ABB REL650 series Applications Manual Download Page 24

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Denial of service................................................................................... 487

Identification.................................................................................... 487
Application....................................................................................... 487
Setting guidelines............................................................................ 487

Section 18 Requirements....................................................................489

Current transformer requirements........................................................ 489

Distance protection.....................................................................492
Breaker failure protection........................................................... 493
Non-directional instantaneous and definitive time, phase and

residual overcurrent protection...................................................494
Non-directional inverse time delayed phase and residual

overcurrent protection.................................................................495
Directional phase and residual overcurrent protection............... 496

Current transformer requirements for CTs according to other

standards.........................................................................................496

Current transformers according to IEC 61869-2, class P, PR.... 496
Current transformers according to IEC 61869-2, class PX,

PXR (and old IEC 60044-6, class TPS

and old British Standard, class X).............................................. 497
Current transformers according to ANSI/IEEE........................... 497

Voltage transformer requirements........................................................ 498
SNTP server requirements................................................................... 499

SNTP server requirements.............................................................. 499

Section 19 Glossary............................................................................ 501

Table of contents

Application manual

Summary of Contents for REL650 series

Page 1: ...Relion 650 series Line distance protection REL650 ANSI Application manual...

Page 2: ......

Page 4: ...L Project for use in the OpenSSL Toolkit http www openssl org This product includes cryptographic software written developed by Eric Young eay cryptsoft com and Tim Hudson tjh cryptsoft com Trademarks...

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: ...ning electrical equipment for use within specified voltage limits Low voltage directive 2006 95 EC This conformity is the result of tests conducted by ABB in accordance with the product standard EN 60...

Page 7: ...lication examples 38 Adaptation to different applications 38 Functionality table 38 Section 3 REL650 setting examples 41 Setting example for a two ended overhead transmission line in a solidly grounde...

Page 8: ...g settings for step 2 68 Calculating settings for step 3 69 Calculating settings for four step residual overcurrent protection zero or negative sequence direction EF4PTOC 51N_67N 70 Calculating genera...

Page 9: ...ect configure and set VT inputs for most commonly used VT connections 100 Examples on how to connect a three phase to ground connected VT to the IED 101 Section 5 Local human machine interface 105 Loc...

Page 10: ...ment for mho FMPSPDIS 21 146 Identification 146 Application 146 Setting guidelines 147 Load encroachment 148 Additional distance protection directional function for ground faults ZDARDIR 21D 149 Ident...

Page 11: ...n 3 phase output OC4PTOC 51 67 179 Identification 179 Application 179 Setting guidelines 180 Settings for steps 1 to 4 181 2nd harmonic restrain 183 Four step phase overcurrent protection phase segreg...

Page 12: ...elines 228 Breaker failure protection 3 phase activation and output CCRBRF 50BF 229 Identification 229 Application 229 Setting guidelines 230 Breaker failure protection phase segregated activation and...

Page 13: ...onnected equipment detection 256 Power supply quality 256 Voltage instability mitigation 257 Backup protection for power system faults 257 Settings for Two step undervoltage protection 257 Two step ov...

Page 14: ...ion CCSRDIF 87 275 Identification 275 Application 275 Setting guidelines 276 Fuse failure supervision SDDRFUF 276 Identification 276 Application 276 Setting guidelines 277 General 277 Setting of commo...

Page 15: ...ser 307 Control of the auto reclosing open time 307 Long trip signal 307 Maximum number of reclosing shots 308 3 phase reclosing one to five shots according to setting NoOfShots 308 Reclosing reset ti...

Page 16: ...sful signal 326 Lock out initiation 326 Automatic continuation of the reclosing sequence 327 Thermal overload protection holding the auto reclosing function back 328 Setting guidelines 328 Configurati...

Page 17: ...iameter BH 3 373 Application 373 Configuration setting 374 Interlocking for double CB bay DB 3 375 Application 375 Configuration setting 376 Interlocking for line bay ABC_LINE 3 377 Application 377 Si...

Page 18: ...schemes 394 Intertrip scheme 397 Setting guidelines 397 Blocking scheme 397 Delta blocking scheme 398 Permissive underreaching scheme 398 Permissive overreaching scheme 398 Unblocking scheme 399 Inter...

Page 19: ...tion 408 Application 409 Fault current reversal logic 409 Weak end infeed logic 410 Setting guidelines 410 Current reversal 410 Weak end infeed 411 Section 13 Logic 413 Tripping logic common 3 phase o...

Page 20: ...n 16 conversion IB16A 424 Identification 424 Application 425 Setting guidelines 425 Integer to boolean 16 conversion with logic node representation IB16FCVB 425 Identification 425 Application 425 Sett...

Page 21: ...cription 438 Application 438 Setting guidelines 438 Disturbance report 439 Identification 439 Application 439 Setting guidelines 440 Binary input signals 443 Analog input signals 444 Sub function para...

Page 22: ...ction 16 Station communication 459 IEC61850 8 1 communication protocol 459 Identification 459 Application 459 Horizontal communication via GOOSE 461 Setting guidelines 464 DNP3 protocol 465 IEC 60870...

Page 23: ...ctory defined settings 477 Primary system values PRIMVAL 478 Identification 478 Application 478 Signal matrix for analog inputs SMAI 478 Identification 478 Application 479 Setting guidelines 479 Summa...

Page 24: ...time phase and residual overcurrent protection 494 Non directional inverse time delayed phase and residual overcurrent protection 495 Directional phase and residual overcurrent protection 496 Current...

Page 25: ...manual can also provides assistance for calculating settings 1 2 Intended audience This manual addresses the protection and control engineer responsible for planning pre engineering and engineering Th...

Page 26: ...he manual provides instructions on how to set up a PCM600 project and insert IEDs to the project structure The manual also recommends a sequence for the engineering of protection and control functions...

Page 27: ...n also provides assistance for calculating settings The technical manual contains application and functionality descriptions and lists function blocks logic diagrams input and output signals setting p...

Page 28: ...S MICS 1MRG 010 656 PICS 1MRG 010 660 PIXIT 1MRG 010 658 1 4 Symbols and conventions 1 4 1 Symbols The electrical warning icon indicates the presence of a hazard which could result in electrical shock...

Page 29: ...e between the options use and HMI menu paths are presented in bold For example select Main menu Settings LHMI messages are shown in Courier font For example to save the changes in non volatile memory...

Page 30: ...24...

Page 31: ...operating time of typically 30 ms The multi shot autoreclose includes priority features for double breaker arrangements It co operates with the synchronism check function with high speed or delayed r...

Page 32: ...each particular application Add binary I O boards as required for the application when ordering The graphical configuration tool ensures simple and fast testing and commissioning Also the customized...

Page 33: ...M RPSB 68 ZCV PSOF SOTF LMB RFLO Monit SES RSYN 25 SYNC ZC PSCH 85 ZCRW PSCH 85 ETP MMTR Wh CV MMXN Meter EC PSCH 85 ECRW PSCH 85 SDD RFUF C MMXU Meter C MSQI Meter IEC61850 ANSI IEC Function Enabled...

Page 34: ...PTUV 27 U SDD RFUF Line data Line length 50km Positive sequence line impedance 0 195 j 0 410 Ohms Primary km Zero sequence line impedance 0 400 j 1 310 Ohms Primary km TCS SCBR Cond SPVN ZBAT Cond Oth...

Page 35: ...Function Enabled in Settings 1000 5 132kV 110V 132kV 110V 132kV 110V 132 kV Bus Line data Line length 50Km Positive sequence line impedance 0 195 j 0 410Ohms Primary Km Zero sequence line impedance 0...

Page 36: ...HIZ Phase preference logic 0 1 1 1 1 ZMRPSB 68 Power swing detection 0 1 1 1 1 ZCVPSOF Automatic switch onto fault logic voltage and current based 1 1 1 1 2 2 2 Back up protection functions IEC 61850...

Page 37: ...failure protection phase segregated activation and output 0 1 1 STBPTOC 50STB Stub protection 0 1 1 1 1 CCRPLD 52PD Pole discordance protection 0 2 1 1 2 BRCPTOC 46 Broken conductor check 0 1 1 1 1 G...

Page 38: ...103IEDCMD IED commands for IEC60870 5 103 1 1 1 1 I103USRCMD Function commands user defined for IEC60870 5 103 4 4 4 4 I103GENCMD Function commands generic for IEC60870 5 103 50 50 50 50 I103POSCMD IE...

Page 39: ...3 Logic SMPPTRC 94 Tripping logic common 3 phase output 1 2 1 2 SPTPTRC 94 Tripping logic phase segregated output 1 1 TMAGGIO Trip matrix logic 12 12 12 12 OR Configurable logic blocks 283 283 283 28...

Page 40: ...e representation 16 16 16 16 TEIGGIO Elapsed time integrator with limit transgression and overflow supervision 12 12 12 12 Monitoring CVMMXN Measurements 6 6 6 6 CMMXU Phase current measurement 10 10...

Page 41: ...SSIMG 63 Insulation gas monitoring function 0 2 1 1 2 SSIML 71 Insulation liquid monitoring function 0 2 1 1 2 SSCBR Circuit breaker condition monitoring 0 2 1 1 2 I103MEAS Measurands for IEC60870 5...

Page 42: ...MST2TCP DNP3 0 for TCP IP communication protocol 1 1 1 1 MST3TCP DNP3 0 for TCP IP communication protocol 1 1 1 1 MST4TCP DNP3 0 for TCP IP communication protocol 1 1 1 1 RS485GEN RS485 1 1 1 1 OPTIC...

Page 43: ...sed blocking scheme signal transmit 0 1 1 1 1 ZCRWPSCH 85 Current reversal and WEI logic for distance protection 3 phase 0 1 1 1 ZCWSPSCH 85 Current reversal and WEI logic for distance protection phas...

Page 44: ...l of service frame rate control for LAN1A and LAN1B ports 1 DOSSCKT Denial of service socket flow control 1 2 3 REL650 application examples 2 3 1 Adaptation to different applications The IED is provid...

Page 45: ...abled Enabled Enabled Instantaneous phase overcurrent protection 3 phase output PHPIOC 50 Application dependent Application dependent Application dependent Application dependent Application dependent...

Page 46: ...dependent Two step overvoltage protection OV2PTOV 59 Application dependent Application dependent Application dependent Application dependent Application dependent Two step residual overvoltage protect...

Page 47: ...ntity Value Line length 50 km Positive sequence impedance 0 05 j 0 35 km 2 5 j17 5 Zero sequence impedance 0 15 j 1 00 km 7 5 j50 High positive sequence source impedance at A j10 about 1 900 MVA Low p...

Page 48: ...ar application 3 1 1 Calculating general settings for analogue TRM inputs 4I 1I 5U The transformer module TRM has the capability of 4 current inputs tapped to 1 or 5 A one current input tapped 0 1 or...

Page 49: ...vity of the protection is used In this application the input is not used 3 Set the primary and secondary values for voltage transformer inputs 6 3 1 Set VTSec6 to 110 V The rated secondary voltage of...

Page 50: ...when doing the setting calculations Errors introduced by current and voltage instrument transformers particularly under transient conditions Inaccuracies in the line zero sequence impedance data and...

Page 51: ...unwanted trip at A Zone 3 together with zone 2 serves as remote back up protection for short circuits faults on the lines out from the remote 138 kV busbar Zone 3 shall if possible cover the whole len...

Page 52: ...definition of the KN factor is line line line Z Z Z KN 1 1 0 3 GUID 201DAAE3 7D9E 48B9 9CCA 33B5C2E51103 V1 EN Equation 2 For phase to ground fault loops the apparent impedance is defined as 0 3 ph L...

Page 53: ...gh Internal start will make all measuring loop timers of that zone start counting time if any one of the 5 zones have been picked up But the trip will be released only if particular loop start signal...

Page 54: ...selected as Quadrilateral then set RFPP1 to 15 The fault resistance setting for phase to phase faults is normally the resistance arc between the faulty phases The fault resistance can approximately b...

Page 55: ...foots The resistance is thus depending on theground resistivity tower footing resistance and the resistance of grounded shield wires if existing The fault resistance can be written R Rarc Rtowerfoot T...

Page 56: ...e line there is a risk of phase shift of the fault resistance that moves the apparent impedance into the zone 1 characteristic even if the fault is external R X 5 10 15 20 5 10 15 Line impedance 20 25...

Page 57: ...g will be used by both mho and quadrilateral characteristics Z2Rev will not have any effect as DirModeZ2 is selected as Forward Zone 2 must be set so that there is no risk for unselective trip on faul...

