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To achieve a more correct regulation, an adjustment to a value of

j

2 slightly less

than -90° (2 – 4° less) can be made.

The effect of changing power factor of the load will be that

j

2 will no longer be

close to -90° resulting in U

L

being smaller or greater than U

B

if the ratio Rline/

Xline is not adjusted.

shows an example of this where the settings of

Rline

and

Xline

for

j

=

11° from figure

has been applied with a different value of

j

(

j

= 30°).

U

B

jI

T

*

Xline

U

L

Xline

Rline

Zline

I

T

I

T

*

Rline

j=30

0

j

1

j

2

D

U

j

1

=11

0

-90

0

=-79

0

en06000630.vsd

IEC06000630 V1 EN-US

Figure 136:

Transformer with reverse reactance regulation poorly adjusted to

the power factor

As can be seen in figure

, the change of power factor has resulted in an increase

of

j

2 which in turn causes the magnitude of U

L

to be greater than U

B

. It can also

be noted that an increase in the load current aggravates the situation, as does also
an increase in the setting of Zline (

Rline

and

Xline

).

Apparently the ratio Rline/Xline according to equation

, that is the value of

j

1

must be set with respect to the power factor, also meaning that the reverse
reactance method should not be applied to systems with varying power factor.

The setting of

Xline

gives the sensitivity of the parallel regulation. If

Xline

is set

too low, the transformers will not pull together and a run away tap situation will
occur. On the other hand, a high setting will keep the transformers strongly
together with no, or only a small difference in tap position, but the voltage
regulation as such will be more sensitive to a deviation from the anticipated power
factor. A too high setting of

Xline

can cause a hunting situation as the transformers

will then be prone to over react on deviations from the target value.

There is no rule for the setting of

Xline

such that an optimal balance between

control response and susceptibility to changing power factor is achieved. One way
of determining the setting is by trial and error. This can be done by setting e.g.

Section 12

1MRK 506 375-UEN A

Control

326

Railway application RER670 2.2 IEC

Application manual

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Summary of Contents for RELION RER670

Page 1: ...RELION 670 SERIES Railway application RER670 Version 2 2 IEC Application manual ...

Page 2: ......

Page 3: ...Document ID 1MRK 506 375 UEN Issued October 2017 Revision A Product version 2 2 1 Copyright 2017 ABB All rights reserved ...

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

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

Page 6: ...nd concerning electrical equipment for use within specified voltage limits Low voltage directive 2006 95 EC This conformity is the result of tests conducted by ABB in accordance with the product standard EN 60255 26 for the EMC directive and with the product standards EN 60255 1 and EN 60255 27 for the low voltage directive The product is designed in accordance with the international standards of ...

Page 7: ... 3 Configuration 37 Description of configuration RER670 37 Introduction 37 Description of configuration transformer protection application in compensated networks 38 Description of configuration transformer protection application in solidly earthed networks 39 Description of configuration line protection application in compensated networks 40 Description of configuration line protection applicatio...

Page 8: ...cations 59 Configuration example 1 60 Configuration example 2 61 Configuration example 3 62 Section 5 Local HMI 65 Display 66 LEDs 68 Keypad 69 Local HMI functionality 71 Protection and alarm indication 71 Parameter management 72 Front communication 73 Section 6 Differential protection 75 Low impedance restricted earth fault protection REFPDIF 75 Identification 75 Application 75 Transformer windin...

Page 9: ...ems 124 Setting examples 135 Compensated earthed systems 135 Solidly earthed systems 143 Underimpedance protection for railway transformers ZGTPDIS 150 Identification 150 Application 150 Zone 1 operation 152 Zone 2 operation 152 Zone 3 operation 152 Setting guidelines 152 Catenary Protection 154 Wrong phase coupling protection 155 Section 8 Current protection 157 Instantaneous phase overcurrent pr...

Page 10: ...n 184 Setting guideline 186 Breaker failure protection CCRWRBRF 187 Application 187 Setting guidelines 188 Overcurrent protection with binary release BRPTOC 190 Identification 190 Application 191 Setting guidelines 191 Tank overcurrent protection TPPIOC 191 Identification 191 Application 192 Setting guidelines 194 Section 9 Voltage protection 195 Two step undervoltage protection U2RWPTUV 195 Ident...

Page 11: ...n 205 Application 205 Setting guidelines 205 Section 11 Secondary system supervision 207 Current circuit supervision CCSSPVC 207 Identification 207 Application 207 Setting guidelines 208 Fuse failure supervision FRWSPVC 208 Identification 208 Application 208 Setting guidelines 209 DeltaU and DeltaI detection 209 Dead line detection 210 Sudden current and voltage change 210 Section 12 Control 211 S...

Page 12: ...tiation 228 Thermal overload protection holding the auto recloser back230 Setting guidelines 230 Configuration 230 Auto recloser settings 234 Apparatus control APC 237 Application 237 Bay control QCBAY 241 Switch controller SCSWI 242 Switches SXCBR SXSWI 243 Proxy for signals from switching device via GOOSE XLNPROXY 244 Reservation function QCRSV and RESIN 246 Interaction between modules 248 Setti...

Page 13: ...r arrangement 275 Signals in 1 1 2 breaker arrangement 278 Interlocking for busbar earthing switch BB_ES 279 Application 279 Signals in single breaker arrangement 279 Signals in double breaker arrangement 283 Signals in 1 1 2 breaker arrangement 284 Interlocking for double CB bay DB 285 Application 285 Configuration setting 286 Interlocking for 1 1 2 CB BH 287 Application 287 Configuration setting...

Page 14: ...ication 337 Setting guidelines 339 Transformer energizing control XENCPOW 340 Identification 340 Application 340 Setting guidelines 341 Setting examples 342 Section 13 Scheme communication 343 Scheme communication logic for distance or overcurrent protection ZCPSCH 343 Identification 343 Application 343 Blocking schemes 344 Permissive schemes 345 Intertrip scheme 347 Setting guidelines 348 Blockin...

Page 15: ...etting guidelines 356 Current reversal 356 Weak end infeed 357 Section 14 Logic 359 Tripping logic SMPPTRC 359 Identification 359 Application 359 Tripping 359 Lock out 360 Example of directional data 360 Blocking of the function block 362 Setting guidelines 362 Trip matrix logic TMAGAPC 362 Identification 362 Application 362 Setting guidelines 363 Logic for group alarm ALMCALH 363 Identification 3...

Page 16: ...n 371 Integer to Boolean 16 conversion with logic node representation ITBGAPC 372 Identification 372 Application 372 Elapsed time integrator with limit transgression and overflow supervision TEIGAPC 373 Identification 373 Application 373 Setting guidelines 374 Comparator for integer inputs INTCOMP 374 Identification 374 Application 374 Setting guidelines 375 Setting example 375 Comparator for real...

Page 17: ...ines 395 Disturbance report DRPRDRE 396 Identification 396 Application 396 Setting guidelines 397 Recording times 400 Binary input signals 400 Analog input signals 401 Sub function parameters 401 Consideration 402 Logical signal status report BINSTATREP 403 Identification 403 Application 403 Setting guidelines 404 Limit counter L4UFCNT 404 Identification 404 Application 404 Setting guidelines 405 ...

Page 18: ...9 Setting guidelines 420 Routes 420 Application 420 Setting guidelines 420 Section 18 Station communication 421 Communication protocols 421 IEC 61850 8 1 communication protocol 421 Application IEC 61850 8 1 421 Setting guidelines 423 Horizontal communication via GOOSE 423 Sending data 423 Receiving data 424 IEC UCA 61850 9 2LE communication protocol 425 Introduction 425 Setting guidelines 427 Spec...

Page 19: ...ication 452 Section 19 Remote communication 453 Binary signal transfer 453 Identification 453 Application 453 Communication hardware solutions 454 Setting guidelines 455 Section 20 Security 459 Authority status ATHSTAT 459 Application 459 Self supervision with internal event list INTERRSIG 459 Application 459 Change lock CHNGLCK 460 Application 460 Denial of service SCHLCCH RCHLCCH 461 Application...

Page 20: ...nal matrix for mA inputs SMMI 468 Application 468 Setting guidelines 468 Signal matrix for analog inputs SMAI 468 Application 468 Frequency values 469 Setting guidelines 469 Test mode functionality TESTMODE 470 Application 470 IEC 61850 protocol test mode 470 Setting guidelines 471 Time synchronization TIMESYNCHGEN 471 Setting guidelines 471 System time 472 Synchronization 472 Process bus IEC UCA ...

Page 21: ...transformers according to IEC 61869 2 class PX PXR and old IEC 60044 6 class TPS and old British Standard class X 483 Current transformers according to ANSI IEEE 483 Voltage transformer requirements 484 SNTP server requirements 485 PTP requirements 485 Sample specification of communication requirements for the protection and control terminals in digital telecommunication networks 485 IEC UCA 61850...

Page 22: ...16 ...

Page 23: ...provide assistance for calculating settings 1 2 Intended audience GUID C9B8127F 5748 4BEA 9E4F CC762FE28A3A v11 This manual addresses the protection and control engineer responsible for planning pre engineering and engineering The protection and control engineer must be experienced in electrical power engineering and have knowledge of related technology such as protection schemes and communication...

Page 24: ...he project structure The manual also recommends a sequence for the engineering of protection and control functions LHMI functions as well as communication engineering for IEC 60870 5 103 IEC 61850 DNP3 LON and SPA The installation manual contains instructions on how to install the IED The manual provides procedures for mechanical and electrical installation The chapters are organized in the chrono...

Page 25: ...setting parameters and technical data sorted per function The manual can be used as a technical reference during the engineering phase installation and commissioning phase and during normal service The communication protocol manual describes the communication protocols supported by the IED The manual concentrates on the vendor specific implementations The point list manual describes the outlook an...

Page 26: ...ition 2 1MRK 511 393 UEN Communication protocol manual LON 1MRK 511 395 UEN Communication protocol manual SPA 1MRK 511 396 UEN Point list manual DNP3 1MRK 511 397 UUS Accessories guide 1MRK 514 012 BEN Cyber security deployment guideline 1MRK 511 399 UEN Connection and Installation components 1MRK 513 003 BEN Test system COMBITEST 1MRK 512 001 BEN Application guide Communication set up 1MRK 505 38...

Page 27: ...ent may result in degraded process performance leading to personal injury or death It is important that the user fully complies with all warning and cautionary notices 1 4 2 Document conventions GUID 96DFAB1A 98FE 4B26 8E90 F7CEB14B1AB6 v6 Abbreviations and acronyms in this manual are spelled out in the glossary The glossary also contains definitions of important terms Push button navigation in th...

Page 28: ...ic diagram and continue in another diagram have the suffix cont Illustrations are used as an example and might show other products than the one the manual describes The example that is illustrated is still valid 1 5 IEC 61850 edition 1 edition 2 mapping GUID C5133366 7260 4C47 A975 7DBAB3A33A96 v4 Function block names are used in ACT and PST to identify functions Respective function block names of...

Page 29: ...VGAPC O2RWPTOV GEN2LLN0 O2RWPTOV PH1PTRC O2RWPTOV PH1PTRC PHPIOC PHPIOC PHPIOC QCBAY QCBAY BAY LLN0 QCRSV QCRSV QCRSV RCHLCCH RCHLCCH RCHLCCH REFPDIF REFPDIF REFPDIF ROV2PTOV GEN2LLN0 PH1PTRC ROV2PTOV PH1PTRC ROV2PTOV RWRFLO RWRFLO SAPTUF SAPTUF SAPTUF SCHLCCH SCHLCCH SCHLCCH SCILO SCILO SCILO SCSWI SCSWI SCSWI SDEPSDE SDEPSDE SDEPSDE SDEPTOC SDEPTOV SDEPTRC SESRSYN RSY1LLN0 AUT1RSYN MAN1RSYN SYNR...

Page 30: ...GGIO TEILGAPC TEILGGIO TEILGAPC TMAGAPC TMAGGIO TMAGAPC TPPIOC TPPIOC TPPIOC U2RWPTUV GEN2LLN0 PH1PTRC U2RWPTUV PH1PTRC U2RWPTUV VMMXU VMMXU VMMXU VMSQI VMSQI VMSQI VNMMXU VNMMXU VNMMXU VSGAPC VSGGIO VSGAPC WRNCALH WRNCALH WRNCALH XENCPOW XENCPOW ZCPSCH ZCPSCH ZCPSCH ZCRWPSCH ZCRWPSCH ZCRWPSCH ZCVPSOF ZCVPSOF ZCVPSOF ZGTPDIS ZGTLLN0 ZGPDIS ZGPTRC ZGPDIS ZGPTRC ZRWPDIS PSRWPDIS ZRWPDIS ZRWPTRC Sect...

Page 31: ... after faults on the transmission line The transformer protection covers transformer differential protection for two phase to two phase as well as two phase to one phase transformers Besides the transformer differential protection a wide range of backup functions are available A very fast transformer tank protection helps to avoid damages in case of short circuits to the transformer tank The trans...

Page 32: ...e packages A50 and B60 contain all main and backup protection functions for transformer or line protection Only one of them can be ordered for a single IED Both packages can be extended with additional functions like synchrocheck H51 and autoreclosure H52 Also full control functionality can be added to these packages The package H50 describes a control IED which can be extended with synchrocheck a...

Page 33: ...ction PHPIOC 50 Instantaneous phase overcurrent protection 2 C61 D2PTOC 51_67 Directional phase overcurrent protection two steps 8 C61 EFRWPIOC 50N Instantaneous residual overcurrent protection 1 C61 EF2PTOC 51N 67N1 Directional residual overcurrent protection two steps 3 C61 SDEPSDE 67N Sensitive directional residual overcurrent and power protection 1 C61 LPTTR 26 Thermal overload protection one ...

Page 34: ...Y Bay control 1 LOCREM Handling of LR switch positions 1 LOCREMCTRL LHMI control of PSTO 1 SXCBR Circuit breaker 6 TCMYLTC 84 Tap changer control and supervision 6 binary inputs 1 H53 TCLYLTC 84 Tap changer control and supervision 32 binary inputs 1 H54 SLGAPC Logic rotating switch for function selection and LHMI presentation 15 VSGAPC Selector mini switch 30 DPGAPC Generic communication function ...

Page 35: ...ic for group indication 5 AND GATE INV LLD OR PULSETIMER RSMEMORY SRMEMORY TIMERSET XOR Basic configurable logic blocks see Table 3 40 420 ANDQT INDCOMBSPQT INDEXTSPQT INVALIDQT INVERTERQT ORQT PULSETIMERQT RSMEMORYQT SRMEMORYQT TIMERSETQT XORQT Configurable logic blocks Q T see Table 6 1 L01 FXDSIGN Fixed signal function block 1 B16I Boolean to integer conversion 16 bit 18 BTIGAPC Boolean to inte...

Page 36: ...nstances SCILO Interlocking 10 BB_ES 3 A1A2_BS 2 A1A2_DC 3 ABC_BC 1 BH_CONN 1 BH_LINE_A 1 BH_LINE_B 1 DB_BUS_A 1 DB_BUS_B 1 DB_LINE 1 ABC_LINE 1 AB_TRAFO 1 SCSWI Switch controller 10 SXSWI Circuit switch 9 QCRSV Apparatus control 2 RESIN1 1 RESIN2 59 POS_EVAL Evaluation of position indication 10 XLNPROXY Proxy for signals from switching device via GOOSE 12 GOOSEXLNRCV GOOSE function block to recei...

Page 37: ...IN2 59 POS_EVAL Evaluation of position indication 15 XLNPROXY Proxy for signals from switching device via GOOSE 20 GOOSEXLNRCV GOOSE function block to receive a switching device 20 Table 6 Total number of instances for configurable logic blocks Q T Configurable logic blocks Q T Total number of instances ANDQT 120 INDCOMBSPQT 20 INDEXTSPQT 20 INVALIDQT 22 INVERTERQT 120 ORQT 120 PULSETIMERQT 40 RSM...

Page 38: ...phase earth 6 AISVBAS General service value presentation of analog inputs 1 EVENT Event function 14 DRPRDRE A4RADR B1RBDR B22RBDR Disturbance report 1 SPGAPC Generic communication function for Single Point indication 64 SP16GAPC Generic communication function for Single Point indication 16 inputs 16 MVGAPC Generic communication function for measured values 24 BINSTATREP Logical signal status repor...

Page 39: ...ng PCFCNT Pulse counter logic 16 ETPMMTR Function for energy calculation and demand handling 6 2 5 Communication GUID 5F144B53 B9A7 4173 80CF CD4C84579CB5 v15 IEC 61850 or function name ANSI Function description Railway RER670 Station communication LONSPA SPA SPA communication protocol 1 ADE LON communication protocol 1 HORZCOMM Network variables via LON 1 RS485GEN RS485 1 DNPGEN DNP3 0 communicat...

Page 40: ...cal device information 1 PCMACCS IED configuration protocol 1 SECALARM Component for mapping security events on protocols such as DNP3 and IEC103 1 FSTACCS Field service tool access 1 IEC 61850 9 2 Process bus communication 8 merging units 1 P30 ACTIVLOG Activity logging 1 ALTRK Service tracking 1 PRP IEC 62439 3 Parallel redundancy protocol 1 P23 HSR IEC 62439 3 High availability seamless redunda...

Page 41: ...ak end infeed logic for distance protection 1 B60 ECPSCH 85 Scheme communication logic for residual overcurrent protection 1 B60 ECRWPSCH 85 Current reversal and weak end infeed logic for residual overcurrent protection 1 B60 2 6 Basic IED functions GUID C8F0E5D2 E305 4184 9627 F6B5864216CA v12 Table 8 Basic IED functions IEC 61850 or function name Description INTERRSIG Self supervision with inter...

Page 42: ...ervision ALTIM Time management COMSTATUS Protocol diagnostic Table 9 Local HMI functions IEC 61850 or function name ANSI Description LHMICTRL Local HMI signals LANGUAGE Local human machine language SCREEN Local HMI Local human machine screen behavior FNKEYTY1 FNKEYTY5 FNKEYMD1 FNKEYMD5 Parameter setting function for HMI in PCM600 LEDGEN General LED indication part for LHMI OPENCLOSE_LED LHMI LEDs ...

Page 43: ...cial logic can be developed such as logic for automatic opening of disconnectors and closing of ring bays automatic load transfer from one busbar to the other and so on On request ABB is available to support the configuration work either directly or to do the design checking Example configurations are given in following sections as a guide what can be achieved using RER670 1MRK 506 375 UEN A Secti...

Page 44: ...W2 T1P PDIF 87T Id I Transducer D2 PTOC 51_67 2 2I D2 PTOC 51_67 2 2I L1 nicht benutzt C MMXU MET I SA PTUF 81 f L2 CT L2 CV MMXN MET P Q TP PIOC 64 IN BF Prot C MMXU MET I D2 PTOC 51_67 2 2I D2 PTOC 51_67 2 2I FRW SPVC U I CCRW RBRF 50BF 2I BF EF2 PTOC 51N_67N 2 IN CV MMXN MET P Q I ASY SA PTUF 81 f U2RW PTUV 27 2 2U V MMXU MET U V MSQI MET Usqi VN MMXU MET UN SMP PTRC 94 1 0 SMP PTRC 94 1 0 SMP ...

Page 45: ... O2RW PTOV 59 2 2U Q CBAY 3 Control S SIML 71 W2 QA1 L2 VT L1 L2 ZGT PDIS 21 Z C MSQI MET Isqi W1 W2 T1P PDIF 87T Id I Transducer D2 PTOC 51_67 2 2I C MMXU MET I SA PTUF 81 f L2 CT L2 CV MMXN MET P Q TP PIOC 64 IN BF Logic C MMXU MET I D2 PTOC 51_67 2 2I FRW SPVC U I CCRW RBRF 50BF 2I BF EF2 PTOC 51N_67N 2 IN CV MMXN MET P Q I ASY SA PTUF 81 f U2RW PTUV 27 2 2U V MMXU MET U V MSQI MET Usqi VN MMXU...

Page 46: ... V MSQI MET Usqi V MMXU MET U CV MMXN MET P Q S SCBR FRW SPVC U I EF2 PTOC 51N 67N 2 IN L PTTR 26 θ CCRW RBRF 50BF 2I BF ZRW PDIS 21 2Z ZCV PSOF Temp Sensor Other Functions available from the function library Optional functions ROV2 PTOV 59N 2 U0 S CSWI 3 Control S XSWI 3 Control S XCBR 3 Control Q CRSV 3 Control S CILO 3 Control PH PIOC 50 2I EFRW PIOC 50N IN O2RW PTOV 59 2 2U U2RW PTUV 27 2 2U Q...

Page 47: ...sqi V MMXU MET U CV MMXN MET P Q S SCBR FRW SPVC U I EF2 PTOC 51N 67N 2 IN L PTTR 26 θ CCRW RBRF 50BF 2I BF ZRW PDIS 21 2Z ZCV PSOF Other Functions available from the function library Optional functions ROV2 PTOV 59N 2 U0 S CSWI 3 Control S XSWI 3 Control S XCBR 3 Control Q CRSV 3 Control S CILO 3 Control PH PIOC 50 2I EFRW PIOC 50N IN O2RW PTOV 59 2 2U U2RW PTUV 27 2 2U Q CBAY 3 Control S SIML 71...

Page 48: ...42 ...

Page 49: ...haseAngleRef can be defined to facilitate service values reading This TRM channel s phase angle will always be forced to zero degrees and remaining analog channel s phase angle information will be shown in relation to this channel During testing and commissioning of the IED the reference channel can be changed to facilitate testing and service values reading The IED has the ability to receive anal...

Page 50: ...must be set in the IED The convention of the directionality is defined as follows A positive value of current power and so on means that the quantity has the direction into the object and a negative value means direction out from the object For directional functions the direction into the object is defined as Forward and the direction out from the object is defined as Reverse See Figure 6 A positi...

Page 51: ...ter CTStarPoint with Transformer as reference object Correct setting is ToObject Setting of current input Set parameter CTStarPoint with Line as reference object Correct setting is FromObject IEC05000753 IEC05 000753 1 en Origin al 1 vsd Is Is Ip Ip Ip IED IED IEC05000753 V2 EN US Figure 7 Example how to set CTStarPoint parameters in the IED Figure 7 shows the normal case where the objects have th...

Page 52: ...000460 V2 EN US Figure 8 Example how to set CTStarPoint parameters in the IED This example is similar to example 1 but here the transformer is feeding just one line and the line protection uses the same CT as the transformer protection does The CT direction is set with different reference objects for the two IEDs though it is the same current from the same CT that is feeding the two IEDs With thes...

Page 53: ...rence object This means that the direction Forward for the line protection is towards the transformer To look towards the line the direction of the directional functions of the line protection must be set to Reverse The direction Forward Reverse is related to the reference object that is the transformer in this case If the IED has sufficient number of analog current inputs an alternative solution ...

