSPTTR protects stator windings ag...

Page 407: ...as shown in Figure 204 100MVA 380 18kV YNd5 G 100MVA 18kV 3210A 500kVA 18 0 4kV Dy5 100 1 1000 5 Field rating 810A 260V DC 320MVA 242 11kV YNd5 G 315MVA 11kV 16533A 1400kVA 11 0 55kV Yd11 100 5 1500 5...

Page 408: ...rder to measure directly rotor winding DC current IBase 1520 Rated current of the field winding i e field current required to produce rated output from the stator CT_Location HV_winding HV side 100 5...

Page 409: ...nual control symmetrical voltage decrease Overload symmetrical voltage decrease Short circuits often as phase to earth faults unsymmetrical voltage decrease UV2PTUV is used in combination with overcur...

Page 410: ...1 3 1 Equipment protection such as for motors and generators The setting must be below the lowest occurring normal voltage and above the lowest acceptable voltage for the equipment 10 1 3 2 Disconnec...

Page 411: ...is sufficient that one phase voltage is low to give operation If UV2PTUV shall be insensitive for single phase to earth faults 2 out of 3 can be chosen In subtransmission and transmission networks th...

Page 412: ...n can be used to prevent function when the protected object is switched off If the parameter is set Block of trip or Block all unwanted trip is prevented IntBlkStValn Voltage level under which the blo...

Page 413: ...rong settings under manual control symmetrical voltage decrease 3 Low load compared to the reactive power generation symmetrical voltage decrease 4 Earth faults in high impedance earthed systems cause...

Page 414: ...w the highest acceptable voltage due to regulation good practice or other agreements 10 2 3 4 High impedance earthed systems In high impedance earthed systems earth faults cause a voltage increase in...

Page 415: ...an be chosen because the voltage will normally rise in the non faulted phases at single phase to earth faults In subtransmission and transmission networks the UV function is mainly a system supervisio...

Page 416: ...0 CrvSatn 100 If the programmable curve is used this parameter must be calculated so that 0 100 CrvSatn B C EQUATION1448 V1 EN Equation 243 HystAbsn Absolute hysteresis set in of UBase The setting of...

Page 417: ...t to the primary nominal voltage phase phase level of the power system or the high voltage equipment under consideration The time delay for ROV2PTOV is seldom critical since residual voltage is relate...

Page 418: ...to earth voltage transformers connected on the generator HV terminal side These three connection options are shown in Figure 205 Depending on start setting and fault resistance such function can typic...

Page 419: ...71 2 en vsd IED IEC10000171 V2 EN Figure 205 Voltage based stator earth fault protection ROV2PTOV application 1 ROV2PTOV is here connected to a voltage or distribution transformer located at generator...

Page 420: ...5 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 respectiv...

Page 421: ...d below the highest acceptable residual voltage due to regulation good practice or other agreements 10 3 3 5 High impedance earthed systems In high impedance earthed systems earth faults cause a neutr...

Page 422: ...t phase The other healthy phase will still have normal phase to earth voltage The residual sum will have the same value as the remaining phase to earth voltage which is shown in Figure 207 UL1 IEC0700...

Page 423: ...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 ti...

Page 424: ...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...

Page 425: ...d 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...

Page 426: ...level therefore OEXPVPH must have thermal memory A fixed cooling time constant is settable within a wide range The general experience is that the overexcitation characteristics for a number of power t...

Page 427: ...n take a long time to reset Activation of the RESET input will reset the function instantaneously Recommendations for Output signals Please see the default factory configuration for examples of config...

Page 428: ...is around 110 180 depending of the capability curve of the transformer generator Setting should be above the knee point when the characteristic starts to be straight on the high side XLeak The transf...

Page 429: ...capability diagram as shown in figure 209 The settings V Hz and V Hz are made in per unit of the rated voltage of the transformer winding at rated frequency Set the transformer adapted curve for a tra...

Page 430: ...130 140 150 100 0 05 0 1 0 2 0 5 10 20 100 V Hz Continous Time minutes t6 t5 t4 t3 t2 t1 transformer capability curve relay operate characteristic en01000377 vsd IEC01000377 V1 EN Figure 209 Example o...

Page 431: ...itor bank phase by phase Difference indicates a fault either short circuited or open element in the capacitor bank It is mainly used on elements with external fuses but can also be used on elements wi...

Page 432: ...arm is given instead of a Undervoltage or Differential voltage alarm and or tripping Fuse failure supervision SDDRFUF function for voltage transformers In many application the voltages of two fuse gro...

Page 433: ...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...

Page 434: ...e undervoltage level for the first voltage input is decided by this parameter The proposed default setting is 70 U2Low The setting of the undervoltage level for the second voltage input is decided by...

Page 435: ...t 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 earth that is earth...

Page 436: ...earthing 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...

Page 437: ...enerator unit transformer IEC06000318 2 en vsd U0 IEC06000318 V2 EN Figure 214 Neutral point voltage transformer measurement of neutral point voltage that is U0 voltage In some applications the neutra...

Page 438: ...arth fault can be made by current measurement as shown in figure 216 Generator unit transformer IEC06000320 3 en vsd IN IL1 IL2 IL3 Other generator IEC06000320 V3 EN Figure 216 Residual current measur...

Page 439: ...ts 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 based protection cannot be used In this protection fun...

Page 440: ...sensitivity for earth fault near to the neutral point of the stator winding One possibility to assure best performance is to make measurements during normal operation of the generator The protective...

Page 441: ...tion is blocked The setting is given as of the rated phase to earth voltage The setting is typically 1 t3rdH t3rdH gives the trip delay of the 3rd harmonic stator earth fault protection The setting is...

Page 442: ...436...

Page 443: ...ors are automatically switched in due to low frequency in order to reduce the power system voltage and hence also reduce the voltage dependent part of the load SAPTUF is very sensitive and accurate an...

Page 444: ...he number of levels and the distance between two levels in time and or in frequency depends very much on the characteristics of the power system under consideration The size of the largest loss of pro...

Page 445: ...dding generation in over production situations The overfrequency start value is set in Hz All voltage magnitude related settings are made as a percentage of a settable global base voltage parameter UB...

Page 446: ...arge negative rate of change of frequency the underfrequency protection can be used at a rather high setting 11 3 3 Setting guidelines The parameters for Rate of change frequency protection SAPFRC are...

Page 447: ...isolated from a large system For more normal severe disturbances in large power systems rate of change of frequency is much less most often just a fraction of 1 0 Hz s 11 4 Frequency time accumulatio...

Page 448: ...s 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 re...

Page 449: ...IEC 60034 3 1996 requirement 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...

Page 450: ...ove 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 requ...

Page 451: ...r 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 deviatio...

Page 452: ...ite 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 i...

Page 453: ...IL1 IL2 11 phase2 phase3 CVGAPC function will measure the current phasor internally calculated as the vector difference between the phase L2 current phasor and phase L3 current phasor IL2 IL3 12 phase...

Page 454: ...erence between the phase L2 voltage phasor and phase L3 voltage phasor UL2 UL3 12 phase3 phase1 CVGAPC function will measure the voltage phasor internally calculated as the vector difference between t...

Page 455: ...racteristic Underimpedance protection circular mho characteristic Voltage Controlled Restrained Overcurrent protection Phase or Negative Positive Zero Sequence Non Directional or Directional Overcurre...

Page 456: ...or may be thermally damaged from excessive high currents the time to damage will be on the order of a few seconds Of more critical concern however is the bearing which can be damaged in a fraction of...

Page 457: ...all be noted that directional negative sequence OC element offers protection against all unbalance faults phase to phase faults as well Care shall be taken that the minimum pickup of such protection f...