Page 58: ...also the fault resistance is influenced by the fault current infeed from the other lines connected to B The apparent value of the fault resistance at A can approximately be calculated as 1 3 2 8 17 5...

Page 59: ...he zones is sufficient The time delay for zone 2 is therefore chosen to 0 s delay zone 1 0 4 s 3 1 3 4 Calculating settings for zone 3 Zone 3 should preferably be set so that the required back up zone...

Page 60: ...is proposed 5 Set RFPG3 to 150 if CharPGZ3 is set to Quadrilateral RFPE3 0 5 Z3 setting is proposed 6 Set OpModetPGZ3 to Enabled Zone 3 phase to earth loop gives trip 7 Set OpModetPPZ3 to Enabled Zon...

Page 61: ...delay for zone 4 need margin to assure selectivity to zone 1 of lines out from substation A A delay time difference of 0 4 s between the zones is sufficient 3 1 4 Calculating settings for phase select...

Page 62: ...se of 2 3 The characteristic are shown in figure 11 30 Phase to phase fault Three phase fault 0 X1 60 4 3X1 ANSI10000188_en_1 vsd 0 5 RFltRevPP 0 5 RFltFwdPP 0 5 RFltFwdPP 2 3 K ANSI10000188 V1 EN Fig...

Page 63: ...n ext max V RLd P W GUID AA7CA356 FAA7 4504 8BA0 C8ADDFC40C68 ANSI V1 EN Equation 20 3 Set LdAngle to 30 It is normally considered that the apparent impedance during non faulted condition has a phase...

Page 64: ...loss of guard is to be used Set to Restart if Unblocking scheme with alarm for loss of guard is to be used 6 Set tSecurity 0 035 s 7 Set DeltaI 10 IB 8 Set DeltaV 5 VB 9 Set Delta3I0 10 IB 10 Set Delt...

Page 65: ...where it can not be assured that the zone 1 reach from both line ends overlap each other The scheme should also be used for lines where the fault current infeed from one of the line ends is small and...

Page 66: ...S Receive signal CR Zone 1 TRIP Zone 1 PICKUP Zone 2 TRIP Zone 2 PICKUP OR ANSI11000074 V2 EN Figure 15 Logic of under reach communication scheme This scheme is used for long lines where it can be ass...

Page 67: ...sd ANSI11000112 V1 EN Figure 16 Principle of blocking communication scheme A communication signal is sent CS if a fault is detected by zone 4 reverse zone When a communication signal is received CR th...

Page 68: ...1000077 V2 EN Figure 17 Logic of blocking communication scheme The trip signal from zone 2 must be delayed so that the blocking signal has enough time for blocking at external faults 3 1 6 4 Principle...

Page 69: ...lta blocking communication scheme When a communication signal is received CR the overeaching zone zone2 is blocked The logic is shown in figure 19 Receive signal CR Trip Send signal CS Zone1 TRIP Zone...

Page 70: ...eak End Y Y REL650 REL650 ANSI11000113_1_en vsd ANSI11000113 V1 EN Figure 20 Line fault for fast fault clearance by means of WEI logic For the fault shown in the figure 20 there is a risk that we get...

Page 71: ...one of the line ends will be tripped 1 Set WEI to Echo Trip Echoes the CR signal as well as trip locally 2 Set tPickUpWEI to 0 01 s The shortest duration of the CR signal 3 Set PU27PP to 70 Should be...

Page 72: ...nitiation based on the voltage and current measurement 3 1 9 Calculating settings for four step phase overcurrent protection 3 phase output OC4PTOC 51_67 The phase overcurrent protection is more diffi...

Page 73: ...ay to enable selectivity Step 3 I with a current setting that enables detection of all short circuits on the adjacent lines connected to the local and remote busbars The function has a longer delay to...

Page 74: ...imized maximum short circuit power 3 1 9 3 Calculating settings for step 2 1 Set Pickup2 to 190 of IBase To assure that step 2 will detect all short circuits on the line a phase phase short circuit is...

Page 75: ...urrent setting of step 2 is if possible chosen as 1 2 max Ifault3 4 5 6max Istep2 0 7 min IAB min IBA min 1 2 1 56 Istep2 0 7 2 50 or 1 9 Istep2 1 75 In this case it is not possible to fulfil the requ...

Page 76: ...22 322 1061 460 7 0 95 0 840 2 1 3 3 step step I or I GUID 871F169F 1B5E 43C5 8628 1E010031999B V1 EN Equation 23 where is the reset ratio of the overcurrent function For the overcurrent function in...

Page 77: ...the four step residual phase overcurrent protection is proposed Step 1 3I0 with high current setting and zero delay Step 1 has directional function with the residual voltage as directional reference T...

Page 78: ...sbar faults at the remote line end are applied see figure 23 The following fault types are applied phase phase ground short circuit and phase ground fault For the faults shown in the figure the source...

Page 79: ...reach adjacent lines out from the remote busbar and out from the local busbar To assure selectivity to ground fault current protections of the other lines going out from the remote busbar the followin...

Page 80: ...nfiguration manly if the line is transposed or not If definite time delay is used there is some risk of unselective trip at high resistive ground faults or series faults If dependent time delay invers...

Page 81: ...logic shall be used as there is a risk of small current infeed Th WEI function requires permissive over reach communication scheme 2 Set tCoord to 0 000 s 3 Set tSendMin to 0 100 s 3 1 11 1 Over reac...

Page 82: ...EN Figure 26 Logic for four step residual overcurrent protection overreach communication scheme This scheme is used for short lines where it can not be assured that the zone 1 reach from both line en...

Page 83: ...gnal is received CR Step 2 3I0 will operate instantaneously The logic can be described as shown in figure 28 Send signal CS Receive signal CR Trip Step 1 TRIP Step 1 PUST1 Step 2 TRIP Step 2 ANSI11000...

Page 84: ...ep Step Step Step ANSI11000117 V1 EN Figure 29 Principle for four step residual overcurrent protection blocking communication scheme A communication signal is sent CS if a fault is detected by step 4...

Page 85: ...aults 3 1 12 Calculating settings for current reversal and weak end infeed logic for residual overcurrent protection ECRWPSCH 85 The four step residual overcurrent protection can only operate if the f...

Page 86: ...he weak end infeed logic WEI is activated The function at internal line fault can be described as For an internal fault step 2 in line end B picks up and sends a signal to line end A CS If none of the...

Page 87: ...given in the base settings in Global base 1 2 Set FunctionMode to Current 3 Set BuTripMode to 1 out of 4 In the current measurement the three phase currents out on the line is used It is also possible...

Page 88: ...BFP reset time is maximum 15 ms The margin should be chosen to about 2 cycles This gives about 155 ms minimum setting of back up trip delay t2 CCRBRF 50BF ANSI11000081_1_en vsd ANSI11000081 V1 EN Fig...

Page 89: ...both faults are fed from the station The faults are within zone 1 Y REL650 REL650 Phase ground fault Phase ground fault ANSI11000118_1_en vsd ANSI11000118 V1 EN Figure 33 Cross country fault The aim o...

Page 90: ...pick up at phase to phase fault in another fault loop is avoided The default value 40 of VBase is recommended Setting PU27PP to 40 4 Set 3V0PU to 20 The setting 3V0PU is used in the logic to evaluate...

Page 91: ...t The default value 0 15 s is proposed 3 2 2 Calculating settings for sensitive directional residual overcurrent protection SDEPSDE 67N In high impedance grounded system the ground fault current at si...

Page 92: ...ulted feeder can be calculated by first to calculate the residual voltage at required sensitivity fault resistance 0 3 1 Phase o f V V R Z GUID 28E30403 2324 4F8E BC5F 0FCA0D974410 V1 EN Equation 26 w...

Page 93: ...s within the set range In this case 3I0Cosfi is chosen 2 Set DirMode to Forward The setting DirMode can be set Forward or Reverse Forward is chosen 3 Set RCADir to 0 The setting RCADir Relay Character...

Page 94: ...sen 10 Use the setting tDef for the definite time delay of the protection function The setting is depending on the setting of other sensitive residual current protections in the system Often pure time...

Page 95: ...se angle will always be fixed to zero degrees and all other angle information will be shown in relation to this analog input During testing and commissioning of the IED the reference channel can be ch...

Page 96: ...largest rated CT primary current among all CTs involved in the protection scheme and installed on the same voltage level This will effectively make the protection scheme less sensitive however such me...

Page 97: ...sured quantity is positive when flowing towards the object Set parameter CTStarPoint Correct Setting is ToObject Set parameter CTStarPoint Correct Setting is FromObject en05000456 2 vsd ANSI05000456 V...

Page 98: ...tting is ToObject ANSI11000020 2 en vsd Is Is Ip Ip Ip IED IED ANSI11000020 V2 EN Figure 36 Example how to set CT_WyePoint parameters in the IED The figure 36 shows the most common case where the obje...

Page 99: ...IED IED ANSI05000460 V2 EN 1MRK 506 334 UUS A Section 4 Analog inputs 93 Application manual...

Page 100: ...s feeding just one line both line protection IED and transformer protection IED use the same CT The CT direction is set with different reference objects for the two IEDs though it is the same current...

Page 101: ...noted that depending on national standard and utility practices the rated secondary current of a CT has typically one of the following values 1A 5A However in some cases the following rated secondary...

Page 102: ...phase CT set to the three CT inputs of the IED 2 The current inputs are located in the TRM It shall be noted that for all these current inputs the following setting values shall be entered for the ex...

Page 103: ...required only for IEDs installed in power plants then the setting parameters DFTReference shall be set accordingly Section SMAI in this manual provides information on adaptive frequency tracking for...

Page 104: ...600A CTsec 5A CTWyePoint FromObject Inside the IED only the ratio of the first two parameters is used The third parameter as set in this example will negate the measured currents in order to ensure th...

Page 105: ...wn in figure 41 CTprim 1000 A CTsec 1A CTWyePoint FromObject 3 shows the connection made in SMT tool which connect this CT input to the fourth input channel of the preprocessing function block 4 4 is...

Page 106: ...es the marking of voltage transformer terminals commonly used around the world A H1 B H2 b X2 a X1 A H1 N H2 n X2 a X1 b c A H1 N H2 dn X2 da X1 d VPri VSec a ANSI11000175_1_en vsd ANSI11000175 V1 EN...

Page 107: ...Examples on how to connect a three phase to ground connected VT to the IED Figure 43 gives an example on how to connect the three phase to ground connected VT to the IED It as well gives overview of r...

Page 108: ...to three VT inputs on the IED 2 is the TRM where these three voltage inputs are located For these three voltage inputs the following setting values shall be entered VTprim 66 kV VTsec 110 V Inside the...

Page 109: ...and calculate fundamental frequency phasors for all four input channels harmonic content for all four input channels positive negative and zero sequence quantities by using the fundamental frequency...

Page 110: ...104...

Page 111: ...LCD Buttons LED indicators Communication port for PCM600 The LHMI is used for setting monitoring and controlling 5 1 1 Display The LHMI includes a graphical monochrome display with a resolution of 320...

Page 112: ...utton panel shows on request what actions are possible with the function buttons Each function button has a LED indication that can be used as a feedback signal for the function button control action...

Page 113: ...on buttons or the Multipage button Pressing the ESC button clears the panel from the display Both the panels have dynamic width that depends on the label string length that the panel contains 5 1 2 LE...

Page 114: ...which are embedded into the control buttons and They represent the status of the circuit breaker 5 1 3 Keypad The LHMI keypad contains push buttons which are used to navigate in different views or men...

Page 115: ...nction button 6 Close 7 Open 8 Escape 9 Left 10 Down 11 Up 12 Right 13 User Log on 14 Enter 15 Remote Local 16 Uplink LED 17 Ethernet communication port RJ 45 18 Multipage 19 Menu 20 Clear 21 Help 22...

Page 116: ...A flashing yellow LED has a higher priority than a steady yellow LED The IED is in test mode and protection functions are blocked The indication disappears when the IED is no longer in test mode and b...

Page 117: ...S sequence The activation signal is on or it is off but the indication has not been acknowledged LatchedAck S F sequence The indication has been acknowledged but the activation signal is still on 5 1...

Page 118: ...front port with a crossed over cable the IED s DHCP server for the front interface assigns an IP address to the computer if DHCPServer Enabled The default IP address for the front port is 10 1 150 3...

Page 119: ...e zones for phase to phase and phase to ground faults The function is equipped with five individually reversible directional zones This provides a fast and reliable functionality with built in redunda...

Page 120: ...circuit current The series impedances determine the magnitude of the fault current The shunt admittance has very limited influence on the ground fault current The shunt admittance may however have so...