Page 54: ...ith Line as reference object Correct setting is FromObject IED IEC05000462 V2 EN US Figure 10 Example how to set CTStarPoint parameters in the IED 4 2 2 4 Examples on how to connect configure and set CT inputs for most commonly used CT connections SEMOD55055 296 v7 Figure 11 defines the marking of current transformer terminals commonly used around the world In the SMAI function block you have to s...

Page 55: ...o cases the CT polarity marking is correct It shall be noted that depending on national standard and utility practices the rated secondary current of a CT has typically one of the following values 1A 5A However in some cases the following rated secondary currents are used as well 2A 10A The IED fully supports all of these rated secondary values It is recommended to use 1A rated CT input into the I...

Page 56: ...136 V1 EN US Figure 12 Star connected two phase CT set with star point towards the protected object Where 1 Shows how to connect two individual phase currents from a star connected two phase CT set to the two CT inputs of the IED 2 The current inputs are located in the TRM It shall be noted that for all these current inputs the following setting values shall be entered for the example shown in Fig...

Page 57: ... AI1 AI2 AI3 AI4 are the output signals from the SMAI function block which contain the fundamental frequency phasors and the harmonic content of the corresponding input channels of the preprocessing function block AIN is the signal which contains the fundamental frequency phasors and the harmonic content of the neutral quantity In this example GRP2N is not connected so this data is calculated by t...

Page 58: ...e 1 Shows how to connect two individual phase currents from a star connected two phase CT set to the two CT inputs of the IED 2 Shows how to connect residual neutral current from the two phase CT set to the fourth input in the IED It shall be noted that if this connection is not made the IED will still calculate this current internally by vectorial summation of the two individual phase currents 3 ...

Page 59: ...ero sequence quantities by using the fundamental frequency phasors of the first two input channels channel one taken as reference for sequence quantities These calculated values are then available for all built in protection and control functions within the IED which are connected to this preprocessing function block in the configuration tool For this application most of the preprocessing settings...

Page 60: ...unction block 4 4 is a Preprocessing block that has the task to digitally filter the connected analog inputs and calculate values The calculated values are then available for all built in protection and control functions within the IED which are connected to this preprocessing function block 4 2 3 Relationships between setting parameter Base Current CT rated primary current and minimum pickup of a...

Page 61: ...e minimum pickup of any instantaneous protection function e g differential restricted earth fault distance instantaneous overcurrent etc shall under no circumstances be less than 4 of the used IED CT input rating i e 1A or 5A This corresponds to 40mA secondary for IED 1A rated inputs and to 200mA secondary for IED 5A rated inputs used by the function This shall be individually verified for all cur...

Page 62: ...r phase to phase connected VTs It shall be noted that depending on national standard and utility practices the rated secondary voltage of a VT has typically one of the following values 100 V 110 V The IED fully supports all of these values and most of them will be shown in the following examples 4 2 4 3 Examples on how to connect a two phase to earth connected VT to the IED SEMOD55055 87 v9 Figure...

Page 63: ...ourth that is residual input channel of the preprocessing block is not connected in SMT tool Thus the preprocessing block will automatically calculate 2Uo inside by vectorial sum from the two phase to earth voltages connected to the first two input channels of the same preprocessing block Alternatively the fourth input channel can be connected to open delta VT input as shown in Figure 18 5 is a Pr...

Page 64: ... to the sum of the two phase voltages Thus the secondary windings of open deltaVTs may have a secondary rating of 110 2V Figure 18 gives overview of required actions by the user in order to make this measurement available to the built in protection and control functions within the IED as well L1 IED L2 2Uo 132 2 100 2 kV V 132 2 100 2 kV V 1 2 4 3 5 IEC16000152 1 en vsdx SMAI2 BLOCK GRP2L1 GRP2L2 ...

Page 65: ... calculated values are then available for all built in protection and control functions within the IED which are connected to this preprocessing function block in the configuration tool For this application most of the preprocessing settings can be left to the default values 4 2 5 Example of analogue configuration for railway applications GUID 24D444FE 4930 4519 BADF E11AD2CD224A v1 Protection and...

Page 66: ... other annotations are often used as given in the following list IL1 is current in phase L1 catenary current for AT system IL2 is current in phase L2 negative feeder current for AT system UL1 is phase L1 voltage catenary to ground voltage for AT system UL2 is phase L2 voltage negative feeder to ground voltage for AT system When configuration shown in Figure 19 is made the preprocessing block will ...

Page 67: ... shall not be used in such installations All other backup protection and measurement functions can be used 4 2 5 2 Configuration example 2 GUID DB95191C 0313 436B 8800 1E3B021FD1A8 v1 In HV two phase railway supply systems grounded via Petersen Coil sometimes only one phase to phase voltage may be available instead of two single phase to ground voltages An example on how to configure the IED analo...

Page 68: ...llowing formulas UL1 UL2 UL1L2 2 Phase to phase current value i e IL1L2 IL1 IL2 will be internally calculated Phase to phase voltage value i e UL1L2 will be directly measured from the TRM Positive sequence quantities i e U1 UL1 UL2 2 and I1 IL1 IL2 2 will be internally calculated Zero sequence current quantity i e 2Io IL1 IL2 will be internally calculated Zero sequence voltage quantity i e 2Uo wil...

Page 69: ... available analogue input signals i e UL1 and IL1 the preprocessing block will perform the following Quantities for the first phase i e UL1 and IL1 will be directly measured from the TRM Quantities for the second phase i e UL2 and IL2 will be forced to zero value Phase to phase values i e UL1L2 and IL1L2 will be directly measured from the TRM but they will have identical values as quantities for t...

Page 70: ...64 ...

Page 71: ...0239 V3 EN US Figure 22 Local human machine interface The LHMI of the IED contains the following elements Keypad Display LCD LED indicators Communication port for PCM600 1MRK 506 375 UEN A Section 5 Local HMI Railway application RER670 2 2 IEC 65 Application manual ...

Page 72: ...iew depends on the character size and the view that is shown The display view is divided into four basic areas IEC15000270 1 en vsdx IEC15000270 V1 EN US Figure 23 Display layout 1 Path 2 Content 3 Status 4 Scroll bar appears when needed The function key button panel shows on request what actions are possible with the function buttons Each function button has a LED indication that can be used as a...

Page 73: ...on LED pages are available IEC13000240 1 en vsd GUID 5157100F E8C0 4FAB B979 FD4A971475E3 V1 EN US Figure 25 Indication LED panel The function button and indication LED panels are not visible at the same time Each panel is shown by pressing one of the function buttons or the Multipage button Pressing the ESC button clears the panel from the display Both panels have a dynamic width that depends on ...

Page 74: ...e LHMI or PCM600 Information panels for the indication LEDs are shown by pressing the Multipage button Pressing that button cycles through the three pages A lit or un acknowledged LED is indicated with a highlight Such lines can be selected by using the Up Down arrow buttons Pressing the Enter key shows details about the selected LED Pressing the ESC button exits from information pop ups as well a...

Page 75: ...e in different views or menus The push buttons are also used to acknowledge alarms reset indications provide help and switch between local and remote control mode The keypad also contains programmable push buttons that can be configured either as menu shortcut or control buttons 1MRK 506 375 UEN A Section 5 Local HMI Railway application RER670 2 2 IEC 69 Application manual ...

Page 76: ...h object control navigation and command push buttons and RJ 45 communication port 1 5 Function button 6 Close 7 Open 8 Escape 9 Left 10 Down 11 Up 12 Right 13 Key 14 Enter 15 Remote Local 16 Uplink LED 17 Not in use 18 Multipage 19 Menu Section 5 1MRK 506 375 UEN A Local HMI 70 Railway application RER670 2 2 IEC Application manual ...

Page 77: ... supply voltage is disconnected On Normal operation Flashing Internal fault has occurred Table 11 Start LED yellow LED state Description Off Normal operation On A protection function has started and an indication message is displayed The start indication is latching and must be reset via communication LHMI or binary input on the LEDGEN component To open the reset menu on the LHMI press Flashing Th...

Page 78: ...e The indication has been acknowledged but the activation signal is still on LatchedAck S F sequence The activation signal is on or it is off but the indication has not been acknowledged LatchedReset S sequence The activation signal is on or it is off but the indication has not been acknowledged Flashing Follow F sequence The activation signal is on LatchedAck F S sequence The activation signal is...

Page 79: ...t and green indicator LED 1 RJ 45 connector 2 Green indicator LED The default IP address for the IED front port is 10 1 150 3 and the corresponding subnetwork mask is 255 255 254 0 It can be set through the local HMI path Main menu Configuration Communication Ethernet configuration FRONT port AP_FRONT Do not connect the IED front port to a LAN Connect only a single local PC with PCM600 to the fron...

Page 80: ...74 ...

Page 81: ...y the restricted earth fault protection The only requirement is that the power transformer winding is connected to earth in the star point in case of star connected windings The low impedance restricted earth fault protection REFPDIF is a winding protection function It protects the power transformer winding against faults involving earth Observe that single phase to earth faults are the most commo...

Page 82: ...in protection of the transformer winding for all faults involving earth 6 1 2 1 Transformer winding solidly earthed M13048 3 v10 The most common application is on a solidly earthed transformer winding The connection is shown in Figure 29 IEC16000117 1 en vsdx REFPDIF I2P ISI IdN I Protected winding IEC16000117 V1 EN US Figure 29 Connection of the low impedance Restricted earth fault function REFPD...

Page 83: ...is temporary arranged among two CTs during de icing operation of the catenary contact line wires Single phase differential protection applied across one winding i e either over one single phase transformer winding or a generator winding 6 1 3 Setting guidelines IP14942 1 v1 6 1 3 1 Setting and configuration M13052 3 v3 Recommendation for analog inputs M13052 8 v10 ISI Neutral current input I2P Pha...

Page 84: ... transformer differential protection T1PPDIF GUID 388AD26B 6803 4C8B 9DE4 E90D0826EB30 v2 6 2 1 Identification GUID 855CD002 4259 44F3 A491 E7DD119C6525 v2 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Single phase railway power transformer differential protection T1PPDIF Id I IEC15000166 V1 EN US 87T 6 2 2 Application GUID 147FA067 0F83 43E8 ...

Page 85: ...D values for primary current IBase primary voltage UBase and primary power SBase are set in the global base values for settings function GBASVAL GlobalBaseSel This is used to select GBASVAL function for reference of base values Operation This is used for transformer differential protection Off On 6 2 3 1 Restrained and unrestrained differential protection GUID B65931F7 5592 4494 93C0 1762287C5299 ...

Page 86: ...rt circuit power of the systems and so on The second section of the restrain characteristic has an increased slope in order to deal with the increased differential current during heavy loading of the transformer and external fault currents The third section of the restrain characteristic further decreases the sensitivity of the restrained differential function in order to cope with CT saturation d...

Page 87: ...15000390 2 en vsdx IEC15000390 V2 EN US Figure 30 Operate restrain characteristic The operate restrained characteristic is determined by five parameter settings IdMin EndSection1 EndSection2 SlopeSection2 SlopeSection3 The slope is relative to the characteristic breakpoint 100 BIAS DIFF I I slope IECEQUATION15054 V1 EN US Equation 3 1MRK 506 375 UEN A Section 6 Differential protection Railway appl...

Page 88: ...ual For a railway power transformer winding the zero sequence current is subtracted when for the phase selection parameter on the respective side the value L1 L2 2 is selected For a detailed explanation see the calculations done in Solution 1 in section Setting example in this manual 6 2 3 3 Inrush restraint methods GUID 39D001F6 6BB0 4378 AB55 51039086F28C v1 With a combination of the 2nd harmoni...

Page 89: ...tection The internal external fault discriminator detects even minor faults with a high sensitivity and at high speed and at the same time discriminates between internal and external faults with a high degree of dependability The goal is to be able to quickly switch off the faulty power transformer before the fault develops into a severe one for example a fault involving the iron core This feature...

Page 90: ...nt The base current is calculated for each side winding 1 and winding 2 of the power transformer 1 1000 1 121 W SBase IBaseW A UBase IECEQUATION16075 V1 EN US Equation 4 2 1000 2 1067 W SBase IBaseW A UBase IECEQUATION16076 V1 EN US Equation 5 where SBase Rated power of transformer MVA UBaseW1 Rated phase to phase voltage of winding 1 kV UBaseW2 Rated phase to phase voltage of winding 2 kV The bas...

Page 91: ...vsdx 132 15kV 15kV 132kV I U v IU Is S V R IEC15000170 V3 EN US Figure 32 Transformer connection example 1 Base current calculation kV U MVA S I Wx Ph Ph Wx Base _ _ _ 1000 IECEQUATION058 V1 EN US Equation 6 The HV currents IV and IU shall be connected as IL1 and IL2 currents respectively for the winding 1 side towards the T1PPDIF function The LV current Is shall be connected as IL1 current for th...

Page 92: ...F73A5 v2 IEC15000171 3 en vsdx 66 15kV 15kV 66kV I U v IU Is S V R IEC15000171 V3 EN US Figure 33 Transformer connection example 2 The HV currents IV and IU shall be connected as IL1 and IL2 currents respectively for the winding 1 side towards the T1PPDIF function The LV current Is shall be connected as IL1 current for the winding 2 side towards the T1PPDIF function Zero sequence current removal i...

Page 93: ...W I I I I I I Max IDLW IDLW Max I I I I IECEQUATION204 V2 EN US Equation 11 Transformer connection example 3 GUID 945C3857 BE28 484D B68F 7C9C3BB05441 v2 IEC15000172 2 en vsdx 132 66kV 66kV 132kV I U v IU IS S V IR R IEC15000172 V2 EN US Figure 34 Transformer connection example 3 The HV currents IV and IU shall be connected as IL1 and IL2 currents respectively for the winding 1 side towards the T1...

Page 94: ...S BaseW BaseW I I I I I I I I I Max IDLW IDLW Max I I I IECEQUATION205 V2 EN US Equation 12 The phase selection settings for the second instance of the T1PPDIF function shall be PhSelW1 L1 L2 2 PhSelW2 L2 InvW2Curr Yes Then the internal calculations will be 2 1 2 2 1 2 100 100 IDLW1 IDLW2 2 100 100 1 2 2 V U Diff R BaseW BaseW V U Bias R BaseW BaseW I I I I I I I I I Max IDLW IDLW Max I I I IECEQU...

Page 95: ...respectively for the winding 2 side towards T1PPDIF function To calculate zero sequence current reduction for U V R and S phases see connection example 1 The phase selection settings for the first instance of the T1PPDIF function shall be PhSelW1 L1 L2 2 PhSelW2 L1 L2 2 InvW2Curr No Then the internal calculations will be 1 2 1 2 100 100 IDLW1 IDLW2 2 2 100 100 1 2 2 2 V U S R Diff BaseW BaseW V U ...

Page 96: ...mple 2 6 2 4 2 How to wire the transformer differential protection to the IED using CTs GUID E732B4DC 77E3 4142 829E D08F9677B789 v1 Here are two examples of how to wire and connect a star connected two phase CT on the high voltage side and a one phase CT on the low voltage side to the IED for protection of a railway power transformer shown in Figure 31 using the T1PPDIF function For the correct t...

Page 97: ...2 G1AI3 G1AI4 G1N IED 1 2 2 3 3 4 4 5 CT 200 1 Star connected CT 1600 1 I S 1 IEC16000064 1 en original vsd IN IEC16000064 V1 EN US Figure 37 CT wiring pre processing blocks and T1PPDIF connections for the proposed Solution 1 1 HV side Two individual phase currents from a star connected two phase CT set are connected to two CT inputs in the IED LV side A single phase current from the one phase CT ...

Page 98: ...quantities by using the fundamental frequency phasors phase L1 taken as reference for sequence quantities These calculated values are then available for all built in protection and control functions within the IED that are connected to this preprocessing function block For this application most of the preprocessing settings can be left to the default values 4 GxAI2P output on the SMAI function blo...

Page 99: ...connected CT 1600 1 I S 1 IEC16000065 1 en Original vsd IN IEC16000065 V1 EN US Figure 38 CT wiring pre processing blocks and T1PPDIF connections for the proposed Solution 2 This solution is similar to Solution 1 The only differences are the following 1 In point 5 the settings in T1PPDIF are the following PhSelW1 IL1 IL2 2 PhSelW2 IL2 InvW2Curr Yes 2 The sequence of the HV currents is swapped by w...

Page 100: ...94 ...

Page 101: ...potential transformer is used Automatic activation based on dead line detection can only be used when the voltage transformer is situated on the line side of a circuit breaker When line side voltage transformers are used the use of the nondirectional distance zones secures switch onto fault tripping for close in three phase short circuits The use of the nondirectional distance zones also gives a f...

Page 102: ...ne phase is disconnected mutual coupling in the other phases UPh is used to set the voltage level for the detection of a dead line UPh is by default set to 70 of UBase This is a suitable setting in most cases but it is recommended to check the suitability in the actual application AutoInitMode automatic activating of ZCVPSOF is by default set to DLD disabled which means the dead line logic detecti...

Page 103: ...an overreaching zone The selection of the Impedance mode gives increased security When Mode is set to UILvl Imp the condition for tripping is an ORed between UILevel and Impedance tDuration The setting of the timer for the release of UILevel is by default 0 02 seconds which has proven to be suitable in most cases from field experience If a shorter time delay is to be set it is necessary to conside...

Page 104: ...t earthed and unearthed When the single earth faults occurs the fault currents are reduced by the earth fault neutralizers or the active compensation facility level decreases until the flashovers are neutralized automatically The concerned phase is not to be tripped However the faulty phase has to be identified and indicated earth fault protection determination of the earth fault direction When th...

Page 105: ...he faulty lines Alternatively the residual earth fault protection is used to trip both lines But due to the low fault currents long tripping times are used Phase preference logic is used to decide the tripping mode for distance protection and the following two selection modes are provided Equal priority L1 before L2 The typical waveform of recovery voltage following arc extinction earth faults in ...

Page 106: ...gure 40 The time delay to detect cross country fault is normally 0 1 0 15 s After the above event another restrike occurs on L2 the voltage on L1 increases and the distance or residual current protection operates again To confirm that the fault exists on phase L2 phase to earth voltage of L1 will be checked Normally in a compensated earthing system the change in measured voltage is big if fault pe...

Page 107: ...imum current is exceeded the distance protection calculates the impedance The default setting is 10 IB IMinOpPP It is used to select the minimum operating current for the phase to phase loops If the minimum current is exceeded the distance protection calculates the impedance The default setting is 10 IB OpLoadEnch This setting is used to select the load discrimination characteristic operation to O...

Page 108: ...erse direction However if it is needed to specify the reverse reaches depending on the application it is recommended to set this parameter to Nonsymmetry Start GUID D2A63BD2 34EA 407C B43F 165DCB576C4E v2 CharStartZ It is used to select the underimpedance start characteristic i e Circular and Quadrilateral Z1CircleStart This is used to set a positive sequence impedance reach in Ohm of the starting...

Page 109: ... 1 and it is set to On by default DirModeZ1 This is used to set the zone 1 direction mode It can be set to Non directional Forward and Reverse The Forward direction mode is set by default PhSelModeZ1 This is used to enable the measuring loops of zone 1 It can be set to Phsel logic Release L1E ReleaseL2E Release PE Release L1L2 and Release PE PP modes The default setting is Phsel logic mode LEModeZ...

Page 110: ...Z1 This is used to set the Off On operation of the phase to earth timer of zone 1 The default setting is Off tPEZ1 This is used to set the time delay to trip for phase to earth faults in zone 1 The default setting is 0 0s OpModetPPZ1 This is used to set the Off On operation of the phase to phase timer of zone 1 The default setting is Off tPPZ1 This is used to set the time delay to trip for phase t...

Page 111: ... phase faults in zone 2 This may be set identical to zone 1 setting RFPPRvZ2 This is used to set the reverse fault resistive reach in Ohm p for phase to phase faults in zone 2 This may be set identical to zone 1 setting TimerSelZ2 This is used to set the zone timer selection mode of zone 2 i e Timers separated Timers linked General start PhSel start Internal start and External start The default se...

Page 112: ...rXLZ3 This is used to set the earth return compensation factor for reactance of zone 3 It provides zero sequence compensation for phase to earth faults RFPEFwZ3 This is used to set the forward fault resistive reach in Ohm p for the phase to earth faults in zone 3 This may be set identical to zone 2 setting resistive reach RFPERvZ3 This is used to set the reverse fault resistive reach in Ohm p for ...

Page 113: ... It avoids overreaching of the zone in to the next section in case of resistive fault due to remote end feed Generally this setting is not needed for zone 4 The default setting is Off X1FwZ4 This is used to set the forward positive sequence reactance reach of zone 4 in Ohm p It may be set identical to X1RvZ4 X1RvZ4 This is used to set the reverse positive sequence impedance reach of zone 4 in Ohm ...

Page 114: ... Off On operation of zone 5 and it is set to Off by default This Zone can be used for the permissive overreach scheme along with a communication channel DirModeZ5 This is used to set the zone 5 direction mode It can be set to Non directional Forward and Reverse The default setting is Forward direction mode PhSelModeZ5 This is used to enable the measuring loops of zone 5 It can be set to Phsel logi...

Page 115: ...his is used to set the time delay to trip for phase to earth faults in zone 5 It should be set identical to zone 2 zone 3 timer setting OpModetPPZ5 This is used to set the Off On operation of the phase to phase timer of zone 5 The default setting is Off tPPZ5 This is used to set the time delay to trip for phase to phase faults in zone 5 It should be set identical to zone 2 zone 3 timer setting zon...

Page 116: ...aults of zone 6 It should be set identical to zone 2 resistive reach setting RFPPRvZ6 This is used to cover the zone 6 fault resistive reach in Ohm p for phase to phase faults in reverse direction It should be set identical to zone 2 resistive reach setting TimerSelZ6 This is used to set the zone timer selection mode of zone 6 i e Timers separated Timers linked General start PhSel start Internal s...

Page 117: ...s also picked up the distance measuring loop of that loop is released immediately This is done in order to clear the high current faults instantaneously Phase to phase fault loop is released if there is output from the under impedance starting and there is no residual overcurrent start output I0MinPhSel This is the minimum current that should be present to detect a phase to phase fault The recomme...

Page 118: ...g is 1 5s OpModet2L2 This is used for Off On operation of the t2L2 timer if phase preference is selected The default setting is Off t2L2 This is an additional time delay to trip phase L2 if the phase preference is set to trip phase L2 in zone 2 The default setting is 2 5s OpModet3L2 This is used for Off On operation of the t3L2 timer if phase preference is selected The default setting is Off t3L2 ...

