ABB RED650 Applications Manual Download

Page: 402 / 454

TerminalNo

is used to assign a unique address to each LDCM in all current

differential IEDs. Up to 256 LDCMs can be assigned a unique number. For
example, in a local IED with two LDCMs:

•

LDCM for slot 305: set

TerminalNo

to 1 and

RemoteTermNo

to 2

•

LDCM for slot 306: set

TerminalNo

to 3 and

RemoteTermNo

to 4

A unique address is necessary to give high security against
incorrect addressing in the communication system. If the same
number is used for

TerminalNo

in some of the LDCMs, a loop-back

test in the communication system can give an incorrect trip.

RemoteTermNo

is used to assign a number to each related LDCM in the remote

IED. For each LDCM,

RemoteTermNo

is set to a different value than

TerminalNo

but equal to the

TerminalNo

of the remote end LDCM. In the remote IED,

TerminalNo

and

RemoteTermNo

are reversed as follows:

•

LDCM for slot 305: set

TerminalNo

to 2 and

RemoteTermNo

to 1

•

LDCM for slot 306: set

TerminalNo

to 4 and

RemoteTermNo

to 3

The redundant channel is always configured to the lower position,
for example:

•

Slot 305: main channel

•

Slot 306: redundant channel

The same is applicable for slot 312-313.

DiffSync

: defines the method of time synchronization for the line differential

function:

Echo

Using

Echo

in this case is safe only if there is no risk of varying

transmission asymmetry.

CommSync

defines the

Master

and

Slave

relation in the communication system,

and should not be mistaken for the synchronization of line differential current
samples. When direct fiber is used, one LDCM is set as

Master

and the other as

Slave

. When a modem and multiplexer is used, the IED is always set as

Slave

because the telecommunication system provides the clock master.

OptoPower

has two settings:

LowPower

is used for fibres 0 – 1 km and

HighPower

for fibres >1 km.

Section 19

1MRK 505 393-UEN B

Remote communication

396

Line differential protection RED650 2.2 IEC

Application manual

Summary of Contents for RED650

Page 1: ...RELION 650 SERIES Line differential protection RED650 Version 2 2 Application manual ...

Page 2: ......

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

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

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

Page 7: ...unctions 29 Control and monitoring functions 30 Communication 33 Basic IED functions 35 Section 3 Configuration 37 Description of configuration RED650 37 Introduction 37 Description of A11 37 Section 4 Analog inputs 39 Introduction 39 Setting guidelines 39 Setting of the phase reference channel 40 Example 40 Setting of current channels 40 Example 1 40 Example 2 41 Example 3 42 Examples on how to c...

Page 8: ... to the IED for low impedance earthed or solidly earthed power systems 64 Section 5 Local HMI 67 Display 68 LEDs 70 Keypad 71 Local HMI functionality 73 Protection and alarm indication 73 Parameter management 74 Front communication 75 Section 6 Differential protection 77 Line differential protection 77 Identification 77 Application 77 Power transformers in the protected zone 78 Small power transfo...

Page 9: ...h respect to load 126 Zone reach setting lower than minimum load impedance 127 Zone reach setting higher than minimum load impedance 129 Other settings 130 ZMMMXU settings 133 Power swing detection ZMRPSB 134 Identification 134 Application 134 General 134 Basic characteristics 135 Setting guidelines 135 Automatic switch onto fault logic ZCVPSOF 143 Identification 143 Application 143 Setting guidel...

Page 10: ...n one time constant Celsius Fahrenheit LCPTTR LFPTTR 180 Identification 180 Application 180 Setting guideline 181 Breaker failure protection CCRBRF 182 Identification 182 Application 182 Setting guidelines 183 Pole discordance protection CCPDSC 186 Identification 187 Application 187 Setting guidelines 187 Section 9 Voltage protection 189 Two step undervoltage protection UV2PTUV 189 Identification ...

Page 11: ...ers 198 Equipment protection capacitors 198 Power supply quality 198 High impedance earthed systems 198 Direct earthed system 199 Settings for two step residual overvoltage protection 200 Section 10 Frequency protection 203 Underfrequency protection SAPTUF 203 Identification 203 Application 203 Setting guidelines 203 Overfrequency protection SAPTOF 204 Identification 204 Application 205 Setting gu...

Page 12: ...ker with double busbar internal voltage selection 223 Setting guidelines 224 Autorecloser for 1 phase 2 phase and or 3 phase operation SMBRREC 229 Identification 229 Application 229 Auto reclosing operation Off and On 233 Start auto reclosing and conditions for start of a reclosing cycle 233 Start auto reclosing from circuit breaker open information 234 Blocking of the auto recloser 234 Control of...

Page 13: ...oser settings 247 Apparatus control 251 Application 251 Bay control QCBAY 256 Switch controller SCSWI 257 Switches SXCBR 258 Proxy for signals from switching device via GOOSE XLNPROXY 259 Interaction between modules 262 Setting guidelines 264 Bay control QCBAY 265 Switch controller SCSWI 265 Switch SXCBR 266 Proxy for signals from switching device via GOOSE XLNPROXY 267 Logic rotating switch for f...

Page 14: ...ing schemes 278 Delta blocking scheme 279 Permissive schemes 280 Intertrip scheme 282 Setting guidelines 283 Blocking scheme 283 Delta blocking scheme 283 Permissive underreaching scheme 284 Permissive overreaching scheme 284 Unblocking scheme 284 Intertrip scheme 284 Current reversal and Weak end infeed logic for distance protection 3 phase ZCRWPSCH 285 Identification 285 Application 285 Current ...

Page 15: ...ng 296 Single and or three phase tripping 296 Single two or three phase tripping 298 Lock out 298 Example of directional data 299 Blocking of the function block 301 Setting guidelines 301 Trip matrix logic TMAGAPC 301 Identification 301 Application 302 Setting guidelines 302 Logic for group alarm ALMCALH 302 Identification 302 Application 302 Setting guidelines 303 Logic for group alarm WRNCALH 30...

Page 16: ...n 310 Application 310 Elapsed time integrator with limit transgression and overflow supervision TEIGAPC 311 Identification 311 Application 312 Setting guidelines 312 Comparator for integer inputs INTCOMP 312 Identification 312 Application 313 Setting guidelines 313 Setting example 313 Comparator for real inputs REALCOMP 314 Identification 314 Application 314 Setting guidelines 314 Setting example ...

Page 17: ...imes 339 Binary input signals 340 Analog input signals 341 Sub function parameters 341 Consideration 342 Logical signal status report BINSTATREP 343 Identification 343 Application 343 Setting guidelines 344 Fault locator LMBRFLO 344 Identification 344 Application 344 Setting guidelines 345 Connection of analog currents 346 Limit counter L4UFCNT 347 Identification 347 Application 347 Setting guidel...

Page 18: ...ation 361 Communication protocols 361 IEC 61850 8 1 communication protocol 361 Application IEC 61850 8 1 361 Setting guidelines 363 Horizontal communication via GOOSE 363 Sending data 363 Receiving data 364 IEC UCA 61850 9 2LE communication protocol 365 Introduction 365 Setting guidelines 367 Specific settings related to the IEC UCA 61850 9 2LE communication 368 Loss of communication when used wit...

Page 19: ...n 393 Communication hardware solutions 394 Setting guidelines 395 Section 20 Security 399 Authority status ATHSTAT 399 Application 399 Self supervision with internal event list INTERRSIG 399 Application 399 Change lock CHNGLCK 400 Application 400 Denial of service SCHLCCH RCHLCCH 401 Application 401 Setting guidelines 401 Section 21 Basic IED functions 403 IED identifiers TERMINALID 403 Applicatio...

Page 20: ...requency values 409 Setting guidelines 410 Test mode functionality TESTMODE 415 Application 415 IEC 61850 protocol test mode 415 Setting guidelines 417 Time synchronization TIMESYNCHGEN 417 Application 417 Setting guidelines 418 System time 418 Synchronization 418 Process bus IEC UCA 61850 9 2LE synchronization 421 Time synchronization for differential protection and IEC UCA 61850 9 2LE sampled da...

Page 21: ...1869 2 class PX PXR and old IEC 60044 6 class TPS and old British Standard class X 431 Current transformers according to ANSI IEEE 431 Voltage transformer requirements 432 SNTP server requirements 433 PTP requirements 433 Sample specification of communication requirements for the protection and control terminals in digital telecommunication networks 433 IEC UCA 61850 9 2LE Merging unit requirement...