Page 121: ...is less than 1 4 The ground fault factor is defined according to equation 36 max e pn V f V ANSIEQUATION1268 V1 EN Equation 36 Where Vmax is the highest fundamental frequency voltage on one of the he...

Page 122: ...k is that the magnitude of the ground fault current is very low compared to the short circuit current The voltage on the healthy phases will get a magnitude of 3 times the phase voltage during the fau...

Page 123: ...nitude of the ground fault current might not give pickup of the zero sequence measurement elements or the sensitivity will be too low for acceptance For this reason a separate high sensitive ground fa...

Page 124: ...in algorithm which compensates the overreach tendency of zone 1 at the exporting end No settings are required for this function 6 1 2 3 Short line application The definition of short medium and long l...

Page 125: ...ncroachment will normally be a major concern It is well known that it is difficult to achieve high sensitivity for phase to ground fault at remote end of a long line when the line is heavily loaded Wh...

Page 126: ...but isolated zero sequence network 3 Parallel circuits with positive and zero sequence sources isolated One example of class 3 networks could be the mutual coupling between a 400kV line and rail road...

Page 127: ...5000221 V1 EN Figure 53 Class 1 parallel line in service The equivalent circuit of the lines can be simplified see figure 54 A B C Z0m Z0m Z0 Z0m Z0 IEC09000253_1_en vsd IEC09000253 V1 EN Figure 54 Eq...

Page 128: ...one line end it is proportionally increased at the opposite line end So this 15 reach reduction does not significantly affect the operation of a permissive underreaching scheme Parallel line out of s...

Page 129: ...uit of the parallel lines will be according to figure 57 A B C IEC09000252_1_en vsd I0 I0 Z0m Z0 Z0m Z0 Z0m IEC09000252 V1 EN Figure 57 Equivalent zero sequence impedance circuit for the double circui...

Page 130: ...o sequence mutual impedance does not influence the measurement of the distance protection in a faulty circuit This means that the reach of the underreaching distance protection zone is reduced if due...

Page 131: ...ansformer This application gives rise to similar problem that was highlighted in section Fault infeed from remote end that is increased measured impedance due to fault current infeed For example for f...

Page 132: ...verse direction from B to C depending on the system parameters see the dotted line in figure 60 given that the distance protection in B to T will measure wrong direction In three end application depen...

Page 133: ...n be separately configured by the setting CharPGZx where x 1 5 for phase to ground loops and by CharPPZx where x 1 5 for phase to phase loops This selectable feature gives an additional flexibility fo...

Page 134: ...resistances especially for phase to ground faults at remote line end For example in quadrilateral characteristic a given setting of the load angle LdAngle for phase selection with load encroachment t...

Page 135: ...etween the necessary emergency load transfer and necessary sensitivity of the distance protection The function can also preferably be used on heavy loaded medium long lines For short lines the major c...

Page 136: ...rameters of the protected line and be coordinated to the selectivity plan for the network Use different setting groups for the cases when the parallel line is in operation out of service and not groun...

Page 137: ...Z1 Z4 Z5 ANSI11000265 V1 EN Figure 64 Impedance characteristic Complex characteristic can be formed with the ZQMPDIS 21 function Figure 65 shows for example when zone 1 is set to combined quadrilater...

Page 138: ...out of service and not grounded and out of service and grounded in both ends The setting of ground fault reach should be selected to be 95 also when parallel line is out of service and grounded at bot...

Page 139: ...uced below 120 of the protected line section The whole line must be covered under all conditions The requirement that the zone 2 shall not reach more than 80 of the shortest adjacent line at remote en...

Page 140: ...must overreach the protected circuit in all cases The greatest reduction of a reach occurs in cases when both parallel circuits are in service with a single phase to ground fault located at the end of...

Page 141: ...pModetPGZx and OpModetPPZx where x is 1 5 depending on selected zone parameter to Disabled Different time delays are possible for the phase to ground tPGZx where x is 1 5 depending on selected zone an...

Page 142: ...n MVA The load impedance phase is a function of the minimum operation voltage and the maximum load current min load max Z V 3 I EQUATION1719 V1 EN Equation 52 Minimum voltage Vmin and maximum current...

Page 143: ...pplicable only when the loop characteristic angle for the phase to phase faults is more than three times as large as the maximum expected load impedance angle More accurate calculations are necessary...

Page 144: ...any zone to ensure that there is a sufficient setting margin between the relay boundary and the minimum load impedance The minimum load impedance phase is calculated as 2 min V Zload S EQUATION1753 A...

Page 145: ...lt resistance coverage Therefore the function has a built in algorithm for load encroachment which gives the possibility to enlarge the resistive setting of both the Phase selection with load encroach...

Page 146: ...creased to avoid that FDPSPDIS 21 characteristic shall cut off some part of the zone characteristic The necessary increased setting of the fault resistance coverage can be derived from trigonometric e...

Page 147: ...tween distance protection ZQMPDIS 21 and FDPSPDIS 21 for phase to ground fault loop 60 setting parameters in italic 1 FDPSPDIS 21 red line 2 ZQMPDIS 21 3 RFltRevPGPHS 4 X1PHS XN tan 60 5 RFltFwdPGPHS...

Page 148: ...required Fault resistance reach The resistive reach must cover RFPG for the overreaching zone to be covered mostly zone 2 Consider the longest overreaching zone if correct fault selection is importan...

Page 149: ...orward direction RFItFwdPP must cover RFPPZm with at least 25 margin RFPPZm is the setting of fault resistance for phase to phase fault for the longest overreaching zone to be covered by FDPSPDIS 21 s...

Page 150: ...68 Relation between distance protection ZQMPDIS 21 and FDPSPDIS 21 characteristic for phase to phase fault for line 60 setting parameters in italic 1 FDPSPDIS 21 red line 2 ZQMPDIS 21 3 0 5 4 60 tan...

Page 151: ...s the same in forward and reverse direction so it could be suitable to begin to calculate the setting for that parameter Set the parameter to the maximum possible load angle at maximum active load A v...

Page 152: ...detect single line to ground fault at remote end on the protected line It is recommended to set 3I0BLK_PP to double value of 3I0Enable_PG 6 3 Faulty phase identification with load enchroachment for m...

Page 153: ...ce current 3I0 that might exist due to un transposed lines 3I0BLK_PP The setting of 3I0BLK_PP is by default set to 40 of IBase which is suitable in most applications I1LowLevel The setting of the posi...

Page 154: ...Load encroachment The load encroachment function has two setting parameters RLd for the load resistance and LdAngle for the inclination of the load sector see figure 70 R X RLdFw RLdRv LdAngle LdAngl...

Page 155: ...he RLd can be calculated according to equation 71 cos RLd ZLoad LdAngle EQUATION1624 ANSI V1 EN Equation 71 The setting of RLd and LdAngle is by default set to 80 ohm phase and 20 degrees Those values...

Page 156: ...ties are adversely affected by load the use of sequence quantities are preferred as polarizing quantities for ground directional elements Optionally six possibilities are available Zero sequence volta...

Page 157: ...polarized and a zero sequence current polarized neutral current polarized directional element into one element the IED can benefit from both elements as the two polarization measurements function in...

Page 158: ...ase selective tripping during two simultaneous single phase ground faults in different phases on different line sections Due to the resonance high resistive grounding principle the ground faults in th...

Page 159: ...utilized Figure 71 shows an occurring cross country fault Figure 72 shows the achievement of line voltage on healthy phases and an occurring cross country fault AG CG Load Load Y Y ANSI06000550_2_en...

Page 160: ...e integer from the phase selection function which gives the type of fault undergoes a check and will release the distance protection zones as decided by the logic The logic includes a check of the fau...

Page 161: ...DIS 21 and Phase selection with load encroachment quadrilateral characteristic function FDPSPDIS 21 As the fault is a double ground faults at different locations of the network the fault current in th...

Page 162: ...he phase Normally in a high impedance grounded system the voltage drop is big and the setting can typically be set to 70 of base voltage VBase PU27PP The setting of the phase to phase voltage level li...

Page 163: ...eneral Various changes in power system may cause oscillations of rotating units The most typical reasons for these oscillations are big changes in load or changes in power system configuration caused...

Page 164: ...which means slip frequency as high as 10 of the rated frequency on the 50 Hz basis It detects the swings under normal system operating conditions ZMRPSB 68 function is able to secure selective operati...

Page 165: ...nts for faults on the corresponding busbar It is necessary to consider separate contributions of different connected circuits The required data is as follows 400 r V kV EQUATION1728 V1 EN Rated system...

Page 166: ...V1 EN Maximum expected load angle 2 5 si f Hz EQUATION1334 V1 EN Maximum possible initial frequency of power oscillation 7 0 sc f Hz EQUATION1335 V1 EN Maximum possible consecutive frequency of power...

Page 167: ...ation 77 1 1 1 17 16 154 8 S SA L SB Z Z Z Z j W EQUATION1339 V1 EN Equation 77 The calculated value of the system impedance is of informative nature and helps determining the position of oscillation...

Page 168: ...tic in forward direction RLdOutFw should be set with certain safety margin KL compared to the minimum expected load resistance RLmin When the exact value of the minimum load resistance is not known th...

Page 169: ...it comes to settings of timers tP1 and tP2 included in oscillation detection logic This requires the maximum permitted setting values of factor kLdRFw 0 8 Equation 82 presents the corresponding maxim...

Page 170: ...5 0 030 64 5 91 5 In si Out f tP d d EQUATION1349 V1 EN Equation 87 max1 min 155 75 75 8 91 5 2 tan 2 tan 2 2 d W S in Z RLdInFw EQUATION1350 V1 EN Equation 88 max1 75 8 0 61 123 5 RLdInFw kLdRFw RLd...

Page 171: ...ngle tan 25 LdAngle arctan arctan 37 5 kLdRFw 0 61 EQUATION1738 ANSI V1 EN Equation 93 It is recommended to set the corresponding resistive reach parameters in reverse direction RLdOutRv and kLdRRv to...

Page 172: ...r Automatic switch onto fault logic voltage and current based ZCVPSOF 6 7 2 Application Automatic switch onto fault logic voltage and current based function ZCVPSOF is a complementary function to impe...

Page 173: ...VPickup is used to set voltage level for detection of dead line UVPickup is by default set to 70 of VBase This is a suitable setting in most cases but it is recommended to checking the suitability in...

Page 174: ...oinit to Enabled Otherwise the logic will be activated by an external BC input tSOTF The drop delay of ZCVPSOF function is by default set to 1 second which is suitable for most applications tDLD The t...

Page 175: ...depends mostly on three parameters at constant amount of transmitted electric power The type of the fault Three phase faults are the most dangerous because no power can be transmitted through the faul...

Page 176: ...to ground conditions Also study transients that could cause a high increase of the line current for short times A typical example is a transmission line with a power transformer at the remote end whi...

Page 177: ...00023 V1 EN Figure 79 Through fault current from B to A IfA The IED must not trip for any of the two through fault currents Hence the minimum theoretical current setting Imin will be Imin MAX IfA IfB...

Page 178: ...given from this formula 100 Is Pickup IBase ANSIEQUATION1147 V1 EN Equation 96 7 1 3 2 Meshed network with parallel line In case of parallel lines the influence of the induced current from the parall...

Page 179: ...ation 97 Where IfA and IfB have been described in the previous paragraph Considering the safety margins mentioned previously the minimum setting Is for the instantaneous phase overcurrent protection 3...

Page 180: ...he fault current A high fault current indicates that the decrease of transmitted power is high The total fault clearing time The phase angles between the Electro motive forces EMFs of the generators o...

Page 181: ...otection Common base IED values for primary current IBase primary voltage setting VBase and primary power SBase are set in a Global base values for settings function GBASVAL Setting GlobalBaseSel is u...

Page 182: ...EQ1 V1 EN Equation 100 A safety margin of 5 for the maximum protection static inaccuracy and a safety margin of 5 for the maximum possible transient overreach have to be introduced An additional 20 i...

Page 183: ...ple is given in figure 85 where the two lines are connected to the same busbars In this case the influence of the induced fault current from the faulty line line 1 to the healthy line line 2 is consid...

Page 184: ...onsidering the safety margins mentioned previously the minimum setting Is as given in equation below Is 1 3 Imin EQUATION83 V2 EN Equation 104 The protection function can be used for the specific appl...

Page 185: ...rs and others Back up short circuit protection of power generators If VT inputs are not available or not connected setting parameter DirModeSelx x step 1 2 3 or 4 shall be left to default value Non di...

Page 186: ...7 have a possibility of 2nd harmonic restrain if the level of this harmonic current reaches a value above a set percentage of the fundamental current 7 3 3 Setting guidelines When inverse time overcur...