Page 458: ...on if communication channels to the remote end of this power line are available In that case typically two NegSeq overcurrent steps are required One for forward and one for reverse direction As explai...

Page 459: ...overcurrent IED k is the generator capability constant in seconds INS is the measured negative sequence current Ir is the generator rated current By defining parameter x equal to maximum continuous ne...

Page 460: ...bility value 2 set A_OC1 equal to the value 1 x2 3 set B_OC1 0 0 C_OC1 0 0 and P_OC1 2 0 4 set StartCurr_OC1 equal to the value x then the OC1 step of the CVGAPC function can be used for generator neg...

Page 461: ...r overload IED k is the generator capability constant in accordance with the relevant standard k 37 5 for the IEC standard or k 41 4 for the ANSI standard Im is the magnitude of the measured current I...

Page 462: ...p in it is obvious that if the following rules are followed 1 set k equal to the IEC or ANSI standard generator capability value 2 set parameter A_OC1 equal to the value 1 x2 3 set parameter C_OC1 equ...

Page 463: ...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...

Page 464: ...t 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...

Page 465: ...et parameter LowVolt_VM to value 5 9 Enable one overcurrent step for example OC1 10 Select parameter CurveType_OC1 to value IEC Def Time 11 Set parameter StartCurr_OC1 to value 38 12 Set parameter tDe...

Page 466: ...ectedifthegeneratorisconnectedtoastrong 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 simila...

Page 467: ...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 funct...

Page 468: ...1 The setting is made in of IBase The setting should be made so that the protection picks up at all situations when the generator is switched on to the grid at stand still situations The generator cur...

Page 469: ...time delay of OV1 should be instantaneous and this is set in the parameter ResCrvType_OV1 where Instantaneous chosen tDef_OV1 The time delay is set in the parameter tDef_OV1 and is set so that the ina...

Page 470: ...inadvertent energizing function is activated after some time when the generator is disconnected from the grid 10 0 s is recommended tResetDef_UV1 The reset time of UV1 is set by the parameter tResetDe...

Page 471: ...y the phasor values at set frequency defined by the setting parameter SetFrequency are calculated The following values are internally available for each of the calculated phasors Magnitude Phase angle...

Page 472: ...pical configuration connections required to utilize this filter in conjunction with multi purpose function as non directional overcurrent protection IEC13000179 1 en vsd IEC13000179 V1 EN Figure 221 R...

Page 473: ...In order to properly extract the weak subsynchronous signal in presence of the dominating 50Hz signal the SMAI HPAC filter shall be set as given in the following table Table 50 Proposed settings for...

Page 474: ...en exact replica of the existing relay will be achieved The following table summarizes all required settings for the multi purpose function Setting Group1 Operation On CurrentInput MaxPh IBase 1000 Vo...

Page 475: ..._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 UEN Section 13 System protection and control G...

Page 476: ...470...

Page 477: ...tion 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 t...

Page 478: ...rgizing check function and voltage check for the weak infeed logic These functions can operate unintentionally if a fault occurs in the secondary circuits between the voltage instrument transformers a...

Page 479: ...ay special attention to the dissymmetry of the measuring quantities when the function is used on long untransposed lines on multicircuit lines and so on The settings of negative sequence zero sequence...

Page 480: ...ce algorithms are activated and the one that has the highest magnitude of measured negative or zero sequence current will operate If there is a requirement to increase the security of the fuse failure...

Page 481: ...s the base voltage for the function according to the setting GlobalBaseSel The setting of the current limit 3I0 is done in percentage of IBase The setting of 3I0 must be higher than the normal unbalan...

Page 482: ...threshold IPh shall be set lower than the IMinOp for the distance protection function A 5 10 lower value is recommended 14 2 3 6 Dead line detection The condition for operation of the dead line detec...

Page 483: ...es or faults in voltage measurement circuit based on comparison of the voltages of the main and pilot fused circuits phase wise VDSPVC output can be configured to block voltage dependent protection fu...

Page 484: ...ge measurement circuit since the voltage on both sides are equal in the healthy condition If USetPrim is the desired pick up primary phase to phase voltage of measured fuse group the setting of Ud Mai...

Page 485: ...circuit and the synchrocheck function is used The synchronizing function measures the difference between the U Line and the U Bus It operates and enables a closing command to the circuit breaker when...

Page 486: ...station a narrower limit for the CloseAngleMax needs to be used Table 51 Dependencies between tBreaker and SlipFrequency with different CloseAngleMax values tBreaker s max settable value with CloseAn...

Page 487: ...aker and compares them to set limits Output is generated only when all measured conditions are within their set limits simultaneously The check consists of Live line and live bus Voltage level differe...

Page 488: ...s UHighLineSC 50 120 of GblBaseSelLine UDiffSC 0 02 0 50 p u PhaseDiffM 5 90 degrees PhaseDiffA 5 90 degrees FreqDiffM 3 1000 mHz FreqDiffA 3 1000 mHz Fuse fail Fuse fail Line voltage Line reference v...

Page 489: ...tive 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 circ...

Page 490: ...ction is then used and connected to the fuse supervision inputs of the SESRSYN function block In case of a fuse failure the SESRSYN energizing function is blocked The UB1OK UB2OK and UB1FF UB2FF input...

Page 491: ...fferent arrangements are connected to the IED analogue inputs and to the function block SESRSYN One function block is used per circuit breaker The input used below in example are typical and can be ch...

Page 492: ...usbar VT is connected to U3PBB1 and the voltage from the line VT is connected to U3PLN1 The conditions of the VT fuses shall also be connected as shown above The voltage selection parameter CBConfig i...

Page 493: ...U3PBB1 U3PBB2 U3PLN1 U3PLN2 B1QOPEN B1QCLD B2QOPEN B2QCLD UB1OK UB1FF UB2OK UB2FF ULN1OK ULN1FF WA1_VT WA2_VT LINE_VT QB1 QB2 WA1_MCB WA2_MCB LINE_MCB IEC10000095 V4 EN Figure 229 Connection of the S...

Page 494: ...rom the line VT is connected to U3PLN1 on both function blocks The condition of VT fuses shall also be connected as shown in figure 229 The voltage selection parameter CBConfig is set to No voltage se...

Page 495: ...LN1 QOPEN LN1 QCLD LN2 QOPEN LN2 QCLD UB1OK UB1FF UB2OK UB2FF ULN1OK ULN1FF ULN2OK ULN2FF U3PLN2 U3PLN1 U3PBB2 WA1_VT WA2_VT LINE1_VT LINE2_VT WA1_QA1 TIE_QA1 LINE1_QB9 LINE2_QB9 WA1_MCB WA2_MCB LINE...

Page 496: ...1 breaker and belonging disconnectors B2QOPEN CLD Position of WA2_QA1 breaker and belonging disconnectors LN1QOPEN CLD Position of LINE1_QB9 disconnector LN2QOPEN CLD Position of LINE2_QB9 disconnecto...

Page 497: ...d into four different setting groups General Synchronizing Synchrocheck and Energizingcheck General settings Operation The operation mode can be set On or Off The setting Off disables the whole functi...

Page 498: ...HighLineSynch The voltage level settings shall be chosen in relation to the bus line network voltage The threshold voltages UHighBusSynch and UHighLineSynch have to be set lower than the value where t...

Page 499: ...or the circuit breaker and should also include the possible auxiliary relays in the closing circuit It is important to check that no slow logic components are used in the configuration of the IED as t...

Page 500: ...autoreclosing a bigger frequency difference setting is preferable where the FreqDiffA setting is used A typical value for FreqDiffM can be10 mHz and a typical value for FreqDiffA can be 100 200 mHz Ph...