Page 22: ...16 ...

Page 23: ...nalogue signal which do not have corresponding primary quantity the 1 1 ratio shall be set for the used analogue inputs on the IED Example of such functions are HZPDIF ROTIPHIZ and STTIPHIZ 4 Parameter IBase used by the tested function is set equal to the rated CT primary current 5 Parameter UBase used by the tested function is set equal to the rated primary phase to phase voltage 6 Parameter SBas...

Page 24: ...ning Operation Maintenance Decommissioning Deinstalling disposal Application manual Operation manual Installation manual Engineering manual Communication protocol manual Cyber security deployment guideline Technical manual Commissioning manual IEC07000220 V4 EN US Figure 1 The intended use of manuals throughout the product lifecycle The engineering manual contains instructions on how to engineer t...

Page 25: ...use of a fault The application manual contains application descriptions and setting guidelines sorted per function The manual can be used to find out when and for what purpose a typical protection function can be used The manual can also provide assistance for calculating settings The technical manual contains operation principle descriptions and lists function blocks logic diagrams input and outp...

Page 26: ...g manual 1MRK 511 420 UEN Installation manual 1MRK 514 027 UEN Communication protocol manual DNP3 1MRK 511 413 UUS Communication protocol manual IEC 60870 5 103 1MRK 511 416 UEN Communication protocol manual IEC 61850 Edition 1 1MRK 511 414 UEN Communication protocol manual IEC 61850 Edition 2 1MRK 511 415 UEN Communication protocol manual LON 1MRK 511 417 UEN Communication protocol manual SPA 1MR...

Page 27: ...g related to the concept discussed in the text It might indicate the presence of a hazard which could result in corruption of software or damage to equipment or property The information icon alerts the reader of important facts and conditions The tip icon indicates advice on for example how to design your project or how to use a certain function Although warning hazards are related to personal inj...

Page 28: ...software the character after an input signal name indicates that the signal must be connected to another function block in the application configuration to achieve a valid application configuration Dimensions are provided both in inches and millimeters If it is not specifically mentioned then the dimension is in millimeters 1 5 IEC 61850 edition 1 edition 2 mapping GUID C5133366 7260 4C47 A975 7DB...

Page 29: ...MMTR FUFSPVC SDDRFUF FUFSPVC HZPDIF HZPDIF HZPDIF INDCALH INDCALH INDCALH ITBGAPC IB16FCVB ITBGAPC L4UFCNT L4UFCNT L4UFCNT LCPTTR LCPTTR LCPTTR LD0LLN0 LLN0 LLN0 LDLPSCH LDLPDIF LDLPSCH LFPTTR LFPTTR LFPTTR LMBRFLO LMBRFLO LMBRFLO LOVPTUV LOVPTUV LOVPTUV LPHD LPHD LPHD LT3CPDIF LT3CPDIF LT3CGAPC LT3CPDIF LT3CPHAR LT3CPTRC MVGAPC MVGGIO MVGAPC NS4PTOC EF4LLN0 EF4PTRC EF4RDIR GEN4PHAR PH1PTOC EF4PTR...

Page 30: ...SYN SLGAPC SLGGIO SLGAPC SMBRREC SMBRREC SMBRREC SMPPTRC SMPPTRC SMPPTRC SP16GAPC SP16GGIO SP16GAPC SPC8GAPC SPC8GGIO SPC8GAPC SPGAPC SPGGIO SPGAPC SSCBR SSCBR SSCBR SSIMG SSIMG SSIMG SSIML SSIML SSIML SXCBR SXCBR SXCBR SXSWI SXSWI SXSWI T3WPDIF T3WPDIF T3WGAPC T3WPDIF T3WPHAR T3WPTRC TEIGAPC TEIGGIO TEIGAPC TEILGAPC TEILGGIO TEILGAPC TMAGAPC TMAGGIO TMAGAPC TRPTTR TRPTTR TRPTTR UV2PTUV GEN2LLN0 P...

Page 31: ...LH WRNCALH ZCLCPSCH ZCLCPLAL ZCLCPSCH ZCPSCH ZCPSCH ZCPSCH ZCRWPSCH ZCRWPSCH ZCRWPSCH ZCVPSOF ZCVPSOF ZCVPSOF ZMFPDIS ZMFLLN0 PSFPDIS ZMFPDIS ZMFPTRC ZMMMXU PSFPDIS PSFPDIS ZMFPDIS ZMFPTRC ZMMMXU 1MRK 505 393 UEN B Section 1 Introduction Line differential protection RED650 2 2 IEC 25 Application manual ...

Page 32: ...26 ...

Page 33: ...oad encroachment and adaptive reach compensation are included The multi shot autoreclose includes priority features for double breaker arrangements It co operates with the synchrocheck function with high speed or delayed reclosing Breaker failure high set instantaneous phase and earth overcurrent four step directional or non directional delayed phase and earth overcurrent and two step undervoltage...

Page 34: ...Management is an authentication infrastructure that offers a secure solution for enforcing access control to IEDs and other systems within a substation This incorporates management of user accounts roles and certificates and the distribution of such a procedure completely transparent to the user The Flexible Product Naming allows the customer to use an IED vendor independent IEC 61850 model of the...

Page 35: ...A11 Current protection PHPIOC 50 Instantaneous phase overcurrent protection 1 OC4PTOC 51_671 Directional phase overcurrent protection four steps 1 EFPIOC 50N Instantaneous residual overcurrent protection 1 EF4PTOC 51N 67N2 Directional residual overcurrent protection four steps 1 LCPTTR 26 Thermal overload protection one time constant Celsius 1 LFPTTR 26 Thermal overload protection one time constan...

Page 36: ...ic rotating switch for function selection and LHMI presentation 15 VSGAPC Selector mini switch 30 DPGAPC Generic communication function for Double Point indication 16 SPC8GAPC Single point generic control function 8 signals 5 AUTOBITS Automation bits command function for DNP3 0 3 SINGLECMD Single command 16 signals 4 I103CMD Function commands for IEC 60870 5 103 1 I103GENCMD Function commands gene...

Page 37: ...C Boolean to integer conversion with logical node representation 16 bit 16 IB16 Integer to Boolean 16 conversion 18 ITBGAPC Integer to Boolean 16 conversion with Logic Node representation 16 TEIGAPC Elapsed time integrator with limit transgression and overflow supervision 12 INTCOMP Comparator for integer inputs 30 REALCOMP Comparator for real inputs 30 Table 3 Total number of instances for basic ...

Page 38: ...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 report 3 RANGE_XP Measured value expander block 66 LMBRFLO Fault locator 1 I103MEAS Measurands for IEC 60870 5 103 1 I103MEASUS...

Page 39: ...communication protocol 1 ADE LON communciation protocol 1 HORZCOMM Network variables via LON 1 PROTOCOL Operation selection between SPA and IEC 60870 5 103 for SLM 1 RS485PROT Operation selection for RS485 1 RS485GEN RS485 1 DNPGEN DNP3 0 communication general protocol 1 CHSERRS485 DNP3 0 for EIA 485 communication protocol 1 CH1TCP CH2TCP CH3TCP CH4TCP DNP3 0 for TCP IP communication protocol 1 CH...

Page 40: ...r mapping security events on protocols such as DNP3 and IEC103 1 FSTACCS Field service tool access 1 IEC 61850 9 2 Process bus communication 4 merging units 1 P31 ACTIVLOG Activity logging 1 ALTRK Service tracking 1 PRP IEC 62439 3 Parallel redundancy protocol 1 P23 HSR IEC 62439 3 High availability seamless redundancy 1 P24 PTP Precision time protocol 1 FRONTSTATUS Access point diagnostic for fro...

Page 41: ...al event list TIMESYNCHGEN Time synchronization module BININPUT SYNCHCAN SYNCHGPS SYNCHCMPPS SYNCHLON SYNCHPPH SYNCHPPS SNTP SYNCHSPA Time synchronization TIMEZONE Time synchronization IRIG B Time synchronization SETGRPS Number of setting groups ACTVGRP Parameter setting groups TESTMODE Test mode functionality CHNGLCK Change lock function SMBI Signal matrix for binary inputs SMBO Signal matrix for...

Page 42: ...or FNKEYTY1 FNKEYTY5 FNKEYMD1 FNKEYMD5 Parameter setting function for HMI in PCM600 LEDGEN General LED indication part for LHMI OPENCLOSE_LED LHMI LEDs for open and close keys GRP1_LED1 GRP1_LED15 GRP2_LED1 GRP2_LED15 GRP3_LED1 GRP3_LED15 Basic part for CP HW LED indication module Section 2 1MRK 505 393 UEN B Application 36 Line differential protection RED650 2 2 IEC Application manual ...