Page 187: ...teristic angle 55 2 ROA Relay operating angle 80 3 Reverse 4 Forward 7 3 3 1 Settings for steps 1 to 4 n means step 1 and 4 x means step 1 2 3 and 4 DirModeSelx The directional mode of step x Possible...

Page 188: ...different characteristics are described in Technical manual Pickupx Operate phase current level for step x given in of IBase tx Definite time delay for step x The definite time tx is added to the inve...

Page 189: ...armonic restrain function 2nd harmonic This function should be used when there is a risk if power transformer inrush currents might cause unwanted trip Can be set Disabled Enabled 7 3 3 2 2nd harmonic...

Page 190: ...description is given below The pickup current setting of the inverse time protection or the lowest current step of the definite time protection must be defined so that the highest possible load curre...

Page 191: ...be chosen within the interval stated in equation 108 Imax 1 2 Ipu 0 7 Iscmin k EQUATION1264 V2 EN Equation 108 The high current function of the overcurrent protection which only has a short delay of...

Page 192: ...short that protected equipment will not be destroyed due to thermal overload at the same time as selectivity is assured For overcurrent protection in a radial fed network the time setting can be chos...

Page 193: ...ection resetting time must be known These time delays can vary significantly between different protective equipment The following time delays can be estimated Protection operation time 15 60 ms Protec...

Page 194: ...ker The operation time of this protection is t1 t t2 is when the circuit breaker at IED B1 opens The circuit breaker opening time is t2 t1 t t3 is when the overcurrent protection at IED A1 resets The...

Page 195: ...output OC4SPTOC ID 2147 VSD V1 EN 51 67 7 4 2 Application The four step phase overcurrent protection phase segregated output OC4SPTOC 51_67 is used in several applications in the power system Some app...

Page 196: ...he protection Therefore OC4SPTOC 51 67 function has a possibility of a second harmonic restrain if the level of this harmonic current reaches a value above a set percentage of the fundamental current...

Page 197: ...ary power SBase are set in a Global base values for settings function GBASVAL Setting GlobalBaseSel Used to select a GBASVAL function for reference of base values MeasType Selection of discrete Fourie...

Page 198: ...eristic 1 RCA Relay characteristic angle 55 2 ROA Relay operating angle 80 3 Reverse 4 Forward 7 4 3 1 Settings for steps 1 to 4 n means step 1 and 4 x means step 1 2 3 and 4 The directional mode of s...

Page 199: ...nverse IEC Inverse IEC Extremely Inverse IEC Short Time Inverse IEC Long Time Inverse IEC Definite Time ASEA RI RXIDG logarithmic The different characteristics are described in the Technical manual Pi...

Page 200: ...of twenty times the set current pickup value Note that the operating time value is dependent on the selected setting value for time multiplier TDn 7 4 3 2 2nd harmonic restrain 2ndHarmStab Operate le...

Page 201: ...p current Current I The IED does not reset Line phase current Time t Reset current ANSI10000274 1 en vsd ANSI10000274 V1 EN Figure 93 Pickup and reset current for an overcurrent protection The lowest...

Page 202: ...DC component of the short circuit current The lowest current setting of the most rapid stage of the phase overcurrent protection can be written according to max 1 2 t sc high I k I EQUATION1265 V1 EN...

Page 203: ...e and protection resetting time must be known These time delays can vary significantly between different protective equipment The following time delays can be estimated Protection operate time 15 60 m...

Page 204: ...t t2 is when the circuit breaker at IED B1 opens The circuit breaker opening time is t2 t1 t t3 is when the overcurrent protection at IED A1 resets The protection resetting time is t3 t2 To ensure th...

Page 205: ...ntaneous ground fault protection can provide fast and selective tripping The Instantaneous residual overcurrent EFPIOC 50N which can operate in 15 ms 50 Hz nominal system frequency for faults characte...

Page 206: ...high source impedance ZA and low source impedance ZB should be used For the fault at the home busbar this fault current is IfA In this calculation the operational state with low source impedance ZA an...

Page 207: ...allel lines with zero sequence mutual coupling a fault on the parallel line as shown in figure 98 should be calculated ZA ZB ZL1 A B I M Fault IED ZL2 M C Line 1 Line 2 ANSI09000025_2_en vsd ANSI09000...

Page 208: ...or negative sequence direction EF4PTOC 2 IEC11000263 V1 EN 51N 67N 7 6 2 Application The four step residual overcurrent protection zero or negative sequence direction EF4PTOC 51N_67N is used in sever...

Page 209: ...ground faults on transmission lines The directional function uses the polarizing quantity as decided by setting Voltage polarizing 3V0 or V2 is most commonly used but alternatively current polarizing...

Page 210: ...lity of second harmonic restrain 2ndHarmStab if the level of this harmonic current reaches a value above a set percentage of the fundamental current 7 6 3 Setting guidelines When inverse time overcurr...

Page 211: ...is mainly used in radial fed networks but can also be used in meshed networks In meshed networks the settings must be based on network fault calculations To assure selectivity between different protec...

Page 212: ...EN Figure 99 Minimum operate current and operate time for inverse time characteristics In order to fully comply with curves definition the setting parameter txMin shall be set to the value which is eq...

Page 213: ...Current polarizing is useful when the local source is strong and a high sensitivity is required In such cases the polarizing voltage 3V0 can be below 1 and it is then necessary to use current polariz...

Page 214: ...rmonic restrain If a power transformer is energized there is a risk that the current transformer core will saturate during part of the period resulting in a transformer inrush current This will give a...

Page 215: ...rated when a three phase set of voltage transformers and current transformers are used xx05000149_ansi vsd 67N ANSI05000149 V1 EN Figure 101 Connection of polarizing voltage from an open ANSI broken d...

Page 216: ...e formulated according to equation 120 step1 0 I 1 2 3I remote busbar EQUATION1199 V3 EN Equation 120 As a consequence of the distribution of zero sequence current in the power system the current to t...

Page 217: ...und fault 67N 0 3I ANSI05000152 V2 EN Figure 104 Step 1 third calculation In this case the residual current out on the line can be larger than in the case of ground fault on the remote busbar step1 0...

Page 218: ...ation 123 To assure selectivity the current setting must be chosen so that step 2 does not operate at step 2 for faults on the next line from the remote substation Consider a fault as shown in figure...

Page 219: ...is to detect and initiate trip for ground faults with large fault resistance for example tree faults Step 4 shall also detect series faults where one or two poles of a breaker or other switching devi...

Page 220: ...heck of angle 3I0 and cos Directional residual power can also be used to detect and give selective trip of phase to ground faults in high impedance grounded networks The protection uses the residual p...

Page 221: ...capacitive ground fault current In some power systems a medium size neutral point resistor is used for example in low impedance grounded system Such a resistor will give a resistive ground fault curre...

Page 222: ...ce voltage and the ground fault current will be calculated at the desired sensitivity fault resistance The complex neutral point voltage zero sequence can be calculated as phase 0 f 0 V V 3 R 1 Z EQUA...

Page 223: ...sformer neutral points In such a system the impedance Z0 can be calculated as n n c 0 c n n n c n n c 9R X X Z jX 3R j3X 3X X j3R 3X X EQUATION1947 V1 EN Equation 130 Where Xn is the reactance of the...

Page 224: ...l fault current can be written phase 0 1 0 f 3V 3I 2 Z Z 3 R EQUATION2023 ANSI V1 EN Equation 131 Where Vphase is the phase voltage in the fault point before the fault Z1 is the total positive sequenc...

Page 225: ...e written 0A prot 0A 0 A S 3V 3I cos j EQUATION2028 ANSI V1 EN Equation 136 0B prot 0B 0 B S 3V 3I cos j EQUATION2029 ANSI V1 EN Equation 137 The angles A and B are the phase angles between the residu...

Page 226: ...qual to the characteristic angleRCADir has the maximum sensitivity The characteristic for RCADir is equal to 0 is shown in figure 110 3V0 Vref 3I0 RCA 0 ROA 90 ang 3I0 ang 3Vref 3I0 cos en06000648_ans...

Page 227: ...rent residual power component in the direction is measured When OpModeSel is set to 3I0 and fi the function will operate if the residual current is larger than the setting INDirPU and the residual cur...

Page 228: ...voltage to be detected tDef is the definite time delay given in s for the directional residual current protection if definite time delay is chosen The characteristic angle of the directional function...

Page 229: ...EQUATION2030 ANSI V1 EN Equation 139 INDirPU is the operate current level for the directional function when OpModeSel is set 3I0 and fi The setting is given in of IBase The setting should be based on...

Page 230: ...rent protection UC2PTUC 37 7 8 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Time delayed 2 step undercurrent protection UC2PTUC...

Page 231: ...to the remote line end in order to open the line circuit breaker in that substation The carrier receive CR signal could trip the line circuit breaker directly according to a so called direct transfer...

Page 232: ...se transfer trip signals a local criterion can be added at the remote end Low current in at least two of the phases is therefore found to be a very useful criterion to increase security 7 8 3 Setting...

Page 233: ...can appear during normal operation conditions 7 9 Thermal overload protection one time constant Fahrenheit Celsius LFPTTR LCPTTR 26 7 9 1 Identification Function description IEC 61850 identification I...

Page 234: ...the trip value TripTemp the protection initiates trip of the protected line 7 9 3 Setting guidelines The parameters for the Thermal overload protection one time constant Fahrenheit Celsius LFPTTR LCPT...

Page 235: ...he signal is released when the estimated temperature is below the set value This temperature value should be chosen below the alarm temperature 7 10 Breaker failure protection 3 phase activation and o...

Page 236: ...re of the breaker is performed In the mode current the current measurement is used for the detection In the mode Contact the long duration of breaker position signal is used as indicator of failure of...

Page 237: ...f breaker failure set in of IBase This parameter should be set so that faults with small fault current can be detected The setting can be chosen in accordance with the most sensitive protection functi...

Page 238: ...ed as _ 2 1 cbopen BFP reset margin t t t t t EQUATION1430 V1 EN Equation 140 where tcbopen is the maximum opening time for the circuit breaker tBFP_reset is the maximum time for breaker failure prote...

Page 239: ...d activation and output CSPRBRF 50BF 7 11 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Breaker failure protection phase segrega...

Page 240: ...for primary current IBase primary voltage VBase and primary power setting SBase are set in a Global base values for settings function GBASVAL Setting GlobalBaseSel is used to select a GBASVAL function...

Page 241: ...hen circuit breaker is closed breaker position is used Pickup_PH Current level for detection of breaker failure set in of IBase This parameter should be set so that faults with small fault current can...

Page 242: ...o dependent of re trip timer The minimum time delay for the re trip can be estimated as _ 2 1 cbopen BFP reset margin t t t t t EQUATION1430 V1 EN Equation 141 where tcbopen is the maximum opening tim...

Page 243: ...850 identification IEC 60617 identification ANSI IEEE C37 2 device number Stub protection STBPTOC 3I STUB SYMBOL T V1 EN 50STB 7 12 2 Application Stub protection STBPTOC 50STB is a simple phase overcu...

Page 244: ...ng guidelines The parameters for Stub protection STBPTOC 50STB are set via the local HMI or PCM600 The following settings can be done for the stub protection GlobalBaseSel Selects the global base valu...

Page 245: ...ive sequence currents that will give stress on rotating machines Zero sequence currents that might give unwanted operation of sensitive ground fault protections in the power system It is therefore imp...

Page 246: ...crepancy protection Can be set Disabled CB oper monitor Continuous monitor In the alternative CB oper monitor the function is activated only directly in connection to breaker open or close command dur...

Page 247: ...must be set to avoid problem with asymmetry under minimum operating conditions Set the time delay tOper 5 60 seconds and reset time tReset 0 010 60 000 seconds 7 15 Directional over under power prote...

Page 248: ...steam supply the electric power consumption will be about 2 of rated power Even if the turbine rotates in vacuum it will soon become overheated and damaged The turbine overheats within minutes if the...

Page 249: ...tion with underpower protection and with overpower protection The underpower protection gives a higher margin and should provide better dependability On the other hand the risk for unwanted operation...

Page 250: ...asurement The setting possibilities are shown in table 14 For reverse power applications PosSeq or Arone modes are strongly recommended Table 14 Complex power calculation Set value Mode Formula used f...

Page 251: ...N2046 V1 EN Equation 150 The function has two stages that can be set independently With the parameter OpMode1 2 the function can be set Enabled Disabled The function gives trip if the power component...