Page 119: ...phase L2 When the priority L1 before L2 is selected the time steps t1L2 t2L2 t3L2 t4L2 t5L2 and t6L2 are extended by tVL2 During trip time of the corresponding zone a normalization of the supply voltage can be identified i e dUL1 dt dUOverdt and dUL2 dt dUOverdt If a restrike of the earth fault is detected during the tVL2 time i e dUL1 dt dUOverdt dUL2 dt dUOverdt an instantaneous trip will be iss...

Page 120: ...al settings GUID 30CF921D 34EE 4F24 B050 C92036619F59 v2 GlobalBaseSel Selects the global base value group used by the function to define IBase UBase and SBase Operation Sets the protection to On or Off System Earthing It is used to select the type of system earthing i e Compensated Solidly and High impedance LineAng This is to used set the distance protection characteristic angle It should be set...

Page 121: ... This is used to select the direction mode of the end zone 2 It can be set to Non directional Forward and Reverse It is recommended to set this as Non directional tEnd2 This is used to set the time delay for the second stage trip It should be set in coordination with the tEnd1 timer The default setting is 3 0s OpModeGenSt This is used to select On or Off of zone timers start by general start signa...

Page 122: ...nts The default setting is 0 8 REOverRLStart This is used to set the earth return compensation factor for resistance of the starting element It is not applicable for compensated and high impedance earthed systems XEOverXLStart This is used to set the earth return compensation factor for reactance of the starting element It is not applicable for compensated and high impedance earthed systems Direct...

Page 123: ... considering minimum expected voltage and maximum load In case of short lines consideration has to be given to overreach due to remote end infeed and reach in resistance direction is restricted RFPERvZ1 This is used to set the reverse fault resistive reach in Ohm p for phase to earth faults in zone 1 It may be set identical to RFPEFwZ1 RFPPFwZ1 This is used to set the forward fault resistive reach...

Page 124: ...FwZ2 REoverRLZ2 This is used to set the earth return compensation factor for resistance of zone 2 It provides zero sequence compensation for phase to earth faults XEoverXLZ2 This is used to set the earth return compensation factor for reactance of zone 2 It provides zero sequence compensation for phase to earth faults RFPEFwZ2 This is used to set the forward fault resistive reach in Ohm p for the ...

Page 125: ...teristic of zone 3 The default setting is Off LCModeZ3 This is used to enable disable the adaptive load compensation mode of zone 3 It avoids overreaching of the zone in to the next section in case of resistive fault due to remote end feed Generally this setting is not needed for zone 3 The default setting is Off X1FwZ3 This is used to set the forward positive sequence reactance reach of zone 3 in...

Page 126: ... to phase faults in zone 3 It should be set so that it provides discrimination with the operating time of relays provided in subsequent sections which zone 3 reach of relay being set overlaps The default setting is 0 7 s Zone 4 GUID E42EF947 C601 494A B561 390BBF616356 v2 OpZ4 This is used for the Off On operation of zone 4 and it is set to Off by default This can be used as reverse zone DirModeZ4...

Page 127: ...ts in reverse direction It should cover apparent phase to phase bus fault resistance allowing for multiple infeed from other circuits Therefore it should be set identical to zone 3 resistive reach setting TimerSelZ4 This is used to set the zone timer selection mode of zone 4 i e Timers separated Timers linked General start PhSel start Internal start and External start The default setting is Timers...

Page 128: ...t the forward fault resistive reach in Ohm p for the phase to earth faults in zone 5 This may be set identical to zone 1 setting In case of permissive overreach schemes used for short lines this has to be set higher than zone 1 resistive reach RFPERvZ5 This is used to cover the zone 5 fault resistive reach in Ohm p for phase to earth faults in reverse direction It may be set identical to zone 1 se...

Page 129: ... may be set identical to zone 2 reach setting X1RvZ6 This is used to set the reverse positive sequence impedance reach of zone 6 in Ohm p It may be set less than zone 1 reach of distance protection for the shortest line in the reverse direction REoverRLZ6 This is used to set the earth return compensation factor for resistance of zone 6 It provides zero sequence compensation for phase to earth faul...

Page 130: ...delayed by settable time delay tI0 The default setting is 0 2s 7 2 2 3 High impedance earthing systems GUID 0D740A9F 64D9 4A0E 80D2 0C71B48E8D35 v2 In isolated high impedance networks following types of errors can be anticipated 2 phase short circuit with or without earth connection Single phase to earth fault cross country double earth faults For double earth faults the disconnection by the dista...

Page 131: ...idated for each application and adopt the appropriate setting values The parameters for ZRWPDIS are set via the local HMI or PCM600 Common base IED values for primary current IBase primary voltage UBase and primary power SBase are set in a global base values for settings function GBASVAL General settings GUID 30CF921D 34EE 4F24 B050 C92036619F59 v2 GlobalBaseSel Selects the global base value group...

Page 132: ...tting should allow the farthest zone to operate The default setting is 2 5s OpModetEnd2 This is used to select the operation On or Off of the end zone 2 OpDirEnd2 This is used to select the direction mode of the end zone 2 It can be set to Non directional Forward and Reverse It is recommended to set this as Non directional tEnd2 This is used to set the time delay for the second stage trip It shoul...

Page 133: ...nt operation of the residual overcurrent start caused by an unbalance or dissimilar CT behaviour in the event of high short circuit currents The default setting is 0 8 REOverRLStart This is used to set the earth return compensation factor for resistance of the starting element It is not applicable for compensated and high impedance earthed systems XEOverXLStart This is used to set the earth return...

Page 134: ...stive reach should be set to give maximum coverage subject to check possibility against load point encroachment considering minimum expected voltage and maximum load In case of short lines consideration has to be given to overreach due to remote end infeed and reach in resistance direction is restricted RFPERvZ1 This is used to set the reverse fault resistive reach in Ohm p for phase to earth faul...

Page 135: ...2 This is used to set the reverse positive sequence impedance reach of zone 2 in Ohm p It may be set identical to X1FwZ2 REoverRLZ2 This is used to set the earth return compensation factor for resistance of zone 2 It provides zero sequence compensation for phase to earth faults XEoverXLZ2 This is used to set the earth return compensation factor for reactance of zone 2 It provides zero sequence com...

Page 136: ...PE Release L1L2 and Release PE PP modes The default setting is Phsel logic mode LEModeZ3 This is used to operate the load discrimination characteristic of zone 3 The default setting is Off LCModeZ3 This is used to enable disable the adaptive load compensation mode of zone 3 It avoids overreaching of the zone in to the next section in case of resistive fault due to remote end feed Generally this se...

Page 137: ...he default setting is Off tPPZ3 This is used to set the time delay to trip for phase to phase faults in zone 3 It should be set so that it provides discrimination with the operating time of relays provided in subsequent sections which zone 3 reach of relay being set overlaps The default setting is 0 7 s Zone 4 GUID E42EF947 C601 494A B561 390BBF616356 v2 OpZ4 This is used for the Off On operation ...

Page 138: ...ts in reverse direction It should cover apparent phase to phase bus fault resistance allowing for multiple infeed from other circuits Therefore it should be set identical to zone 3 resistive reach setting TimerSelZ4 This is used to set the zone timer selection mode of zone 4 i e Timers separated Timers linked General start PhSel start Internal start and External start The default setting is Timers...

Page 139: ...t the forward fault resistive reach in Ohm p for the phase to earth faults in zone 5 This may be set identical to zone 1 setting In case of permissive overreach schemes used for short lines this has to be set higher than zone 1 resistive reach RFPERvZ5 This is used to cover the zone 5 fault resistive reach in Ohm p for phase to earth faults in reverse direction It may be set identical to zone 1 se...

Page 140: ... may be set identical to zone 2 reach setting X1RvZ6 This is used to set the reverse positive sequence impedance reach of zone 6 in Ohm p It may be set less than zone 1 reach of distance protection for the shortest line in the reverse direction REoverRLZ6 This is used to set the earth return compensation factor for resistance of zone 6 It provides zero sequence compensation for phase to earth faul...

Page 141: ...ting is Off U0DetMin This is used to set the minimum operate value for the neutral voltage shift The default value is 20 UB UDisp GUID 1885B794 9F95 446B A656 0A37AAB7F193 v2 OpModeU0 This is used for the Off On operation of the neutral voltage displacement logic The default value is Off UMinDisp This is used to check the neutral voltage displacement for single phase earth faults occur in the syst...

Page 142: ...al GUID 0539986A C449 4E29 9067 ACF82F94995C v2 Common base IED values for primary current IBase and primary voltage UBase are set in a Global base values for settings function GBASVAL GlobalBaseSel It is used to select a GBASVAL function for reference of base values IBase Sets the base current in primary ampere This is 50MVA 110kV 454 54A UBase Sets the base voltage in kV This is 110 0kV Operatio...

Page 143: ...ble load Set this to 30 deg OpModetEnd1 It is used to select the On Off operation of the first stage timer tEnd1 Set this to On OpDirEnd1 This is used to select the direction mode of end zone 1 Set this to Forward tEnd1 This is used to set time delay for the first stage remote backup Set this higher than zone 3 time delay of 0 7s plus additional delays provided Set this to the default 2 5s OpModet...

Page 144: ...The stabilizing factor to prevent operation of the residual overcurrent start caused by an unbalance or dissimilar CT behaviour in the event of high short circuit currents Set this to 0 8 Direction GUID 464CA6EE 24D9 4F19 972C F1EE1D4B9FFE v2 ArgNegRes This is the angle for blinder in the second quadrant Set this to 120 deg ArgDir This is the angle of setting in the fourth quadrant Set this to 15 ...

Page 145: ...ended that the resistive reach does not exceed 4 5 times reactive reach Therefore RFPEFwZ1 may be set to 4 5 x X1FwZ1 4 5 x 5 6 25 52 Ohm RFPPFwZ1 It should be set to cover the arc resistance for phase to phase faults It may be set identical to RFPEFwZ1 which is 25 52 Ohm TimerSelZ1 This is used to set the zone timer selection mode of zone 1 Set this to Timers Separated OpModetPEZ1 Set this to On ...

Page 146: ...PEFwStart is set to 50 16 Ohm to give more resistive coverage RFPEFwZ2 can be set at 0 8 x 50 16 40 13 Ohm RFPPFwZ2 It may be set identical to RFPEFwZ2 which is 40 13 Ohm TimerSelZ2 This is used to set the zone timer selection mode of zone 2 Set this to Timers Separated OpModetPEZ2 Set this to On tPEZ2 Choose a time delay for zone 2 with margin to assure selectivity to zone 1 of adjacent lines A d...

Page 147: ...se to earth faults 83 0 1 112 0 298 0 2 1 1 2 1 1 0 X X X X L E IECEQUATION15053 V1 EN US Equation 24 Therefore set this to 0 83 RFPEFwZ3 This may be set identical to setting RFPEFwZ2 which is 40 13 Ohm RFPPFwZ3 This may be set identical to setting RFPEFwZ3 which is 40 13 Ohm TimerSelZ3 This is used for Zone timer selection mode of zone 3 Set this to Timers separated OpModetPEZ3 Set this to On tPE...

Page 148: ...re L2 OpModet1L2 Set this to On t1L2 Set this to 1 0s OpModet2L2 Set this to On t2L2 Set this to 2 0s OpModet3L2 Set this to On t3L2 Set this to 3 0s U0Min This is used to check minimum residual voltage if start signal falls back Set this to 50 UB tVL2 This is used to extend the time for phase L2 to check the voltage shift To time t0L2 to t6L2 is a settable time tVL2 operation time extension L2 ad...

Page 149: ...tem Frequency 16 7Hz Full load 50MVA Short time maximum Power 250 of Full load Minimum operating voltage 90 of rated voltage PT Ratio 110kV 110V CT Ratio 600 1A Line length A B 50km Line length B C 100km Positive sequence impedance of line 0 097 j0 112 Ohm km 0 1481 49 3 Ohm km Zero sequence impedance of line 0 151 j0 298 Ohm km 0 334 63 13 Ohm km Arc resistance 2 Ohm Tower footing resistance 10 O...

Page 150: ...2 5 times the rated power of 50MVA Umin is the minimum voltage which can be taken as 90 of 110 0kV which is equal to 99kV 0 8 is security factor Therefore RLd 0 8 99 0 2 2 5 x 50 0 62 7 Ohm ArgLd This is used to set the load angle determining the load impedance area of the load discrimination characteristic Set the parameter to the maximum possible load angle at maximum possible load Set this to 3...

Page 151: ... faults within the protected area To provide maximum coverage for the high resistive faults it may be set as high as possible subject to check of possibility against load point encroachment Therefore set this to 80 of the setting RLd resistive reach of the starter The setting RLd being 62 7 Ohm the RFPEStart can be set to 0 8 x 62 7 50 16 Ohm RFPPStart This is used to set the forward and reverse r...

Page 152: ...et this to On X1FwZ1 This is used to set the forward positive sequence reactance reach of zone 1 in Ohm p The recommended setting is 90 of the protected line length Therefore set the X1FwZ1 to 0 9 x 50 0 x 0 112 5 6 Ohm X1RvZ1 This is used to set the reverse positive sequence impedance reach of zone 1 in Ohm p Set this to 5 6 Ohm REoverRLZ1 It provides zero sequence compensation for phase to earth...

Page 153: ... to Timers Separated OpModetPEZ1 Set this to On tPEZ1 Set this to 0 0s OpModetPPZ1 Set this to On tPPZ1 Set this to 0 0s Zone 2 GUID 5D2EB529 C387 4548 845F D92D60384327 v1 OpZ2 Set this to On DirModeZ2 This is used to set the zone 2 direction mode Set this to Forward PhSelModeZ2 This is used to enable the measuring loops of zone 2 Set this to Phsel logic LEModeZ2 This is used to operate the load ...

Page 154: ...er selection mode of zone 2 Set this to Timers Separated OpModetPEZ2 Set this to On tPEZ2 Choose a time delay for zone 2 with margin to assure selectivity to zone 1 of adjacent lines A delay time difference of 0 4s between the zones is sufficient Therefore the time delay for zone 2 can be set to 0 4s OpModetPPZ2 Set this to On tPPZ2 Set this identical to tPEZ2 which is 0 4s Zone 3 GUID 4E4DD511 DB...

Page 155: ...wZ3 This may be set identical to setting RFPEFwZ2 which is 40 13 Ohm RFPERvZ3 It is set identical to setting RFPEFwZ3 which is 40 13 Ohm RFPPFwZ3 This may be set identical to setting RFPEFwZ3 which is 40 13 Ohm RFPPRvZ3 It is set identical to setting RFPEFwZ3 which is 40 13 Ohm TimerSelZ3 This is used for Zone timer selection mode of zone 3 Set this to Timers separated OpModetPEZ3 Set this to On t...

Page 156: ...EC 61850 identification IEC 60617 identification ANSI IEEEidentification Underimpedance protection for railway transformers ZGTPDIS Z IEC15000305 V1 EN US 21T 7 3 2 Application GUID 54FF2835 A45F 4192 BDA8 D15A0C650BB8 v2 ZGTPDIS is generally used as backup protection for faults on the transformer and the associated transmission lines These transformers can be classified in two basic categories 2 ...

Page 157: ...faults in the transformer and the associated lines Zone 1 can be used to provide high speed protection for faults in the HV winding of the transformer Zone 2 can be used to cover the entire transformer and substation LV busbar Zone 3 can be used to cover power system faults beyond the LV busbar Backup impedance protection characteristics The characteristics of zone 1 zone 2 and zone 3 are shown in...

Page 158: ...v5 Zone 2 can be used to cover the LV side of the transformer and the associated busbar It is usually set to cover 125 of the transformer impedance The time to trip must be provided in order to coordinate with the zone 1 element on the shortest outgoing line from the bus 7 3 2 3 Zone 3 operation GUID 131391BB 2E2A 4EEB B021 D996AEC84524 v4 Zone 3 covers the whole of the transformer the interconnec...

Page 159: ...on calculates the impedance A default setting of 10 of IB is recommended Zone 1 OpModeZ1 This is to select the operating characteristic of zone 1 underimpedance element This can be selected as Off Mho offset Quad non dir Z1Fwd This is to set the zone 1 forward positive sequence impedance reach in ohm p It is recommended to set this to 70 of transformer impedance Z1Rev This is to set the zone 1 rev...

Page 160: ...ce element This can be selected as Off Mho offset Quad non dir Z3Fwd This is to set the zone 3 forward positive sequence impedance reach in ohm p It should be set to overreach the remote terminal of the longest adjacent line about 20 for all fault conditions Z3Rev This is to set the zone 3 reverse positive sequence impedance reach in ohm p This may be set identical to Z2Rev RFFwZ3 This is to set t...

Page 161: ... for catenary protection For this purpose individual zones can be supervised by outputs STDI and STDU from the FRWSPVC function Several instances of FRWSPVC function are readily available in the IED To achieve any of the above mentioned supervisions corresponding configuration logic and appropriate setting in the PCM600 tool shall be done For external supervision from any additional logic input BL...

Page 162: ... 1 en vsdx R X Z2 Z1 Wrong Phase Coupling IEC16000116 V1 EN US Figure 46 Wrong phase coupling protection Section 7 1MRK 506 375 UEN A Impedance protection 156 Railway application RER670 2 2 IEC Application manual ...

Page 163: ...high fault current indicates that the decrease of transmitted power is high The total fault clearing time The phase angles between the EMFs of the generators on both sides of the transmission line increase over the permitted stability limits if the total fault clearing time which consists of the protection operating time and the breaker opening time is too long The fault current on railway lines d...

Page 164: ...ion GBASVAL GlobalBaseSel This is used to select GBASVAL function for reference of base values Operation Set the protection to On Off IP Set operate current in of IB IP Max and IP Min should only be changed if remote setting of operation current level IP is used The limits are used for decreasing the used range of the IP setting If IP is set outside IP Max and IP Min the closest of the limits to I...

Page 165: ...e IED must not trip for any of the two through fault currents Hence the minimum theoretical current setting Imin will be Imin MAX IfA IfB EQUATION78 V1 EN US Equation 35 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 is suggested due to the inaccuracy of the instrument tr...

Page 166: ... 2 Two step directional phase overcurrent protection D2PTOC SEMOD129998 1 v8 8 2 1 Identification M14885 1 v6 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Directional phase overcurrent protection two steps D2PTOC 2 2I 2 2 alt IEC15000155 V2 EN US 51_67 8 2 2 Application M15335 3 v9 The two step directional phase overcurrent protection D2PTOC ...

Page 167: ...ion between all overcurrent protections they should have the same time delay characteristic Therefore several inverse time characteristics are available within D2PTOC function Normally it is required that the phase overcurrent protection shall reset as fast as possible when the current level gets lower than the operation level Power transformers can have a large inrush current when being energized...

Page 168: ...ected as phase1 phase2 which is shown in Table 17 For two phase railway supply system UBase shall be entered as Rated phase to earth voltage of the protected object in primary kV when the measured voltage quantity is selected other than phase1 phase2 which is shown in Table 18 Rated phase to phase voltage of the protected object in primary kV when the measured voltage quantity is selected as phase...

Page 169: ...e 1 2 2 UL UL phase1 phase2 D2PTOC function will measure the voltage internally calculated as the vector difference between the phase L1 voltage and phase L2 voltage UL UL For directional operation of the D2PTOC function the identical values for current and voltage measurement selection shall be set e g both set to PosSeq or both set to phase1 OperHarmRestr This is used to Off On the 2nd harmonic ...

Page 170: ...982 19 v10 Operation1 This is used to Off On the operation of step 1 StartCurr1 This is used to set operate current level for step 1 given in of IBase CurveType1 Selection of time characteristic for step 1 Definite time delay and different types of inverse time characteristics are available according to Table 19 Section 8 1MRK 506 375 UEN A Current protection 164 Railway application RER670 2 2 IEC...

Page 171: ...e characteristic might give a very short operation time By setting this parameter the operation time of the step can never be shorter than the setting Setting range 0 000 60 000s in steps of 0 001s Operate time Current tDef1 tMin1 IMin1 IEC16000212 1 en vsdx IEC16000212 V1 EN US Figure 51 Minimum operate current and operate time for inverse time characteristics In order to fully comply with the de...

Page 172: ...s the time between activation of the start and the trip outputs HarmRestrain2 This is used to block the operation of step 2 from the 2nd harmonic restrain function This function should be used when there is a risk if power transformer inrush currents might cause unwanted trip It can be set Off On DirMode2 This is used to set the directional mode of step 2 The possible modes are Non directional For...

Page 173: ... EFRWPIOC shall not be allowed to operate for faults at other objects than the protected object line For a normal line in a meshed system single phase to earth faults and phase to phase to earth faults shall be calculated as shown in Figure 52 and Figure 53 The residual currents 3I0 to the protection are calculated For a fault at the remote line end this fault current is IfB In this calculation th...

Page 174: ...uced An additional 20 is suggested due to inaccuracy of instrument transformers under transient conditions and inaccuracy in the system data The minimum primary current setting Is is Is 1 3 Imin EQUATION285 V3 EN US Equation 39 In case of parallel lines with zero sequence mutual coupling a fault on the parallel line as shown in Figure 54 should be calculated IEC09000025 1 en vsd ZA ZB ZL1 A B I M ...

Page 175: ...set the protection to On or Off IN Set operate current in of IB 8 4 Two step residual overcurrent protection EF2PTOC GUID 9E7DA007 48BA 4A87 974C 3AAFD5E336D1 v2 8 4 1 Identification M14881 1 v6 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Two step residual overcurrent protection EF2PTOC 2 IN IEC15000229 V1 EN US 51N_67N 8 4 2 Application M12...

Page 176: ...arance the directional functionality may be necessary Note that for directional operation additional logic in the IED configuration tool is needed Choice of time characteristics There are several types of time characteristics available such as definite time delay and different types of inverse time characteristics The selectivity between different overcurrent protections is normally enabled by co ...

Page 177: ...assured This 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 protections in the radial network there have to be a minimum time difference Dt between the time delays of two protections The minimum time difference can be determined for different cases To d...

Page 178: ...t1Min shall be set to the value which is equal to the operate time of the selected IEC inverse curve for measured current of twenty times the set current pickup value Note that the operate time value is dependent on the selected setting value for time multiplier k1 8 4 3 2 Common settings M15282 81 v10 tx Definite time delay for step x Used if definite time characteristic is chosen AngleRCA Relay ...

Page 179: ...scheme block 8 4 3 3 2nd harmonic restrain M15282 90 v6 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 declining residual current in the network as the inrush current is deviating between the phases There is a risk that the residual overcurrent function will giv...

Page 180: ...ase to earth faults in high impedance earthed networks The protection uses the residual current component 2I0 cos φ where φ is the angle between the residual current and the residual voltage 2U0 compensated with a characteristic angle Alternatively the function can be set to strict 2I0 level with a check of angle φ Directional residual power can also be used to detect and give selective trip of ph...