Page 43: ...ified by the customer since these are specific to the system object or application Optional functions and optional IO ordered will not be configured at delivery It should be noted that the standard only includes one binary input and one binary output module and only the key functions such as tripping are connected to the outputs in the signal matrix tool The required total IO must be calculated an...

Page 44: ... 63 S SIML 71 LINE_VT UV2 PTUV 27 2 3U V MSQI MET Usqi VN MMXU MET UN V MMXU MET U LMB RFLO 21FL FL ZCV PSOF FUF SPVC U I DRP RDRE DFR SER DR C MMXU MET I C MSQI MET Isqi ETP MMTR MET W Varh CV MMXN MET P Q CC PDSC 52PD PD S SCBR S SCBR S SCBR Control REM_CT1 REM_CT2 Optional LDL PSCH 87L LT3C PDIF 87L 3Id I QA1 IEC15000403 3 en vsdx OV2 PTOV 59 2 3U ROV2 PTOV 59N 2 U0 SA PTUF 81 f SA PTOF 81 f SA...

Page 45: ...ed to zero degrees and remaining analog channel s phase angle information will be shown in relation to this analog input During testing and commissioning of the IED the reference channel can be changed to facilitate testing and service values reading The IED has the ability to receive analog values from primary equipment that are sampled by Merging units MU connected to a process bus via the IEC 6...

Page 46: ...igure 3 A positive value of current power and so on forward means that the quantity flows towards the object A negative value of current power and so on reverse means that the quantity flows away from the object See Figure 3 Protected Object Line transformer etc Forward Reverse Definition of direction for directional functions Measured quantity is positive when flowing towards the object e g P Q I...

Page 47: ...Object IEC05000753 IEC05 000753 1 en Origin al 1 vsd Is Is Ip Ip Ip IED IED IEC05000753 V2 EN US Figure 4 Example how to set CTStarPoint parameters in the IED Figure 4 shows the normal case where the objects have their own CTs The settings for CT direction shall be done according to the figure To protect the line direction of the directional functions of the line protection shall be set to Forward...

Page 48: ...60 V2 EN US Figure 5 Example how to set CTStarPoint parameters in the IED This example is similar to example 1 but here the transformer is feeding just one line and the line protection uses the same CT as the transformer protection does The CT direction is set with different reference objects for the two IEDs though it is the same current from the same CT that is feeding the two IEDs With these se...

Page 49: ...rse The direction Forward Reverse is related to the reference object that is the transformer in this case When a function is set to Reverse and shall protect an object in reverse direction it shall be noted that some directional functions are not symmetrical regarding the reach in forward and reverse direction It is in first hand the reach of the directional criteria that can differ Normally it is...

Page 50: ... in two ways The first solution will be to use busbar as a reference object In that case for all CT inputs marked with 1 in Figure 8 set CTStarPoint ToObject and for all CT inputs marked with 2 in Figure 8 set CTStarPoint FromObject The second solution will be to use all connected bays as reference objects In that case for all CT inputs marked with 1 in Figure 8 set CTStarPoint FromObject and for ...

Page 51: ...s of CT terminals Where a is symbol and terminal marking used in this document Terminals marked with a square indicates the primary and secondary winding terminals with the same that is positive polarity b and c are equivalent symbols and terminal marking used by IEC ANSI standard for CTs Note that for these two cases the CT polarity marking is correct It shall be noted that depending on national ...

Page 52: ... actions which are needed to make this measurement available to the built in protection and control functions within the IED as well For correct terminal designations see the connection diagrams valid for the delivered IED L1 IL1 IL2 IL3 L2 L3 Protected Object CT 600 5 Star Connected IL1 IL2 IL3 IED IEC13000002 4 en vsdx 1 2 3 4 SMAI2 BLOCK REVROT GRP2L1 GRP2L2 GRP2L3 GRP2N AI3P AI1 AI2 AI3 AI4 AI...

Page 53: ...or all built in protection and control functions within the IED which are connected to this preprocessing function block For this application most of the preprocessing settings can be left to the default values If frequency tracking and compensation is required this feature is typically required only for IEDs installed in power plants then the setting parameters DFTReference shall be set according...

Page 54: ... setting of the parameter CTStarPoint of the used current inputs on the TRM item 2 in Figure 11 and 10 CTprim 600A CTsec 5A CTStarPoint FromObject The ratio of the first two parameters is only used inside the IED The third parameter as set in this example will negate the measured currents in order to ensure that the currents are measured towards the protected object within the IED A third alternat...

Page 55: ...ase currents 3 Is the TRM where these current inputs are located It shall be noted that for all these current inputs the following setting values shall be entered CTprim 800A CTsec 1A CTStarPoint FromObject ConnectionType Ph N The ratio of the first two parameters is only used inside the IED The third parameter as set in this example will have no influence on measured currents that is currents are...

Page 56: ...on and control functions within the IED which are connected to this preprocessing function block in the configuration tool For this application most of the preprocessing settings can be left to the default values If frequency tracking and compensation is required this feature is typically required only for IEDs installed in the generating stations then the setting parameters DFTReference shall be ...

Page 57: ...3 IL3 IL1 1 2 3 4 IEC11000027 3 en vsdx SMAI2 BLOCK REVROT GRP2L1 GRP2L2 GRP2L3 GRP2N AI3P AI1 AI2 AI3 AI4 AIN IEC11000027 V3 EN US Figure 13 Delta DAB connected three phase CT set 1MRK 505 393 UEN B Section 4 Analog inputs Line differential protection RED650 2 2 IEC 51 Application manual ...

Page 58: ...the connected analog inputs and calculate fundamental frequency phasors for all three input channels harmonic content for all three input channels positive negative and zero sequence quantities by using the fundamental frequency phasors for the first three input channels channel one taken as reference for sequence quantities These calculated values are then available for all built in protection an...

Page 59: ...ed CTprim 800A CTsec 1A CTStarPoint ToObject ConnectionType Ph Ph It is important to notice the references in SMAI As inputs at Ph Ph are expected to be L1L2 L2L3 respectively L3L1 we need to tilt 180º by setting ToObject 4 2 2 7 Example how to connect single phase CT to the IED SEMOD55055 431 v8 Figure 15 gives an example how to connect the single phase CT to the IED It gives an overview of the r...

Page 60: ...ect For connection b shown in Figure 15 CTprim 1000 A CTsec 1A CTStarPoint FromObject 3 shows the connection made in SMT tool which connect this CT input to the fourth input channel of the preprocessing function block 4 4 is a Preprocessing block that has the task to digitally filter the connected analog inputs and calculate values The calculated values are then available for all built in protecti...

Page 61: ...e the protection scheme less sensitive however such measures are necessary in order to avoid possible problems with loss of the measurement accuracy in the IED Regardless of the applied relationship between the IBase parameter and the rated CT primary current the corresponding minimum pickup of the function on the CT secondary side must always be verified It is strongly recommended that the minimu...

Page 62: ...are indicate the primary and secondary winding terminals with the same positive polarity b is the equivalent symbol and terminal marking used by IEC ANSI standard for phase to earth connected VTs c is the equivalent symbol and terminal marking used by IEC ANSI standard for open delta connected VTs d is the equivalent symbol and terminal marking used by IEC ANSI standard for phase to phase connecte...

Page 63: ... built in protection and control functions within the IED For correct terminal designations see the connection diagrams valid for the delivered IED L1 IED L2 L3 66 3 110 3 kV V 1 3 2 66 3 110 3 kV V 66 3 110 3 kV V Not used 5 IEC06000599 4 en vsdx 4 SMAI2 BLOCK REVROT GRP2L1 GRP2L2 GRP2L3 GRP2N AI3P AI1 AI2 AI3 AI4 AIN IEC06000599 V4 EN US Figure 17 A Three phase to earth connected VT 1MRK 505 393...

Page 64: ... the TRM where these three voltage inputs are located For these three voltage inputs the following setting values shall be entered VTprim 132 kV VTsec 110 V Inside the IED only the ratio of these two parameters is used It shall be noted that the ratio of the entered values exactly corresponds to ratio of one individual VT 66 66 3 110 110 3 EQUATION1903 V1 EN US Equation 2 Table continues on next p...