Page 501: ...and UHighLineEnerg The voltage level settings must be chosen in relation to the bus or line network voltage The threshold voltages UHighBusEnerg and UHighLineEnerg have to be set lower than the value...

Page 502: ...The apparatus control is a functionality for control and supervising of circuit breakers disconnectors and earthing switches within a bay Permission to operate is given after evaluation of conditions...

Page 503: ...on Selection and supervision of operator place Command supervision Block deblock of operation Block deblock of updating of position indications Substitution of position indications Overriding of inter...

Page 504: ...ical 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 d...

Page 505: ...BR and XSWI located in a breaker IED Control operation can be performed from the local IED HMI If users are defined in the IED then the local remote switch is under authority control otherwise the def...

Page 506: ...ces All operator places are allowed to operate According to IEC 61850 standard the orCat attribute in originator category are defined in Table 53 Table 53 orCat attribute according to IE C61850 Value...

Page 507: ...different apparatuses within the bay There are two different blocking alternatives Blocking of update of positions Blocking of commands IEC13000016 2 en vsd IEC13000016 V2 EN Figure 235 APC Local remo...

Page 508: ...switching device SXCBR or SXSWI The switch controller represents the content of the SCSWI logical node according to IEC 61850 with mandatory functionality 15 2 1 3 Switches SXCBR SXSWI Switches are fu...

Page 509: ...ed by a SXCBR or SXSWI function The command response functionality is dependent on the connection of the execution information XIN from the SCSWI function controlling the represented switch Otherwise...

Page 510: ...ion with XLNPROXY and GOOSEXLNRCV where all the IEC 61850 modelled data is used including selection Section 15 1MRK 502 071 UEN Control 504 Generator protection REG670 2 2 IEC and Injection equipment...

Page 511: ...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 s...

Page 512: ...interpretation for the command following is controlled through the setting SwitchType 15 2 1 5 Reservation function QCRSV and RESIN The purpose of the reservation function is primarily to transfer int...

Page 513: ...eservation 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 receive...

Page 514: ...but instead have a higher availability since no acknowledgment is required SCSWI SELECTED RES_EXT IED IED OR Other SCWI in the bay Station bus SPGAPC IN RESGRANT IntlReceive RESGRANT IntlReceive IEC0...

Page 515: ...BR The Autorecloser SMBRREC consists of the facilities to automatically close a tripped breaker with respect to a number of configurable conditions The logical node Interlocking SCILO provides the inf...

Page 516: ...ose 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 pr...

Page 517: ...enhanced security there is an additional supervision of the status value by the control object which means that each command sequence must be terminated by a termination command The parameter PosDepe...

Page 518: ...r the apparatus to start moving after a command execution is done from the SCSWI function When the time has expired the command supervision is reset and a cause code is given During the tIntermediate...

Page 519: ...a cause code is given The indication of the mid position at SCSWI is suppressed during this time period when the position changes from open to close or vice versa if the parameter SuppressMidPos is s...

Page 520: ...ctive coupling there may be some voltage for example 40 of rated voltage before earthing and some current for example 100A after earthing of a line Circuit breakers are usually not interlocked Closing...

Page 521: ...wn double indication state 15 3 1 Configuration guidelines The following sections describe how the interlocking for a certain switchgear configuration can be realized in the IED by using standard inte...

Page 522: ...switch status of disconnectors on bypass busbar WA7 are valid EXDU_BPB No transmission error from any bay containing disconnectors on bypass busbar WA7 These signals from each line bay ABC_LINE except...

Page 523: ...vsd IEC04000479 V1 EN Figure 244 Busbars divided by bus section disconnectors circuit breakers To derive the signals Signal BC_12_CL A bus coupler connection exists between busbar WA1 and WA2 BC_17_O...

Page 524: ...for both bus section disconnector A1A2_DC and B1B2_DC Signal DCOPTR The bus section disconnector is open DCCLTR The bus section disconnector is closed VPDCTR The switch status of bus section disconne...

Page 525: ..._CL VP_BC_12 BC_17_OP BC_17_CL VP_BC_17 BC_27_OP BC_27_CL VP_BC_27 EXDU_BC en04000480 vsd IEC04000480 V1 EN Figure 245 Signals to a line bay in section 1 from the bus coupler bays in each section For...

Page 526: ...no QB2 disconnector then the interlocking for QB2 is not used The state for QB2 QC21 BC_12 BC_27 are set to open by setting the appropriate module inputs as follows In the functional block diagram 0...

Page 527: ...3 Signals from all feeders 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 bus...

Page 528: ...TRAFO IEC04000482 V1 EN Figure 248 Busbars divided by bus section disconnectors circuit breakers The following signals from each bus section disconnector bay A1A2_DC are needed For B1B2_DC correspondi...

Page 529: ...DU_12 en04000483 vsd EXDU_DC A1A2 BBTR_OP 1 IEC04000483 V1 EN Figure 249 Signals to a bus coupler bay in section 1 from any bays in each section For a bus coupler bay in section 2 the same conditions...

Page 530: ...DCCLTR The bus section disconnector is closed VPDCTR The switch status of bus section disconnector DC is valid EXDU_DC No transmission error from the bay that contains the above information If the bus...

Page 531: ...not used The states for QB2 QB7 QC71 are set to open by setting the appropriate module inputs as follows In the functional block diagram 0 and 1 are designated 0 FALSE and 1 TRUE QB2_OP 1 QB2_CL 0 QB...

Page 532: ...ransformer Otherwise the interlocking for line bay ABC_LINE function can be used This function can also be used in single busbar arrangements QB1 QB2 QC1 QA1 QC2 WA1 A WA2 B QA2 QC3 T QC4 QB4 QB3 QA2...

Page 533: ...s of BC_12 is valid EXDU_BC No transmission error from bus coupler bay BC The logic is identical to the double busbar configuration Signals from bus coupler 15 3 4 3 Configuration setting If there are...

Page 534: ...BS are described below 15 3 5 2 Signals from all feeders If the busbar is divided by bus section circuit breakers into bus sections and both circuit breakers are closed the opening of the circuit brea...

Page 535: ...Signal BC12OPTR No bus coupler connection through the own bus coupler between busbar WA1 and WA2 VPBC12TR The switch status of BC_12 is valid EXDU_BC No transmission error from the bay that contains...

Page 536: ...t 1 VPQB12TR bay n sect 1 EXDU_12 bay 1 sect 2 EXDU_12 bay n sect 2 EXDU_12 bay 1 sect 1 EXDU_12 bay n sect 1 EXDU_BS B1B2 EXDU_BC sect 1 EXDU_BC sect 2 IEC04000490 V1 EN Figure 256 Signals from any b...

Page 537: ...ay n sect 1 EXDU_BS A1A2 EXDU_BC sect 1 EXDU_BC sect 2 IEC04000491 V1 EN Figure 257 Signals from any bays for a bus section circuit breaker between sections B1 and B2 15 3 5 3 Configuration setting If...

Page 538: ...rrangement 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_...

Page 539: ...l 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...

Page 540: ...are valid QB1OPTR bay 1 sect A2 S2DC_OP VPS2_DC EXDU_BB en04000495 vsd QB1OPTR bay n sect A2 VPQB1TR bay 1 sect A2 VPQB1TR bay n sect A2 VPDCTR A2 A3 EXDU_BB bay n sect A2 DCOPTR A2 A3 EXDU_BB bay 1 s...

Page 541: ...B2 VPDCTR B2 B3 EXDU_BB bay n sect B2 DCOPTR B2 B3 EXDU_BB bay 1 sect B2 EXDU_DC B2 B3 IEC04000497 V1 EN Figure 263 Signals from any bays in section B2 to a bus section disconnector 15 3 6 3 Signals...