Page 181: ...is sensitivity is in most cases sufficient in high impedance network applications if the measuring CT ratio is not too high Sensitive directional residual power protection gives possibility to use inverse time characteristics This is applicable in large high impedance earthed networks with large capacitive earth fault currents In such networks the active fault current would be small and by using s...

Page 182: ...etting of earth fault protection in a high impedance earthed system the neutral point voltage zero sequence voltage and the earth fault current will be calculated at the desired sensitivity fault resistance The complex neutral point voltage zero sequence can be calculated as 0 0 2 1 phase f U U R Z IECEQUATION16029 V1 EN US Equation 42 Where Uphase is the phase voltage in the fault point before th...

Page 183: ...nts In such a system the impedance Z0 can be calculated as 0 4 2 2 2 2 2 n n c c n n n c n n c R X X Z jX R j X X X j R X X IECEQUATION16033 V1 EN US Equation 46 Where Xn is the reactance of the Petersen coil If the Petersen coil is well tuned we have 2Xn Xc In this case the impedance Z0 will be Z0 2Rn Now consider a system with an earthing via a resistor giving higher earth fault current than the...

Page 184: ... US Equation 47 Where Uphase is the phase voltage in the fault point before the fault Z1 is the total positive sequence impedance to the fault point Z1 Zsc ZT 1 ZlineAB 1 ZlineBC 1 Z0 is the total zero sequence impedance to the fault point Z0 ZT 0 2RN ZlineAB 0 ZlineBC 0 Rf is the fault resistance The residual voltages in stations A and B can be written 0 0 0 2 2 A T N U I Z R IECEQUATION16097 V1 ...

Page 185: ...on for measurement and as base for the inverse time delay The inverse time delay is defined as 0 0 2 2 cos inv kSN Sref t I U measured IECEQUATION16103 V1 EN US Equation 54 The function can be set On Off with the setting of Operation Common base IED values for primary current IBase primary voltage UBase and primary power SBase are set in a Global base values for settings function GBASVAL GlobalBas...

Page 186: ...6000127 V1 EN US Figure 59 Characteristic for RCADir equal to 0 The characteristic is for RCADir equal to 90 is shown in Figure 60 IEC16000128 1 en vsdx ref U 90 90 RCADir ROADir 0 2I 0 2I cos 0 2 ref ang I ang U 0 2U IEC16000128 V1 EN US Figure 60 Characteristic for RCADir equal to 90 When OpMode is set to 2U02I0cosfi the apparent residual power component in the direction is measured Section 8 1M...

Page 187: ...ected All the directional protection modes have a residual voltage release level setting UNRel which is set in of UBase This setting should be chosen smaller than or equal to the lowest fault residual voltage to be detected tDef is the definite time delay given in s for the directional residual current protection tReset is the time delay before the definite timer gets reset given in s With a tRese...

Page 188: ...directional residual over current and power protection function has the same short circuit capacity as the phase current transformers Hence there is no specific requirement for the external CT core i e any CT core can be used If the time delay for residual power is chosen the delay time is dependent on two setting parameters SRef is the reference residual power given in of SBase kSN is the time mu...

Page 189: ...anual for the description of different characteristics tPCrv tACrv tBCrv tCCrv Parameters for customer creation of inverse time characteristic curve Curve type 17 The time characteristic equation is æ ö ç ç ç æ ö ç ç è ø è ø p A t s B InMult i C in EQUATION1958 V1 EN US Equation 56 tINNonDir is the definite time delay for the non directional earth fault current protection given in s OpUN is set On...

Page 190: ...f this phase to phase or phase to earth faults can occur The paper insulation used inside a power transformer will deteriorate quicker and expected life of the transformer will be shortened Even an internal flash over may occur In stressed situations in the power system it can be required to overload lines and transformers for a limited time This should be done while managing the risks safely The ...

Page 191: ...e set as top oil temperature raise above the ambient for the set reference current of 100 i e 60 C in accordance with IEC 60076 2 The trip temperature TripTemp shall be set as maximum permissible top oil temperature in degrees Centigrade For power transformer manufactured by ABB a trip value of 105 C is recommended The same value is also recommended in IEC 60076 7 published in 2005 Thermal overloa...

Page 192: ... function for reference of base values primary current IBase primary voltage UBase and primary power SBase Imult Enter the number of lines in case the protection function is applied on multiple parallel lines sharing one CT IRef Reference steady state current given in of IBase that will give a steady state end temperature rise TRef It is suggested to set this current to the maximum steady state cu...

Page 193: ...s high The signal is released when the estimated temperature is below the set value This temperature value should be chosen below the alarm temperature 8 7 Breaker failure protection CCRWRBRF IP14514 1 v6 8 7 1 Application M13916 3 v7 In the design of the fault clearance system the N 1 criterion is often used This means that a fault needs to be cleared even if any component in the fault clearance ...

Page 194: ...e the case for some generator protection application for example reverse power protection or in case of line ends with weak end infeed RetripMode This setting states how the re trip function shall operate Retrip Off means that the re trip function is not activated CB Pos Check circuit breaker position check and Current means that a phase current must be larger than the operate level to allow re tr...

Page 195: ...rement should be enabled only for small currents The setting can be given within the range 5 200 of IBase t1 Time delay of the re trip The setting can be given within the range 0 60s in steps of 0 001 s Typical setting is 0 50ms t2 Time delay of the back up trip The choice of this setting is made as short as possible at the same time as unwanted operation must be avoided Typical setting is 90 200m...

Page 196: ...er the set time an alarm is given so that actions can be done to repair the circuit breaker The time delay for back up trip is bypassed when the CBFLT is active Typical setting is 2 0 seconds tPulse Trip pulse duration This setting must be larger than the critical impulse time of circuit breakers to be tripped from the breaker failure protection Typical setting is 200 ms 8 8 Overcurrent protection...

Page 197: ...n be used in a single phase railway supply systems as well 8 8 3 Setting guidelines GUID 809614D6 C191 4C41 9094 9FD4CB9ED0F7 v2 The parameters for Overcurrent protection with binary release BRPTOC are set via the local HMI or PCM600 Common base IED values for primary current IBase primary voltage UBase and primary power SBase are set in the global base values for settings function GBASVAL GlobalB...

Page 198: ... current and operates if the current is above the set level In the case of grounded neutral systems protection can be provided by insulating the transformer tank from ground apart from a connection to ground through a CT whose secondary energizes an overcurrent relay Such an arrangement gives sensitive protection for arc overs to the tank or to the core but it will not respond to turn faults or to...

Page 199: ... as C G Fe NG I G Fe R I I R I IECEQUATION052 V2 EN US Equation 59 For C G I G G R R Z IECEQUATION053 V2 EN US Equation 60 IFe is described as I G C G G NG Fe R R Z V I IECEQUATION054 V2 EN US Equation 61 The current flow in case of an external phase to ground fault should not operate the tank protection Therefore start value is set above the absolute value of this current In other words the ratio...

Page 200: ...setting parameters for the transformer tank protection TPPIOC are described below Common base IED values for primary current setting IBase is set in a Global base values for settings function GBASVAL setting GlobalBaseSel Selects the global base value group used by the function to define IBase I Instantaneous peak current start value in of IBase Section 8 1MRK 506 375 UEN A Current protection 194 ...

Page 201: ...2RWPTUV is used in combination with overcurrent protections either as restraint or in logic and gates of the trip signals issued by the two functions Other applications are the detection of no voltage condition for example before the energization of a HV line or for automatic breaker trip in case of a blackout U2RWPTUV is used to disconnect apparatuses which will be damaged when subject to service...

Page 202: ...9 1 3 1 Disconnected equipment detection M13851 53 v3 The setting must be below the lowest occurring normal voltage and above the highest occurring voltage caused by inductive or capacitive coupling when the equipment is disconnected 9 1 3 2 Power supply quality M13851 56 v3 The setting must be below the lowest occurring normal voltage and above the lowest acceptable voltage due to regulation good...

Page 203: ...ltage of the protected object This means operation for phase to earth voltage under 2 kV UBase U IECEQUATION048 V1 EN US Equation 62 and operation for phase to phase voltage under U UBase kV EQUATION1990 V1 EN US Equation 63 Thus for any selected measuring type setting of 100 corresponds to the rated primary voltage The below described setting parameters are identical for the two steps n 1 and 2 T...

Page 204: ...when subject to service under high voltage conditions It deals with high voltage conditions at power system frequency which can be caused by 1 Different kinds of faults where a too high voltage appears in a certain power system like metallic connection to a higher voltage level broken conductor falling down to a crossing overhead line transformer flash over fault from the high voltage winding to t...

Page 205: ...1 Equipment protection transformers M13852 10 v3 High voltage will cause overexcitation of the core and deteriorate the winding insulation The setting has to be well above the highest occurring normal voltage and well below the highest acceptable voltage for the equipment 9 2 3 2 Power supply quality M13852 16 v1 The setting has to be well above the highest occurring normal voltage and below the h...

Page 206: ...of step n OpModen This parameter describes how many of the two measured voltages that should be above the set level to give operation The setting can be Any phase or All phases In most applications it is sufficient that one phase voltage is high to give operation If the function shall be insensitive for single phase to earth faults All phases can be chosen because the voltage will normally rise in...

Page 207: ... used as a backup protection or as a release signal for the feeder earth fault protection 9 3 3 Setting guidelines M13853 3 v8 All the voltage conditions in the system where ROV2PTOV performs its functions should be considered The same also applies to the associated equipment its voltage withstand capability and time characteristic All voltage related settings are made as a percentage of a settabl...

Page 208: ...for reference of base values Operation This is used for residual overvoltage protection Off On UBase given in GlobalBaseSel is used as voltage reference for the set pickup values UBase shall be set equal to rated phase to phase voltage Note that the set value for UBase will be multiplied by factor 0 5 within the ROV2PTOV function The voltage can be fed to the IED in different ways 1 The IED is fed...

Page 209: ...ms this value depends on the ratio Z0 Z1 The required setting to detect high resistive earth faults must be based on network calculations Typically it shall be lesser than 100 tn time delay of step n given in s The setting is highly dependent on the protection application The time delay must be co ordinated with other automated actions in the system 1MRK 506 375 UEN A Section 9 Voltage protection ...

Page 210: ...204 ...

Page 211: ...oint change gas turbine start up and so on Sometimes shunt reactors are automatically switched in due to low frequency in order to reduce the power system voltage and hence also reduce the voltage dependent part of the load SAPTUF is very sensitive and accurate and is used to alert operators that frequency has slightly deviated from the set point and that manual actions might be enough The underfr...

Page 212: ... to be below the lowest occurring normal frequency and well above the lowest acceptable frequency for power stations or sensitive loads The setting level the number of levels and the distance between two levels in time and or in frequency depends very much on the characteristics of the power system under consideration The size of the largest loss of production compared to the size of the power sys...

Page 213: ...tion functions concerned can be blocked and an alarm will be given In case of large currents unequal transient saturation of CT cores with different remanence or different saturation factor may result in differences in the secondary currents from the two CT sets Unwanted blocking of protection functions during the transient stage must then be avoided Current circuit supervision CCSSPVC must be sen...

Page 214: ... is normally set at 150 to block the function during transient conditions The FAIL output is connected to the blocking input of the protection function to be blocked at faulty CT secondary circuits 11 2 Fuse failure supervision FRWSPVC GUID 05837FFD AA6B 4C09 AE02 323BA78E948A v1 11 2 1 Identification GUID 56A2FF28 197A 4AF4 91DF 331E9E323EB8 v1 Function description IEC 61850 identification IEC 60...

Page 215: ...ng time A criterion based on delta current and delta voltage measurements is used as the fuse failure supervision function in order to detect a fuse failure 11 2 3 Setting guidelines GUID 12FB02B1 9191 4831 820C F086B767DFD2 v1 The parameters for fuse failure supervision FRWSPVC are set via the local HMI or Protection and Control Manager PCM600 Common base IED values for primary current IBase prim...

Page 216: ...7AD377F507C3 v1 The condition for operation of the dead line detection is set by the parameters IDLD for the current threshold and UDLD for the voltage threshold Set the IDLD with a sufficient margin below the minimum expected load current A safety margin of at least 15 20 is recommended The operate value must however exceed the maximum charging current of an overhead line when only one phase is d...

Page 217: ...his threshold value the system is defined to have a parallel circuit and the synchrocheck function is used The synchronizing function measures the difference between the U Line and the U Bus It operates and enables a closing command to the circuit breaker when the calculated closing angle is equal to the measured phase angle and the following conditions are simultaneously fulfilled The voltages U ...

Page 218: ...able 23 below shows the maximum settable value for tBreaker when CloseAngleMax is set to 15 or 30 degrees at different allowed slip frequencies for synchronizing To minimize the moment stress when synchronizing near a power station a narrower limit for the CloseAngleMax needs to be used Table 23 Dependencies between tBreaker and SlipFrequency with different CloseAngleMax values tBreaker s max sett...

Page 219: ...s For such cases high speed shot within the auto reclosing function shall be used SESRSYN function block includes both the synchrocheck and the energizing features The energizing function allows closing when one side of the breaker is dead IEC16000121 1 en vsdx IEC16000121 V1 EN US Figure 65 Two interconnected power systems Figure 65 shows two interconnected power systems The cloud means that the ...

Page 220: ...he network and the phase angle difference may begin to oscillate Generally the frequency difference is the time derivative of the phase angle difference and typically oscillates between positive and negative values When the circuit breaker needs to be closed by auto reclosing after fault clearance some frequency difference should be tolerated But if a big and increasing phase angle difference is a...

Page 221: ... dead bus live line DBLL direction or in both directions over the circuit breaker Energizing from different directions can be different for automatic reclosing and manual closing of the circuit breaker For manual closing it is also possible to allow closing when both sides of the breaker are dead Dead Bus Dead Line DBDL The equipment is considered energized Live if the voltage is above the set val...

Page 222: ...the ULNOK and ULNFF inputs are related to the line voltage External selection of energizing direction M12322 10 v8 The energizing can be selected by use of the available logic function blocks Below is an example where the choice of mode is done from a symbol created in the Graphical Design Editor GDE tool on the local HMI through selector switch function block but alternatively there can for examp...

Page 223: ...09 P10 P11 P12 P13 P14 P15 P16 P17 P18 P19 P20 P21 P22 P23 P24 P25 P26 P27 P28 P29 P30 P31 P32 SWPOSN INTONE U2PBB U2PLN IEC17000001 V1 EN US Figure 68 Selection of the energizing direction from a local HMI symbol through a selector switch function block 12 1 3 Application examples M12323 3 v7 The synchronizing function block can be used in different switchyard arrangements but with different para...

Page 224: ...ESRSYN are set via the local HMI LHMI or PCM600 This setting guidelines describes the settings of the SESRSYN function via the LHMI Common base IED value for primary voltage UBase is set in a Global base value function GBASVAL found under Main menu Configuration Power system GlobalBaseValue GBASVAL_X UBase The SESRSYN function has one setting for the bus reference voltage GblBaseSelBus and one set...

Page 225: ...tage and line voltage when different phase neutral voltages are selected for example UL1 for bus and UL2 for line one available voltage is positive sequence and the other one is phase neutral for example Pos Seq for bus and UL2 for line The set value is added to the measured line phase angle The bus voltage is reference voltage Synchronizing settings OperationSynch The setting Off disables the Syn...

Page 226: ... is accepted 1 FreqDiffMax shows the time for the vector to move 360 degrees one turn on the synchronoscope and is called Beat time A typical value for FreqDiffMax is 200 250 mHz which gives beat times on 4 5 seconds Higher values should be avoided as the two networks normally are regulated to nominal frequency independent of each other so the frequency difference shall be small FreqRateChange The...

Page 227: ...TOSYOK MANSYOK TSTAUTSY and TSTMANSY to low With the setting On the function is in the service mode and the output signal depends on the input conditions UHighBusSC and UHighLineSC The voltage level settings must be chosen in relation to the bus or line network voltage The threshold voltages UHighBusSC and UHighLineSC have to be set lower than the value at which the breaker is expected to close wi...

Page 228: ...operation time delay setting is preferable where the tSCA setting is used A typical value for tSCM can be 1 second and a typical value for tSCA can be 0 1 seconds Energizingcheck settings AutoEnerg and ManEnerg Two different settings can be used for automatic and manual closing of the circuit breaker The settings for each of them are Off the energizing function is disabled DLLB Dead Line Live Bus ...

Page 229: ... is above the set value of UMaxEnerg tAutoEnerg 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 Should the conditions not persist for the specified time the delay timer is reset and the procedure is restarted when the conditions are fulfilled again Circu...

Page 230: ... time Line protection Circuit breaker Break time Trip command Contacts separated Arc extinguishers Fault duration Circuit breaker open time Fault duration Resets Instant of fault Operates Break time Closing time Operate time Fault Operates Resets Close command Contact closed Set AR dead time Reclaim time Auto reclosing function Start AR Reclosing command AR reset IEC04000146 3 en vsd IEC04000146 V...

Page 231: ...l overload protection Back up protection zones indicating faults outside the own line are typically connected to inhibit the auto recloser Automatic reclosing should not be attempted when closing a CB and energizing a line onto a fault SOTF except when multiple shots are used where shots 2 etc will be started at SOTF Auto reclosing is often combined with a release condition from synchrocheck and d...

Page 232: ...osing sequence In cases where one wants to differentiate auto reclosing dead time for different power system configuration or at tripping by different protection stages one can also use the STARTHS input start high speed reclosing When initiating STARTHS the auto reclosing dead time for high speed shot 1 t1_HS is used and the closing is done without checking the synchrocheck condition A number of ...

Page 233: ...d time for shot 1 M12391 113 v5 For the first shot there is a separate setting for the dead time t1 If no particular input signal is applied the auto reclosing dead time t1 will be used There is also a separate time setting facility for high speed auto reclosing without synchrocheck t1_HS available for use when required It is activated by the STARTHS input 12 2 2 6 Long trip signal M12391 117 v4 W...

Page 234: ... number of auto reclosing shots further shots may be made or the auto reclosing sequence is ended After reclaim timer time out the auto recloser resets but the circuit breaker remains open The circuit breaker closed information through the CBCLOSED input is missing Thus the auto recloser is not ready for a new auto reclosing cycle Normally the UNSUCCL output appears when a new start is received af...

Page 235: ...l closing going through the synchrocheck function An example of lock out logic Lock out RXMD1 11 12 21 MAIN ZAK CLOSE CLOSE COMMAND SMBO OR SMBRREC OR CCRBRF BU TRIP ZCVPSOF TRIP INHIBIT UNSUCCL TRBU IEC05000315 4 en vsd IEC05000315 WMF V4 EN US Figure 71 Lock out arranged with an external lock out relay CLOSE COMMAND OR SMBRREC OR CCRBRF BU TRIP ZCVPSOF TRIP INHIBIT UNSUCCL TRBU SMPPTRC AND RESET...

Page 236: ...sed to block the auto recloser for example when certain special service conditions arise When used blocking must be reset with BLKOFF CBCLOSED and CBREADY These binary inputs should pick up information from the circuit breaker At three operating gears in the circuit breaker single pole operated circuit breakers the connection should be All poles closed series connection of the NO contacts or At le...

Page 237: ...ot START The START input should be connected to the trip function SMPPTRC output which starts the auto recloser operation It can also be connected to a binary input for start from an external contact A logical OR gate can be used to combine the number of start sources If StartByCBOpen is used the circuit breaker open condition shall also be connected to the START input STARTHS Start high speed aut...

Page 238: ... Figure 73 and default factory configuration for examples IPT1 IPT2 IPT3 IPT4 and IPT5 Indicates that auto reclosing shots one to five are in progress The signals can be used as an indication of progress or for own logic ABORTED The ABORTED output indicates that the auto recloser is inhibited while it is in one of the following internal states inProgress auto recloser is started and dead time is i...

Page 239: ...erative SUCCL If the circuit breaker closing command is given and the circuit breaker is closed within the set time interval tUnsucCl the SUCCL output is activated after the set time interval tSuccessful SYNCFAIL The SYNCFAIL output indicates that the auto recloser is inhibited because the synchrocheck or energizing check condition has not been fulfilled within the set time interval tSync Also ABO...

Page 240: ... the auto recloser are found under Main menu Settings IED Settings Control AutoRecloser 79 5 0 1 SMBRREC 79 5 0 X and have been divided into four different setting groups General CircuitBreaker DeadTime and MasterSlave General settings Operation The operation of the auto recloser can be switched On or Off ExternalCtrl This setting makes it possible to switch the auto recloser On or Off using an ex...

Page 241: ...on is also checked after the set auto reclosing dead time This selection has a value first of all at multi shot auto reclosing to ensure that the circuit breaker is ready for a C O sequence at shot two and further shots During single shot auto reclosing the OCO selection can be used A breaker shall according to its duty cycle always have storing energy for a CO operation after the first trip IEC 5...

Page 242: ...cCl the SUCCL output is activated after the set time interval tSuccessful tUnsucCl The reclaim timer tReclaim is started each time a circuit breaker closing command is given If no start occurs within this time the auto recloser will reset A new start received in reclaim time status will reenter the auto recloser to in progress status as long as the final shot is not reached The auto recloser will ...

Page 243: ...it breakers disconnectors and earthing switches within a bay Permission to operate is given after evaluation of conditions from other functions such as interlocking synchrocheck operator place selection and external or internal blockings The complete apparatus control function is not included in this product and the information below is included for understanding of the principle for the use of QC...

Page 244: ...ent simultaneous operation Selection and supervision of operator place Command supervision Block deblock of operation Block deblock of updating of position indications Substitution of position indications Overriding of interlocking functions Overriding of synchrocheck Pole discordance supervision Operation counter Suppression of mid position The apparatus control function is realized by means of a...

Page 245: ...igure below is the logical node for interlocking When the circuit breaker or switch is located in a breaker IED two more functions are added GOOSE receive for switching device GOOSEXLNRCV Proxy for signals from switching device via GOOSE XLNPROXY The extension of the signal flow and the usage of the GOOSE communication are shown in Figure 76 en05000116 vsd IEC 61850 IEC05000116 V2 EN US Figure 75 ...

Page 246: ...ontrol functions with XCBR and XSWI located in a breaker IED Control operation can be performed from the local IED HMI If users are defined in the IED then the local remote switch is under authority control otherwise the default user can perform control operations from the local IED HMI without logging in The default position of the local remote switch is on remote Section 12 1MRK 506 375 UEN A Co...

Page 247: ...3 4 5 6 PSTO All then it is no priority between operator places All operator places are allowed to operate According to IEC 61850 standard the orCat attribute in originator category are defined in Table 26 Table 26 orCat attribute according to IE C61850 Value Description 0 not supported 1 bay control 2 station control 3 remote control 4 automatic bay 5 automatic station 6 automatic remote 7 mainte...