Page 252: ...t 9 mA secondary N S 3 VBase IBase EQUATION2047 V1 EN Equation 151 The setting Angle1 2 gives the characteristic angle giving maximum sensitivity of the power protection function The setting is given...

Page 253: ...Old Calculated 1 EQUATION1893 ANSI V1 EN Equation 152 Where S is a new measured value to be used for the protection function Sold is the measured value given from the function in previous execution cy...

Page 254: ...and current used for the power measurement The setting possibilities are shown in table 15 For reverse power applications PosSeq or Arone modes are strongly recommended Table 15 Complex power calculat...

Page 255: ...ion 160 C 3 C C S V I EQUATION2063 ANSI V1 EN Equation 161 The function has two stages that can be set independently With the parameter OpMode1 2 the function can be set Enabled Disabled The function...

Page 256: ...g is 1 0 of SN At the same time the minimum IED pickup current shall be at least 9 mA secondary N S 3 VBase IBase EQUATION2047 V1 EN Equation 162 The setting Angle1 2 gives the characteristic angle gi...

Page 257: ...lculated 1 EQUATION1893 ANSI V1 EN Equation 163 Where S is a new measured value to be used for the protection function Sold is the measured value given from the function in previous execution cycle SC...

Page 258: ...nce is practically constant The directional function is current and voltage polarized The function can be set to forward reverse or non directional independently for each step Both steps are provided...

Page 259: ...er in reverse direction The OC1 stage is used to detect faults in forward direction and the OC2 stage is used to detect faults in reverse direction However the following must be noted for such applica...

Page 260: ...254...

Page 261: ...caused by abnormal operation or fault in the power system UV2PTUV 27 is used in combination with overcurrent protections either as restraint or in logic and gates of the trip signals issued by the two...

Page 262: ...VBase which normally is set to the primary rated voltage level phase to phase of the power system or the high voltage equipment under consideration The setting for UV2PTUV 27 is normally not critical...

Page 263: ...phase to ground RMS value or phase to phase RMS value Operation Disabled Enabled UV2PTUV 27 measures selectively phase to ground voltages or phase to phase voltage chosen by the setting ConnType This...

Page 264: ...t1Min Minimum operating time for inverse time characteristic for step 1 given in s When using inverse time characteristic for the undervoltage function during very low voltages can give a short opera...

Page 265: ...quency which can be caused by 1 Different kinds of faults where a too high voltage appears in a certain power system like metallic connection to a higher voltage level broken conductor falling down to...

Page 266: ...ectricum and the insulation The setting must be above the highest occurring normal voltage and below the highest acceptable voltage for the capacitor High impedance grounded systems In high impedance...

Page 267: ...ng is highly dependent of the protection application Here it is essential to consider the Maximum voltage at non faulted situations Normally this voltage is less than 110 of nominal voltage tn time de...

Page 268: ...fault connected to ground Depending on the type of fault and fault resistance the residual voltage will reach different values The highest residual voltage equal to three times the phase to ground vol...

Page 269: ...ltage in the feeding transformer neutral Two step residual overvoltage protection ROV2PTOV 59N is used to trip the transformer as a backup protection for the feeder ground fault protection and as a ba...

Page 270: ...in Non effectively grounded systems 8 3 3 3 Direct grounded system In direct grounded systems an ground fault on one phase indicates a voltage collapse in that phase The two healthy phases will have n...

Page 271: ...o define IBase VBase and SBase Operation Disabled or Enabled VBase is used as voltage reference for the voltage The voltage can be fed to the IED in different ways 1 The IED is fed from a normal volta...

Page 272: ...In non effectively grounded systems the residual voltage can be maximum the rated phase to ground voltage which should correspond to 100 In effectively grounded systems this value is dependent of the...

Page 273: ...le independent of the protection functions It requires to be set to open the circuit breaker in order to allow a simple system restoration following a main voltage loss of a big part of the network an...

Page 274: ...268...

Page 275: ...SAPTUF 81 detects such situations and provides an output signal suitable for load shedding generator boosting HVDC set point change gas turbine start up and so on Sometimes shunt reactors are automat...

Page 276: ...el are given below Equipment protection such as for motors and generators The setting has to be well below the lowest occurring normal frequency and well above the lowest acceptable frequency for the...

Page 277: ...d can also be used to alert operators that frequency has slightly deviated from the set point and that manual actions might be enough 9 2 3 Setting guidelines All the frequency and voltage magnitude c...

Page 278: ...ction SAPFRC 81 9 3 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Rate of change frequency protection SAPFRC df dt SYMBOL N V1 E...

Page 279: ...a frequency level closer to the primary nominal level if the rate of change frequency is large with respect to sign SAPFRC 81 PICKUP value is set in Hz s All voltage magnitude related settings are ma...

Page 280: ...274...

Page 281: ...ection functions concerned can be blocked and an alarm given In case of large currents unequal transient saturation of CT cores with different remanence or different saturation factor may result in di...

Page 282: ...on SDDRFUF 10 2 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Fuse failure supervision SDDRFUF 10 2 2 Application Different prot...

Page 283: ...added to the fuse failure supervision function in order to detect a three phase fuse failure This is beneficial for example during three phase transformer switching 10 2 3 Setting guidelines 10 2 3 1...

Page 284: ...selector OpModeSel has been introduced for better adaptation to system requirements The mode selector makes it possible to select interactions between the negative sequence and zero sequence algorith...

Page 285: ...lus a margin of 10 20 IBase is the setting of base current for the function 10 2 3 4 Zero sequence based The relay setting value 3V0PU is given in percentage of the global parameter VBase The setting...

Page 286: ...voltage for operation of dU dt and ISetprim the primary current for operation of dI dt the setting of DVPU and DIPU will be given according to equation 173 and equation 174 VSetprim DVPU 100 VBase EQU...

Page 287: ...ing is necessary to find out the vitality of the control circuits continuously Trip circuit supervision generates a current of approximately 1 0 mA through the supervised circuit It must be ensured th...

Page 288: ...with an external resistor The TCSSCBR blocking switch is not required since the external resistor is used If the TCSSCBR is required only in a closed position the external shunt resistance may be omi...

Page 289: ...p circuit supervision without an external resistor The circuit breaker open indication is set to block TCSSCBR when the circuit breaker is open Trip circuit monitoring and other trip contacts It is ty...

Page 290: ...circuit monitoring with auxiliary relays Many retrofit projects are carried out partially that is the old electromechanical relays are replaced with new ones but the circuit breaker is not replaced Th...

Page 291: ...20 mA Rext external shunt resistance Rs trip coil resistance If the external shunt resistance is used it has to be calculated not to interfere with the functionality of the supervision or the trip coi...

Page 292: ...it is recommended to use the circuit breaker position to block unintentional operation of TCSSCBR The use of the position indication is described earlier in this chapter Section 10 1MRK 506 334 UUS A...

Page 293: ...he breaker are satisfied in order to avoid stress on the network and its components The systems are defined to be asynchronous when the frequency difference between bus and line is larger than an adju...

Page 294: ...uously Closing angle is the change in angle during the set breaker closing operate time tBreaker The reference voltage can be phase neutral A B C or phase phase A B B C C A or positive sequence The bu...

Page 295: ...s insignificant or zero for manually initiated closing or closing by automatic restoration In steady conditions a bigger phase angle difference can be allowed as this is sometimes the case in a long a...

Page 296: ...FreqDiffM 3 1000 mHz FreqDiffA 3 1000 mHz ANSI10000195 2 en vsd ANSI10000195 V2 EN Figure 129 Principle for the synchronism check function 11 1 2 3 Energizing check The main purpose of the energizing...

Page 297: ...LineEnerg of the base voltage A disconnected line can have a considerable potential because of factors such as induction from a line running in parallel or feeding via extinguishing capacitors in the...

Page 298: ...signal BLKU from the internal fuse failure supervision function is then used and connected to the fuse supervision inputs of the energizing check function block In case of a fuse failure the SESRSYN...

Page 299: ...2SEL SYNPROGR SYNFAIL FRDIFSYN FRDERIVA VOKSC VDIFFSC FRDIFFA PHDIFFA FRDIFFM PHDIFFM INADVCLS VDIFFME FRDIFFME PHDIFFME VBUS VLINE MODEAEN MODEMEN ANSI08000023 V1 EN Figure 131 Selection of the energ...

Page 300: ...SYNFAIL FRDIFSYN FRDERIVA VOKSC VDIFFSC FRDIFFA PHDIFFA FRDIFFM PHDIFFM INADVCLS VDIFFME FRDIFFME PHDIFFME Vbus VLine MODEAEN MODEMEN 189 BKR1 52 ANSI11000164 V2 EN Figure 132 Connection of SESRSYN 25...

Page 301: ...IFFA PHDIFFA FRDIFFM PHDIFFM INADVCLS VDIFFME FRDIFFME PHDIFFME Vbus VLine MODEAEN MODEMEN 52 ANSI11000165 V2 EN Figure 133 Connection of SESRSYN 25 function block in a single breaker double busbar ar...

Page 302: ...C VDIFFSC FRDIFFA PHDIFFA FRDIFFM PHDIFFM INADVCLS VDIFFME FRDIFFME PHDIFFME Vbus VLine MODEAEN MODEMEN 189 289 BKR1 52 ANSI10000196 V2 EN Figure 134 Connection of the SESRSYN 25 function block in a s...

Page 303: ...DEMEN SESRSYN 25 V3PB1 V3PB2 V3PL1 V3PL2 BLOCK BLKSYNCH BLKSC BLKENERG BUS1_OP BUS1_CL BUS2_OP BUS2_CL LINE1_OP LINE1_CL LINE2_OP LINE2_CL VB1OK VB1FF VB2OK VB2FF VL1OK VL1FF VL2OK VL2FF STARTSYN TSTS...

Page 304: ...setting for the line reference voltage GblBaseSelLine which independently of each other can be set to select one of the six GBASVAL functions used for reference of base values This means that the refe...

Page 305: ...to line 1 and 2 tie breaker VRatio The VRatio is defined as VRatio bus voltage line voltage This setting scales up the line voltage to an equal level with the bus voltage PhaseShift This setting is u...

Page 306: ...ce and the output signal depends on the input conditions FreqDiffMin The setting FreqDiffMin is the minimum frequency difference where the system are defined to be asynchronous For frequency differenc...

Page 307: ...the breaker close pulse tMaxSynch The tMaxSynch is set to reset the operation of the synchronizing function if the operation does not take place within this time The setting must allow for the settin...

Page 308: ...low 25 degrees The setting of PhaseDiffAsetting is limited by the PhaseDiffM setting tSCM and tSCA The purpose of the timer delay settings tSCM and tSCA is to ensure that the synchronism check conditi...

Page 309: ...and tManEnerg The purpose of the timer delay settings tAutoEnerg and tManEnerg is to ensure that the dead side remains de energized and that the condition is not due to a temporary interference Shoul...

Page 310: ...roximately equal to the line dead time If the open time and dead time differ then the line will be energized until the breakers at both ends have opened Open Closed Operate time Line protection Circui...

Page 311: ...equence breaker prepared for an auto reclose sequence and so on is much simpler The auto reclosing function performs three phase automatic reclosing with single shot or multiple shots In power transmi...

Page 312: ...reclosing shots auto reclosing open times dead time for each shot 11 2 2 1 Auto reclosing operation OFF and ON Operation of the automatic reclosing can be set OFF and ON by a setting parameter and by...

Page 313: ...e reclosing sequence continues as usual One needs to connect signals from manual tripping and other functions which shall prevent reclosing to the input INHIBIT 11 2 2 4 Blocking of the autorecloser A...

Page 314: ...state and the signal ACTIVE resets If the first reclosing shot fails 2nd to 5th reclosing shots will follow if selected 11 2 2 9 Reclosing reset timer The reset timer tReset defines the time it takes...

Page 315: ...enerated when the auto reclosing attempt fails This is done with logic connected to the in and outputs of the Autoreclose function and connected to Binary IO as required Many alternative ways of perfo...

Page 316: ...UT RSTLKOUT SETLKOUT ANSI11000167_1_en vsd ANSI11000167 V1 EN Figure 138 Lock out arranged with internal logic with manual closing going through in IED 11 2 2 13 Automatic continuation of the reclosin...

Page 317: ...cted to binary inputs or to a communication interface block for external control RI It should be connected to the trip output protection function which starts the autorecloser for 3 phase operation SM...

Page 318: ...witch Onto Fault It is usually connected to the switch onto fault output of line protection if multi shot Auto Reclose attempts are used The input will start the shots 2 5 For single shot applications...