Page 542: ...BB No transmission error from double breaker bay DB that contains the above information These signals from each double breaker bay DB_BUS are needed Signal QB1OPTR QB1 is open QB2OPTR QB2 is open VPQB...

Page 543: ...e A2 busbar section are valid QB1OPTR bay 1 sect A2 S2DC_OP VPS2_DC EXDU_BB en04000500 vsd QB1OPTR bay n sect A2 VPQB1TR bay 1 sect A2 VPQB1TR bay n sect A2 EXDU_DB bay 1 sect A2 EXDU_DB bay n sect A2...

Page 544: ...1 sect B2 EXDU_DB bay n sect B2 IEC04000502 V1 EN Figure 268 Signals from double breaker bays in section B2 to a bus section disconnector 15 3 6 4 Signals in 1 1 2 breaker arrangement If the busbar is...

Page 545: ...U_BB No transmission error from breaker and a half BH that contains the above information 15 3 7 Interlocking for busbar earthing switch BB_ES 15 3 7 1 Application The interlocking for busbar earthing...

Page 546: ...ch status of QB1 is valid VPQB2TR The switch status of QB2 is valid VQB220TR The switch status of QB2and QB20 is valid VPQB7TR The switch status of QB7 is valid EXDU_BB No transmission error from the...

Page 547: ...error from the bay BS bus section coupler bay that contains the above information For a busbar earthing switch these conditions from the A1 busbar section are valid QB1OPTR bay 1 sect A1 BB_DC_OP VP_...

Page 548: ...n are valid QB2OPTR QB220OTR bay 1 sect B1 BB_DC_OP VP_BB_DC EXDU_BB en04000508 vsd QB2OPTR QB220OTR bay n sect B1 VPQB2TR VQB220TR bay 1 sect B1 VPQB2TR VQB220TR bay n sect B1 VPDCTR B1 B2 EXDU_BB ba...

Page 549: ...busbar earthing switch on bypass busbar C these conditions are valid QB7OPTR bay 1 BB_DC_OP VP_BB_DC EXDU_BB en04000510 vsd QB7OPTR bay n VPQB7TR bay 1 VPQB7TR bay n EXDU_BB bay 1 EXDU_BB bay n IEC04...

Page 550: ...contains the above information These signals from each bus section disconnector bay A1A2_DC are also needed For B1B2_DC corresponding signals from busbar B are used The same type of module A1A2_DC is...

Page 551: ...art of the busbar are open VP_BB_DC The switch status of all disconnectors on this part of the busbar is valid EXDU_BB No transmission error from any bay that contains the above information 15 3 8 Int...

Page 552: ...s to open state and disregard the outputs In the functional block diagram 0 and 1 are designated 0 FALSE and 1 TRUE QB9_OP 1 QB9_CL 0 QC9_OP 1 QC9_CL 0 If in this case line voltage supervision is adde...

Page 553: ...g modules per diameter are defined BH_LINE_A and BH_LINE_B are the connections from a line to a busbar BH_CONN is the connection between the two lines of the diameter in the 1 1 2 breaker switchyard l...

Page 554: ...condary 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...

Page 555: ...ithin 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...

Page 556: ...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...

Page 557: ...th However it shall be remembered that this can only be used in solidly earthed systems as the measured phase earth voltage can increase with as much as a factor 3 in case of earth faults in a non sol...

Page 558: ...d voltage stays outside the inner deadband If this condition persists longer than the preset time delay TR1ATCC will initiate that the appropriate ULOWER or URAISE command will be sent from TCMYLTC or...

Page 559: ...orter time delays higher up in the system The first time delay t1 is used as a time delay usually long delay for the first command in one direction It can have a definite or inverse time characteristi...

Page 560: ...tead of t1 Line voltage drop The purpose with the line voltage drop compensation is to control the voltage not at the power transformer low voltage side but at a point closer to the load point Figure...

Page 561: ...r line voltage drop compensation The calculated load voltage UL is shown on the local HMI as value ULOAD under Main menu Test Function status Control TransformerVoltageControl ATCC 90 TR1ATCC x TR8ATC...

Page 562: ...nst2 LVAConst3 and LVAConst4 It shall be noted that the adjustment factor is negative in order to decrease the load voltage and positive in order to increase the load voltage After this calculation Us...

Page 563: ...opposite end positions High circulating currents and loss of control would be the result of this runaway tap situation Parallel control with the master follower method In the master follower method o...

Page 564: ...ontrol or automatic control in single mode is made with a three position switch in the substation an arrangement as in figure 285 below is arranged with application configuration M F I SNGLMODE FORCMA...

Page 565: ...of the parameter Xline Figure 287 shows a vector diagram where the principle of reverse reactance has been introduced for the transformers in figure 286 The transformers are here supposed to be on th...

Page 566: ...vsd Load T1 T2 UB UL IT1 IT2 UB RIT1 jXLIT1 Icc Icc IT1 IT2 2 IT1 IT2 RLIT2 jXLIT2 ICC T2 ICC T1 IL IEC06000491 V3 EN Figure 288 Circulating current caused by T1 on a higher tap than T2 The circulatin...

Page 567: ...n on the IEC 61850 communication protocol Complete exchange of TR8ATCC data analog as well as binary via GOOSE is made cyclically every 300 ms The busbar voltage UB is measured individually for each t...

Page 568: ...lating current the calculated no load voltage will be greater smaller than the measured voltage UBmean The calculated no load voltage will then be compared with the set voltage USet A steady deviation...

Page 569: ...mer with the greatest voltage deviation Udi to tap first That transformer will then start timing and after time delay t1 the appropriate URAISE or ULOWER command will be initiated If now further tappi...

Page 570: ...r more follower has its LV circuit breaker open and its HV circuit breaker closed and if OperHoming On this follower continues to follow the master just as it would have made with the LV circuit break...

Page 571: ...n manual mode will of course disregard any possible tapping of the master However as one transformer in the parallel group is now exempted from the parallel control the binary output signal ADAPT on T...

Page 572: ...HV side will divide between the two transformers and it will be measured with opposite direction for T2 and T1 This in turn would be misinterpreted as a circulating current and would upset a correct c...

Page 573: ...C function blocks PGTFWD PLTREV QGTFWD and QLTREV When passing the pre set value the associated output will be activated after the common time delay setting tPower The definition of direction of the p...

Page 574: ...Exchange of information between TR8ATCC functions for more details Figure 291 shows an example where T3 is disconnected which will lead to T3 sending the DISC 1 signal to the other two parallel TR8ATC...

Page 575: ...y signals and 6 analog signals in the data set that is transmitted from one TR8ATCC block to the other TR8ATCC blocks in the same parallel group Table 56 Binary signals Signal Explanation TimerOn This...

Page 576: ...between two TR8ATCC To achieve this each TR8ATCC is transmitting its own data set on the output ATCCOUT as previously mentioned To receive data from the other transformers in the parallel group the ou...

Page 577: ...K will be activated depending on the actual parameter setting OVPartBk automatically reset Alarm Auto Man Block If the busbar voltage UB not the compensated load point voltage UVL exceedsUmax see figu...

Page 578: ...fore a new command is issued The command error signal CMDERRAL on the TCMYLTC or TCLYLTC function block will be set if the tap changer position does not change one step in the correct direction within...

Page 579: ...put module error or BIERR on TCMYLTC or TCLYLTC function block Interruption of communication with the tap changer The outputs POSERRAL and AUTOBLK or TOTBLK will be set This error condition can be res...