Page 65: ...s for the first three input channels channel one taken as reference for sequence quantities These calculated values are then available for all built in protection and control functions within the IED which are connected to this preprocessing function block in the configuration tool For this application most of the preprocessing settings can be left to the default values However the following setti...

Page 66: ...dary side of a phase to phase VT to the VT inputs on the IED 2 is the TRM where these three voltage inputs are located It shall be noted that for these three voltage inputs the following setting values shall be entered VTprim 13 8 kV VTsec 120 V Please note that inside the IED only ratio of these two parameters is used Table continues on next page Section 4 1MRK 505 393 UEN B Analog inputs 60 Line...

Page 67: ... shall be set as shown here ConnectionType Ph Ph UBase 13 8 kV If frequency tracking and compensation is required this feature is typically required only for IEDs installed in the generating stations then the setting parameters DFTReference shall be set accordingly 4 2 4 5 Example on how to connect an open delta VT to the IED for high impedance earthed or unearthed networks SEMOD55055 163 v9 Figur...

Page 68: ...4 en vsdx Not Used Not Used SMAI2 BLOCK REVROT GRP2L1 GRP2L2 GRP2L3 GRP2N AI3P AI1 AI2 AI3 AI4 AIN IEC06000601 V4 EN US Figure 20 Open delta connected VT in high impedance earthed power system Section 4 1MRK 505 393 UEN B Analog inputs 62 Line differential protection RED650 2 2 IEC Application manual ...

Page 69: ...e input to the fourth input channel of the preprocessing function block 5 5 is a Preprocessing block that has the task to digitally filter the connected analog input and calculate fundamental frequency phasors for all four input channels harmonic content for all four input channels positive negative and zero sequence quantities by using the fundamental frequency phasors for the first three input c...

Page 70: ... EQUATION1926 V1 EN US Equation 7 The primary rated voltage of such VT is always equal to UPh E Therefore three series connected VT secondary windings will give the secondary voltage equal only to one individual VT secondary winding rating Thus the secondary windings of such open delta VTs quite often has a secondary rated voltage close to rated phase to phase VT secondary voltage that is 115V or ...

Page 71: ... Used Not Used SMAI2 BLOCK REVROT GRP2L1 GRP2L2 GRP2L3 GRP2N AI3P AI1 AI2 AI3 AI4 AIN 2 3 4 5 IEC06000602 V4 EN US Figure 21 Open delta connected VT in low impedance or solidly earthed power system 1MRK 505 393 UEN B Section 4 Analog inputs Line differential protection RED650 2 2 IEC 65 Application manual ...

Page 72: ...input channel of the preprocessing function block 4 5 preprocessing block has a task to digitally filter the connected analog inputs and calculate fundamental frequency phasors for all four input channels harmonic content for all four input channels positive negative and zero sequence quantities by using the fundamental frequency phasors for the first three input channels channel one taken as refe...

Page 73: ...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 505 393 UEN B Section 5 Local HMI Line differential protection RED650 2 2 IEC 67 Application manual ...

Page 74: ...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 Sec...

Page 75: ...D 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 the l...

Page 76: ...MI or PCM600 Information panels for the indication LEDs are shown by pressing the Multipage button Pressing that button cycles through the three pages A lit or un acknowledged LED is indicated with a highlight Such lines can be selected by using the Up Down arrow buttons Pressing the Enter key shows details about the selected LED Pressing the ESC button exits from information pop ups as well as fr...

Page 77: ... 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 505 393 UEN B Section 5 Local HMI Line differential protection RED650 2 2 IEC 71 Application manual ...

Page 78: ...ect 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 505 393 UEN B Local HMI 72 Line differential protection RED650 2 2 IEC Application manual ...

Page 79: ...ly voltage is disconnected On Normal operation Flashing Internal fault has occurred Table 7 Start LED yellow LED state Description Off Normal operation On A protection function has started and an indication message is displayed The start indication is latching and must be reset via communication LHMI or binary input on the LEDGEN component To open the reset menu on the LHMI press Flashing The IED ...

Page 80: ... indication has been acknowledged but the activation signal is still on LatchedAck S F sequence The activation signal is on or it is off but the indication has not been acknowledged LatchedReset S sequence The activation signal is on or it is off but the indication has not been acknowledged Flashing Follow F sequence The activation signal is on LatchedAck F S sequence The activation signal is on o...

Page 81: ...5 connector 2 Green indicator LED The default IP address for the IED front port is 10 1 150 3 and the corresponding subnetwork mask is 255 255 254 0 It can be set through the local HMI path Main menu Configuration Communication Ethernet configuration FRONT port AP_FRONT Ensure not to change the default IP address of the IED Do not connect the IED front port to a LAN Connect only a single local PC ...

Page 82: ...76 ...

Page 83: ...nd or current inversion associated with faults in series compensated networks It is not influenced by fault current reversal at earth faults on parallel lines As it is phase segregated the identification of faulted phases is inherent and thus the application of single or two phase trip and auto reclosing can be made robust and reliable Note that if an in line or shunt power transformer is included...

Page 84: ...on can also be applied with in line power transformers in the protected zone Such an in line power transformer can be situated in tap as shown in Figure 30 or in one end of a two terminal line Observe that the currents of the in line power transformer are measured by the IED on the low voltage side A one three winding transformer can be included IEC05000429 2 en vsdx IED IED IED Protected zone IEC...

Page 85: ... will be subtracted when these currents are transformed to the HV side 6 1 2 2 Small power transformers in a tap M12022 54 v5 If there is a line tap with a comparatively small power transformer say 1 20MVA line differential protection can be applied without the need of current measurement from the tap It works such that line differential protection function will be time delayed for small different...

Page 86: ...Idiff false Ic1 Ic2 IEC05000436 2 en vsdx IED IEC05000436 V2 EN US Figure 32 Charging currents The magnitude of the charging current is dependent of the line capacitance and the system voltage For earth cables and long overhead lines the magnitude can be such that it affects the possibility to achieve the wanted sensitivity of the differential protection To overcome this a charging current compens...

Page 87: ...be achieved To demonstrate this two cases can be studied one with a low resistive short circuit and one with a high resistive short circuit The charging current is generated because there is a voltage applied over the line capacitance as seen in figure 32 If an external short circuit with negligible fault resistance occurs close to the line the voltage in the fault location will be approximately z...

Page 88: ...r to achieve maximum sensitivity The stability at external faults will not be affected 6 1 2 4 Time synchronization M12022 66 v3 Time synchronization of sampled current values is a crucial matter in numerical line differential protections The synchronization is made with the so called echo method which can be complemented with IRIG B time synchronization In applications with symmetrical communicat...

Page 89: ... function Current values from two CTs in double breakers ring main or 1 breaker system ends with dual breaker arrangements need to be sent to the remote end As a 64 kbit s LDCM only has capacity for one three phase current duplex this implies that two communication channels are needed at both ends and this is also the normal solution To reduce the number of communication channels needed it is also...

Page 90: ...l values via local IED s LDCM and they are then forwarded to the protection function in the local IED LDLPSCH acts as the interface to and from the protection function Configuration of this data flow is made in the SMT tool as shown in Figure 36 Currents from remote end 1 Currents to remote end 1 Currents from remote end 2 Currents to remote end 2 LDCM 2 LDCM 1 Currents from local CT A D SMAI Pre ...

Page 91: ...ion of the protected circuit The Open CT can be detected in approximately 14 2 ms and the differential protection might by that time in some cases have already issued a trip command Nevertheless the information on an open CT as the reason for trip is still very important An alarm signal can also be issued to the substation operational personnel to make remedy action once the open CT condition is d...

Page 92: ...LPSCH logic in order for the Open CT detection to operate properly Observe that summation of currents shall be avoided where possible The outputs of the open CT conditions are OPENCT and OPENCTAL OPENCT Open CT detected OPENCTAL Alarm issued after the setting delay Outputs positive integer for information on the local HMI OPENCTIN Open CT in CT group inputs 1 for input 1 and 2 for input 2 OPENCTPH...

Page 93: ...CTs 3 in 1 breaker configurations 6 1 3 2 Percentage restrained differential operation M12541 104 v4 Line differential protection is phase segregated where the operate current is the vector sum of all measured currents taken separately for each phase The restrain current on the other hand is considered the greatest phase current in any line end and it is common for all three phases Observe that th...

Page 94: ...erate slope Irestrain D D EQUATION1246 V1 EN US Line differential protection is phase segregated where the operate current is the vector sum of all measured currents taken separately for each phase The restrain current on the other hand is considered as the greatest phase current in any line end and it is common for all three phases IdMin M12541 121 v6 This setting is a multiple of IBase and must ...