Page 319: ...s that SMRREC 79 function is temporarily or permanently blocked ACTIVE Indicates that SMBRREC 79 is active from start until end of Reset time INPROGR Indicates that a sequence is in progress from star...

Page 320: ...xx xx xx xx xx xx xx PROTECTION xxxx TRIP ZCVPSOF TRIP ZQMPDIS 21 TRIP SESRSYN 25 AUTOOK BIO BIO SMBRREC 79 F F T WAIT RSTCOUNT F F 3PT1 3PT2 3PT3 3PT4 3PT5 F OR OR ANSI10000193_2_en vsd ANSI10000193...

Page 321: ...power swing when reclosing after a line fault Too short a time may prevent a potentially successful reclosing A typical setting may be 2 0 s In cases where synchronization is used together with auto r...

Page 322: ...eady for an Open Close Open cycle the condition is checked only at the start of the reclosing cycle The signal will disappear after tripping but the CB will still be able to perform the C O sequence F...

Page 323: ...continuation to the next shot if the CB is not closed within the set time The normal setting is AutoCont Disabled The tAutoContWait is the length of time SMBRREC 79 waits to see if the breaker is clos...

Page 324: ...duration Resets Operates Break time Closing time Operate time Fault Operates Resets Close command Contact closed Set STBRREC 79 open time Reset time Auto reclosing function Reclosing command Pickup ST...

Page 325: ...al line breakers and auto reclosing equipment the auto reclosing open time expression is used This is the dead time setting for the Auto Recloser During simultaneous tripping and reclosing at the two...

Page 326: ...ot closed when a fault occurred should not be closed by operation of the Auto Reclosing function Auto Reclosing is often combined with a release condition from synchronism check and dead line or dead...

Page 327: ...he auto reclosing function allows a number of parameters to be adjusted Examples number of auto reclosing shots auto reclosing program auto reclosing open times dead time for each shot 11 3 2 1 Auto r...

Page 328: ...ssary to block reclosing for all manual trip operations Typically CBAuxContType NormClosed is also set and a CB auxiliary contact of type NC normally closed 52b is connected to inputs 52a and PICKUP W...

Page 329: ...The user can set a maximum trip pulse duration tTrip When trip signals are longer the auto reclosing open time is extended by tExtended t1 If Extended t1 Disabled a long trip signal interrupts the rec...

Page 330: ...e 3 phase trip is set When issuing a CB closing command a resettimer tReset is started If no tripping takes place during that time the auto reclosing function resets to the Ready state and the signal...

Page 331: ...to Reclosing function will start a single phase reclosing if programmed to do so At the evolving fault clearance there will be a new signal PICKUP and three pole trip information TR3P The single phase...

Page 332: ...not respond to the closing command and does not close but remains open the output UNSUCCL is set high after time tUnsucCl The Unsuccessful output can for example be used in Multi Breaker arrangement t...

Page 333: ...141 Lock out arranged with an external Lock out relay CLOSE COMMAND OR STBRREC 79 OR CSPBRF 50BF BJ TRIP ZCVPSOF TRIP INHIBIT UNSUCCL BJTRIP ANSI10000265 1 en vsd STPPTRC 94 SMBO AND RESET LOCK OUT O...

Page 334: ...g and reclosing command to the circuit breaker An external logic limiting the time and sending an inhibit to the INHIBIT input can be used The input can also be used to set the Auto Reclosing on hold...

Page 335: ...ON and OFF These inputs can be connected to binary inputs or to a communication interface block for external control PICKUP It should be connected to the trip output protection function which starts t...

Page 336: ...nnected to a binary input for synchronization from an external device If neither internal nor external synchronism or energizing check is required it can be connected to a permanently high source TRUE...

Page 337: ...set times Input is normally set to FALSE Recommendations for output signals SETON Indicates that the auto reclose function is switched ON and operative BLOCKED Indicates that the auto reclose function...

Page 338: ...n of the Autorecloser for 1 3 phase operation STBRREC 79 function can be switched Enabled and Disabled The setting makes it possible to switch it Enabled or Disabled using an external switch via IO or...

Page 339: ...n such a case Extended t1 Enabled and tExtended t1 0 5 s tTrip Long trip pulse Usually the trip command and initiate auto reclosing signal reset quickly as the fault is cleared A prolonged trip comman...

Page 340: ...rm the C O sequence For the selection CO CB ready for a Close Open cycle the condition is also checked after the set auto reclosing dead time This selection has a value first of all at multi shot recl...

Page 341: ...he length of time STBRREC 79 waits to see if the breaker is closed when AutoCont is set to Enabled Normally the setting can be tAutoContWait 2 s 11 4 Apparatus control 11 4 1 Identification Function d...

Page 342: ...ctions Features in the apparatus control function Operation of primary apparatuses Select Execute principle to give high security Selection function to prevent simultaneous operation Selection and sup...

Page 343: ...n can be performed from the local IED HMI If the administrator has defined users with the UMT tool then the local remote switch is under authority control If not the default factory user is the SuperU...

Page 344: ...value are shown in Table 18 Table 18 Accepted originator categories for each PSTO PermittdSourceToOperate Originator 0 Off 4 5 6 1 Local 1 4 5 6 2 Remote 2 3 4 5 6 3 Faulty 4 5 6 4 Not in use 1 2 3 4...

Page 345: ...d sequence is cancelled The mid position of apparatuses can be suppressed at SCSWI by setting the tIntermediate at SXCBR SXSWI to an appropriate value The switch controller is not dependent on the typ...

Page 346: ...SELGGIO block then other SCSWI functions as configured are blocked for selection The RESERVED signal from SELGGIO is also sent to other bay devices Due to the design of the plant some apparatus might...

Page 347: ...260_2_en vsd IEC09000260 V2 EN Figure 148 Application principle for an alternative reservation solution Bay control QCBAY The Bay control QCBAY is used to handle the selection of the operator place fo...

Page 348: ...ponding functionality defined in the IEC 61850 standard which means that this function is included as a vendor specific logical node IEC13000016 1 en vsd IEC13000016 V1 EN Figure 149 APC Local remote...

Page 349: ...R The Autorecloser SMBRREC 79 consists of the facilities to automatically close a tripped breaker with respect to a number of configurable conditions The logical node Interlocking SCILO 3 provides the...

Page 350: ...control SXSWI Disconnector Open cmd Close cmd Position SESRSYN 25 Synchrocheck SCILO 3 SCILO 3 Synchrocheck OK SELGGIO Reservation Selected Reserved Enable close Enable open Open rel Close rel Open re...

Page 351: ...me between the select and the execute command signal that is the time the operator has to perform the command execution after the selection of the object to operate When the time has expired the selec...

Page 352: ...LINE 3 Interlocking for transformer bay AB_TRAFO 3 11 5 2 Application The main purpose of switchgear interlocking is To avoid the dangerous or damaging operation of switchgear To enforce restrictions...

Page 353: ...rlocking Take care to avoid a dangerous enable condition at the loss of a VT secondary voltage for example because of a blown fuse The switch positions used by the operational interlocking logic are o...

Page 354: ...ding to figure 151 89G en04000504 vsd ANSI04000504 V1 EN Figure 151 Switchyard layout BB_ES 3 The signals from other bays connected to the module BB_ES are described below 11 5 4 2 Signals in single b...

Page 355: ...alid VP789TR The switch status of 789 is valid EXDU_BB No transmission error from the bay that contains the above information These signals from each bus section disconnector bay A1A2_DC are also need...

Page 356: ...tains the above information For a busbar grounding switch these conditions from the A1 busbar section are valid en04000506_ansi vsd 189OPTR bay 1 sect A1 BB_DC_OP VP_BB_DC EXDU_BB 189OPTR bay n sect A...

Page 357: ...2 EXDU_BB bay n sect A2 AND DCOPTR A1 A2 EXDU_BB bay 1 sect A2 EXDU_DC A1 A2 AND AND ANSI04000507 V1 EN Figure 154 Signals from any bays in section A2 to a busbar grounding switch in the same section...

Page 358: ...ect B1 VPDCTR B1 B2 EXDU_BB bay n sect B1 AND AND AND DCOPTR B1 B2 EXDU_BB bay 1 sect B1 EXDU_DC B1 B2 ANSI04000508 V1 EN Figure 155 Signals from any bays in section B1 to a busbar grounding switch in...

Page 359: ...000509 V1 EN Figure 156 Signals from any bays in section B2 to a busbar grounding switch in the same section For a busbar grounding switch on bypass busbar C these conditions are valid 789OPTR bay 1 B...

Page 360: ...nformation These signals from each double breaker bay DB_BUS are needed Signal 189OPTR 189 is open 289OPTR 289 is open VP189TR The switch status of 189 is valid VP289TR The switch status of 289 is val...

Page 361: ...r the logic for the double busbar configuration described in section Signals in single breaker arrangement Signal BB_DC_OP All disconnectors on this part of the busbar are open VP_BB_DC The switch sta...

Page 362: ...ing of the circuit breaker must be blocked if a bus coupler connection exists between busbars on one bus section side and if on the other bus section side a busbar transfer is in progress en04000489_a...

Page 363: ...coupler bay ABC_BC are needed Signal BC12OPTR No bus coupler connection through the own bus coupler between busbar WA1 and WA2 VPBC12TR The switch status of BC_12 is valid EXDU_BC No transmission erro...

Page 364: ...bay n sect 1 VPBC12TR sect 2 VP1289TR bay 1 sect 1 VP1289TR bay n sect 1 AND EXDU_12 bay 1 sect 2 EXDU_12 bay n sect 2 EXDU_12 bay 1 sect 1 EXDU_12 bay n sect 1 EXDU_BS B1B2 EXDU_BC sect 1 EXDU_BC se...

Page 365: ...EXDU_12 bay n sect 2 EXDU_12 bay 1 sect 1 EXDU_12 bay n sect 1 EXDU_BS A1A2 EXDU_BC sect 1 EXDU_BC sect 2 ANSI04000491 V1 EN Figure 163 Signals from any bays for a bus section circuit breaker between...

Page 366: ...re described below 11 5 6 2 Signals in single breaker arrangement If the busbar is divided by bus section disconnectors the condition no other disconnector connected to the bus section must be made by...

Page 367: ...open ABC_BC VP189TR The switch status of 189 is valid VP289TR The switch status of 289 is valid V22089TR The switch status of 289 and 2089 are valid EXDU_BB No transmission error from the bay that co...

Page 368: ...189TR bay n sect A1 EXDU_BB bay 1 sect A1 EXDU_BB bay n sect A1 AND AND ANSI04000494 V1 EN Figure 166 Signals from any bays in section A1 to a bus section disconnector For a bus section disconnector t...

Page 369: ...bays in section B1 to a bus section disconnector For a bus section disconnector these conditions from the B2 busbar section are valid en04000497_ansi vsd 289OPTR 22089OTR bay 1 sect B2 S2DC_OP VPS2_D...

Page 370: ...usbars divided by bus section disconnectors circuit breakers To derive the signals Signal S1DC_OP All disconnectors on bus section 1 are open S2DC_OP All disconnectors on bus section 2 are open VPS1_D...

Page 371: ...gnals from double breaker bays in section A1 to a bus section disconnector For a bus section disconnector these conditions from the A2 busbar section are valid en04000500_ansi vsd 189OPTR bay 1 sect A...

Page 372: ...y 1 sect B2 VP289TR bay n sect B2 EXDU_DB bay 1 sect B2 EXDU_DB bay n sect B2 AND AND ANSI04000502 V1 EN Figure 174 Signals from double breaker bays in section B2 to a bus section disconnector 11 5 6...

Page 373: ...status of disconnectors on bus section 1 is valid VPS2_DC The switch status of disconnectors on bus section 2 is valid EXDU_BB No transmission error from breaker and a half BH that contains the above...

Page 374: ...busbar transfer is in progress concerning this bus coupler VP_BBTR The switch status is valid for all apparatuses involved in the busbar transfer EXDU_12 No transmission error from any bay connected...

Page 375: ...th bus section disconnectors are closed So for the basic project specific logic for BBTR above add this logic Section 1 Section 2 A1A2_DC BS B1B2_DC BS ABC_LINE ABC_BC ABC_LINE ABC_BC WA1 A1 WA2 B1 WA...

Page 376: ...cuit breakers A1A2_BS and B1B2_BS Signal S1S2OPTR No bus section coupler connection between bus sections 1 and 2 VPS1S2TR The switch status of bus section coupler BS is valid EXDU_BS No transmission e...

Page 377: ...us coupler connection exists between busbar WA1 and WA2 VP_BC_12 The switch status of BC_12 is valid EXDU_BC No transmission error from any bus coupler bay BC These signals from each bus coupler bay A...