Page 580: ...61 Blocking via binary inputs Input name Activation Description BLOCK manually reset On Off via binary input The voltage control function can be totally blocked via the binary input BLOCK on TR1ATCC...

Page 581: ...en 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 Of...

Page 582: ...conditions in any of the followers will also cause mutual blocking Master follower out of position Master follower error No master More than one master General It should be noted that partial blocking...

Page 583: ...oltTap When the tap changer reaches its lowest highest position the corresponding ULOWER URAISE command is prevented in both automatic and manual mode Monitoring of tap changer operation The Tap chang...

Page 584: ...INPROG signal is not fed back from the tap changer mechanism TR1ATCC or TR8ATCC will not reset until tTCTimeout has timed out The advantage with monitoring the TCINPROG signal in this case is thus tha...

Page 585: ...eed the number given by the setting HourHuntDetect during the last hour sliding window Active as well in manual as in automatic mode 3 TR1ATCC or TR8ATCC function will activate the output signal HUNTI...

Page 586: ...OOSE must have unique identities Xr2 The reactance of the transformer in primary ohms referred to the LV side tAutoMSF Time delay set in a follower for execution of a raise or lower command given from...

Page 587: ...asMode Selection of single phase or phase phase or positive sequence quantity to be used for voltage and current measurement on the LV side The involved phases are also selected Thus single phase as w...

Page 588: ...Umax This setting gives the upper limit of permitted busbar voltage see section Automatic voltage control for a single transformer figure 282 It is set in percent of UBase If OVPartBk is set to Auto...

Page 589: ...t The settings for Rline and Xline are given in primary system ohms If more than one line is connected to the LV busbar equivalent Rline and Xline values should be calculated and given as settings Whe...

Page 590: ...regulates the voltage towards a set target value representing a voltage magnitude without considering the phase angle Thus UB as well as UL and also the dashed line could all be said to be on the targ...

Page 591: ...io Rline Xline according to equation 278 that is the value of j1 must be set with respect to the power factor also meaning that the reverse reactance method should not be applied to systems with varyi...

Page 592: ...justment of the target value USet is given in percent of UBase LVAConst4 Setting of the fourth load voltage adjustment value This adjustment of the target value USet is given in percent of UBase VRAut...

Page 593: ...hown in figure 295 where a negative value of P means pickup for all values to the right of the setting Reference is made to figure 290 for definition of forward and reverse direction of power through...

Page 594: ...rent 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 u...

Page 595: ...l voltage measurements in the parallel group tVTmismatch Time delay for activation of the output VTALARM T1RXOP T8RXOP This setting is set On for every transformer that can participate in a parallel g...

Page 596: ...ions at rated load that the tap changer is designed for EnabTapCmd This setting enables disables the lower and raise commands to the tap changer It shall be On for voltage control and Off for tap posi...

Page 597: ...ngs with the configuration if one sets the number of positions to x in settings for example there will be only the first x outputs available from the block in the configuration Also the frequency of t...

Page 598: ...C is configured to switch Autorecloser on off from a button symbol on the local HMI is shown in figure297 The I and O buttons on the local HMI are normally used for on off operations of the circuit br...

Page 599: ...position indication output POSITION by evaluating the value and the timestamp attributes of the inputs OPEN and CLOSE together with the logical input signal VALID When the input signal VALID is activ...

Page 600: ...the commands is supposed to be achieved by other means such as binary inputs and SPGAPC function blocks PSTO is the universal operator place selector for all control functions Even if PSTO can be con...

Page 601: ...count on time and off time To operate an AUTOBITS 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 exam...

Page 602: ...c circuit 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 breake...

Page 603: ...ined conditions Configuration logic circuits en04000208 vsd IEC04000208 V2 EN Figure 300 Application example showing a logic diagram for control of external devices via configuration logic circuits 15...

Page 604: ...te 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...

Page 605: ...equest three phase tripping Single phase tripping for single phase faults two phase tripping for two phase faults and three phase tripping for three phase faults 1ph 2ph 3ph operating mode To meet the...

Page 606: ...always be activated at every trip and can be utilized on individual trip outputs if single phase operating devices are available on the circuit breaker even when a three phase tripping scheme is selec...

Page 607: ...p and is always activated independent of which phase is involved Depending on which phases are involved the outputs TR1P TR2P and TR3P will be activated as well When single phase tripping schemes are...

Page 608: ...tripping application 16 1 2 3 Single two or three phase tripping The single two three phase tripping mode provides single phase tripping for single phase faults two phase tripping for two phase faults...

Page 609: ...he 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...

Page 610: ...gure 303 Example of the connection of directional start logic Protection functions connect the directional data via the STARTCOMB function to SMAGAPC and then to the SMPPTRC or directly to SMAGAPC and...

Page 611: ...g circuit lock out output On activates the closing circuit lock out output and latches the TRIP related outputs The normal selection is Off AutoLock Sets the scheme for lock out Off only activates loc...

Page 612: ...o obtain satisfactory minimum duration of the trip pulse to the circuit breaker trip coils OnDelay Used to prevent output signals to be given for spurious inputs Normally set to 0 or a low value OffDe...

Page 613: ...r group warning WRNCALH 16 4 1 1 Application 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 physi...

Page 614: ...stamp and the quality of signals They have the suffix QT at the end of their function block name for example SRMEMORYQT 16 6 1 Application A set of standard logic blocks like AND OR etc and timers are...

Page 615: ...gic function that also propagates timestamp and quality of input signals The execution of different function blocks within the same cycle is determined by the order of their serial execution numbers A...

Page 616: ...ult function REFPDIF can be used both for auto transformers and normal transformers When used for auto transformers information from both windings parts together with the neutral point current needs t...

Page 617: ...ransfer a combination of up to 16 binary inputs INx where 1 x 16 to an integer Each INx represents a value according to the table below from 0 to 32768 This follows the general formula INx 2x 1 where...

Page 618: ...d when all INx where 1 x 16 are active that is 1 is 65535 65535 is the highest boolean value that can be converted to an integer by the B16I function block 16 9 Boolean to integer conversion with logi...

Page 619: ...e integer presented on the output OUT on the function block BTIGAPC Name of input Type Default Description Value when activated Value when deactivated IN1 BOOLEAN 0 Input 1 1 0 IN2 BOOLEAN 0 Input 2 2...

Page 620: ...1 x 16 are activated that is Boolean 1 it corresponds to that integer 65535 is available on the output OUT IB16 function is designed for receiving up to 16 booleans input locally If the BLOCK input i...

Page 621: ...or selector switches or voltage controllers by inputting an integer number ITBGAPC function has a logical node mapping in IEC 61850 The Integer to Boolean 16 conversion with logic node representation...

Page 622: ...ation The pulse integrator function TIGAPC is intended for applications where there is a need for a integration of a pulsed signal For example the pulses from the start output of certain functions lik...

Page 623: ...econds 16 13 3 Setting guidelines 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 re...

Page 624: ...ed 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...

Page 625: ...IEEE C37 2 device number Comparator for real inputs REALCOMP Real 16 15 2 Application The function gives the possibility to monitor the level of real values in the system relative to each other or to...

Page 626: ...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 limit will act as reset limit for INLOW ou...

Page 627: ...tion inputs INPUT and REF Then the settings should be adjusted as below EnaAbs Absolute RefSource Input REF EqualBandHigh 5 0 of reference value EqualBandLow 5 0 of reference value 1MRK 502 071 UEN Se...

Page 628: ...622...

Page 629: ...e sequence component measurement VMSQI U1 U2 U0 SYMBOL TT V1 EN Phase neutral voltage measurement VNMMXU U SYMBOL UU V1 EN 17 1 2 Application Measurement functions are used for power system measuremen...