Page 95: ... currents but as they are rich in harmonics they can partly be measured by the differential protection which in this case measures the Fourier filtered differential current Desensitizing the differential protection in this situation by using IdMinHigh instead of IdMin is a safety precaution and a setting of 1 00 IBase should be suitable in most cases If there is a power transformer included in the...

Page 96: ...rent that can appear on the protected line Consequently to set this value properly the fault current must be calculated in each specific case For a short line or a situation with a 1 breaker bay the through fault current might be practically the same as the differential current at an internal fault Extreme unequal CT saturation at external faults could then be a risk of unwanted operation if the u...

Page 97: ...block scheme is permanently active only if an in line power transformer A or B alternatively both A and B is part of the protected circuit This is a must due to phenomena specific for power transformers such as inrush and over excitation If there is no power transformer included in the protected multi terminal line circuit then the 2nd and 5th harmonic block scheme is only active under the followi...

Page 98: ... set On Off It is an important complement to the percentage restrained differential function As it is directional it can distinguish between external and internal faults also in difficult conditions such as CT saturation and so on It is strongly recommended that it is always activated On NegSeqROA M12541 218 v4 This is the setting of the relay operate angle of the negative sequence current based i...

Page 99: ...ult is declared in this case The default value 0 04 IBase can be used if no special considerations such as extremely week sources are taken into account Observe that internally whenever the bias current is higher than 1 5 times IBase the actual threshold is equal to the sum of IminNegSeq 0 1 Ibias This is in order to prevent wrong decisions of the internal external fault discriminator under heavy ...

Page 100: ...inding power transformer is seen by the differential protection as two separate power transformers A and B which have one common winding on the HV side IEC15000451 2 en vsdx IED IED A B T T Protected zone IEC15000451 V2 EN US Figure 43 One three winding transformer in the protected zone TraAOnInpCh M12541 239 v6 This parameter is used to indicate that a power transformer is included in the protect...

Page 101: ...he phase shift is given in intervals of 30 degrees where 1 is 30 degrees 2 is 60 degrees and so on The parameter can be set within the range 0 11 TraBOnInpCh M12541 292 v5 This parameter is used to indicate that a power transformer is included in the protection zone at current terminal Y This can be either a two winding transformer or the second secondary winding of a three winding transformer The...

Page 102: ...he current level under which a possible extra added time delay of the output trip command can be applied The possibility for delayed operation for small differential currents is typically used for lines with a minor tapped transformer somewhere in the protected circuit and where no protection terminal of the multi terminal differential protection is applied at the transformer site If such a minor ...

Page 103: ...ions 1 and 2 The circuit is protected by two terminals 1 and 2 These terminals process the same data except for minor distortion in data that takes place during communication between them Both terminals operate as masters If at least one of them indicates an internal fault the protected circuit is disconnected IED 2 Line 50 km CT 3 Substation 2 Substation 1 Current samples from terminals 2 and 3 C...

Page 104: ...r of current sources circuit ends IBase Global base 600 A 600 A Reference current of the protection in the primary system note 1 IBase is set in the Global base values function GBASVAL TransfAonInpCh 2 1 Input currents on the input channels are referred to the high voltage side note 2 TraAWind1Volt 220 kV 220 kV Transformer A Y side voltage TraAWind2Volt 70 kV 70 kV Transformer A d side voltage Cl...

Page 105: ... restrain characteristic SlopeSection2 40 40 Slope of the operate restrain characteristic in Section 2 SlopeSection3 80 80 Slope of the operate restrain characteristic in Section 3 IdMinHigh 2 00 IBase 2 00 IBase Temporarily decreased sensitivity used when the protected circuit is connected to a power source note 4 IntervIdMinHig 30 000 s 30 000 s Time interval when IdMinHig is active note 5 Idunr...

Page 106: ... and CT3 are internally separately referred to the high voltage side of the transformer by the multi terminal differential algorithm using the same transformation rule This rule is defined by the power transformer transformation ratio and its type Yd1 in this example If an in line power transformer is included in the protected zone the protected power lines are usually on the high voltage side of ...

Page 107: ...f 20 1 2 1 2 2 75 3 30 5 50 0 6 0 6 Through I kA kA Idunre Ibase kA kA EQUATION1424 V1 EN US Equation 19 7 The cross block logic should always be active when there is a power transformer in the protected zone Setting example with a small tap transformer in the protected zone A typical example is shown in Figure 46 IEC12000193 2 en vsd 3Id 3Id SA 1700 MVA SA 1280 MVA 10MVA ek 10 138 10kV 3Id 3Id A ...

Page 108: ...4000046 V1 EN US Figure 47 Thevenin equivalent of the tap transformer Converting the sources into impedances gives ZSA 138 1700 11 2 2 Ω EQUATION14000034 V1 EN US Equation 20 ZSB 138 1200 15 9 2 Ω EQUATION14000035 V1 EN US Equation 21 Calculating the short circuit impedance of the transformer gives Z e U S trf k n n 100 0 1 138 10 190 4 2 2 Ω EQUATION14000036 V1 EN US Equation 22 Based on the Thev...

Page 109: ...n The setting is calculated as ImaxAddDelay S U I n n Base 2 3 2 0 EQUATION14000041 V1 EN US Equation 27 Table 12 Backup protection example data Station Tap transformer 10 MVA Type of fault Three phase fault Object 1 10 kV Line A 2 T1 10 kV 50 51 3 130 kV 87L ImaxAddDelay Setting 2 MVA 14 MVA 20 MVA Characteristic IEC Extr inverse k 0 5 A 80 p 2 IEC Norm inverse k 0 12 A 0 14 p 0 02 IEC Norm inver...

Page 110: ...erential operation IEC13000295 2 en vsdx A B C T B T A IED IED IED IEC13000295 V2 EN US Figure 49 Master slave differential operation Setting Station A Station B Station C PDIF L3TCPDIF NoOfUsedCTs 3 TraAOnInpCh 2 TraBOnInpCh 3 Section 6 1MRK 505 393 UEN B Differential protection 104 Line differential protection RED650 2 2 IEC Application manual ...

Page 111: ... T IEC13000296 V2 EN US Figure 50 Three winding transformer in the zone Settings Station A Station B PDIF L3TCPDIF L3TCPDIF NoOfUsedCTs 3 3 TraAOnInpCh 2 1 TraBOnInpCh 3 2 Currents from the secondary and tertiary windings of the power transformer are connected to one line differential protection IED Currents for each CT group are sent to the IED at station A by the LDCM To inform the differential ...

Page 112: ...106 ...

Page 113: ...become more and more complex consisting of a high number of multi circuit and or multi terminal lines of very different lengths These changes in the network will normally impose more stringent demands on the fault clearing equipment in order to maintain an unchanged or increased security level of the power system 7 1 2 1 System earthing GUID EB5B5594 AA81 4FC5 BBC0 7627A8609A23 v1 The type of syst...

Page 114: ...egative sequence impedance Ω phase Z0 is the zero sequence impedance Ω phase Zf is the fault impedance Ω often resistive ZN is the earth return impedance defined as Z0 Z1 3 The high zero sequence current in solidly earthed networks makes it possible to use impedance measuring techniques to detect earth faults However distance protection has limited possibilities to detect high resistance faults an...

Page 115: ...ossibilities to detect high resistance faults and should therefore always be complemented with other protection function s that can carry out the fault clearance in this case High impedance earthed networks GUID 02F306F5 1038 42AC AFAE 3F8423C4C066 v5 In high impedance networks the neutral of the system transformers are connected to the earth through high impedance mostly a reactance in parallel w...

Page 116: ... to earth faults immediately they clear the line later when it is more convenient In case of cross country faults many network operators want to selectively clear one of the two earth faults In this type of network it is mostly not possible to use distance protection for detection and clearance of earth faults The low magnitude of the earth fault current might not give start of the zero sequence m...

Page 117: ...A p ZL Rf EQUATION1274 IEC 650 V1 EN US Equation 35 The infeed factor IA IB IA can be very high 10 20 depending on the differences in source impedances at local and remote end Z ZL Z ESA UA UB A B ESB IA IB Rf p ZL 1 p ZL ZSA ZSB IEC09000247 1 en vsd IEC09000247 V1 EN US Figure 53 Influence of fault current infeed from remote line end The effect of fault current infeed from the remote line end is ...