Page 378: ...h status of bus section coupler BS is valid EXDU_BS No transmission error from the bay containing the above information For a bus coupler bay in section 1 these conditions are valid AND BC_12_CL VP_BC...

Page 379: ...t to open by setting the appropriate module inputs as follows In the functional block diagram 0 and 1 are designated 0 FALSE and 1 TRUE 289_OP 1 289_CL 0 2089_OP 1 2089_CL 0 2189G_OP 1 2189G_CL 0 BC_1...

Page 380: ...tions from a line to a busbar BH_CONN 3 is the connection between the two lines of the diameter in the breaker and a half switchyard layout For a breaker and a half arrangement the modules BH_LINE_A B...

Page 381: ...ge supervision then set the corresponding inputs as follows VOLT_OFF 1 VOLT_ON 0 11 5 9 Interlocking for double CB bay DB 3 11 5 9 1 Application The interlocking for a double busbar double circuit bre...

Page 382: ...earthing switches of this section DB_BUS_B 3 handles the circuit breaker QA2 that is connected to busbar WA2 and the disconnectors and earthing switches of this section For a double circuit breaker ba...

Page 383: ...line bay ABC_LINE 3 function is used for a line connected to a double busbar arrangement with a transfer busbar according to figure 184 The function can also be used for a double busbar arrangement wi...

Page 384: ...ese signals from each line bay ABC_LINE 3 except that of the own bay are needed Signal 789OPTR 789 is open VP789TR The switch status for 789 is valid EXDU_BPB No transmission error from the bay that c...

Page 385: ...ndle the transfer bus WA7 C To derive the signals Signal BC_12_CL A bus coupler connection exists between busbar WA1 and WA2 BC_17_OP No bus coupler connection between busbar WA1 and WA7 BC_17_CL A bu...

Page 386: ...ars that is for both bus section disconnector A1A2_DC and B1B2_DC Signal DCOPTR The bus section disconnector is open DCCLTR The bus section disconnector is closed VPDCTR The switch status of bus secti...

Page 387: ...sect 2 VPBC27TR sect 1 VPDCTR B1B2 VPBC27TR sect 2 EXDU_BC sect 1 EXDU_DC A1A2 EXDU_DC B1B2 EXDU_BC sect 2 BC_12_CL VP_BC_12 BC_17_OP BC_17_CL VP_BC_17 BC_27_OP BC_27_CL VP_BC_27 EXDU_BC en04000480_a...

Page 388: ...OP 1 7189G_CL 0 BB7_D_OP 1 BC_17_OP 1 BC_17_CL 0 BC_27_OP 1 BC_27_CL 0 EXDU_BPB 1 VP_BB7_D 1 VP_BC_17 1 VP_BC_27 1 If there is no second busbar WA2 and therefore no 289 disconnector then the interlock...

Page 389: ...an also be used in single busbar arrangements 189 289 189G 289G WA1 A WA2 B 389G 489G 489 389 252 and 489G are not used in this interlocking AB_TRAFO en04000515_ansi vsd 252 152 ANSI04000515 V1 EN Fig...

Page 390: ...upler connection exists between busbar WA1 and WA2 VP_BC_12 The switch status of BC_12 is valid EXDU_BC No transmission error from bus coupler bay BC The logic is identical to the double busbar config...

Page 391: ...in order to have different functions operating on pre set values Hardware switches are however sources for maintenance issues lower system reliability and extended purchase portfolio The virtual selec...

Page 392: ...DOWN activation signal positive front and the output activation StopAtExtremes Sets the behavior of the switch at the end positions if set to Disabled when pressing UP while on first position the swit...

Page 393: ...E INV OUT INPUT ANSI07000112 V2 EN Figure 190 Control of Autorecloser from local HMI through Selector mini switch 11 7 3 Setting guidelines Selector mini switch VSGGIO function can generate pulsed or...

Page 394: ...ol 8 signals SPC8GGIO function block is a collection of 8 single point commands designed to bring in commands from REMOTE SCADA to those parts of the logic configuration that do not need complicated f...

Page 395: ...the DNP3 protocol AUTOBITS function block have 32 individual outputs which each can be mapped as a Binary Output point in DNP3 The output is operated by a Object 12 in DNP3 This object contains parame...

Page 396: ...390...

Page 397: ...special channels are used for this purpose When power line carrier is used for communication these special channels are strongly recommended due to the communication disturbance caused by the primary...

Page 398: ...it is common to use the line itself as communication media PLC The scheme can be used on all line lengths The blocking scheme is very dependable because it will operate for faults anywhere on the prot...

Page 399: ...a forward directed distance or directional current or directional ground fault element Since the scheme is sending the blocking signal during conditions where the protected line is healthy it is commo...

Page 400: ...fault on the protected object The received signal s is combined with an overreaching zone and gives an instantaneous trip if the received signal is present during the time the chosen zone is detected...

Page 401: ...re a sufficient duration of the received signal CR the send signal CS can be prolonged by a tSendMin reset timer The recommended setting of tSendMin is 100 ms Since the received communication signal i...

Page 402: ...dependability can cause delayed tripping for internal faults or even unwanted operations At the permissive overreaching scheme the send signal CS might be issued in parallel both from an overreaching...

Page 403: ...breakers or for remote tripping following operation of breaker failure protection In intertrip scheme the send signal is initiated by an underreaching zone or from an external protection transformer...

Page 404: ...to be used Set to Restart if Unblocking scheme with alarm for loss of guard is to be used Set tSecurity 0 035 s Set DeltaI 10 IB Set DeltaV 5 VB Set Delta3I0 10 IB Set Delta3V0 5 VB 12 1 3 3 Permissi...

Page 405: ...0 identification IEC 60617 identification ANSI IEEE C37 2 device number Current reversal and WEI logic for distance protection 3 phase ZCRWPSCH 85 12 2 2 Application 12 2 2 1 Current reversal logic If...

Page 406: ...f breaker B2 at B side en99000044_ansi vsd Strong source LINE 1 LINE 2 A 1 A 2 B 1 B 2 A B Weak source CLOSED CLOSED OPEN CLOSED FAULT ANSI99000044 V1 EN Figure 196 Current distribution for a fault cl...

Page 407: ...e line IED The echo signal would block the operation of the distance protection at the remote line end and in this way prevent the correct operation of a complete protection scheme A separate direct i...

Page 408: ...ic for distance protection phase segregated ZCWSPSCH 85 12 3 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Current reversal and...

Page 409: ...t distribution for a fault close to B side when breaker B 1 has opened To handle this the send signal CS from B 2 is held back until the reverse zone IRVL has reset and the tDelayRev time has elapsed...

Page 410: ...direct intertrip channel must be arranged from remote end when a trip or accelerated trip is given there The intertrip receive signal is connect to input CRL Avoid using WEI function at both line ends...

Page 411: ...nd faults 12 4 Local acceleration logic ZCLCPLAL 12 4 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Local acceleration logic ZCL...

Page 412: ...used to increase the security of the loss of load function for example to avoid unwanted release due to transient inrush current when energizing the line power transformer The loss of load function w...

Page 413: ...o the transmission channel speed and security against false or lost signals In the directional scheme information of the fault current direction must be transmitted to the other line end With directio...

Page 414: ...to Off Intertrip Permissive UR Permissive OR or Blocking tCoord Delay time for trip from ECPSCH 85 function For Permissive under overreaching schemes this timer shall be set to at least 20 ms plus max...

Page 415: ...rce CLOSED CLOSED OPEN CLOSED FAULT ANSI99000044 V1 EN Figure 200 Current distribution for a fault close to B side when breaker at B1 is opened When the breaker on the parallel line operates the fault...

Page 416: ...fine IBase VBase and SBase 12 6 3 1 Current reversal The current reversal function is set on or off by setting the parameter CurrRev to Enabled or Disabled Time delays shall be set for the timers tPic...

Page 417: ...o the communication system operating and reset time CS propagation propagation CR selection and decision operating and reset time CR to the protection function operating and reset time Time Fault occu...

Page 418: ...voltage that can occur during normal service conditions The recommended minimum setting is two times the false zero sequence voltage during normal service conditions Section 12 1MRK 506 334 UUS A Sch...

Page 419: ...ers a simple solution and is often sufficient in well meshed transmission systems and in High Voltage HV systems One SMPPTRC 94 function block should be used for each breaker if the object is connecte...

Page 420: ...iate Lock out but not initiate trip this can be achieved by activating input SETLKOUT The setting AutoLock Disabled means that the internal trip will not activate lock out so only initiation of the in...

Page 421: ...ion itself The normal selection is Disabled tTripMin Sets the required minimum duration of the trip pulse It should be set to ensure that the breaker is tripped correctly Normal setting is 0 150s 13 2...

Page 422: ...the function block The inputs 1PTRZ and 1PTREF are used for single pole tripping for distance protection and directional ground fault protection as required The inputs are combined with the phase sel...

Page 423: ...utput and also maintain the trip signal latched trip The lock out can then be manually reset after checking the primary fault by activating the input reset lock out RSTLKOUT If external conditions are...

Page 424: ...he normal selection is Disabled tTripMin Sets the required minimum duration of the trip pulse It should be set to ensure that the breaker is tripped and if a signal is used to initiate the Breaker fai...

Page 425: ...direct tripping of circuit breaker s the off delay time shall be set to approximately 0 150 seconds in order to obtain a satisfactory minimum duration of the trip pulse to the circuit breaker trip coi...

Page 426: ...ication IEC 60617 identification ANSI IEEE C37 2 device number AND function block AND Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Set reset mem...

Page 427: ...igure 205 Example designation serial execution number and cycle time for logic function The execution of different function blocks within the same cycle is determined by the order of their serial exec...

Page 428: ...a certain level value or for creating certain logic Boolean integer floating point string types of signals are available Example for use of GRP_OFF signal in FXDSIGN The Restricted earth fault functi...

Page 429: ...application 13 6 Boolean 16 to integer conversion B16I 13 6 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Boolean 16 to integer...

Page 430: ...of 16 binary logical signals into an integer B16IFCVI can receive an integer from a station computer for example over IEC 61850 8 1 These functions are very useful when you want to generate logical c...

Page 431: ...IEC 60617 identification ANSI IEEE C37 2 device number Integer to boolean 16 conversion with logic node representation IB16FCVB 13 9 2 Application Integer to boolean 16 conversion with logic node repr...

Page 432: ...rflow indication is fixed 13 10 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...

Page 433: ...output to other systems or equipment in the substation It has one visible input that should be connected in ACT tool 14 1 3 Setting guidelines The function does not have any parameters available in L...

Page 434: ...n analog signal to other systems or equipment in the substation It can also be used inside the same IED to attach a RANGE aspect to an analog value and to permit measurement supervision on that value...

Page 435: ...Application Measurement functions is used for power system measurement supervision and reporting to the local HMI monitoring tool within PCM600 or to station level for example via IEC 61850 The possi...

Page 436: ...lamping of U12 is handled by VLZeroDB in VMMXU zero clamping of I1 is handled by ILZeroDb in CMMXU Dead band supervision can be used to report measured signal value to station level when change in mea...

Page 437: ...the logic configuration made in PCM600 The parameters for the Measurement functions CVMMXN CMMXU VMMXU CMSQI VMSQI VNMMXU are set via the local HMI or PCM600 GlobalBaseSel Selects the global base val...

Page 438: ...ibrate angle measurements at Y of In where Y is equal to 5 30 or 100 The following general settings can be set for the Phase phase voltage measurement VMMXU VMagCompY Amplitude compensation to calibra...

Page 439: ...m Low limit XLowLowLim Low low limit XLimHyst Hysteresis value in of range and is common for all limits All phase angles are presented in relation to defined reference channel The parameter PhaseAngle...

Page 440: ...xamples in connection to Measurement function CVMMXN are provided Measurement function CVMMXN application for a 380kV OHL Measurement function CVMMXN application on the secondary side of a transformer...

Page 441: ...ed in figure 209 it is necessary to do the following 1 Set correctly CT and VT data and phase angle reference channel PhaseAngleRef see settings for analog input modules in PCM600 using PCM600 for ana...

Page 442: ...ement V and I 0 00 Typically no additional filtering is required Table 21 Settings parameters for level supervision Setting Short Description Selected value Comments PMin Minimum value 100 Minimum exp...

Page 443: ...libration for current at 30 of In 0 00 IAngComp100 Angle pre calibration for current at 100 of In 0 00 14 5 Event counter CNTGGIO 14 5 1 Identification Function description IEC 61850 identification IE...

Page 444: ...unction It is also possible to initiate the counter from a non zero value by resetting the function to the wanted initial value provided as a setting If applicable the counter can be set to stop or ro...