Page 630: ...ts Dead band supervision can be used to report measured signal value to station level when change in measured value is above set threshold limit or time integral of all changes since the last time val...

Page 631: ...clampings are also handled entirely by ZeroDb separately for each function s every output signal For example zero clamping of U12 is handled by UL12ZeroDb in VMMXU zero clamping of I1 is handled by I...

Page 632: ...wing general settings can be set for the Measurement function CVMMXN PowAmpFact Amplitude factor to scale power calculations PowAngComp Angle compensation for phase shift between measured I U Mode Sel...

Page 633: ...his forms the maximum limit of the range XZeroDb Zero point clamping A signal value less than XZeroDb is forced to zero Observe the related zero point clamping settings in Setting group N for CVMMXN U...

Page 634: ...erence Calibration curves It is possible to calibrate the functions CVMMXN CMMXU VMMXU and VNMMXU to get class 0 5 presentations of currents voltages and powers This is accomplished by amplitude and a...

Page 635: ...OHL Single line diagram for this application is given in figure 309 400kV Busbar 400kV OHL P Q 1000 1 A IEC09000039 3 en vsdx IED kV 3 1 0 3 400 IEC09000039 1 EN V3 EN Figure 309 Single line diagram...

Page 636: ...ro point clamping in of Ubase 25 Set minimum voltage level to 25 Voltage below 25 will force S P and Q to zero IGenZeroDb Zero point clamping in of Ibase 3 Set minimum current level to 3 Current below...

Page 637: ...ts IAmpComp5 Amplitude factor to calibrate current at 5 of Ir 0 00 IAmpComp30 Amplitude factor to calibrate current at 30 of Ir 0 00 IAmpComp100 Amplitude factor to calibrate current at 100 of Ir 0 00...

Page 638: ...310 it is 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 funct...

Page 639: ...1L2 phase to phase voltage is available k Low pass filter coefficient for power measurement U and I 0 00 Typically no additional filtering is required UGenZeroDb Zero point clamping in of Ubase 25 Set...

Page 640: ...311 it is necessary to do the following 1 Set correctly all CT and VT data and phase angle reference channel PhaseAngleRef using PCM600 for analog input channels 2 Connect in PCM600 measurement functi...

Page 641: ...et 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 17 2 1 Identification Function...

Page 642: ...he 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...

Page 643: ...is used to set the limit for a temperature alarm condition in the transformer TempLOLimit This is used to set the limit for a temperature lockout condition in the transformer tLevelAlarm This is used...

Page 644: ...riving mechanism or failures of the contacts Circuit breaker status Monitoring the breaker status ensures proper functioning of the features within the protection relay such as breaker control breaker...

Page 645: ...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 curr...

Page 646: ...e 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 ca...

Page 647: ...ng travel time OperAlmLevel Alarm limit for number of mechanical operations OperLOLevel Lockout limit for number of mechanical operations CurrExponent Current exponent setting for energy calculation I...

Page 648: ...ing a Substation Automation system with LON or SPA communication time tagged events can be sent at change or cyclically from the IED to the station level These events are created from any available si...

Page 649: ...e load on the station bus 17 6 Disturbance report DRPRDRE 17 6 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Disturbance report...

Page 650: ...plies to all events which are continuously saved in a ring buffer Local HMI can be used to get information about the recordings and the disturbance report files may be uploaded in the PCM600 using the...

Page 651: ...PRDRE IEC09000337 3 en vsdx IEC09000337 V3 EN Figure 313 Disturbance report functions and related function blocks For Disturbance report function there are a number of settings which also influences t...

Page 652: ...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...

Page 653: ...mal mode and the status is indicated in the saved recording Post Retrigger Disturbance report function does not automatically respond to any new trig condition during a recording after all signals set...

Page 654: ...DCM 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 affect...

Page 655: ...ncy is used when calculating trip values It is suggested to point out a sampled voltage input signal for example a line or busbar phase voltage channel 1 30 Event list Event list EL SOE function has n...

Page 656: ...nal status report BINSTATREP 17 7 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Logical signal status report BINSTATREP 17 7 2 A...

Page 657: ...e proceeding actions The output indicators remain high until the reset of the function It is also possible to initiate the counter from a non zero value by resetting the function to the wanted initial...

Page 658: ...ts from zero again 17 9 3 Setting guidelines The settings tAlarm and tWarning are user settable limits defined in hours The achievable resolution of the settings is 0 1 hours 6 minutes tAlarm and tWar...

Page 659: ...load level is highly depends on the transformer cooling system Both IEEE and IEC standards have established transformer thermal model for all cooling system types and described formulae for transform...

Page 660: ...ould be calculated using the empirical formulae given by relevant standards The hot spot temperature shall be monitored continuously so that it will not exceed the transformer oil flashover value Figu...

Page 661: ...ng leads to unacceptable temperature rise in windings leads insulation and oil When temperature changes moisture and gas content in the insulation and oil will change IEEE C57 91 1995 standard has dev...

Page 662: ...r 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 t...

Page 663: ...rmer 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 ri...

Page 664: ...mer The options are Three winding The function considers the given transformer as three winding transformer Two winding The function considers the given transformer as two winding transformer Based on...

Page 665: ...former is considered Winding 2 Only winding 2 CT is available This option can be selected when two winding transformer is considered Winding 1 2 Only winding 1 and winding 2 CTs are available This opt...

Page 666: ...sts of all winding mass core mass and paper mass of the transformer OilMass This setting is used to set the transformer oil mass This mass consists of free oil mass and oil insulation mass of the tran...

Page 667: ...rial is selected as copper Aluminum Winding material is selected as aluminum Winding to oil temperature gradient differs from winding to winding depending on current density in the winding physical di...

Page 668: ...rated voltage HighVoltTap This setting is used to set the position number of tap changer at possible maximum voltage LowVoltTap This setting is used to set the position number of tap changer at possi...

Page 669: ...his setting is used to set the top oil temperature rise above ambient temperature in K Kelvin The above setting values HPTmpRiseWX and TopOilTmpRise should be obtained from the manufacturer based on c...

Page 670: ...erature of 110 C is 180 000 Hours AgeingRateMeth This setting is used to select the method to be used for transformer insulation relative ageing rate calculation between IEC standard method and IEEE s...

Page 671: ...to set the level 1 value for hot spot temperature warning WrnHPTmpLev2 This setting is used to set the level 2 value for hot spot temperature warning This should be more than the WrnHPTmpLev1 setting...

Page 672: ...e transformer number of windings Three winding ConstSelection Select the standard from which the transformer parameters should be taken IEC CurrSelectMode Select the method for the determination of cu...

Page 673: ...ulation of oil time constant 2 0 MW WdgTmConstMode Select the transformer winding time constant mode of input to the function Standard WdgTimeConst1 Set the transformer winding time constant for the w...

Page 674: ...sition 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 minimum voltage is possible for t...

Page 675: ...mperature sensor failure absence 30 C DecAmbTmp Set the December month average ambient temperature for the calculation of top oil temperature when ambient temperature sensor failure absence 30 C HPTmp...

Page 676: ...ormer insulation paper type Upgraded TimeToUpdate Set the time interval for the update of loss of life outputs 1 Hour WrnHPTmpLev1 Set the hot spot temperature value for the level 1 warning 110 C WrnH...

Page 677: ...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 p...

Page 678: ...ts on the same board used for pulse counting 18 2 Function for energy calculation and demand handling ETPMMTR 18 2 1 Identification Function description IEC 61850 identification IEC 60617 identificati...

Page 679: ...lse 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 t...

Page 680: ...se 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 shoul...