Page 248: ... IEC 61850 8 1 edition 2 command LocSta QCBAY also provides blocking functions that can be distributed to different apparatuses within the bay There are two different blocking alternatives Blocking of update of positions Blocking of commands IEC13000016 2 en vsd IEC13000016 V2 EN US Figure 77 APC Local remote function block 12 3 1 2 Switch controller SCSWI M16596 3 v5 After the selection of an app...

Page 249: ...ircuit under normal conditions or to interrupt the circuit under fault or emergency conditions The intention with these functions is to represent the lowest level of a power switching device with or without short circuit breaking capability for example circuit breakers disconnectors earthing switches etc The purpose of these functions is to provide the actual status of positions and to perform the...

Page 250: ...ing the represented switch Otherwise the function only reflects the current status of the switch such as blocking selection position operating capability and operation counter Since different switches are represented differently on IEC 61850 the data that is mandatory to model in IEC 61850 is mandatory inputs and the other useful data for the command and status following is optional To make it eas...

Page 251: ...itch to start moving it checks if the switch is blocked for the operation When the switch has started moving and no blocking condition has been detected XLNPROXY issues a response to the SCSWI function that the command has started If OPOK is used this response is given when XLNPROXY receives the signal If no movement of the switch is registered within the limit tStartMove the command is considered...

Page 252: ...vely SwOpCap for a XSWI The interpretation for the command following is controlled through the setting SwitchType 12 3 1 5 Reservation function QCRSV and RESIN M16609 3 v4 The purpose of the reservation function is primarily to transfer interlocking information between IEDs in a safe way and to prevent double operation in a bay switchyard part or complete substation For interlocking evaluation in ...

Page 253: ...nals are either the request for reservation from another bay or the acknowledgment from each bay respectively which have received a request from this bay Also the information of valid transmission over the station bus must be received en05000117 vsd IED IED From other SCSWI in the bay To other SCSWI in the bay 3 Station bus 3 RESIN EXCH_OUT EXCH_IN RESIN EXCH_OUT EXCH_IN SCSWI RES_RQ RES_GRT RES_D...

Page 254: ...on in Figure 80 but instead have a higher availability since no acknowledgment is required SCSWI SELECTED RES_EXT IED IED OR Other SCWI in the bay Station bus SPGAPC IN RESGRANT IntlReceive RESGRANT IntlReceive IEC05000178 3 en vsd IEC05000178 V3 EN US Figure 82 Application principle for an alternative reservation solution 12 3 2 Interaction between modules M16626 3 v8 A typical bay with apparatus...

Page 255: ...to be transmitted to SXCBR The Autorecloser SMBRREC consists of the facilities to automatically close a tripped breaker with respect to a number of configurable conditions The logical node Interlocking SCILO provides the information to SCSWI whether it is permitted to operate due to the switchyard topology The interlocking conditions are evaluated with separate logic and connected to SCILO The Syn...

Page 256: ...en Close Open Close Enable close Enable open Open rel Close rel Open rel SMPPTRC Trip logic Position Pos from other bays I O Open cmd Close cmd Synchronizing OK Synchrocheck OK Start Synchronizing Synchronizing in progress SCILO Interlocking Enable open Enable close IEC05000120 3 EN vsdx IEC05000120 V3 EN US Figure 83 Example overview of the interactions between functions in a typical bay 12 3 3 S...

Page 257: ...ommand is desired the model direct control with normal security is used At control with enhanced security there is an additional supervision of the status value by the control object which means that each command sequence must be terminated by a termination command The parameter PosDependent gives permission to operate depending on the position indication that is at Always permitted it is always p...

Page 258: ... and operate Sel Op phase or only at operate Op phase 12 3 3 3 Switch SXCBR SXSWI M16675 3 v8 tStartMove is the supervision time for the apparatus to start moving after a command execution is done from the SCSWI function When the time has expired the command supervision is reset and a cause code is given During the tIntermediate time the position indication is allowed to be in an intermediate 00 s...

Page 259: ...en During the tIntermediate time the position indication is allowed to be in an intermediate 00 state When the time has expired the command supervision is reset and a cause code is given The indication of the mid position at SCSWI is suppressed during this time period when the position changes from open to close or vice versa if the parameter SuppressMidPos is set to On in the SCSWI function In mo...

Page 260: ...ed To connect or disconnect a parallel circuit carrying load current The switching voltage across the open contacts is thus virtually zero thanks to the parallel circuit for example 1 of rated voltage Paralleling of power transformers is not allowed Earthing switches are allowed to connect and disconnect earthing of isolated points Due to capacitive or inductive coupling there may be some voltage ...

Page 261: ...al operation gear per phase the evaluation must consider possible phase discrepancies This is done with the aid of an AND function for both two phases in each apparatus for both open and close indications Phase discrepancies will result in an unknown double indication state 12 4 1 Configuration guidelines M13529 4 v4 The following sections describe how the interlocking for a certain switchgear con...

Page 262: ...n the own bay are open VP_BB7_D The switch status of disconnectors on bypass busbar WA7 are valid EXDU_BPB No transmission error from any bay containing disconnectors on bypass busbar WA7 These signals from each line bay ABC_LINE except that of the own bay are needed Signal QB7OPTR Q7 is open VPQB7TR The switch status for QB7 is valid EXDU_BPB No transmission error from the bay that contains the a...

Page 263: ...2 B1 WA7 C C B2 A2 en04000479 vsd IEC04000479 V1 EN US Figure 86 Busbars divided by bus section disconnectors circuit breakers To derive the signals Signal BC_12_CL A bus coupler connection exists between busbar WA1 and WA2 BC_17_OP No bus coupler connection between busbar WA1 and WA7 BC_17_CL A bus coupler connection exists between busbar WA1and WA7 BC_27_OP No bus coupler connection between busb...

Page 264: ...fferent busbars that is for both bus section disconnector A1A2_DC and B1B2_DC Signal DCOPTR The bus section disconnector is open DCCLTR The bus section disconnector is closed VPDCTR The switch status of bus section disconnector DC is valid EXDU_DC No transmission error from the bay that contains the above information If the busbar is divided by bus section circuit breakers the signals from the bus...

Page 265: ... 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 vsd IEC04000480 V1 EN US Figure 87 Signals to a line bay in section 1 from the bus coupler bays in each section For a line bay in section 2 the same conditions as above are valid by changing section 1 to section 2 and vice versa 12 4 2 4 Configuration setting M13560 108 v4 If there is no...

Page 266: ...ond busbar WA2 and therefore no QB2 disconnector then the interlocking for QB2 is not used The state for QB2 QC21 BC_12 BC_27 are set to open by setting the appropriate module inputs as follows In the functional block diagram 0 and 1 are designated 0 FALSE and 1 TRUE QB2_OP 1 QB2_CL 0 QC21_OP 1 QC21_CL 0 BC_12_CL 0 BC_27_OP 1 BC_27_CL 0 VP_BC_12 1 12 4 3 Interlocking for bus coupler bay ABC_BC IP1...

Page 267: ..._BC are described below 12 4 3 3 Signals from all feeders M13553 6 v4 To derive the signals Signal BBTR_OP No busbar transfer is in progress concerning this bus coupler VP_BBTR The switch status is valid for all apparatuses involved in the busbar transfer EXDU_12 No transmission error from any bay connected to the WA1 WA2 busbars These signals from each line bay ABC_LINE each transformer bay AB_TR...

Page 268: ...0482 V1 EN US Figure 90 Busbars divided by bus section disconnectors circuit breakers The following signals from each bus section disconnector bay A1A2_DC are needed For B1B2_DC corresponding signals from busbar B are used The same type of module A1A2_DC is used for different busbars that is for both bus section disconnector A1A2_DC and B1B2_DC Signal DCOPTR The bus section disconnector is open VP...

Page 269: ... BBTR_OP 1 IEC04000483 V1 EN US Figure 91 Signals to a bus coupler bay in section 1 from any bays in each section For a bus coupler bay in section 2 the same conditions as above are valid by changing section 1 to section 2 and vice versa 12 4 3 4 Signals from bus coupler M13553 58 v5 If the busbar is divided by bus section disconnectors into bus sections the signals BC_12 from the busbar coupler o...

Page 270: ...2_DC Signal DCCLTR The bus section disconnector is closed VPDCTR The switch status of bus section disconnector DC is valid EXDU_DC No transmission error from the bay that contains the above information If the busbar is divided by bus section circuit breakers the signals from the bus section coupler bay A1A2_BS rather than the bus section disconnector bay A1A2_DC must be used For B1B2_BS correspond...

Page 271: ...interlocking for QB2 and QB7 is not used The states for QB2 QB7 QC71 are set to open by setting the appropriate module inputs as follows In the functional block diagram 0 and 1 are designated 0 FALSE and 1 TRUE QB2_OP 1 QB2_CL 0 QB7_OP 1 QB7_CL 0 QC71_OP 1 QC71_CL 0 If there is no second busbar B and therefore no QB2 and QB20 disconnectors then the interlocking for QB2 and QB20 are not used The st...

Page 272: ...etween circuit breaker and transformer Otherwise the interlocking for line bay ABC_LINE function can be used This function can also be used in single busbar arrangements QB1 QB2 QC1 QA1 QC2 WA1 A WA2 B QA2 QC3 T QC4 QB4 QB3 QA2 and QC4 are not used in this interlocking AB_TRAFO en04000515 vsd IEC04000515 V1 EN US Figure 94 Switchyard layout AB_TRAFO M13566 4 v4 The signals from other bays connecte...

Page 273: ...e line bay ABC_LINE Signal BC_12_CL A bus coupler connection exists between busbar WA1 and WA2 VP_BC_12 The switch status of BC_12 is valid EXDU_BC No transmission error from bus coupler bay BC The logic is identical to the double busbar configuration Signals from bus coupler 12 4 4 3 Configuration setting M13566 22 v5 If there are no second busbar B and therefore no QB2 disconnector then the inte...

Page 274: ...hich includes a bus section circuit breaker QA1 WA1 A1 QB2 QC4 QB1 QC3 WA2 A2 en04000516 vsd QC2 QC1 A1A2_BS IEC04000516 V1 EN US Figure 96 Switchyard layout A1A2_BS M15111 4 v3 The signals from other bays connected to the module A1A2_BS are described below 12 4 5 2 Signals from all feeders M15111 6 v4 If the busbar is divided by bus section circuit breakers into bus sections and both circuit brea...

Page 275: ...o transmission error from the bay that contains the above information These signals from each bus coupler bay ABC_BC are needed Signal BC12OPTR No bus coupler connection through the own bus coupler between busbar WA1 and WA2 VPBC12TR The switch status of BC_12 is valid EXDU_BC No transmission error from the bay that contains the above information These signals from the bus section circuit breaker ...

Page 276: ...t 2 VPQB12TR bay 1 sect 1 VPQB12TR bay n sect 1 EXDU_12 bay 1 sect 2 EXDU_12 bay n sect 2 EXDU_12 bay 1 sect 1 EXDU_12 bay n sect 1 EXDU_BS B1B2 EXDU_BC sect 1 EXDU_BC sect 2 IEC04000490 V1 EN US Figure 98 Signals from any bays for a bus section circuit breaker between sections A1 and A2 For a bus section circuit breaker between B1 and B2 section busbars these conditions are valid Section 12 1MRK ...

Page 277: ...ect 1 EXDU_12 bay n sect 1 EXDU_BS A1A2 EXDU_BC sect 1 EXDU_BC sect 2 IEC04000491 V1 EN US Figure 99 Signals from any bays for a bus section circuit breaker between sections B1 and B2 12 4 5 3 Configuration setting M15111 57 v3 If there is no other busbar via the busbar loops that are possible then either the interlocking for the QA1 open circuit breaker is not used or the state for BBTR is set to...

Page 278: ...2 4 6 2 Signals in single breaker arrangement M13542 6 v5 If the busbar is divided by bus section disconnectors the condition no other disconnector connected to the bus section must be made by a project specific logic The same type of module A1A2_DC is used for different busbars that is for both bus section disconnector A1A2_DC and B1B2_DC But for B1B2_DC corresponding signals from busbar B are us...

Page 279: ...f there is an additional bus section disconnector the signal from the bus section disconnector bay A1A2_DC must be used Signal DCOPTR The bus section disconnector is open VPDCTR The switch status of bus section disconnector DC is valid EXDU_DC No transmission error from the bay that contains the above information If there is an additional bus section circuit breaker rather than an additional bus s...

Page 280: ... the A2 busbar section are valid QB1OPTR bay 1 sect A2 S2DC_OP VPS2_DC EXDU_BB en04000495 vsd QB1OPTR bay n sect A2 VPQB1TR bay 1 sect A2 VPQB1TR bay n sect A2 VPDCTR A2 A3 EXDU_BB bay n sect A2 DCOPTR A2 A3 EXDU_BB bay 1 sect A2 EXDU_DC A2 A3 IEC04000495 V1 EN US Figure 103 Signals from any bays in section A2 to a bus section disconnector For a bus section disconnector these conditions from the B...

Page 281: ...220TR bay n sect B2 VPDCTR B2 B3 EXDU_BB bay n sect B2 DCOPTR B2 B3 EXDU_BB bay 1 sect B2 EXDU_DC B2 B3 IEC04000497 V1 EN US Figure 105 Signals from any bays in section B2 to a bus section disconnector 12 4 6 3 Signals in double breaker arrangement M13542 80 v5 If the busbar is divided by bus section disconnectors the condition for the busbar disconnector bay no other disconnector connected to the...

Page 282: ... section 2 is valid EXDU_BB No transmission error from double breaker bay DB that contains the above information These signals from each double breaker bay DB_BUS are needed Signal QB1OPTR QB1 is open QB2OPTR QB2 is open VPQB1TR The switch status of QB1 is valid VPQB2TR The switch status of QB2 is valid EXDU_DB No transmission error from the bay that contains the above information The logic is ide...

Page 283: ...hese conditions from the A2 busbar section are valid QB1OPTR bay 1 sect A2 S2DC_OP VPS2_DC EXDU_BB en04000500 vsd QB1OPTR bay n sect A2 VPQB1TR bay 1 sect A2 VPQB1TR bay n sect A2 EXDU_DB bay 1 sect A2 EXDU_DB bay n sect A2 IEC04000500 V1 EN US Figure 108 Signals from double breaker bays in section A2 to a bus section disconnector For a bus section disconnector these conditions from the B1 busbar ...

Page 284: ... B2 EXDU_DB bay 1 sect B2 EXDU_DB bay n sect B2 IEC04000502 V1 EN US Figure 110 Signals from double breaker bays in section B2 to a bus section disconnector 12 4 6 4 Signals in 1 1 2 breaker arrangement M13542 127 v5 If the busbar is divided by bus section disconnectors the condition for the busbar disconnector bay no other disconnector connected to the bus section must be made by a project specif...

Page 285: ..._BB No transmission error from breaker and a half BH that contains the above information 12 4 7 Interlocking for busbar earthing switch BB_ES IP14164 1 v4 12 4 7 1 Application M15015 3 v7 The interlocking for busbar earthing switch BB_ES function is used for one busbar earthing switch on any busbar parts according to figure 112 QC en04000504 vsd IEC04000504 V1 EN US Figure 112 Switchyard layout BB...

Page 286: ... is open VPQB1TR The switch status of QB1 is valid VPQB2TR The switch status of QB2 is valid VQB220TR The switch status of QB2and QB20 is valid VPQB7TR The switch status of QB7 is valid EXDU_BB No transmission error from the bay that contains the above information These signals from each bus section disconnector bay A1A2_DC are also needed For B1B2_DC corresponding signals from busbar B are used T...

Page 287: ...XDU_BS No transmission error from the bay BS bus section coupler bay that contains the above information For a busbar earthing switch these conditions from the A1 busbar section are valid QB1OPTR bay 1 sect A1 BB_DC_OP VP_BB_DC EXDU_BB en04000506 vsd QB1OPTR bay n sect A1 VPQB1TR bay 1 sect A1 VPQB1TR bay n sect A1 VPDCTR A1 A2 EXDU_BB bay n sect A1 DCOPTR A1 A2 EXDU_BB bay 1 sect A1 EXDU_DC A1 A2...

Page 288: ...om the B1 busbar section are valid QB2OPTR QB220OTR bay 1 sect B1 BB_DC_OP VP_BB_DC EXDU_BB en04000508 vsd QB2OPTR QB220OTR bay n sect B1 VPQB2TR VQB220TR bay 1 sect B1 VPQB2TR VQB220TR bay n sect B1 VPDCTR B1 B2 EXDU_BB bay n sect B1 DCOPTR B1 B2 EXDU_BB bay 1 sect B1 EXDU_DC B1 B2 IEC04000508 V1 EN US Figure 116 Signals from any bays in section B1 to a busbar earthing switch in the same section ...

Page 289: ...ame section For a busbar earthing switch on bypass busbar C these conditions are valid QB7OPTR bay 1 BB_DC_OP VP_BB_DC EXDU_BB en04000510 vsd QB7OPTR bay n VPQB7TR bay 1 VPQB7TR bay n EXDU_BB bay 1 EXDU_BB bay n IEC04000510 V1 EN US Figure 118 Signals from bypass busbar to busbar earthing switch 12 4 7 3 Signals in double breaker arrangement M15053 83 v4 The busbar earthing switch is only allowed ...

Page 290: ...rom the bay that contains the above information These signals from each bus section disconnector bay A1A2_DC are also needed For B1B2_DC corresponding signals from busbar B are used The same type of module A1A2_DC is used for different busbars that is for both bus section disconnectors A1A2_DC and B1B2_DC Signal DCOPTR The bus section disconnector is open VPDCTR The switch status of bus section di...

Page 291: ...rs on this part of the busbar are open VP_BB_DC The switch status of all disconnectors on this part of the busbar is valid EXDU_BB No transmission error from any bay that contains the above information 12 4 8 Interlocking for double CB bay DB IP14167 1 v2 12 4 8 1 Application M13585 3 v10 The interlocking for a double busbar double circuit breaker bay including DB_BUS_A DB_BUS_B and DB_LINE functi...

Page 292: ...nd QC9 just set the appropriate inputs to open state and disregard the outputs In the functional block diagram 0 and 1 are designated 0 FALSE and 1 TRUE QB9_OP 1 QB9_CL 0 QC9_OP 1 QC9_CL 0 If in this case line voltage supervision is added then rather than setting QB9 to open state specify the state of the voltage supervision QB9_OP VOLT_OFF QB9_CL VOLT_ON If there is no voltage supervision then se...

Page 293: ...7 v4 Three types of interlocking modules per diameter are defined BH_LINE_A and BH_LINE_B are the connections from a line to a busbar BH_CONN is the connection between the two lines of the diameter in the 1 1 2 breaker switchyard layout M13569 4 v4 For a 1 1 2 breaker arrangement the modules BH_LINE_A BH_CONN and BH_LINE_B must be used 12 4 9 2 Configuration setting M13569 6 v5 For application wit...

Page 294: ...ion is designed to regulate the voltage at the secondary side of the power transformer The control method is based on a step by step principle which means that a control pulse one at a time will be issued to the tap changer mechanism to move it one position up or down The length of the control pulse can be set within a wide range to accommodate different types of tap changer mechanisms The pulse i...

Page 295: ... transformer within given limits around a set target voltage A raise or lower command is generated whenever the measured voltage for a given period of time deviates from the set target value by more than the preset deadband value degree of insensitivity A time delay inverse or definite time is set to avoid unnecessary operation during shorter voltage deviations from the target value and in order t...

Page 296: ...P2 and U3P2 corresponding to HV current LV current and LV voltage respectively These analog quantities are fed to the IED via the transformer input module the Analog to Digital Converter and thereafter a Pre Processing Block In the Pre Processing Block a great number of quantities for example phase to phase analog values sequence values max value in a three phase group etc are derived The differen...

Page 297: ...ingle phase earth However it shall be remembered that this can only be used in solidly earthed systems as the measured phase earth voltage can increase with as much as a factor 3 in case of earth faults in a non solidly earthed system The analog input signals are normally common with other functions in the IED for example protection functions The LV busbar voltage is designated UB the load current...

Page 298: ...aise or lower timer will start The timer will run as long as the measured voltage stays outside the inner deadband If this condition persists longer than the preset time delay TR1ATCC will initiate that the appropriate ULOWER or URAISE command will be sent from TCMYLTC or TCLYLTC function block to the transformer tap changer If necessary the procedure will be repeated until the magnitude of the bu...

Page 299: ... This can be done by setting a longer time delay closer to the consumer and shorter time delays higher up in the system The first time delay t1 is used as a time delay usually long delay for the first command in one direction It can have a definite or inverse time characteristic according to the setting t1Use Constant Inverse For inverse time characteristics larger voltage deviations from the USet...

Page 300: ... delay follows the similar formulas as for the first time delay but the t2 setting is used instead of t1 Line voltage drop SEMOD159053 105 v6 The purpose with the line voltage drop compensation is to control the voltage not at the power transformer low voltage side but at a point closer to the load point Figure 126 shows the vector diagram for a line modelled as a series impedance with the voltage...

Page 301: ...ition and if the wish is to allow for a situation like that the limitation can be removed by setting the parameter OperCapaLDC to On Load RL XL UB UL UB RLIL jXLIL Re IEC06000487 2 en vsd IEC06000487 V2 EN US Figure 126 Vector diagram for line voltage drop compensation The calculated load voltage UL is shown on the local HMI as value ULOAD under Main menu Test Function status Control TransformerVo...

Page 302: ... Automatic load voltage adjustment factor setting VRAuto IL Load current I2Base Rated current LV winding Sci Constant load voltage adjust factor for active input i corresponding to LVAConst1 LVAConst2 LVAConst3 and LVAConst4 It shall be noted that the adjustment factor is negative in order to decrease the load voltage and positive in order to increase the load voltage After this calculation Uset a...

Page 303: ...turn causes an increasing circulating current This course of events will then repeat with T1 initiating raise commands and T2 initiating lower commands in order to keep the busbar voltage within USet DU but at the same time it will drive the two tap changers to their opposite end positions High circulating currents and loss of control would be the result of this runaway tap situation Parallel cont...

Page 304: ... these inputs has been activated the default is that the transformer acts as a follower given of course that the settings are parallel control with the master follower method When the selection of master or follower in parallel control or automatic control in single mode is made with a three position switch in the substation an arrangement as in figure 127 below is arranged with application config...

Page 305: ...ere the principle of reverse reactance has been introduced for the transformers in figure 128 The transformers are here supposed to be on the same tap position and the busbar voltage is supposed to give a calculated compensated value UL that coincides with the target voltage USet IEC06000485_2_en vsd UB RLIT1 RLIT2 jXLIT1 jXLIT2 IT1 IT2 IT1 IT2 2 UL1 UL2 USet IEC06000485 V3 EN US Figure 129 Vector...