Page 118: ...ty to detect high fault resistances especially for phase to earth faults at the remote line end For example for a given setting of the load angle ArgLd the resistive blinder for the zone measurement can be set according to figure 54 affording higher fault resistance coverage without risk for unwanted operation due to load encroachment Separate resistive blinder settings are available in forward an...

Page 119: ...ng 7 1 2 5 Long transmission line application GUID 0C99A197 06CD 4668 A017 3CA9E5E01ED2 v4 For long transmission lines the margin to the load impedance that is to avoid load encroachment will normally be a major concern It is well known that it is difficult to achieve high sensitivity for phase to earth fault at remote line end of long lines when the line is heavy loaded What can be recognized as ...

Page 120: ...lel circuits with common positive but isolated zero sequence network 3 Parallel circuits with positive and zero sequence sources isolated One example of class 3 networks could be the mutual coupling between a 400 kV line and rail road overhead lines This type of mutual coupling is not so common although it exists and is not treated any further in this manual For each type of network class there ar...

Page 121: ...networks Let us analyze what happens when a fault occurs on the parallel line see figure 55 From symmetrical components we can derive the impedance Z at the relay point for normal lines without mutual coupling according to equation 36 Z U I I Z Z Z U I I K ph ph ph ph N 3 3 3 0 0 1 1 0 IECEQUATION1275 V2 EN US Equation 36 Where Uph is phase to earth voltage at the relay point Iph is phase current ...

Page 122: ...e error introduced to the measurement of the line impedance If the current on the parallel line has negative sign compared to the current on the protected line that is the current on the parallel line has an opposite direction compared to the current on the protected line the distance function will overreach If the currents have the same direction the distance protection will underreach Maximum ov...

Page 123: ... p 71 that is the protection is underreaching with approximately 20 The zero sequence mutual coupling can reduce the reach of distance protection on the protected circuit when the parallel line is in normal operation The reduction of the reach is most pronounced with no current infeed in the IED closest to the fault This reach reduction is normally less than 15 But when the reach is reduced at one...

Page 124: ...ment will be a considerable overreach which must be considered when calculating the settings It is recommended to use a separate setting group for this operation condition since it will reduce the reach considerably when the line is in operation All expressions below are proposed for practical use They assume the value of zero sequence mutual resistance R0m equals to zero They consider only the ze...

Page 125: ... of the underreaching distance protection zone is reduced if due to operating conditions the equivalent zero sequence impedance is set according to the conditions when the parallel system is out of operation and earthed at both ends A B C IEC09000255_1_en vsd I0 I0 Z0m Z0 Z0m Z0m Z0 IEC09000255 V1 EN US Figure 60 Equivalent zero sequence impedance circuit for a double circuit line with one circuit...

Page 126: ...û EQUATION1288 V2 EN US Equation 50 Ensure that the underreaching zones from both line ends will overlap a sufficient amount at least 10 in the middle of the protected circuit 7 1 2 7 Tapped line application GUID 740E8C46 45EE 4CE8 8718 9FAE658E9FCE v1 GUID 7AA566A4 B6E9 41A7 9927 4DAB50BE8D1A v1 C B BC IEC09000160 3 en vsd A IEC09000160 V3 EN US Figure 61 Example of tapped line with Auto transfor...

Page 127: ...int to the fault divided by the IED current For the IED at C the impedance on the high voltage side U1 has to be transferred to the measuring voltage level by the transformer ratio Another complication that might occur depending on the topology is that the current from one end can have a reverse direction for fault on the protected line For example for faults at T the current from B might go in re...

Page 128: ...g guidelines IP14962 1 v1 7 1 3 1 General GUID BA20D421 4435 44CA A6E9 743E461F8C59 v2 The settings for Distance measuring zones quadrilateral characteristic ZMFPDIS are done in primary values The instrument transformer ratio that has been set for the analog input card is used to automatically convert the measured secondary input signals to primary values used in ZMFPDIS The following basics must ...

Page 129: ...igher than the fault current at the IED location The setting shall generally not exceed 80 of the following impedances The impedance corresponding to the protected line plus the first zone reach of the shortest adjacent line The impedance corresponding to the protected line plus the impedance of the maximum number of transformers operating in parallel on the bus at the remote end of the protected ...

Page 130: ...irection when the zone is used for blocking scheme weak end infeed and so on 1 2 2 Zrev ZL Z rem EQUATION1525 V5 EN US Equation 55 Where ZL is the protected line impedance Z2rem is zone 2 setting at remote end of protected line In many applications it might be necessary to consider the enlarging factor due to fault current infeed from adjacent lines in the reverse direction in order to obtain cert...

Page 131: ...ero sequence mutual coupling The reach is reduced for a factor 0 0 1 2 1 0 m f Z K Z Z R EQUATION1426 V1 EN US Equation 58 If the denominator in equation 58 is called B and Z0m is simplified to X0m then the real and imaginary part of the reach reduction factor for the overreaching zones can be written as 2 2 0 Re Re 0 1 Re Im X m B K B B EQUATION1427 V2 EN US Equation 59 2 2 0 Im Im 0 Re Im X m B ...

Page 132: ...ION2304 V2 EN US Equation 64 Setting of the resistive reach for the underreaching zone 1 should follow the condition to minimize the risk for overreaching RFPEZx 4 5 X1Zx IECEQUATION2305 V2 EN US Equation 65 The fault resistance for phase to phase faults is normally quite low compared to the fault resistance for phase to earth faults To minimize the risk for overreaching limit the setting of the z...

Page 133: ...s reference points to improve the performance of the phase selection The maximum permissible resistive reach for any zone must be checked to ensure that there is a sufficient setting margin between the boundary and the minimum load impedance The minimum load impedance Ω phase is calculated with equation 67 Zloadmin U 2 S EQUATION571 V1 EN US Equation 67 Where U the minimum phase to phase voltage i...

Page 134: ...elated to the maximum load power To avoid load encroachment for the phase to phase measuring elements the set resistive reach of any distance protection zone must be less than 160 of the minimum load impedance load 1 6 Z RFPPZx EQUATION579 V3 EN US Equation 71 Equation 71 is applicable only when the loop characteristic angle for the phase to phase faults is more than three times as large as the ma...

Page 135: ... a phase to earth fault it corresponds to the per loop impedance including the earth return impedance R X RLdFw RLdRv ArgLd 90 10 10 ARGLd Possible load ARGLd ARGLd R X RLdFw RLdRv XLd XLd ARGLd ARGLd ARGLd ARGLd IEC12000176 2 en vsd IEC12000176 V2 EN US Figure 63 Load impedance limitation with load encroachment During the initial current change for phase to phase and for phase to earth faults ope...

Page 136: ...IMinOpPP Zx ILmLn is the RMS value of the vector difference between phase currents Lm and Ln Both current limits IMinOpPEZx and IMinOpPPZx are automatically reduced to 75 of regular set values if the zone is set to operate in reverse direction that is OperationDir is set to Reverse OpModePPZx and OpModePEZx These settings two per zone x 1 2 5 RV with options Off Quadrilateral Mho Offset are used t...

Page 137: ...zones 3 to 5 tPPZx tPEZx TimerModeZx ZoneLinkStart and TimerLinksZx The logic for the linking of the timer settings can be described with a module diagram The figure 65 shows only the case when TimerModeZx is selected to Ph Ph and Ph E 1MRK 505 393 UEN B Section 7 Impedance protection Line differential protection RED650 2 2 IEC 131 Application manual ...

Page 138: ...ro resonance This component is practically idle during normal load and fault conditions hence the name passive CVTs that have a high resistive burden to mitigate ferro resonance also fall into this category Any This option is primarily related to the so called active type CVT which uses a set of reactive components to form a filter circuit that essentially attenuates frequencies other than the nom...

Page 139: ...ircuits of a double line One specific situation where the INReleasePE setting should be altered is for cross country faults in high impedance earthed networks in order to make sure that operation is phase to earth This is particularly important when using phase preference logic since it is only working per phase not for phase to phase measurement The limit should be set so that it will be exceeded...

Page 140: ...tions until they reach the final stability The extent of the oscillations depends on the extent of the disturbances and on the natural stability of the system The oscillation rate depends also on the inertia of the system and on the total system impedance between different generating units These oscillations cause changes in phase and amplitude of the voltage difference between the oscillating gen...

Page 141: ...faults during power swing The operation of the distance protection function remains stable for external faults during the power swing condition even with the swing electrical centre located on the protected power line The operating characteristic of the ZMRPSB function is easily adjustable to the selected impedance operating characteristics of the corresponding controlled distance protection zones...