Page 681: ...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...

Page 682: ...the other subnetwork By default this is set to 0 0 0 0 which means that no default gateway is selected ECT validates the entered value but the default gateway has to be in the same subnetwork as the...

Page 683: ...ovides redundant communication over station bus running the available communication protocols The redundant communication uses two Ethernet ports IEC09000758 4 en vsd Switch A AP1 PhyPortB PhyPortA AP...

Page 684: ...r 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...

Page 685: ...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...

Page 686: ...he 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 Routes are configured usin...

Page 687: ...two or more intelligent electronic devices IEDs from one or several vendors to exchange information and to use it in the performance of their functions and for correct co operation GOOSE Generic Obje...

Page 688: ...8 1 Figure323 shows the GOOSE peer to peer communication Control Protection Control Protection Control and protection GOOSE en05000734 vsd Station HSI MicroSCADA Gateway IED A IED A IED A IED A IED A...

Page 689: ...unction is used to send one single logical output to other systems or equipment in the substation SP16GAPC can be used to send up to 16 single point values from the application functions running in th...

Page 690: ...E receive function blocks are used to receive subscribed data from the GOOSE protocol The validity of the data value is exposed as outputs of the function block as well as the validity of the communic...

Page 691: ...l type of protection function Factors influencing the accuracy of the sampled values from the merging unit are for example anti aliasing filters frequency range step response truncating A D conversion...

Page 692: ...em Some merging units are able to get data from classical measuring transformers others from non conventional measuring transducers and yet others can pick up data from both types The electronic part...

Page 693: ...elays IEC61850 8 1 en08000069 3 vsd IEC08000069 V2 EN Figure 326 Example of a station configuration with the IED receiving analog values from both classical measuring transformers and merging units 20...

Page 694: ...or the synchronization to the MU time is lost the protection functions in the list 74 will be blocked due to conditional blocking If this parameter is set to BlockOnLostUTC the protection functions in...

Page 695: ...13000299 V2 EN Figure 328 MU failed mixed system Case 3 Failure of one MU sample lost blocks the sending and receiving of binary signals through LDCM DTT from the remote end is not working IEC13000300...

Page 696: ...nd voltage protection CVGAPC Overfrequency protection SAPTOF Current reversal and weakend infeed logic for residual overcurrent protection ECRWPSCH Underfrequency protection SAPTUF Four step residual...

Page 697: ...logic ZCLCPSCH Negative sequence overvoltage protection LCNSPTOV Scheme communication logic for distance or overcurrent protection ZCPSCH Three phase overcurrent LCP3PTOC Current reversal and weak en...

Page 698: ...SMGAPC Out of step protection OOSPPAM Transformer tank overcurrent protection TPPIOC 20 3 2 3 Setting examples for IEC UCA 61850 9 2LE and time synchronization The IED and the Merging Units MU should...

Page 699: ...example with PTP synchronization Settings on the local HMI under Main menu Configuration Time Synchronization TIMESYNCHGEN 1 IEC61850 9 2 HwSyncSrc is not used as the SW time and HW time are connecte...

Page 700: ...erential protection when PTP is enabled or when the PMU report is used IED MU Analog data PPS IEC UCA 61850 9 2LE Synchronization IEC10000061 2 en Original vsd IEC10000061 V2 EN Figure 331 Setting exa...

Page 701: ...t data are generated by internal substitution or one more channel s Quality is not good or merging unit is in Testmode detailed quality Test IED is not in test mode Using external clock for time synch...

Page 702: ...rnal time synchronization to the IED that is loss of the hardware synchSrc MUSYNCH signal on the MUx function block monitors the synchronization flag smpSynch in the datastream and IED hardware time s...

Page 703: ...thout blocking protection functions if PPS is lost 20 3 3 IEC 61850 quality expander QUALEXP The quality expander component is used to display the detailed quality of an IEC UCA 61850 9 2LE analog cha...

Page 704: ...tion with the IEDs through the LON bus from the operator s workplace from the control center and also from other IEDs via bay to bay horizontal communication For LON communication an SLM card should b...

Page 705: ...on 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 pro...

Page 706: ...tings The parameters for the multiple command function are set via PCM600 The Mode setting sets the outputs to either a Steady or Pulsed mode 20 5 SPA communication protocol 20 5 1 Application SPA com...

Page 707: ...lave and the PC is the master Only one master can be applied on each fibre optic loop A program is required in the master computer for interpretation of the SPA bus codes and for translation of the da...

Page 708: ...n speeds are used in the same fibre optical loop or RS485 network take this into account when making the communication setup in the communication master the PC With local fibre optic communication com...

Page 709: ...ssing 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 6 1 1 Functionality...

Page 710: ...ned in the IEC 60870 5 103 protocol are represented in dedicated function blocks These blocks have output signals for all available commands according to the protocol For more information refer to the...

Page 711: ...for each input signal Supervision indications in monitor direction Function block with defined functions for supervision indications in monitor direction I103Superv This block includes the FUNCTION TY...

Page 712: ...ocator function is included in the IED Disturbance recordings The transfer functionality is based on the Disturbance recorder function The analog and binary signals recorded will be reported to the ma...

Page 713: ...RevPolarity optical channel only CycMeasRepTime MasterTimeDomain TimeSyncMode EvalTimeAccuracy EventRepMode CmdMode RepIntermediatePos config selector is OPTICAL103 1 for the optical serial channel on...

Page 714: ...ing for the information number of the connected signal The information number can be set to any value between 0 and 255 To get proper operation of the sequence of events the event masks in the event f...

Page 715: ...1 IL1 2 2 IL2 3 3 IL3 4 4 IN 5 5 UL1 6 6 UL2 7 7 UL3 8 8 UN 9 64 Private range 10 65 Private range 11 66 Private range 12 67 Private range 13 68 Private range 14 69 Private range 15 70 Private range 1...

Page 716: ...to the tables in the Technical reference manual Station communication specifying the information types supported by the communication protocol IEC 60870 5 103 To support the information corresponding...

Page 717: ...tion For more information on the application and setting guidelines for the DNP3 communication protocol refer to the DNP3 Communication protocol manual 1MRK 502 071 UEN Section 20 Station communicatio...

Page 718: ...712...

Page 719: ...re 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 substat...

Page 720: ...rrents 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...

Page 721: ...V2 EN Figure 341 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...

Page 722: ...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 inc...

Page 723: ...ause interruptions with a duration of up to 50 ms Too short a time delay can thus cause nuisance alarms ComAlrmResDel defines the time delay for communication failure alarm reset RedChSwTime defines t...

Page 724: ...When a merging unit according to IEC 61850 9 2 is used instead of the TRM this parameter shall be set to 5 CompRange value indicates the current peak value over which truncation is made To set this va...

Page 725: ...t 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 indic...

Page 726: ...ange lock CHNGLCK 22 3 1 Application 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 727: ...traffic on the IED The communication facilities must not be allowed to compromise the primary functionality of the device All inbound network traffic will be quota controlled so that too heavy networ...

Page 728: ...722...

Page 729: ...cs IED status Product identifiers and under Main menu Diagnostics IED Status Identifiers ProductVer ProductDef FirmwareVer SerialNo OrderingNo ProductionDate IEDProdType This information is very helpf...

Page 730: ...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 product this means new...

Page 731: ...y adaptable IED that can cope with a variety of power system scenarios Different conditions in networks with different voltage levels require highly adaptable protection and control units to best prov...

Page 732: ...EC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Primary system values PRIMVAL 23 5 2 Application The rated system frequency and phase rotation direction are set under Ma...

Page 733: ...n Global base values function GBASVAL is used to provide global values common for all applicable functions within the IED One set of global values consists of values for current voltage and apparent p...