Page 306: ...IT1 IT2 RLIT2 jXLIT2 ICC T2 ICC T1 IL IEC06000491 V3 EN US Figure 130 Circulating current caused by T1 on a higher tap than T2 The circulating current Icc is predominantly reactive due to the reactive nature of the transformers The impact of Icc on the individual transformer currents is that it increases the current in T1 the transformer that is driving Icc and decreases it in T2 at the same time ...

Page 307: ... operate or in different IEDs If the functions are located in different IEDs they must communicate via GOOSE interbay communication on the IEC 61850 communication protocol Complete exchange of TR8ATCC data analog as well as binary via GOOSE is made cyclically every 300 ms The busbar voltage UB is measured individually for each transformer in the parallel group by its associated TR8ATCC function Th...

Page 308: ...cribed previously in section Automatic voltage control for a single transformer By doing this the overall control strategy can be summarized as follows For the transformer producing receiving the circulating current the calculated no load voltage will be greater smaller than the measured voltage UBmean The calculated no load voltage will then be compared with the set voltage USet A steady deviatio...

Page 309: ... to On Simultaneous tapping is then avoided at the same time as tapping actions in the long term are distributed evenly amongst the parallel transformers The algorithm in Automatic voltage control for tap changer parallel control TR8ATCC will select the transformer with the greatest voltage deviation Udi to tap first That transformer will then start timing and after time delay t1 the appropriate U...

Page 310: ...nsformer will then automatically initiate URAISE or ULOWER commands with appropriate t1 or t2 time delay in order to keep the LV side of the transformer within the deadband of the busbar voltage Homing operation with the master follower method SEMOD159053 216 v3 If one or more follower has its LV circuit breaker open and its HV circuit breaker closed and if OperHoming On this follower continues to...

Page 311: ...er control In this situation the followers will continue to follow the master the same way as when it is in automatic control If one follower in a master follower parallel group is put in manual mode still with the setting OperationAdaptOn the rest of the group will continue in automatic master follower control The follower in manual mode will of course disregard any possible tapping of the master...

Page 312: ...garding the currents in the primary network However the CT measured currents for the transformers would be different The capacitor bank current may flow entirely to the load on the LV side or it may be divided between the LV and the HV side In the latter case the part of IC that goes to the HV side will divide between the two transformers and it will be measured with opposite direction for T2 and ...

Page 313: ...an be utilized for different purposes for example to block the voltage control function when active power is flowing from the LV side to the HV side or to initiate switching of reactive power compensation plant and so on There are four setting parameters P P Q and Q with associated outputs in TR8ATCC and TR1ATCC function blocks PGTFWD PLTREV QGTFWD and QLTREV When passing the pre set value the ass...

Page 314: ...has to consider in the parallel control In a simple case when only the switchgear in the transformer bays needs to be considered there is a built in function in TR8ATCC block that can provide information on whether a transformer is connected to the parallel group or not This is made by connecting the transformer CB auxiliary contact status to TR8ATCC function block input DISC which can be made via...

Page 315: ...ions working in parallel according to the current station configuration When the parallel voltage control function detects that no other transformers work in parallel it will behave as a single voltage control function in automatic mode Exchange of information between TR8ATCC functions SEMOD159053 267 v6 Each transformer in a parallel group needs an Automatic voltage control for tap changer parall...

Page 316: ...ntrol mode termReadyForMSF Activated when the transformer is ready for master follower parallel control mode raiseVoltageOut Order from the master to the followers to tap up lowerVoltageOut Order from the master to the followers to tap down Table 30 Analog signals Signal Explanation voltageBusbar Measured busbar voltage for this transformer ownLoadCurrim Measured load current imaginary part for th...

Page 317: ...the transformers in figure 133 would then be according to the table 31 Table 31 Setting of TxRXOP TrfId T1 T1RXOP Off T2RXOP On T3RXOP On T4RXOP Off T5RXOP Off T6RXOP Off T7RXOP Off T8RXOP Off TrfId T2 T1RXOP On T2RXOP Off T3RXOP On T4RXOP Off T5RXOP Off T6RXOP Off T7RXOP Off T8RXOP Off TrfId T3 T1RXOP On T2RXOP On T3RXOP Off T4RXOP Off T5RXOP Off T6RXOP Off T7RXOP Off T8RXOP Off Observe that this...

Page 318: ...voltage into the range Umin UB Umax The FSD function is blocked when the lowest voltage tap position is reached The time delay for the FSD function is separately set The output UHIGH will be activated as long as the voltage is above Umax UVPartBk automatically reset Alarm Auto Man Block If the busbar voltage UB not the compensated load point voltage UL is between Ublock and Umin see figure124 an a...

Page 319: ...or a position change before a new command is issued The command error signal CMDERRAL on the TCMYLTC or TCLYLTC function block will be set if the tap changer position does not change one step in the correct direction within the time given by the setting tTCTimeout in TCMYLTC or TCLYLTC function block The tap changer module TCMYLTC or TCLYLTC will then indicate the error until a successful command ...

Page 320: ...l to the INERR input input module error or BIERR on TCMYLTC or TCLYLTC function block Interruption of communication with the tap changer The outputs POSERRAL and AUTOBLK or TOTBLK will be set This error condition can be reset by the input RESETERR on TCMYLTCfunction block or alternatively by changing control mode of TR1ATCC or TR8ATCC function to Manual and then back to Automatic CircCurrBk automa...

Page 321: ...isted in table 34 Table 34 Blocking via binary inputs Input name Activation Description BLOCK manually reset On Off via binary input The voltage control function can be totally blocked via the binary input BLOCK on TR1ATCC or TR8ATCC function block The output TOTBLK will be activated EAUTOBLK manually reset On Off via binary input The voltage control function can be blocked for automatic control v...

Page 322: ...be removed when the transformer is reconnected input signal DISC set back to zero One transformer in a parallel group switched to manual control automatically reset Auto Block When the setting OperationAdapt is Off automatic control will be blocked when parallel control with the master follower or the circulating current method is used and one of the transformers in the group is switched from auto...

Page 323: ...hod the following blocking conditions in any of the followers will also cause mutual blocking Master follower out of position Master follower error No master More than one master General It should be noted that partial blocking will not cause mutual blocking TR8ATCC which is the source of the mutual blocking will set its AUTOBLK output as well as the output which corresponds to the actual blocking...

Page 324: ...p changer according to the settings LowVoltTap and HighVoltTap When the tap changer reaches its lowest highest position the corresponding LOPOSAL HIPOSAL alarm signal will be activated Monitoring of tap changer operation SEMOD159053 344 v5 The Tap changer control and supervision 6 binary inputs TCMYLTC or 32 binary inputs TCLYLTC output signal URAISE or ULOWER is set high when TR1ATCC or TR8ATCC f...

Page 325: ...ROG disappears If the TCINPROG signal is not fed back from the tap changer mechanism TR1ATCC or TR8ATCC will not reset until tTCTimeout has timed out The advantage with monitoring the TCINPROG signal in this case is thus that resetting of TR1ATCC or TR8ATCC can sometimes be made faster which in turn makes the system ready for consecutive commands in a shorter time The second use is to detect a jam...

Page 326: ...ignal HOURHUNT when the number of tap changer operations exceed the number given by the setting HourHuntDetect during the last hour sliding window Active as well in manual as in automatic mode 3 TR1ATCC or TR8ATCC function will activate the output signal HUNTING when the total number of contradictory tap changer operations RAISE LOWER RAISE LOWER and so on exceeds the pre set value given by the se...

Page 327: ...ndividuals in a parallel group Thus transformers that can be part of the same parallel group must have unique identities Moreover all transformers that communicate over the same horizontal communication GOOSE must have unique identities Xr2 The reactance of the transformer in primary ohms referred to the LV side tAutoMSF Time delay set in a follower for execution of a raise or lower command given ...

Page 328: ... voltage control for tap changer TR1ATCC for single control and TR8ATCC for parallel control function On Off I1Base Base current in primary Ampere for the HV side of the transformer I2Base Base current in primary Ampere for the LV side of the transformer UBase Base voltage in primary kV for the LV side of the transformer MeasMode Selection of single phase or phase phase or positive sequence quanti...

Page 329: ... 75 125 of the tap changer step UDeadbandInner Setting value for one half of the inner deadband to be set in percent of UBase The inner deadband is symmetrical around USet see section Automatic voltage control for a single transformer figure 124 In that figure UDeadbandInner is equal to DUin The setting shall be smaller than UDeadband Typically the inner deadband can be set to 25 70 of the UDeadba...

Page 330: ...or parallel control with the reverse reactance method then OperCapaLDC must always be set On Rline and Xline For line voltage drop compensation these settings give the line resistance and reactance from the station busbar to the load point The settings for Rline and Xline are given in primary system ohms If more than one line is connected to the LV busbar equivalent Rline and Xline values should b...

Page 331: ...tap change control regulates the voltage towards a set target value representing a voltage magnitude without considering the phase angle Thus UB as well as UL and also the dashed line could all be said to be on the target value Assume that we want to achieve that j2 90 then 0 1 1 90 0 1 0 1 90 90 j j j j U Z I Ue Ze Ie ZIe j j j j j j j j D ß D ß ß EQUATION1938 V1 EN US Equation 76 If for example ...

Page 332: ...ne and Xline Apparently the ratio Rline Xline according to equation 77 that is the value of j1 must be set with respect to the power factor also meaning that the reverse reactance method should not be applied to systems with varying power factor The setting of Xline gives the sensitivity of the parallel regulation If Xline is set too low the transformers will not pull together and a run away tap s...

Page 333: ...e USet is given in percent of UBase LVAConst3 Setting of the third load voltage adjustment value This adjustment of the target value USet is given in percent of UBase LVAConst4 Setting of the fourth load voltage adjustment value This adjustment of the target value USet is given in percent of UBase VRAuto Setting of the automatic load voltage adjustment This adjustment of the target value USet is g...

Page 334: ...th sign which effectively means that a negative value of P means an active power greater than a value in the reverse direction This is shown in figure 137 where a negative value of P means pickup for all values to the right of the setting Reference is made to figure 132 for definition of forward and reverse direction of power through the transformer en06000634_2_en vsd P P IEC06000634 V2 EN US Fig...

Page 335: ...ut signals PGTFWD PLTREV QGTFWD and QLTREV Parallel control ParCtrl OperationPAR Setting of the method for parallel operation OperCCBlock This setting enables disables blocking if the circulating current exceeds CircCurrLimit CircCurrLimit Pick up value for the circulating current blocking function The setting is made in percent of I2Base tCircCurr Time delay for the circulating current blocking f...

Page 336: ...t values for the transformers in the same parallel group will be calculated and used OperHoming Enables disables the homing function Applicable for parallel control with the circulating current method as well for parallel control with the master follower method VTmismatch Setting of the level for activation of the output VTALARM in case the voltage measurement in one transformer bay deviates to th...

Page 337: ... 1 irrespective of the setting of CLFactor The setting of this factor gives the weighting of the deviation with respect to the load current InitCLCounter The ContactLife counter monitors the remaining number of operations decremental counter The setting InitCLCounter then gives the start value for the counter that is the total number of operations at rated load that the tap changer is designed for...

Page 338: ...and DOWN one blocking input BLOCK and one operator position input PSTO SLGAPC can be activated both from the local HMI and from external sources switches via the IED binary inputs It also allows the operation from remote like the station computer SWPOSN is an integer value output giving the actual output number Since the number of positions of the switch can be established by settings see below on...

Page 339: ...ini switch VSGAPC function is a multipurpose function used in the configuration tool in PCM600 for a variety of applications as a general purpose switch VSGAPC can be used for both acquiring an external switch position through the IPOS1 and the IPOS2 inputs and represent it through the single line diagram symbols or use it in the configuration through the outputs POS1 and POS2 as well as a command...

Page 340: ...h 12 8 Generic communication function for Double Point indication DPGAPC SEMOD55384 1 v4 12 8 1 Identification GUID E16EA78F 6DF9 4B37 A92D 5C09827E2297 v3 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Generic communication function for Double Point indication DPGAPC 12 8 2 Application SEMOD55391 5 v8 Generic communication function for Double ...

Page 341: ...ALID changes the timestamp of the output POSITION will be updated as the time when DPGAPC function detects the change Refer to Table 36 for the description of the input output relationship in terms of the value and the quality attributes Table 36 Description of the input output relationship VALID OPEN CLOSE POSITION Value Description 0 0 Intermediate 1 0 0 0 Intermediate 1 1 0 1 Open 1 0 1 2 Close...

Page 342: ...h the SPC8GAPC function block is REMOTE 12 9 3 Setting guidelines SEMOD176518 4 v6 The parameters for the single point generic control 8 signals SPC8GAPC function are set via the local HMI or PCM600 Operation turning the function operation On Off There are two settings for every command output totally 8 PulseModex decides if the command signal for output x is Latched steady or Pulsed tPulsex if Pu...

Page 343: ...8639 5 v3 AUTOBITS function block has one setting Operation On Off enabling or disabling the function These names will be seen in the DNP3 communication management tool in PCM600 12 11 Single command 16 signals SINGLECMD SEMOD119849 1 v2 12 11 1 Identification GUID 2217CCC2 5581 407F A4BC 266CD6808984 v1 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device ...

Page 344: ... check condition Single command function SINGLECMD CMDOUTy OUTy Close CB1 User defined conditions Synchro check Configuration logic circuits en04000206 vsd IEC04000206 V2 EN US Figure 140 Application example showing a logic diagram for control of a circuit breaker via configuration logic circuits Figure 141 and figure 142 show other ways to control functions which require steady On Off signals Her...

Page 345: ...Device 1 User defined conditions Configuration logic circuits en04000208 vsd IEC04000208 V2 EN US Figure 142 Application example showing a logic diagram for control of external devices via configuration logic circuits 12 11 3 Setting guidelines M12448 3 v2 The parameters for Single command 16 signals SINGLECMD are set via the local HMI or PCM600 1MRK 506 375 UEN A Section 12 Control Railway applic...

Page 346: ...dentification ANSI IEEE C37 2 device number Transformer Energizing Control XENCPOW 0 1T IEC15000180 V1 EN US 25T 12 12 2 Application GUID 11110C3C 33A3 4B36 9D85 F112334B29D1 v2 The transformer core may become saturated due to an abrupt change in the voltage applied to it This may be caused by Switching transients Out of phase synchronization of a generator Clearing of an external fault When satur...

Page 347: ...W is used to minimize inrush currents by energizing the transformer near the voltage peak Energizing the transformer at a voltage zero crossing results in the most severe inrush current Energizing the transformer at voltage peak results in no DC offset other than that caused by the initial residual flux 12 12 3 Setting guidelines GUID CC37700A 5AA0 4A71 8073 0D63C79BBDFE v1 The controlled close op...

Page 348: ... when the START input is activated The typical setting is 120 of UBase tBreaker It should be set to match the total closing time of the circuit breaker and it should also include possible auxiliary relays in the closing circuit A typical setting is 80 150 ms tPulse This setting is used to set the close command pulse duration The setting must be grater than the critical impulse time of the circuit ...

Page 349: ...lse or lost signals Communication speed or minimum time delay is always of utmost importance because the purpose of using communication is to improve the tripping speed of the scheme To avoid false signals that could cause false tripping it is necessary to pay attention to the security of the communication channel At the same time it is important to pay attention to the communication channel depen...

Page 350: ...the tripping function if the communication channel is out of service Inadequate speed or dependability can cause spurious tripping for external faults Inadequate security can cause delayed tripping for internal faults To secure that the send signal will arrive before the zone used in the communication scheme will trip the trip is released first after the time delay tCoord has elapsed The setting o...

Page 351: ...ent a gap between the protection zones where faults would not be detected If the underreaching zone do not meet the required sensitivity due to for instance fault infeed from the remote end a blocking or permissive overreaching scheme should be considered The received signal CR must be received when the overreaching zone is activated to achieve an instantaneous trip In some cases due to the fault ...

Page 352: ...cheme must consider besides the general requirement of fast and secure operation also consider requirement on the dependability Inadequate security can cause unwanted tripping for external faults Inadequate speed or dependability can cause delayed tripping for internal faults or even unwanted operations This scheme may use virtually any communication media that is not adversely affected by electri...

Page 353: ...ereby disabling the communication channel To overcome the lower dependability in permissive schemes an unblocking function can be used Use this function at older less reliable power line carrier PLC communication where the signal has to be sent through the primary fault The unblocking function uses a guard signal CRG which must always be present even when no CR signal is received The absence of th...

Page 354: ... communication logic function are set via the local HMI or PCM600 Configure the zones used for the CS send and for scheme communication tripping by using the ACT configuration tool The recommended settings of tCoord timer are based on maximal recommended transmission time for analogue channels according to IEC 60834 1 It is recommended to coordinate the proposed settings with actual performance fo...

Page 355: ...n On Set SchemeType Intertrip Set tCoord 50 ms 10 ms maximal transmission time Set tSendMin 0 1 s 0 s in parallel line applications Set Unblock Off Set tSecurity 0 015 s 13 2 Current reversal and Weak end infeed logic for distance protection 2 phase ZCRWPSCH GUID 3ECC2737 04F1 42EC A44D 75D68E8D1A56 v1 13 2 1 Identification M15073 1 v5 Function description IEC 61850 identification IEC 60617 identi...

Page 356: ...99000043 V3 EN US Figure 147 Current distribution for a fault close to B side when all breakers are closed When the breaker B1 opens for clearing the fault the fault current through B2 bay will invert If the communication signal has not reset at the same time as the distance protection function used in the teleprotection scheme has switched on to forward direction we will have an unwanted operatio...

Page 357: ...on the weak end by different fault detection elements distance protection in forward and reverse direction Also the WEI function can be extended to trip the breaker in the weak side The trip is achieved when one or more phase voltages are low during an echo function Together with the blocking teleprotection scheme some limitations apply Only the trip part of the function can be used together with ...

Page 358: ...breaker operate time communication delay time but with a minimum of 20 ms 13 2 3 2 Weak end infeed logic M13856 10 v7 Set WEI to Echo to activate the weak end infeed function with only echo function Set WEI to Echo Trip to obtain echo with trip Set tPickUpWEI to 10 ms a short delay is recommended to avoid that spurious carrier received signals will activate WEI and cause unwanted carrier send ECHO...

Page 359: ...ths adversely affected by fault generated noise may not be suitable for conventional permissive schemes that rely on signal transmitted during a protected line fault With power line carrier for example the communication signal may be attenuated by the fault especially when the fault is close to the line end thereby disabling the communication channel To overcome the lower dependability in permissi...

Page 360: ... ECRWPSCH IP14365 1 v4 13 4 1 Identification M14883 1 v2 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Current reversal and weak end infeed logic for residual overcurrent protection ECRWPSCH 85 13 4 2 Application IP15041 1 v1 13 4 2 1 Fault current reversal logic M15285 3 v7 Figure 149 and figure 150 show a typical system condition which can r...

Page 361: ...t occur the permissive overreaching function at B2 needs to be blocked by IRVL till the received permissive signal from A2 is reset The IED at A2 where the forward direction element was initially activated must reset before the send signal is initiated from B2 The delayed reset of output signal IRVL also ensures the send signal from IED B2 is held back till the forward direction element is reset i...

Page 362: ...imum tDelayRev setting of 40 ms is recommended The reset time of the directional residual overcurrent protection EF4PTOC is typically 25 ms If other type of residual overcurrent protection is used in the remote line end its reset time should be used The signal propagation time is in the range 3 10 ms km for most types of communication media In communication networks small additional time delays ar...

Page 363: ...c drop Minimum setting of tDelay IEC05000536 2 en vsd IEC05000536 V2 EN US Figure 152 Time sequence of signaling at current reversal 13 4 3 2 Weak end infeed M13933 12 v6 The weak end infeed can be set by setting the parameter WEI to Off Echo or Echo Trip Operating zero sequence voltage when parameter WEI is set to Echo Trip is set with 2U0 The zero sequence voltage for a fault at the remote line ...

Page 364: ...358 ...

Page 365: ...eaker To prevent closing of a circuit breaker after a trip the function offers a lockout function 14 1 2 1 Tripping M14828 7 v10 A simple application with tripping utilizes part of the function block Connect the inputs from the protection function blocks to the input TRIN to combine the different function outputs to this input Connect the output TRIP to the binary outputs on the IO board This sign...

Page 366: ...he activation of the RSTLKOUT input will initiate a short pulse of 3 ms A new reset needs a new activation of the RSTLKOUT input If external conditions are required to initiate a lockout but not initiate a trip this can be achieved by activating input SETLKOUT The setting AutoLock Off means that the internal trip will not activate lockout so only initiation of the input SETLKOUT will result in loc...

Page 367: ...n functions connect the directional data via the start combinator function STARTCOMB to the start matrix function SMAGAPC and then to the trip function SMPPTRC or directly to SMAGAPC and then to the SMPPTRC The SMAGAPC merge start and directional output signals from different application functions and create a common directional output signal STDIR to be connected to SMPPTRC The trip function SMPP...

Page 368: ...ivates lockout through the input SETLKOUT On additionally allows activation of lockout from the trip function itself The normal selection is Off tTripMin Sets the required minimum duration of the trip pulse It should be set to ensure that the circuit breaker is tripped correctly Normal setting is 0 150s 14 2 Trip matrix logic TMAGAPC IP15121 1 v4 14 2 1 Identification SEMOD167882 2 v3 Function des...

Page 369: ...duration of the trip pulse to the circuit breaker trip coils ModeOutputx Defines if output signal OUTPUTx where x 1 3 is Steady or Pulsed 14 3 Logic for group alarm ALMCALH GUID 64EA392C 950F 486C 8D96 6E7736B592BF v1 14 3 1 Identification GUID 64EA392C 950F 486C 8D96 6E7736B592BF v1 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Logic for grou...

Page 370: ...A 4937 92EB 1A8AC0909AB4 v2 OperationOn or Off 14 5 Logic for group indication INDCALH 14 5 1 Identification GUID 3B5D4371 420D 4249 B6A4 5A168920D635 v4 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Logic for group indication INDCALH 14 5 1 1 Application GUID 9BAD30FB 4B75 4E14 82A8 6A59B09FA6EA v1 Group indication logic function INDCALH is u...

Page 371: ...like ANDQT ORQT etc 14 6 2 Setting guidelines GUID E6BD982D 9E47 4CC2 9666 6E5CABA414C0 v3 There are no settings for AND gates OR gates inverters or XOR gates as well as for ANDQT gates ORQT gates or XORQT gates For normal On Off delay and pulse timers the time delays and pulse lengths are set from the local HMI or via the PST tool Both timers in the same logic block the one delayed on pick up and...

Page 372: ...etermined by the order of their serial execution numbers Always remember this when connecting two or more logical function blocks in series Always be careful when connecting function blocks with a fast cycle time to function blocks with a slow cycle time Remember to design the logic circuits carefully and always check the execution sequence for different functions In other cases additional time de...