Page 142: ...system voltage min 380 U kV EQUATION1322 V1 EN US Minimum expected system voltage under critical system conditions 50 r f Hz EQUATION1323 V1 EN US Rated system frequency 400 3 p U kV EQUATION1324 V1 EN US Rated primary voltage of voltage or potential transformers used 0 11 3 s U kV EQUATION1325 V1 EN US Rated secondary voltage of voltage or potential transformers used 1200 p I A EQUATION1326 V1 EN...

Page 143: ... 2 2 min min max 380 144 4 1000 L U Z S W EQUATION1337 V1 EN US Equation 76 The minimum load resistance RLmin at maximum load and minimum system voltage is equal to equation 77 min min max cos 144 4 0 95 137 2 L L R Z j W EQUATION1338 V1 EN US Equation 77 The system impedance ZS is determined as a sum of all impedances in an equivalent two machine system see figure 67 Its value is calculated accor...

Page 144: ...UATION1342 V1 EN US Equation 80 The center of oscillation resides on the impedance point according to equation 81 1 7 43 33 9 2 S CO SA Z Z Z j W EQUATION1341 V1 EN US Equation 81 Section 7 1MRK 505 393 UEN B Impedance protection 138 Line differential protection RED650 2 2 IEC Application manual ...

Page 145: ...ith certain safety margin KL compared to the minimum expected load resistance RLmin When the exact value of the minimum load resistance is not known the following approximations may be considered for lines with a rated voltage of 400 kV KL 0 9 for lines longer than 150 km KL 0 85 for lines between 80 and 150 km KL 0 8 for lines shorter than 80 km 1MRK 505 393 UEN B Section 7 Impedance protection L...

Page 146: ...nal δIn boundary of proposed oscillation detection characteristic in forward direction are calculated with sufficient accuracy according to equation 84 and 85 respectively 155 75 2 arc tan 2 arc tan 64 5 2 2 123 5 d æ ö æ ö ç ç ç è ø è ø S Out Z RLdOutFw EQUATION1345 V1 EN US Equation 84 max 155 75 2 arctan 2 arc tan 76 5 2 2 98 8 d æ ö æ ö ç ç ç è ø è ø S In Z RLdInFw EQUATION1346 V1 EN US Equati...

Page 147: ...f tP2 time remains higher than 10 ms see equation 91 max 91 5 64 5 2 10 7 360 7 360 In Out sc tP ms f d d EQUATION1352 V1 EN US Equation 91 The final proposed settings are as follows RLdOutFw 123 5Ω kLdRFw 0 61 tP1 30 ms tP2 10 ms Consider RLdInFw 75 0Ω Do not forget to adjust the setting of load encroachment resistance RLdFw in Phase selection with load encroachment FDPSPDIS or FRPSPDIS to the va...

Page 148: ...mmended to use different setting groups for operating conditions which are changing only between different periods of year summer winter System studies should determine the settings for the hold timer tH The purpose of this timer is to secure continuous output signal from the Power swing detection function ZMRPSB during the power swing even after the transient impedance leaves ZMRPSB operating cha...

Page 149: ...ample due to lack of polarizing voltage when a line 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...

Page 150: ...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 detection is dis...

Page 151: ...nd release a trip When Mode is set to Impedance the operate criterion is based on the BC input breaker closing which can be the start of the overreaching zone from the impedance zone measurement or a tOperate delayed START_DLYD input A nondirectional output signal should be used from an overreaching zone The selection of the Impedance mode gives increased security When Mode is set to UILvl Imp the...

Page 152: ...146 ...

Page 153: ...ous because no power can be transmitted through the fault point during fault conditions The magnitude of the fault current A high fault current indicates that the decrease of transmitted power is high The total fault clearing time The phase angles between the EMFs of the generators on both sides of the transmission line increase over the permitted stability limits if the total fault clearing time ...

Page 154: ...SVAL function for reference of base values Operation Set the protection to On Off OpMode This parameter can be set to 2 out of 3 or 1 out of 3 The setting controls the minimum number of phase currents that must be larger than the set operate current IP for operation Normally this parameter is set to 1 out of 3and will thus detect all fault types If the protection is to be used mainly for multi pha...

Page 155: ...idered IEC09000023 1 en vsd ZA ZB ZL A B IED I fA Fault IEC09000023 V1 EN US Figure 70 Through fault current from B to A IfA The IED must not trip for any of the two through fault currents Hence the minimum theoretical current setting Imin will be Imin MAX IfA IfB EQUATION78 V1 EN US Equation 95 A safety margin of 5 for the maximum protection static inaccuracy and a safety margin of 5 for the maxi...

Page 156: ... from the parallel line to the protected line has to be considered One example is given in Figure 72 where the two lines are connected to the same busbars In this case the influence of the induced fault current from the faulty line line 1 to the healthy line line 2 is considered together with the two through fault currents IfA and IfB mentioned previously The maximal influence from the parallel li...

Page 157: ...ioned previously the minimum setting Is for the instantaneous phase overcurrent protection 3 phase output is then Is 1 3 Imin EQUATION83 V2 EN US Equation 99 The protection function can be used for the specific application only if this setting value is equal or less than the maximum phase fault current that the IED has to clear The IED setting value IP is given in percentage of the primary base cu...

Page 158: ...al steps with different current pickup levels and time delays are needed OC4PTOC can have up to four different individually settable steps The following options are possible Non directional Directional function In most applications the non directional functionality is used This is mostly the case when no fault current can be fed from the protected object itself In order to achieve both selectivity...

Page 159: ...otection The inrush current has a large 2nd harmonic content This can be used to avoid unwanted operation of the protection function Therefore OC4PTOC has a possibility of 2nd harmonic restrain if the level of 2nd harmonic current reaches a value above a set percent of the fundamental current The phase overcurrent protection is often used as a protection for two and three phase short circuits In s...

Page 160: ...op current has the angle RCA the direction to the fault is forward AngleROA Angle value given in degrees to define the angle sector of the directional function shown in Figure 73 StartPhSel Number of phases with high current required for operation The setting possibilities are 1 out of 3 2 out of 3 and 3 out of 3 The default setting is 1 out of 3 IMinOpPhSel Minimum current setting level for relea...

Page 161: ... M12982 19 v10 x means step 1 2 3 and 4 DirModex The directional mode of step x Possible settings are Off Non directional Forward Reverse Characteristx Selection of time characteristic for step x Definite time delay and different types of inverse time characteristics are available according to Table 15 1MRK 505 393 UEN B Section 8 Current protection Line differential protection RED650 2 2 IEC 155 ...

Page 162: ...ng If Ix is set outside Ix Max and Ix Min the closest of the limits to Ix is used by the function If Ix Max is smaller than Ix Min the limits are swapped tx Definite time delay for step x The definite time tx is added to the inverse time when inverse time characteristic is selected Note that the value set is the time between activation of the start and the trip outputs kx Time multiplier for inver...

Page 163: ... order to fully comply with the definition of the curve the setting parameter txMin shall be set to a value equal to the operating time of the selected inverse curve for twenty times the set current pickup value Note that the operate time is dependent on the selected time multiplier setting kx ResetTypeCrvx The reset of the delay timer can be made as shown in Table 16 Table 16 Reset possibilities ...

Page 164: ...Crvx tCRCrvx These parameters are used by the customer to create the inverse reset time characteristic curve For more information refer to Technical manual HarmRestrainx Enables the block of step x from the harmonic restrain function 2nd harmonic This function should be used when there is a risk of an unwanted trip caused by power transformer inrush currents It can be set to Off On 8 2 3 2 Setting...

Page 165: ...or several years In most cases the setting values are updated once every five years or less often Investigate the maximum load current that the equipment on the line can withstand Study components such as line conductors current transformers circuit breakers and disconnectors The manufacturer of the equipment normally gives the maximum thermal load current of the equipment The maximum load current...

Page 166: ... must be considered due to a possible DC component of the short circuit current The lowest current setting of the fastest stage can be written according to max 1 2 t sc high I k I EQUATION1265 V1 EN US Equation 105 where 1 2 is a safety factor kt is a factor that takes care of the transient overreach due to the DC component of the fault current and can be considered to be less than 1 05 Iscmax is ...

Page 167: ...s in the radial network there has to be a minimum time difference Dt between the time delays of two protections To determine the shortest possible time difference the operation time of the protection the breaker opening time and the protection resetting time must be known These time delays can vary significantly between different protective equipment The following time delays can be estimated Prot...