Page 445: ...e to monitor in an overview perspective These tasks are accomplished by the disturbance report function DRPRDRE and facilitate a better understanding of the power system behavior and related primary a...

Page 446: ...C 61850 8 1 the disturbance recorder record made and fault number and the fault locator information are available as GOOSE or Report Control data 14 7 3 Setting guidelines The setting parameters for t...

Page 447: ...e report function there are a number of settings which also influences the sub functions Three LED indications placed above the LCD screen makes it possible to get quick status information about the I...

Page 448: ...umber The sequence number is automatically increased by one for each new recording and is reset to zero at midnight The maximum number of recordings stored in the IED is 100 The oldest recording will...

Page 449: ...ations might be saved in the previous report too due to overlap new fault locator and trip value calculations if installed in operation and started Operation in test mode If the IED is in test mode an...

Page 450: ...ig level Trig high low level relative nominal value for analog input M in percent of nominal value 14 7 3 3 Sub function parameters All functions are in operation as long as Disturbance report is in o...

Page 451: ...st valuable disturbances and to maximize the number that is possible to save in the IED The recording time should not be longer than necessary PostFaultrecT and TimeLimit Should the function record fa...

Page 452: ...gh limit The measure value expander block MVEXP has been introduced to be able to translate the integer output signalfrom themeasuringfunctionsto5binarysignals thatisbelowlow lowlimit below low limit...

Page 453: ...een the faulted phases for phase to ground faults the phase to ground loop LMBRFLO function indicates the distance to fault as a percentage of the line length in kilometers or miles as selected on the...

Page 454: ...Z0m Z0m jX0m R1A jX1A R0L jX0L R1L jX1L R0L jX0L R1L jX1L R1B jX1B DRPRDRE LMBRFLO ANSI05000045_2_en vsd ANSI05000045 V2 EN Figure 211 Simplified network configuration with network data required for...

Page 455: ...V1 EN Figure 212 Example of connection of parallel line IN for Fault locator LMBRFLO 14 10 Station battery supervision SPVNZBAT 14 10 1 Identification Function description IEC 61850 identification IE...

Page 456: ...ufficient charging current to offset internal losses resulting in a gradual loss of capacity If a lead acid battery is subjected to a continuous undervoltage heavy sulfation occurs on the plates which...

Page 457: ...s based on received information 14 13 Circuit breaker condition monitoring SSCBR 14 13 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device nu...

Page 458: ...ceeds the set limit helps preventive maintenance This can also be used to indicate the requirement for oil sampling for dielectric testing in case of an oil circuit breaker The change of state can be...

Page 459: ...ber of closing opening operations allowed for the circuit breaker Ia the current at the time of tripping of the circuit breaker Calculation of Directional Coefficient The directional coefficient is ca...

Page 460: ...after one operation of 10 kA the remaining life of the circuit breaker is 15 000 60 14 940 at the rated operating current Spring charging time indication For normal circuit breaker operation the circu...

Page 461: ...tion automation system or read via the station monitoring system as a service value When using IEC 61850 8 1 a scaled service value is available over the station bus The normal use for this function i...

Page 462: ...inputs not connected to the pulse counter it will not influence the inputs used for pulse counting 15 2 Energy calculation and demand handling EPTMMTR 15 2 1 Identification Function description IEC 6...

Page 463: ...sQty and ERRAccPlsQty of the energy metering function and then the pulse counter can be set up to present the correct values by scaling in this function Pulse counter values can then be presented on t...

Page 464: ...100 ms tEnergyOffPls gives the OFF time between pulses Typical value can be 100 ms EAFAccPlsQty and EARAccPlsQty gives the MWh value in each pulse It should be selected together with the setting of th...

Page 465: ...orrect co operation GOOSE Generic Object Oriented Substation Event which is a part of IEC 61850 8 1 standard allows the IEDs to communicate state and control information amongst themselves using a pub...

Page 466: ...09000135_en v sd KIOSK 1 IED 1 IED 2 IED 3 IED 1 IED 2 IED 3 IED 1 IED 2 IED 3 IEC09000135 V1 EN Figure 215 Example of a communication system with IEC 61850 8 1 Figure 216 shows the GOOSE peer to peer...

Page 467: ...g breaker failure protection busbar voltage selection and so on The simplified principle is shown in Figure 217 and can be described as follows When IED1 has decided to transmit the data set it forces...

Page 468: ...n block as output signals for application functions in the application configuration Different GOOSE receive function blocks are available for the specific tasks SMT links the different data object at...

Page 469: ...e used within the application configuration Crosses in the SMT matrix connect received values to the respective function block signal in SMT see Figure 219 The corresponding quality attribute is autom...

Page 470: ...otocol Operation User can set IEC 61850 communication to Enabled or Disabled GOOSE has to be set to the Ethernet link where GOOSE traffic shall be send and received IEC 61850 8 1 specific data logical...

Page 471: ...ntation IEC 60870 5 103 protocol can be configured to use either the optical serial or RS485 serial communication interface on the COM03 or the COM05 communication module The functions Operation selec...

Page 472: ...ome reason PRPSTATUS provides redundant communication over the station bus running IEC 61850 8 1 protocol The redundant communication uses port L1_A and L1_B on the COM3 module Switch A Switch B 1 2 D...

Page 473: ...onfiguration ETHLAN1_AB where OperationMode can be set to Off NonRedundant A or PRP A B The redundant communication will be activated when this parameter is set to PRP A B The ETHLAN1_AB in the Parame...

Page 474: ...IEC13000008 1 en vsd IEC13000008 V1 EN Figure 223 PST screen OperationMode is set to PRP A B Section 16 1MRK 506 334 UUS A Station communication 468 Application manual...

Page 475: ...e possible faults through a hardware contact on the power supply module and or through the software communication Internal events are generated by the built in supervisory functions The supervisory fu...

Page 476: ...ime synchronization TIMESYNCHGE N Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Time system summer time begins DSTBEGIN Function description IEC...

Page 477: ...ine ends can be compared during evaluation In the IED the internal time can be synchronized from a number of sources SNTP IRIG B DNP IEC60870 5 103 Micro SCADA OPC server should not be used as a time...

Page 478: ...n is needed for example when no other synchronization is available First set the IED to be synchronized via IEC 60870 5 103 either from IED Configuration Time Synchronization TIMESYNCHGEN 1 in PST or...

Page 479: ...se masters that are really bad in time sync the EvalTimeAccuracy can be set to Disabled According to the standard the Bad Time flag is reported when synchronization has been omitted in the protection...

Page 480: ...selected with configured input to the function block ACTVGRP The parameter MaxNoSetGrp defines the maximum number of setting groups in use to switch between Only the selected number of setting groups...

Page 481: ...5 2 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 perform inadvertent IE...

Page 482: ...nput If such a situation would occur in spite of these precautions then please contact the local ABB representative for remedial action 17 5 3 Setting guidelines The Change lock function CHNGLCK does...

Page 483: ...Product identifiers The following identifiers are available IEDProdType Describes the type of the IED like REL REC or RET Example REL650 ProductVer Describes the product version Example 1 2 3 1 is the...

Page 484: ...g has no specific meaning except that it is used for internal identification purposes within ABB ProductionDate states the production date in the YYYY MM_DD format 17 8 Primary system values PRIMVAL 1...

Page 485: ...og signals acquired phase angle RMS value frequency and frequency derivates and so on 244 values in total Besides the block group name the analog inputs type voltage or current and the analog input na...

Page 486: ...to negate the 3ph signal it is possible to choose to negate only the phase signals Negate3Ph only the neutral signal NegateN or both Negate3Ph N MinValFreqMeas The minimum value of the voltage for wh...

Page 487: ...n with adaptive frequency tracking with one reference selected for all instances In practice each instance can be adapted to the needs of the actual application The adaptive frequency tracking is need...

Page 488: ...ence For task time group 2 this gives the following settings SMAI_20_2 2 DFTReference ExternalDFTRef to use DFTSPFC input as reference SMAI_20_7 1 DFTRefExtOut ExternalDFTRef even if the output SPCFOU...

Page 489: ...AL 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 power and it is possible to have six...

Page 490: ...ATHCHCK 17 12 2 Application To safeguard the interests of our customers both the IED and the tools that are accessing the IED are protected by means of authorization handling The authorization handli...

Page 491: ...er created an attempt to log on will display a message box No user defined If one user leaves the IED without logging off then after the timeout set in Main menu Configuration HMI Screen SCREEN 1 elap...

Page 492: ...sword three times that user will be blocked for ten minutes before a new attempt to log in can be performed The user will be blocked from logging in both from the local HMI and PCM600 However other us...

Page 493: ...e primary functionality of the device All inbound network traffic will be quota controlled so that too heavy network loads can be controlled Heavy network load might for instance be the result of malf...

Page 494: ...488...

Page 495: ...magnetic core CTs are usually specified and manufactured according to some international or national standards which specify different protection classes as well There are many different standards an...

Page 496: ...function phase to ground phase to phase and three phase faults have been tested for different relevant fault positions for example close in forward and reverse faults zone 1 reach faults internal and...

Page 497: ...the circuit For ground faults the loop includes the phase and neutral wire normally twice the resistance of the single secondary wire For three phase faults the neutral current is zero and it is just...

Page 498: ...ary e m f requirements With regard to saturation of the current transformer all current transformers of high remanence and low remanence type that fulfill the requirements on the rated equivalent limi...

Page 499: ...mpedance grounded systems the resistance of the single secondary wire always can be used SR The burden of an IED current input channel VA SR 0 010 VA channel for Ir 1 A and Sr 0 250 VA channel for Ir...

Page 500: ...ive time phase and residual overcurrent protection The CTs must have a rated equivalent secondary e m f Eal that is larger than or equal to the required secondary e m f Ealreq below sn R al alreq CT L...

Page 501: ...he rated primary CT current A Isn The rated secondary CT current A In The nominal current of the protection IED A RCT The secondary resistance of the CT W RL The resistance of the secondary cable and...

Page 502: ...current input channel VA Sr 0 010 VA channel for Ir 1 A and Sr 0 250 VA channel for Ir 5 A 18 1 7 Current transformer requirements for CTs according to other standards All kinds of conventional magne...

Page 503: ...Eknee that fulfills the following 1 Old Calculated S TD S TD S EQUATION1893 ANSI V1 EN Equation 186 18 1 7 3 Current transformers according to ANSI IEEE Current transformers according to ANSI IEEE ar...

Page 504: ...7 110 2007 IEEE Guide for the Application of Current Transformers Used for Protective Relaying Purposes 18 2 Voltage transformer requirements The performance of a protection function will depend on th...

Page 505: ...task or at least equipped with a real time operating system that is not a PC with SNTP server software The SNTP server should be stable that is either synchronized from a stable source like GPS or lo...

Page 506: ...500...

Page 507: ...ection BFOC 2 5 Bayonet fibre optic connector BFP Breaker failure protection BI Binary input BOS Binary outputs status BR External bistable relay BS British Standards CB Circuit breaker CCITT Consulta...

Page 508: ...rojects Agency The US developer of the TCP IP protocol etc DBDL Dead bus dead line DBLL Dead bus live line DC Direct current DFC Data flow control DFT Discrete Fourier transform DHCP Dynamic Host Conf...

Page 509: ...nication interface module with carrier of GPS receiver module GDE Graphical display editor within PCM600 GI General interrogation command GIS Gas insulated switchgear GOOSE Generic object oriented sub...

Page 510: ...referred to as instances of that function One instance of a function is identical to another of the same kind but has a different number in the IED user interfaces The word instance is sometimes defin...

Page 511: ...term used to describe how the relay behaves during a fault condition For example a distance relay is overreaching when the impedance presented to it is smaller than the apparent impedance to the faul...

Page 512: ...rding to standard IEC 61850 SDU Service data unit SMA connector Subminiature version A A threaded connector with constant impedance SMT Signal matrix tool within PCM600 SMS Station monitoring system S...

Page 513: ...is module transforms currents and voltages taken from the process into levels suitable for further signal processing TYP Type identification UMT User management tool Underreach A term used to describe...

Page 514: ...n the phonetic alphabet stands for Z which stands for longitude zero UV Undervoltage WEI Weak end infeed logic VT Voltage transformer 3IO Three times zero sequence current Often referred to as the res...

Page 515: ...509...

Page 516: ...ce ABB AB does not accept any responsibility whatsoever for potential errors or possible lack of information in this document We reserve all rights in this document and in the subject matter and illus...

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ABB REL650 series, Applications Manual

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Summary of Contents for REL650 series

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