Page 373: ...F signal in FXDSIGN The Restricted earth fault function REFPDIF can be used both for auto transformers and normal transformers When used for auto transformers information from both windings parts together with the neutral point current needs to be available to the function This means that three inputs are needed I3PW1CT1 I3PW2CT1 I3P REFPDIF IEC09000619_3_en vsd IEC09000619 V3 EN US Figure 157 REF...

Page 374: ...lean 16 to integer conversion function B16I will transfer a combination of up to 16 binary inputs INx where 1 x 16 to an integer Each INx represents a value according to the table below from 0 to 32768 This follows the general formula INx 2x 1 where 1 x 16 The sum of all the values on the activated INx will be available on the output OUT as a sum of the values of all the inputs INx that are activa...

Page 375: ...hen all INx where 1 x 16 are active that is 1 is 65535 65535 is the highest boolean value that can be converted to an integer by the B16I function block 14 9 Boolean to integer conversion with logical node representation 16 bit BTIGAPC SEMOD175753 1 v4 14 9 1 Identification SEMOD175757 2 v5 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Boolean...

Page 376: ...responds to the integer presented on the output OUT on the function block BTIGAPC Name of input Type Default Description Value when activated Value when deactivated IN1 BOOLEAN 0 Input 1 1 0 IN2 BOOLEAN 0 Input 2 2 0 IN3 BOOLEAN 0 Input 3 4 0 IN4 BOOLEAN 0 Input 4 8 0 IN5 BOOLEAN 0 Input 5 16 0 IN6 BOOLEAN 0 Input 6 32 0 IN7 BOOLEAN 0 Input 7 64 0 IN8 BOOLEAN 0 Input 8 128 0 IN9 BOOLEAN 0 Input 9 ...

Page 377: ...ll the inputs INx that are activated OUT is an integer When all INx where 1 x 16 are activated that is Boolean 1 it corresponds to that integer 65535 is available on the output OUT IB16 function is designed for receiving up to 16 booleans input locally If the BLOCK input is activated it will freeze the output at the last value Values of each of the different OUTx from function block IB16 for 1 x 1...

Page 378: ...olean 16 conversion with logic node representation function ITBGAPC is used to transform an integer into a set of 16 boolean signals ITBGAPC function can receive an integer from a station computer for example over IEC 61850 8 1 This function is very useful when the user wants to generate logical commands for selector switches or voltage controllers by inputting an integer number ITBGAPC function h...

Page 379: ...x 16 are active equals 65535 This is the highest integer that can be converted by the ITBGAPC function block 14 12 Elapsed time integrator with limit transgression and overflow supervision TEIGAPC 14 12 1 Identification GUID 1913E066 37D1 4689 9178 5B3C8B029815 v3 Function Description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Elapsed time integrator TEIGAPC 14...

Page 380: ... 99 999 99 seconds tWarning 999 999 0 seconds Note that tAlarm and tWarning are independent settings that is there is no check if tAlarm tWarning The limit for the overflow supervision is fixed at 999999 9 seconds 14 13 Comparator for integer inputs INTCOMP 14 13 1 Identification GUID 5992B0F2 FC1B 4838 9BAB 2D2542BB264D v1 Function description IEC 61850 identification IEC 60617 identification ANS...

Page 381: ...erence value from input REF Set Value The function will take reference value from setting SetValue SetValue This setting is used to set the reference value for comparison when setting RefSource is selected as SetValue 14 13 4 Setting example GUID 13302FD6 1585 42FE BD6D 44F231982C59 v2 For absolute comparison between inputs Set the EnaAbs Absolute Set the RefSource Input REF Similarly for Signed c...

Page 382: ...ting is used to select the comparison type between signed and absolute values Absolute Comparison is performed with absolute values of input and reference Signed Comparison is performed with signed values of input and reference RefSource This setting is used to select the reference source between input and setting for comparison Input REF The function will take reference value from input REF Set V...

Page 383: ...signed with settings as follows EnaAbs Absolute RefSource Set Value SetValue 100 RefPrefix Kilo EqualBandHigh 5 0 of reference value EqualBandLow 5 0 of reference value Operation The function will set the outputs for the following conditions INEQUAL will set when the INPUT is between the ranges of 95 to 105 kA INHIGH will set when the INPUT crosses above 105 kA INLOW will set when the INPUT crosse...

Page 384: ...378 ...

Page 385: ...tral voltage measurement VNMMXU UN IEC15000115 V1 EN US 15 1 2 Application SEMOD54488 4 v12 Measurement functions are used for power system measurement and supervision for reporting to the local HMI the monitoring tool within PCM600 or to station level for example via IEC 61850 The measurement functions operates properly for 16 7Hz 50Hz and 60Hz railway power supply systems The possibility to cont...

Page 386: ...tegral of all changes since the last time value updating exceeds the threshold limit The measure value can also be based on periodic reporting All measurement functions uses fundamental frequency phasors i e DFT filtering for internal calculations and for reporting of measured values However from the following three measurement functions CMMXU VMMXU and VNMMXU it is also possible to report the tot...

Page 387: ...component quantities I sequence currents positive and zero sequence amplitude and angle U sequence voltages positive and zero sequence amplitude and angle It is possible to calibrate the measuring function to get better than class 0 5 presentation This is accomplished by angle and amplitude compensation at 5 30 and 100 of the rated current and at 100 of the rated voltage 15 1 3 Zero clamping GUID ...

Page 388: ...ailable setting parameters of the measurement function CVMMXN CMMXU VMMXU CMSQI VMSQI VNMMXU are depending on the actual hardware TRM and the logic configuration made in PCM600 The parameters for the Measurement functions CVMMXN CMMXU VMMXU CMSQI VMSQI VNMMXU are set via the local HMI or PCM600 GlobalBaseSel Selects the global base value group used by the function to define IBase UBase and SBase a...

Page 389: ...ll monitored quantities included in the functions CVMMXN CMMXU VMMXU CMSQI VMSQI VNMMXU X in setting names below equals S P Q PF F IL1 2 UL1 2 UL12 I1 2I0 U1 or 2U0 Xmin Minimum value for analog signal X set directly in applicable measuring unit Xmax Maximum value for analog signal X XZeroDb Zero point clamping A signal value less than XZeroDb is forced to zero Observe the related zero point clamp...

Page 390: ...nd VNMMXU to get class 0 5 presentations of currents and voltages This is accomplished by amplitude and angle compensation at 5 30 and 100 of rated current and voltage The compensation curve will have the characteristic for amplitude and angle compensation of currents as shown in figure 159 example The first phase will be used as reference channel and compared with the curve for calculation of fac...

Page 391: ... v11 Single line diagram for this application is given in figure 160 110kV Busbar 110kV OHL P Q 600 1 A IEC16000124 1 en vsdx IED 110 0 1kV IEC16000124 V1 EN US Figure 160 Single line diagram for 110kV OHL application In order to monitor supervise and calibrate the active and reactive power as indicated in figure 160 it is necessary to do the following 1 Set correctly CT and VT data and phase angl...

Page 392: ...or level supervision Setting Short Description Selected value Comments PMin Minimum value 100 Minimum expected load PMax Maximum value 100 Maximum expected load PZeroDb Zero point clamping in 0 001 of range 1000 Set zero point clamping to 0 66 MW that is 1 of 66 MW PRepTyp Reporting type db Select amplitude deadband supervision PDbRepInt Cycl Report interval s Db In of range Int Db In s 5 Set Δdb ...

Page 393: ...a using PCM600 for analog input channels 2 Connect in PCM600 measurement function to LV side CT VT inputs 3 Set the setting parameters for relevant Measurement function as shown in table 40 The power P Q measurement is needed towards busbar not towards IED as default Proper inversion of current should be done in SMAI block for the current channels in order to get correct direction of P Q Note that...

Page 394: ...ication IEC 60617 identification ANSI IEEE C37 2 device number Insulation gas monitoring function SSIMG 63 15 2 2 Application GUID A840E38C CC42 4995 A569 A6092DDB81B2 v5 Gas medium supervision SSIMG is used for monitoring the circuit breaker condition Proper arc extinction by the compressed gas in the circuit breaker is very important When the pressure becomes too low compared to the required val...

Page 395: ...cation to reset after a set time delay in s tResetTempLO This is used for the temperature lockout indication to reset after a set time delay in s tResetTempAlm This is used for the temperature alarm indication to reset after a set time delay in s 15 3 Liquid medium supervision SSIML GUID 37669E94 4830 4C96 8A67 09600F847F23 v3 15 3 1 Identification GUID 4CE96EF6 42C6 4F2E A190 D288ABF766F6 v3 Func...

Page 396: ...temperature lockout condition in the transformer tLevelAlarm This is used to set the time delay for a level alarm indication given in s tLevelLockOut This is used to set the time delay for a level lockout indication given in s tTempAlarm This is used to set the time delay for a temperature alarm indication given in s tTempLockOut This is used to set the time delay for a temperature lockout indicat...

Page 397: ... mechanism The excessive travel time can be due to problems in the driving mechanism or failures of the contacts Circuit breaker status Monitoring the breaker status ensures proper functioning of the features within the protection relay such as breaker control breaker failure and autoreclosing The breaker status is monitored using breaker auxiliary contacts The breaker status is indicated by the b...

Page 398: ...of a breaker is 10000 operations Remaining life calculation for three different interrupted current conditions is explained below Breaker interrupts at and below the rated operating current that is 2 kA the remaining life of the CB is decreased by 1 operation and therefore 9999 operations remaining at the rated operating current Breaker interrupts between rated operating current and rated fault cu...

Page 399: ...s it is possible to calculate the number of days the breaker has been inactive Long periods of inactivity degrade the reliability for the protection system Circuit breaker spring charge monitoring For normal circuit breaker operation the circuit breaker spring should be charged within a specified time Detecting a long spring charging time indicates the time for circuit breaker maintenance The last...

Page 400: ...ns CurrExponent Current exponent setting for energy calculation It varies for different types of circuit breakers This factor ranges from 0 5 to 3 0 AccStopCurr RMS current setting below which calculation of energy accumulation stops It is given as a percentage of IBase ContTrCorr Correction factor for time difference in auxiliary and main contacts opening time AlmAccCurrPwr Setting of alarm level...

Page 401: ...ble signal in the IED that is connected to the Event function EVENT The EVENT function block is used for LON and SPA communication Analog integer and double indication values are also transferred through the EVENT function 15 5 3 Setting guidelines IP14841 1 v1 M12811 3 v3 The input parameters for the Event function EVENT can be set individually via the local HMI Main Menu Settings IED Settings Mo...

Page 402: ...BDR 15 6 2 Application M12152 3 v9 To get fast complete and reliable information about disturbances in the primary and or in the secondary system it is very important to gather information on fault currents voltages and events It is also important having a continuous event logging to be able to monitor in an overview perspective These tasks are accomplished by the disturbance report function DRPRD...

Page 403: ...lation CD The user can also upload disturbance report files using FTP or MMS over 61850 8 1 clients If the IED is connected to a station bus IEC 61850 8 1 the disturbance recorder record made and fault number and the fault locator information are available The same information is obtainable if IEC 60870 5 103 is used 15 6 3 Setting guidelines IP14874 1 v1 M12179 64 v8 The setting parameters for th...

Page 404: ...ctions and related function blocks For Disturbance 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 IED Green LED Steady light In Service Flashing light Internal failure Dark No power supply Yellow LED Steady light Triggered on binary signal N with Set...

Page 405: ...g will get a number 0 to 999 which is used as identifier local HMI disturbance handling tool and IEC 61850 An alternative recording identification is date time and sequence number The sequence number is automatically increased by one for each new recording and is reset to zero at midnight The maximum number of recordings stored in the IED is 100 The oldest recording will be overwritten when a new ...

Page 406: ...t function works in normal mode and the status is indicated in the saved recording Post Retrigger M12155 173 v7 Disturbance report function does not automatically respond to any new trig condition during a recording after all signals set as trigger signals have been reset However under certain circumstances the fault condition may reoccur during the post fault recording for instance by automatic r...

Page 407: ...ing remote data from LDCM module the Disturbance report function should be connected to a 8 ms SMAI function block if this is the only intended use for the remote data The analog trigger of Disturbance report is not affected if analog input M is to be included in the disturbance recording or not OperationM On Off If OperationM Off no waveform samples will be recorded and reported in graph However ...

Page 408: ...ted parameters Trip value recorder M12179 442 v3 ZeroAngleRef The parameter defines which analog signal that will be used as phase angle reference for all other analog input signals This signal will also be used for frequency measurement and the measured frequency is used when calculating trip values It is suggested to point out a sampled voltage input signal for example a line or busbar phase vol...

Page 409: ...lsewhere are linked to the information on a report Such parameters are for example station and object identifiers CT and VT ratios 15 7 Logical signal status report BINSTATREP GUID E7A2DB38 DD96 4296 B3D5 EB7FBE77CE07 v2 15 7 1 Identification GUID E0247779 27A2 4E6C A6DD D4C31516CA5C v3 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Logical sig...

Page 410: ...flanks on a binary signal need to be counted The limit counter provides four independent limits to be checked against the accumulated counted value The four limit reach indication outputs can be utilized to initiate proceeding actions The output indicators remain high until the reset of the function It is also possible to initiate the counter from a non zero value by resetting the function to the ...

Page 411: ...ing and alarm are provided The time limit for overflow indication is fixed to 99999 9 hours At overflow the accumulated time resets and the accumulation starts from zero again 15 9 3 Setting guidelines GUID D3BED56A BA80 486F B2A8 E47F7AC63468 v1 The settings tAlarm and tWarning are user settable limits defined in hours The achievable resolution of the settings is 0 1 hours 6 minutes tAlarm and tW...

Page 412: ...p cannot be considered as one single line Fault location algorithms for a single line will thus not meet accuracy requirements in railway supply system This can be explained by considering an example of transmission line with 3 sections as shown in the figure 165 Source A 1 2 3 RFLO Source B IEC15000299 1 en vsdx IEC15000299 V1 EN US Figure 165 Single line diagram with three line sections For exam...

Page 413: ...n The following loops are used for different types of faults For two phase faults loop L1 L2 For phase to earth faults L1N L2N phase to earth loop RWRFLO function indicates distance to faults as a percentage of the line length and in kilometres The calculated distance to fault is stored together with the recorded disturbances Information can be read on the local HMI or uploaded to PCM600 Is also a...

Page 414: ... XEOverXL IECEQUATION15083 V1 EN US Where X01 is zero sequence reactance of section 1 per phase The settings are set in the same way for line sections 2 3 and so on 15 10 3 1 Setting example GUID F3F5D7EC 1574 45F1 8D54 632D6E66D960 v2 Consider a 110kV 16 7Hz system with three transmission line sections see Figure 167 Source A 1 2 3 RFLO Source B IEC15000299 1 en vsdx IEC15000299 V1 EN US Figure 1...

Page 415: ...rRL1 should be set as 0 02783 1 2 1 01 1 XL XL X XEOverXL IECEQUATION15083 V1 EN US Equation 80 XEOverXL1 The positive sequence reactance REOverRL1 should be set as 0 0323 Setting related to line section 2 2 2 2 02 2 RL RL R REOverRL IECEQUATION15112 V1 EN US Equation 81 REOverRL2 The positive sequence resistance REOverRL2 should be set as 0 1272 2 2 2 02 2 XL XL X XEOverXL IECEQUATION15113 V1 EN ...

Page 416: ...XEOverXL IECEQUATION15115 V1 EN US Equation 84 XEOverXL3 The positive sequence reactance REOverRL3 should be set as 0 219 Section 15 1MRK 506 375 UEN A Monitoring 410 Railway application RER670 2 2 IEC Application manual ...

Page 417: ... the substation automation system or read via the station monitoring system as a service value When using IEC 61850 8 1 a scaled service value is available over the station bus The normal use for this function is the counting of energy pulses from external energy meters An optional number of inputs from an arbitrary input module in IED can be used for this purpose with a frequency of up to 40 Hz T...

Page 418: ... on the same board used for pulse counting 16 2 Function for energy calculation and demand handling ETPMMTR SEMOD153638 1 v2 16 2 1 Identification SEMOD175537 2 v4 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Function for energy calculation and demand handling ETPMMTR W_Varh 16 2 2 Application SEMOD175546 4 v5 Energy calculation and demand ha...

Page 419: ...aled with the pulse output setting values EAFAccPlsQty EARAccPlsQty ERFAccPlsQty and ERVAccPlsQty of the energy metering function and then the pulse counter can be set up to present the correct values by scaling in this function Pulse counter values can then be presented on the local HMI in the same way and or sent to the SA Substation Automation system through communication where the total energy...

Page 420: ...e MWh value in each pulse It should be selected together with the setting of the Pulse counter PCGGIO settings to give the correct total pulse value ERFAccPlsQty and ERVAccPlsQty gives the MVArh value in each pulse It should be selected together with the setting of the Pulse counter PCGGIO settings to give the correct total pulse value For the advanced user there are a number of settings for direc...

Page 421: ...onfiguration tool ECT in PCM600 The access point is activated if the Operation checkbox is checked for the respective access point and a partial or common write to IED is performed To increase security it is recommended to deactivate the access point when it is not in use Redundancy and PTP cannot be set for the front port Access point 0 as redundant communication and PTP are only available for th...

Page 422: ...n the other subnetwork By default this is set to 0 0 0 0 which means that no default gateway is selected ECT validates the entered value but the default gateway has to be in the same subnetwork as the access point The default gateway is the router that is being used as default that is when no route has been set up for the destination If communication with a device in another subnetwork is needed a...

Page 423: ...High availability Seamless Redundancy HSR provides redundant communication over station bus running the available communication protocols The redundant communication uses two Ethernet ports IEC09000758 4 en vsd Switch A AP1 PhyPortB PhyPortA AP1 PhyPortA PhyPortB AP1 PhyPortB PhyPortA AP1 PhyPortA PhyPortB Switch B Device 1 Device 2 Device 3 Device 4 IEC09000758 V4 EN US Figure 169 Parallel Redund...

Page 424: ...ated when the parameter is set to PRP 0 PRP 1 or HSR The settings for the next access point will be hidden and PhyPortB will show the second port information Redundant communication is activated after a common write to IED is done PRP 1 should be used primarily PRP 0 is intended only for use in existing PRP networks PRP 1 and HSR can be combined in a mixed network If the access point is not taken ...

Page 425: ...ommunication The merging units MU are called so because they can gather analog values from one or more measuring transformers sample the data and send the data over process bus to other clients or subscribers in the system Some merging units are able to get data from classical measuring transformers others from non conventional measuring transducers and yet others can pick up data from both types ...

Page 426: ...oute specifies that when a package is sent to the destination device it should be sent through the selected router If no route is specified the source device will not find the destination device 17 4 2 Setting guidelines GUID 2C4A312A 00DC 44C8 B2D9 CD0822E1C806 v1 Routes are configured using the Ethernet configuration tool in PCM600 Operation for the route can be set to On Off by checking and unc...

Page 427: ...ontal communication between two or more intelligent electronic devices IEDs from one or several vendors to exchange information and to use it in the performance of their functions and for correct co operation GOOSE Generic Object Oriented Substation Event which is a part of IEC 61850 8 1 standard allows the IEDs to communicate state and control information amongst themselves using a publish subscr...

Page 428: ...em with IEC 61850 8 1 M16925 3 v4 Figure174 shows the GOOSE peer to peer communication Control Protection Control Protection Control and protection GOOSE en05000734 vsd Station HSI MicroSCADA Gateway IED A IED A IED A IED A IED A IEC05000734 V1 EN US Figure 174 Example of a broadcasted GOOSE message Section 18 1MRK 506 375 UEN A Station communication 422 Railway application RER670 2 2 IEC Applicat...

Page 429: ...ction for Single Point Value SPGAPC function is used to send one single logical output to other systems or equipment in the substation SP16GAPC can be used to send up to 16 single point values from the application functions running in the same cycle time SPGAPC has one visible input and SPGAPC16 has 16 visible inputs that should be connected in the ACT tool Setting guidelines SEMOD55376 5 v5 There...

Page 430: ... Application GUID 808177B7 02CA 40DF B41B 8B580E38478B v1 The GOOSE receive function blocks are used to receive subscribed data from the GOOSE protocol The validity of the data value is exposed as outputs of the function block as well as the validity of the communication It is recommended to use these outputs to ensure that only valid data is handled on the subscriber IED An example could be to co...

Page 431: ...t and the inaccuracy added by the merging unit must be coordinated with the requirement for the actual type of protection function Factors influencing the accuracy of the sampled values from the merging unit are for example anti aliasing filters frequency range step response truncating A D conversion inaccuracy time tagging accuracy etc In principle the accuracy of the current and voltage transfor...

Page 432: ...and send the data over process bus to other clients or subscribers in the system Some merging units are able to get data from classical measuring transformers others from non conventional measuring transducers and yet others can pick up data from both types The electronic part of a non conventional measuring transducer like a Rogowski coil or a capacitive divider can represent a MU by itself as lo...

Page 433: ...lays IEC61850 8 1 en08000069 3 vsd IEC08000069 V2 EN US Figure 177 Example of a station configuration with the IED receiving analog values from both classical measuring transformers and merging units 18 3 2 Setting guidelines GUID 29B296B3 6185 459F B06F 8E7F0C6C9460 v4 Merging Units MUs have several settings on local HMI under 1MRK 506 375 UEN A Section 18 Station communication Railway applicatio...

Page 434: ...ter is set to Block and the IED hardware time synchronization is lost or the synchronization to the MU time is lost the protection functions in the list 42 will be blocked due to conditional blocking If this parameter is set to BlockOnLostUTC the protection functions in list 42 are blocked if the IED hardware time synchronization is lost or the synchronization of the MU time is lost or the IED has...

Page 435: ...ked and processd normally DTT from the remote end is still processed IEC13000299 2 en vsd Direct transfer trip DTT local remote IED IED MU Not OK OK IEC13000299 V2 EN US Figure 179 MU failed mixed system Case 3 Failure of one MU sample lost blocks the sending and receiving of binary signals through LDCM DTT from the remote end is not working 1MRK 506 375 UEN A Section 18 Station communication Rail...

Page 436: ...C Breaker failure protection CCRWRBRF PoleSlip Out of step protection PSPPPAM Breaker failure protection single phase version CCSRBRF Restricted earth fault protection low impedance REFPDIF Current circuit supervison CCSSPVC Two step residual overvoltage protection ROV2PTOV Compensated over and undervoltage protection COUVGAPC Rate of change frequency protection SAPFRC General currrent and voltage...

Page 437: ...l TR1ATCC Generator stator overload protection GSPTTR Automatic voltage control for tapchanger parallel control TR8ATCC Directional Underpower protection GUPPDUP Thermal overload protection two time constants TRPTTR 1Ph High impedance differential protection HZPDIF Two step undervoltage protection U2RWPTUV Line differential protection 3 CT sets 2 3 line ends L3CPDIF Voltage differential protection...