Page 734: ...Signal Matrix tool The user defined name for the input or output signal will also appear on the respective output or input signal 23 9 Signal matrix for binary outputs SMBO 23 9 1 Application The Sig...

Page 735: ...sed on the level of positive sequence voltage MinValFreqMeas to validate if the frequency measurement is valid or not If the positive sequence voltage is lower than MinValFreqMeas the function freezes...

Page 736: ...change frequency protection SAPFRC due to that all other information except frequency and positive sequence voltage might be wrongly calculated The same phase phase voltage connection principle shall...

Page 737: ...he phase component during faults IN UN must be connected to input 4 Negation If the user wants to negate the 3ph signal it is possible to choose to negate only the phase signals Negate3Ph only the neu...

Page 738: ...to feed one protection function e g over power function GOPPDOP it is of outmost importance that parameter setting DFTReference has the same set value for all of the preprocessing blocks involved Sect...

Page 739: ...e 343 Twelve SMAI instances are grouped within one task time SMAI blocks are available in three different task times in the IED Two pointed instances are used in the following examples The examples sh...

Page 740: ...for the frequency tracking feature For task time group 1 this gives the following settings see Figure 343 for numbering SMAI1 1 DFTRefExtOut DFTRefGrp7 to route SMAI7 7 reference to the SPFCOUT output...

Page 741: ...ve sequence voltage is used for the frequency tracking feature For task time group 1 this gives the following settings see Figure 343 for numbering SMAI1 1 SMAI12 12 DFTReference ExternalDFTRef to use...

Page 742: ...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 the originator orCat is Maint...

Page 743: ...n their Beh is blocked This can be done if the component has a block input The block status of a component is shown as the Blk output under the Test Function status menu If the Blk output is not shown...

Page 744: ...m the IED to the MU by using a GTM Out of these LON and SPA contains two types of synchronization messages Coarse time messages are sent every minute and contain complete date and time that is year mo...

Page 745: ...3 2 1 System time The time is set with years month day hour minute second and millisecond 23 13 2 2 Synchronization The setting parameters for the real time clock with external time synchronization ar...

Page 746: ...g source CoarseSyncSrc to Off when GPS time synchronization of line differential function is used Set the fine time synchronization source FineSyncSource to GPS The GPS will thus provide the complete...

Page 747: ...using the 9 2 stream from the SAM600 and gets its synch from the GPS Moreover the REL and REC both acts as a boundary clock to provide synch to the SAM600 The REL contains a GTM card which has a PPS o...

Page 748: ...P synch as well as sync to the merging unit If synchronization of the IED and the merging unit is based on GPS set the parameter LostSyncMode to BlockOnLostUTC in order to provide a block of protectio...

Page 749: ...s 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 rema...

Page 750: ...I IEEE but with an iron core material traditional material that gives a remanent flux that is limited to maximum 80 of the saturation flux The Low Remanence LR type is a CT with small airgaps in the i...

Page 751: ...e thus applicable both for symmetrical and asymmetrical fault currents Depending on the protection function phase to earth phase to phase and three phase faults have been tested for different relevant...

Page 752: ...nd it is just necessary to consider the resistance up to the point where the phase wires are connected to the common neutral wire The most common practice is to use four wires secondary cables so it n...

Page 753: ...well defined as far as the phase angle error is concerned If no explicit recommendation is given for a specific function we therefore recommend contacting ABB to confirm that the non remanence type ca...

Page 754: ...case Ipr CT rated primary current Isr CT rated secondary current Rct CT secondary winding resistance Rw The resistance of the secondary wire For phase to earth faults the loop resistance containing th...

Page 755: ...T1 and CT2 have the following data CT1 4000 1 A 5P10 15 VA the secondary winding resistance Rct 5 The rated burden W b 2 sr 15 15 R 15 1 I EQUATION2529 V2 EN Equation 284 CT2 4000 1 A class PX the rat...

Page 756: ...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 Equation 289 tf al alreqExt sr ct w addbu pr I 13000 E E 2 I R R R 2 1 5 2 5 0 3 51 V I 4000 EQUATION2535 V2 EN Equation...

Page 757: ...burden to Rb 5 5 VA Now we can assume the CT secondary winding resistance to be 60 of Rb Rct 3 We can now calculate the required secondary e m f according to equation 280 and 281 As the 16 kV system...

Page 758: ...8 As an alternative it can be suitable to provide the CT manufacturer with the data according to equation 299 as follows NG al alreqRat sr ct w addbu ct pr I 3250 E E 30 I R R R 30 1 R 2 8 I 4000 EQUA...

Page 759: ...nce containing the phase and neutral wires must be used for faults in solidly earthed systems The resistance of a single secondary wire should be used for faults in high impedance earthed systems SR T...

Page 760: ...VA SR 0 020 VA channel for Ir 1 A and SR 0 150 VA channel for Ir 5 A 24 1 6 4 Restricted earth fault protection low impedance differential The requirements are specified separately for solidly earthe...

Page 761: ...equal ratios and magnetization characteristics the CTs must satisfy Requirement 306 and the Requirement 307 2 sr R al alreq ef ct L pr r I S E E I R R I I EQUATION2239 V2 EN Equation 308 Where Ief Max...

Page 762: ...ents often are relatively small and the requirements might result in small CTs However in applications where the zero sequence current from the phase side of the transformer is a summation of currents...

Page 763: ...ccording to IEC 61869 2 is specified by the secondary limiting e m f EALF The value of the EALF is approximately equal to the corresponding Eal Therefore the CTs according to class P and PR must have...

Page 764: ...valent limiting secondary e m f EalANSI that fulfils the following alANSI alreq E maximum of E EQUATION1384 V2 EN Equation 315 A CT according to ANSI IEEE is also specified by the knee point voltage U...

Page 765: ...ized from a stable source like GPS or local without synchronization Using a local SNTP server without synchronization as primary or secondary server in a redundant configuration is not recommended 24...

Page 766: ...pendent 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 deviatio...

Page 767: ...mples sec at 60 Hz for a merging unit type1 and 256 samples cycle for a merging unit type2 The IED can receive data rates of 80 samples cycle Note that the IEC UCA 61850 9 2LE standard does not specif...

Page 768: ...762...

Page 769: ...BP 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 bistab...

Page 770: ...ording 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 directio...

Page 771: ...re 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 protec...

Page 772: ...nsient performance IEC 60870 5 103 Communication standard for protection equipment A serial master slave protocol for point to point communication IEC 61850 Substation automation communication standar...

Page 773: ...r 2 Ingression protection according to IEC 60529 IP 20 Ingression protection according to IEC 60529 level 20 IP 40 Ingression protection according to IEC 60529 level 40 IP 54 Ingression protection acc...

Page 774: ...PCM600 Protection and control IED manager PC MIP Mezzanine card standard PMC PCI Mezzanine card POR Permissive overreach POTT Permissive overreach transfer trip Process bus Bus or LAN used at the pro...

Page 775: ...al area networks This reduces the requirement to have accurate hardware clocks in every embedded system in a network Each embedded node can instead synchronize with a remote clock providing the requir...

Page 776: ...he apparent impedance to the fault applied to the balance point that is the set reach The relay does not see the fault but perhaps it should have seen it See also Overreach UTC Coordinated Universal T...

Page 777: ...ten referred to as the residual or the earth fault current 3UO Three times the zero sequence voltage Often referred to as the residual voltage or the neutral point voltage 1MRK 502 071 UEN Section 25...

Page 778: ...772...

Page 779: ...773...

Page 780: ...AB Grid Automation Products 721 59 V ster s 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...

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