Page 438: ...e constant LFPTTR Fullscheme distance protection quadrilateral for earth faults ZMMAPDIS Loss of voltage check LOVPTUV Fullscheme distance protection quadrilateral for earth faults ZMMPDIS Line differential protection 3 CT sets with inzone transformers 2 3 line ends LT3CPDIF Distance protection zone quadrilateral characteristic ZMQAPDIS Line differential protection 6 CT sets with inzone transforme...

Page 439: ... analog source it is theoretically possible to do without time synchronization However this would mean that timestamps for analog and binary data events become uncorrelated If the IED has no time synchronization source configured then the binary data events will be synchronized with the merging unit However the global complete time might not be correct Disturbance recordings then appear incorrect ...

Page 440: ... to PTP SyncLostMode set to Block to block protection functions if time synchronization is lost or set to BlockOnLostUTC if the protection functions are to be blocked when global common synchronization is lost SyncAccLevel can be set to 1μs since this corresponds to a maximum phase angle error of 0 018 degrees at 50Hz Settings on the local HMI under Main menu Configuration Communication Ethernet c...

Page 441: ...00061 V2 EN US Figure 182 Setting example when MU is the synchronizing source Settings on the local HMI under Main menu Configuration Time Synchronization TIMESYNCHGEN 1 IEC61850 9 2 HwSyncSrc set to PPS as generated by the MU ABB MU SyncLostMode set to Block to block protection functions if time synchronization is lost SyncAccLevel can be set to 4μs since this corresponds to a maximum phase angle...

Page 442: ...E PPS IRIG B STATION CLOCK IEC10000074 2 en Original vsd IEC10000074 V2 EN US Figure 183 Setting example with external synchronization Settings on the local HMI under Main menu Configuration Time Synchronization TIMESYNCHGEN 1 IEC61850 9 2 HwSyncSrc set to PPS IRIG B depending on available outputs on the clock SyncLostMode set to Block to block protection functions if time synchronization is lost ...

Page 443: ...MU report is used IEC UCA 61850 9 2LE Data MU IED IEC10000075 2 en Original vsd IEC10000075 V2 EN US Figure 184 Setting example without time synchronization It is also possible to use IEC UCA 61850 9 2LE communication without time synchronization Settings on the local HMI under Main menu Configuration Time Synchronization TIMESYNCHGEN 1 IEC61850 9 2 HwSyncSrc set to Off SyncLostMode set to No bloc...

Page 444: ...is used to display the detailed quality of an IEC UCA 61850 9 2LE analog channel The component expands the channel quality output of a Merging Unit analog channel received in the IED as per the IEC 61850 7 3 standard This component can be used during the ACT monitoring to get the particular channel quality of the Merging Unit Figure 185 depicts the usage of the quality expander block in ACT IEC160...

Page 445: ...trol center and also from other IEDs via bay to bay horizontal communication For LON communication an SLM card should be ordered for the IEDs The fibre optic LON bus is implemented using either glass core or plastic core fibre optic cables Table 43 Specification of the fibre optic connectors Glass fibre Plastic fibre Cable connector ST connector snap in connector Cable diameter 62 5 125 m 1 mm Max...

Page 446: ...are module is used for control functions in the IEDs The module contains a process picture dialogues and a tool to generate a process database for the control application in MicroSCADA When using MicroSCADA Monitor Pro instead of the Classic Monitor SA LIB is used together with 670 series Object Type files The HV Control 670 software module and 670 series Object Type files are used with both 650 a...

Page 447: ...119915 1 v1 Settings M14789 4 v3 The parameters for the multiple command function are set via PCM600 The Mode setting sets the outputs to either a Steady or Pulsed mode 18 5 SPA communication protocol IP14614 1 v1 18 5 1 Application IP14785 1 v1 SEMOD115767 5 v6 SPA communication protocol is an alternative to IEC 60870 5 103 and they use the same rear communication port When communicating with a P...

Page 448: ...nciple where the IED is a slave and the PC is the master Only one master can be applied on each fibre optic loop A program is required in the master computer for interpretation of the SPA bus codes and for translation of the data that should be sent to the IED For the specification of the SPA protocol V2 5 refer to SPA bus Communication Protocol V2 5 18 5 2 Setting guidelines M11876 3 v6 SPA IEC 6...

Page 449: ... different communication speeds are used in the same fibre optical loop or RS485 network take this into account when making the communication setup in the communication master the PC With local fibre optic communication communication speed is usually set to 19200 or 38400 baud With telephone communication the speed setting depends on the quality of the connection and the type of modem used Refer t...

Page 450: ...it RTU connected to the Communication and processing module the only hardware needed is optical fibres and an opto electrical converter for the PC RTU or a RS 485 connection depending on the used IED communication interface 18 6 1 1 Functionality M17109 38 v3 IEC 60870 5 103 is an unbalanced master slave protocol for coded bit serial communication exchanging information with a control system In IE...

Page 451: ...r the PC RTU PC RTU Commands M17109 62 v4 The commands defined in the IEC 60870 5 103 protocol are represented in dedicated function blocks These blocks have output signals for all available commands according to the protocol For more information refer to the Communication protocol manual IEC 60870 5 103 IED commands in control direction Function block with defined IED functions in control directi...

Page 452: ...INFORMATION NUMBER parameter for each input signal Supervision indications in monitor direction Function block with defined functions for supervision indications in monitor direction I103Superv This block includes the FUNCTION TYPE parameter and the INFORMATION NUMBER parameter is defined for each output signal Earth fault indications in monitor direction Function block with defined functions for ...

Page 453: ...ported when the fault locator function is included in the IED Disturbance recordings M17109 111 v9 The transfer functionality is based on the Disturbance recorder function The analog and binary signals recorded will be reported to the master by polling The eight last disturbances that are recorded are available for transfer to the master A file that has been transferred and acknowledged by the mas...

Page 454: ...u Configuration Communication Station Communication IEC60870 5 103 config selector SlaveAddress BaudRate RevPolarity optical channel only CycMeasRepTime MasterTimeDomain TimeSyncMode EvalTimeAccuracy EventRepMode CmdMode RepIntermediatePos config selector is OPTICAL103 1 for the optical serial channel on the SLM RS485103 1 for the RS485 port 2 The protocol to activate on a physical port is selecte...

Page 455: ...lue delivered All GI data from a single block will come from the same cycle If EventRepMode HiPriSpont spontaneous events will be delivered prior to GI event To prevent old GI data from being delivered after a new spontaneous event the pending GI event is modified to contain the same value as the spontaneous event As a result the GI dataset is not time correlated 18 6 2 2 Settings from PCM600 M171...

Page 456: ...rs on the disturbance recorder for each input The user must set these parameters to whatever he connects to the corresponding input Refer to description of Main Function type set on the local HMI Recorded analog channels are sent with ASDU26 and ASDU31 One information element in these ASDUs is called ACC and it indicates the actual channel to be processed The channels on disturbance recorder are s...

Page 457: ... range 36 91 Private range 37 92 Private range 38 93 Private range 39 94 Private range 40 95 Private range 18 6 3 Function and information types M17109 145 v6 Product type IEC103mainFunType value Comment REL 128 Compatible range REC 242 Private range use default RED 192 Compatible range RET 176 Compatible range REB 207 Private range REG 150 Private range REQ 245 Private range RER 152 Private range...

Page 458: ... plastic fibre should be used BFOC 2 5 is the recommended interface to use BFOC 2 5 is the same as ST connectors ST connectors are used with the optical power as specified in standard For more information refer to IEC standard IEC 60870 5 103 18 7 DNP3 Communication protocol 18 7 1 Application GUID EF1F0C38 9FF6 4683 8B10 AAA372D42185 v1 For more information on the application and setting guidelin...

Page 459: ...s In addition to this there are application possibilities for example blocking enabling functionality in the remote substation changing setting group in the remote IED depending on the switching situation in the local substation and so on If equipped with a 64kbit s LDCM module the IED can be configured to send either 192 binary signals or 3 analog and 8 binary signals to a remote IED If equipped ...

Page 460: ...her with the local three currents In order to forward the logic signals for example inter trip or inter block between IED A and IED C the setting LinkForwarded should be defined In IED B it is set to LDCM313 for Ldcm312 and to LDCM312 for ldcm313 This setup results in a master master master configuration but without the benefit of reverting to a slave master slave configuration in case of a commun...

Page 461: ...lvanic G 703 IEC05000527 V2 EN US Figure 192 LDCM with an external optical to galvanic converter and a multiplexer When an external modem G 703 is used the connection between LDCM and the modem is made with a multimode fibre of max 3 km length The IEEE ANSI C37 94 protocol is always used between LDCM and the modem 19 1 3 Setting guidelines M12454 3 v6 64 kbit and 2 Mbit mode common settings Channe...

Page 462: ...unique address is necessary to give high security against incorrect addressing in the communication system If the same number is used for TerminalNo in some of the LDCMs a loop back test in the communication system can give an incorrect trip RemoteTermNo is used to assign a number to each related LDCM in the remote IED For each LDCM RemoteTermNo is set to a different value than TerminalNo but equa...

Page 463: ...itching can sometimes cause interruptions with a duration of up to 50 ms Too short a time delay can thus cause nuisance alarms ComAlrmResDel defines the time delay for communication failure alarm reset RedChSwTime defines the time delay before switching over to a redundant channel in case of primary channel failure RedChRturnTime defines the time delay before switching back to the primary channel ...

Page 464: ...ansmitting analog data When a merging unit according to IEC 61850 9 2 is used instead of the TRM this parameter shall be set to 5 CompRange value indicates the current peak value over which truncation is made To set this value knowledge of fault current levels is required It is recommended to set the minimum range that will cover the expected fault current value For example if a 40kA fault level i...

Page 465: ...he included self supervision with internal event list function block provides good supervision of the IED The fault signals make it easier to analyze and locate a fault Both hardware and software supervision is included and it is also possible to indicate possible faults through a hardware contact on the power supply module and or through the communication Internal events are generated by the buil...

Page 466: ... B48775D0 ACF0 49C6 A7F6 69AF37F1C68F v1 20 3 1 Application GUID 51EEC9C7 8ECF 4546 BC26 326861654340 v4 Change lock function CHNGLCK is used to block further changes to the IED configuration once the commissioning is complete The purpose is to make it impossible to perform inadvertent IED configuration and setting changes However when activated CHNGLCK will still allow the following actions that ...

Page 467: ... load that can be produced by Ethernet network traffic on the IED The communication facilities must not be allowed to compromise the primary functionality of the device All inbound network traffic will be quota controlled so that too heavy network loads can be controlled Heavy network load might for instance be the result of malfunctioning equipment connected to the network The functions Access po...

Page 468: ...462 ...

Page 469: ...n the local HMI under Main menu Diagnostics IED status Product identifiers and under Main menu Diagnostics IED Status Identifiers ProductVer ProductDef FirmwareVer SerialNo OrderingNo ProductionDate IEDProdType This information is very helpful when interacting with ABB product support for example during repair and maintenance 21 2 2 Factory defined settings M11789 39 v10 The factory defined settin...

Page 470: ...ion Example 2 1 0 1 is the Major version of the manufactured product this means new platform of the product 2 is the Minor version of the manufactured product this means new functions or new hardware added to the product 3 is the Major revision of the manufactured product this means functions or hardware is either changed or enhanced in the product IEDMainFunType Main function type code according ...

Page 471: ...MI or configurable binary inputs results in a highly adaptable IED that can cope with a variety of power system scenarios Different conditions in networks with different voltage levels require highly adaptable protection and control units to best provide for dependability security and selectivity requirements Protection units operate with a higher degree of availability especially if the setting v...

Page 472: ...E v1 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Primary system values PRIMVAL 21 5 2 Application M15288 3 v6 The rated system frequency and phase rotation direction are set under Main menu Configuration Power system Primary Values in the local HMI and PCM600 parameter setting tree 21 5 3 Setting guidelines M15292 3 v2 Set the system rated f...

Page 473: ...s a base value for applicable functions throughout the IED SBase Standard apparent power value to be used as a base value for applicable functions throughout the IED typically SBase UBase IBase 21 7 Signal matrix for binary inputs SMBI SEMOD55793 1 v2 21 7 1 Application M15310 3 v2 The Signal matrix for binary inputs function SMBI is used within the Application Configuration tool in direct relatio...

Page 474: ... function SMMI is used within the Application Configuration tool in direct relation with the Signal Matrix tool SMMI represents the way milliamp mA inputs are brought in for one IED configuration 21 9 2 Setting guidelines SEMOD55247 5 v2 There are no setting parameters for the Signal matrix for mA inputs SMMI available to the user in the Parameter Setting tool However the user must give a name to ...

Page 475: ...neutral signal NegateN or both Negate2Ph N Negation means rotation with 180 of the vectors GlobalBaseSel Selects the global base value group used by the function to define IBase UBase and SBase MinValFreqMeas The minimum value of the voltage for which the frequency is calculated expressed as percent of UBase for each instance n A valid input voltage signal level for frequency measurement can be se...

Page 476: ...meter remotely the PST setting RemoteModControl may not be set to Off The possible values are Off Maintenance or All levels The Off value denies all access to data object Mod from remote Maintenance requires that the category of the originator orCat is Maintenance and All levels allow any orCat The mod of the Root LD LNN0 can be configured under Main menu Test Function test modes Communication Sta...

Page 477: ...set to Blocked all control commands with a test bit are accepted Outputs to the process via a non IEC 61850 link data are blocked by the LN In addition the components can be blocked when their Beh is blocked This can be done if the component has a block input The block status of a component is shown as the Blk output under the Test Function status menu If the Blk output is not shown the component ...

Page 478: ...n tool ECT in PCM600 PTP can be set to On Off or Slave only When set to Slave only the IED is connected to the PTP group and will synchronize to the grandmaster but cannot function as the grandmaster A PTP group is set up by connecting the IEDs to a network and enabling PTP To set one IED as the grandmaster change Priority2 to 127 instead of the default 128 IEC16000089 1 en vsdx IEC16000089 V1 EN ...

Page 479: ...the parameter FineSyncSource under Configuration Time Synchronization TIMESYNCHGEN 1 General is set to GPS if there is a GPS antenna attached If the GTM is used as a PPS output only the FineSynchSource is not set 21 12 1 3 Process bus IEC UCA 61850 9 2LE synchronization GUID 6E384BDB 5598 4108 99B4 0B4A4E1828B2 v4 When process bus communication IEC UCA 61850 9 2LE protocol is used it is essential ...

Page 480: ...unit provides PPS as synchronization use PPS as HwSyncSrc If either PMU or LDCM in GPS mode is used that is the hardware and software clocks are connected to each other HwSyncSrc is not used and other means to synchronize the merging unit to the IED is required Either FineSyncSource is set to the same source that the merging unit uses or the PPS output from the GTM module is used to synchronize th...

Page 481: ... These types are related to the design of the iron core and the presence of airgaps Airgaps affects the properties of the remanent flux The following three different types of protection CTs have been specified The High Remanence type with closed iron core and no specified limit of the remanent flux The Low Remanence type with small airgaps in the iron core and the remanent flux limit is specified ...

Page 482: ... gives a remanent flux higher than 80 of the saturation flux The High Remanence HR type is a CT with closed iron core for example protection classes TPX P PX according to IEC class C K according to ANSI IEEE but with an iron core material traditional material that gives a remanent flux that is limited to maximum 80 of the saturation flux The Low Remanence LR type is a CT with small airgaps in the ...

Page 483: ...erformed in our network simulator The current transformer models are representative for current transformers of high remanence and low remanence type The results may not always be valid for non remanence type CTs TPZ The performances of the protection functions have been checked in the range from symmetrical to fully asymmetrical fault currents Primary time constants of at least 120 ms have been c...

Page 484: ...aximum fault current for the relevant fault position should be used and therefore both fault types have to be considered 22 1 4 Secondary wire resistance and additional load M11614 3 v1 M11614 4 v4 The voltage at the current transformer secondary terminals directly affects the current transformer saturation This voltage is developed in a loop containing the secondary wires and the burden of all re...

Page 485: ...rmers with less accuracy are used it is advisable to check the actual unwanted residual current during the commissioning 22 1 6 Rated equivalent secondary e m f requirements SEMOD53723 1 v1 M11616 3 v2 With regard to saturation of the current transformer all current transformers of high remanence and low remanence type that fulfill the requirements on the rated equivalent limiting secondary e m f ...

Page 486: ...ance earthed transformers For impedance earthed transformers the requirements for the phase CTs are depending whether it is three individual CTs connected in parallel or it is a cable CT enclosing all three phases Neutral CTs and phase CTs for solidly earthed transformers GUID 7CD7512F F7BD 479E B7B6 0D5DF22869D4 v3 The neutral CT and the phase CTs must have a rated equivalent limiting secondary e...

Page 487: ...at passes two main CTs without passing the power transformer neutral A Neutral CTs and phase CTs for impedance earthed transformers GUID FA79C943 A19B 47E2 BFC5 C9D01347302A v3 The neutral CT and phase CTs must have a rated equivalent limiting secondary e m f Eal that is larger than or equal to the required rated equivalent limiting secondary e m f Ealreq below 2 3 sr R al alreq etf ct L pr r I S ...

Page 488: ...Ts in Holmgren connection for example in substations with breaker and a half or double busbar double breaker arrangement or if the transformer has a T connection to different busbars there is a risk that the CTs can be exposed for higher fault currents than the considered phase to earth fault currents above Examples of such cases can be cross country faults or phase to phase faults with high fault...

Page 489: ...22 1 7 2 Current transformers according to IEC 61869 2 class PX PXR and old IEC 60044 6 class TPS and old British Standard class X M11623 14 v5 CTs according to these classes are specified approximately in the same way by a rated knee point e m f Eknee Ek for class PX and PXR EkneeBS for class X and the limiting secondary voltage Ual for TPS The value of the Eknee is lower than the corresponding E...

Page 490: ...f the corresponding Eal according to IEC 61869 2 Therefore the CTs according to ANSI IEEE must have a knee point voltage UkneeANSI that fulfills the following kneeANSI alreq V 0 75 maximum of E EQUATION2101 V2 EN US Equation 96 22 2 Voltage transformer requirements M11608 3 v5 The performance of a protection function will depend on the quality of the measured input signal Transients caused by capa...

Page 491: ...E1588 standard BMC Best Master Algorithm and shall for instance not claim class 7 for a longer time than it can guarantee 1us absolute accuracy 22 5 Sample specification of communication requirements for the protection and control terminals in digital telecommunication networks GUID 0A9F36AF 3802 42FE 8970 4662798C19D1 v2 The communication requirements are based on echo timing Bit Error Rate BER a...

Page 492: ...0 ms IED with echo synchronization of differential clock without GPS clock Both channels must have the same route with maximum asymmetry of 0 2 0 5 ms depending on set sensitivity of the differential protection A fixed asymmetry can be compensated setting of asymmetric delay in built in HMI or the parameter setting tool PST IED with GPS clock Independent of asymmetry 22 6 IEC UCA 61850 9 2LE Mergi...

Page 493: ... not specify the quality of the sampled values only the transportation Thus the accuracy of the current and voltage inputs to the merging unit and the inaccuracy added by the merging unit must be coordinated with the requirement for actual type of protection function Factors influencing the accuracy of the sampled values from the merging unit are for example anti aliasing filters frequency range s...

Page 494: ...488 ...

Page 495: ...American Wire Gauge standard BBP Busbar protection BFOC 2 5 Bayonet fibre optic connector BFP Breaker failure protection BI Binary input BIM Binary input module BOM Binary output module BOS Binary outputs status BR External bistable relay BS British Standards BSR Binary signal transfer function receiver blocks BST Binary signal transfer function transmit blocks C37 94 IEEE ANSI protocol used when ...

Page 496: ...isturbance recorder according to IEEE ANSI C37 111 1999 IEC 60255 24 Contra directional Way of transmitting G 703 over a balanced line Involves four twisted pairs two of which are used for transmitting data in both directions and two for transmitting clock signals COT Cause of transmission CPU Central processing unit CR Carrier receive CRC Cyclic redundancy check CROB Control relay output block CS...

Page 497: ... performance architecture ESD Electrostatic discharge F SMA Type of optical fibre connector FAN Fault number FCB Flow control bit Frame count bit FOX 20 Modular 20 channel telecommunication system for speech data and protection signals FOX 512 515 Access multiplexer FOX 6Plus Compact time division multiplexer for the transmission of up to seven duplex channels of digital data over optical fibers F...

Page 498: ... IEC 60870 5 103 Communication standard for protection equipment A serial master slave protocol for point to point communication IEC 61850 Substation automation communication standard IEC 61850 8 1 Communication protocol standard IEEE Institute of Electrical and Electronics Engineers IEEE 802 12 A network technology standard that provides 100 Mbits s on twisted pair or optical fiber cable IEEE P13...

Page 499: ...ough the data link layer 2 Ingression protection according to IEC 60529 IP 20 Ingression protection according to IEC 60529 level 20 IP 40 Ingression protection according to IEC 60529 level 40 IP 54 Ingression protection according to IEC 60529 level 54 IRF Internal failure signal IRIG B InterRange Instrumentation Group Time code format B standard 200 ITU International Telecommunications Union LAN L...

Page 500: ...M Pulse code modulation PCM600 Protection and control IED manager PC MIP Mezzanine card standard PMC PCI Mezzanine card POR Permissive overreach POTT Permissive overreach transfer trip Process bus Bus or LAN used at the process level that is in near proximity to the measured and or controlled components PRP Parallel redundancy protocol PSM Power supply module PST Parameter setting tool within PCM6...

Page 501: ...tem SNTP Simple network time protocol is used to synchronize computer clocks on local area networks This reduces the requirement to have accurate hardware clocks in every embedded system in a network Each embedded node can instead synchronize with a remote clock providing the required accuracy SOF Status of fault SPA Strömberg Protection Acquisition SPA a serial master slave protocol for point to ...

Page 502: ... fault condition For example a distance relay is underreaching when the impedance presented to it is greater than the apparent impedance to the fault applied to the balance point that is the set reach The relay does not see the fault but perhaps it should have seen it See also Overreach UTC Coordinated Universal Time A coordinated time scale maintained by the Bureau International des Poids et Mesu...

Page 503: ...lecom equipment 3IO Three times zero sequence current Often referred to as the residual or the earth fault current 3UO Three times the zero sequence voltage Often referred to as the residual voltage or the neutral point voltage 1MRK 506 375 UEN A Section 23 Glossary Railway application RER670 2 2 IEC 497 Application manual ...

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Page 506: ... AB Grid Automation Products 721 59 Västerås Sweden Phone 46 0 21 32 50 00 abb com protection control Copyright 2017 ABB All rights reserved Specifications subject to change without notice 1MRK 506 375 UEN ...

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