Page 168: ...Sequence of events during fault where t 0 is when the fault occurs t t1 is when protection IED B1 and protection IED A1 start t t2 is when the trip signal from the overcurrent protection at IED B1 is sent to the circuit breaker t t3 is when the circuit breaker at IED B1 opens The circuit breaker opening time is t3 t2 t t4 is when the overcurrent protection at IED A1 resets The protection resetting...

Page 169: ... a defined value by the object impedance an instantaneous earth fault protection can provide fast and selective tripping The Instantaneous residual overcurrent EFPIOC which can operate in 15 ms 50 Hz nominal system frequency for faults characterized by very high currents is included in the IED 8 3 3 Setting guidelines IP14985 1 v1 M12762 44 v2 M12762 4 v4 The parameters for the Instantaneous resid...

Page 170: ... impedance ZA and low source impedance ZB should be used For the fault at the home busbar this fault current is IfA In this calculation the operational state with low source impedance ZA and high source impedance ZB should be used ZA ZB ZL A B IED I fB Fault IEC09000022 1 en vsd IEC09000022 V1 EN US Figure 78 Through fault current from A to B IfB IEC09000023 1 en vsd ZA ZB ZL A B IED I fA Fault IE...

Page 171: ...en vsd ZA ZB ZL1 A B I M Fault IED ZL2 M C Line 1 Line 2 IEC09000025 V1 EN US Figure 80 Two parallel lines Influence from parallel line to the through fault current IM The minimum theoretical current setting Imin will in this case be Imin M AX IfA IfB IM EQUATION287 V1 EN US Equation 109 Where IfA and IfB have been described for the single line case Considering the safety margins mentioned previou...

Page 172: ...Min the limits are swapped StValMult The set operate current can be changed by activation of the binary input ENMULT to the set factor StValMult 8 4 Directional residual overcurrent protection four steps EF4PTOC IP14509 1 v8 8 4 1 Identification M14881 1 v6 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Directional residual overcurrent protecti...

Page 173: ...ection is also well suited to operate in teleprotection communication schemes which enables fast clearance of earth faults on transmission lines The directional function uses the polarizing quantity as decided by setting Voltage polarizing is the most commonly used but alternatively current polarizing where currents in transformer neutrals providing the neutral source ZN is used to polarize IN ZN ...

Page 174: ... a large inrush current when being energized This inrush current can produce residual current component The phenomenon is due to saturation of the transformer magnetic core during parts of the cycle There is a risk that inrush current will give a residual current that reaches level above the operating current of the residual overcurrent protection The inrush current has a large second harmonic con...

Page 175: ...e of current polarising quantity i e Zero seq or Neg seq for direction detection SeqTypeIDir This is used to select the type of operating current quantity i e Zero seq or Neg seq for direction detection 8 4 3 1 Common settings for all steps M15282 81 v10 AngleRCA Relay characteristic angle given in degree This angle is defined as shown in Figure 81 The angle is defined positive when the residual c...

Page 176: ... dual polarizing method is used it is important that the setting INx or the product 3I0 ZNpol is not greater than 3U0 If so there is a risk for incorrect operation for faults in the reverse direction IPolMin is the minimum earth fault current accepted for directional evaluation For smaller currents than this value the operation will be blocked A typical setting is 5 10 of IB UPolMin Minimum polari...

Page 177: ...ual fundamental current will however be significant The inrush current of the transformer in service before the parallel transformer energizing will be a little delayed compared to the first transformer Therefore we will have high 2nd harmonic current initially After a short period this current will however be small and the normal 2nd harmonic blocking will reset en05000136 vsd Power System IN IN ...

Page 178: ...armonic restrain will prevent unwanted function in case of transformer inrush current The under time function has a set time delay Below the settings for switch on to fault logics are described SOTF This parameter can be set Off SOTF Under Time SOTF Under Time ActivationSOTF This setting will select the signal to activate SOTF function CB position open CB position closed CB close command StepForSO...

Page 179: ...otective equipment The following time delays can be estimated Protection operate time 15 60 ms Protection resetting time 15 60 ms Breaker opening time 20 120 ms The different characteristics are described in the technical reference manual tx Definite time delay for step x The definite time tx is added to the inverse time when inverse time characteristic is selected Note that the value set is the t...

Page 180: ...kup value Note that the operate time value is dependent on the selected setting value for time multiplier kx INxMult Multiplier for scaling of the current setting value If a binary input signal ENMULTx is activated the current operation level is increased by this setting constant ResetTypeCrvx The reset of the delay timer can be made in different ways The possibilities are described in the technic...

Page 181: ...bed one application possibility to be used in meshed and effectively earthed systems The protection measures the residual current out on the protected line The protection function has a directional function where the polarizing voltage zero sequence voltage is the polarizing quantity The polarizing voltage and current can be internally generated when a three phase set of voltage transformers and c...

Page 182: ...lculated at a fault on the remote busbar one or two phase to earth fault To assure selectivity it is required that step 1 shall not give a trip at this fault The requirement can be formulated according to Equation 113 step1 0 I 1 2 3I remote busbar EQUATION1199 V3 EN US Equation 113 As a consequence of the distribution of zero sequence current in the power system the current to the protection migh...

Page 183: ...ssary if a big power transformer Y0 D at remote bus bar is disconnected A special case occurs at double circuit lines with mutual zero sequence impedance between the parallel lines see Figure 87 IN One phase to earth fault 3I0 IEC05000152 en 2 vsd IEC05000152 V2 EN US Figure 87 Step 1 third calculation In this case the residual current out on the line can be larger than in the case of earth fault ...

Page 184: ...Figure 88 Step 2 check of reach calculation The residual current out on the line is calculated at an operational case with minimal earth fault current The requirement that the whole line shall be covered by step 2 can be formulated according to equation 116 step2 0 I 0 7 3I at remote busbar EQUATION1202 V4 EN US Equation 116 To assure selectivity the current setting must be chosen so that step 2 d...

Page 185: ... s Step 3 shall enable selective trip of earth faults having higher fault resistance to earth compared to step 2 The requirement on step 3 is selectivity to other earth fault protections in the network One criterion for setting is shown in Figure 90 IEC05000156 3 en vsd IN One phase to earth fault 3I0 IN 3I02 IEC05000156 V3 EN US Figure 90 Step 3 Selectivity calculation 1 0 step3 step2 02 3I I 2 I...

Page 186: ...r applications a current dependent inverse time characteristic is used This enables a higher degree of selectivity also for sensitive earth fault current protection 8 5 Thermal overload protection one time constant Celsius Fahrenheit LCPTTR LFPTTR IP14512 1 v7 8 5 1 Identification M17106 1 v7 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Therm...

Page 187: ...tes trip of the protected line 8 5 3 Setting guideline IP14994 1 v1 M15094 3 v8 The parameters for the Thermal overload protection one time constant Celsius Fahrenheit LCPTTR LFPTTR are set via the local HMI or PCM600 M15094 5 v10 The following settings can be done for the thermal overload protection Operation Off On GlobalBaseSel is used to select a GBASVAL function for reference of base values p...

Page 188: ...d to block switch in of the protected circuit as long as the conductor temperature is 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 6 Breaker failure protection CCRBRF IP14514 1 v6 8 6 1 Identification M14878 1 v5 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE...

Page 189: ...e way the detection of failure of the breaker is performed In the mode current the current measurement is used for the detection In the mode Contact the long duration of breaker position signal is used as indicator of failure of the breaker The mode Current Contact means that both ways of detections are activated Contact mode can be usable in applications where the fault current through the circui...

Page 190: ...out of 3 is sufficient For Contact operation means back up trip is done when circuit breaker is closed breaker position is used IP Current level for detection of breaker failure set in of IBase This parameter should be set so that faults with small fault current can be detected The setting can be chosen in accordance with the most sensitive protection function to start the breaker failure protecti...

Page 191: ...nt of re trip timer The minimum time delay for the re trip can be estimated as _ 2 1 cbopen BFP reset margin t t t t t EQUATION1430 V1 EN US Equation 119 where tcbopen is the maximum opening time for the circuit breaker tBFP_reset is the maximum time for breaker failure protection to detect correct breaker function the current criteria reset tmargin is a safety margin It is often required that the...

Page 192: ...ons tripping different back up circuit breakers tCBAlarm Time delay for alarm in case of indication of faulty circuit breaker There is a binary input CBFLT from the circuit breaker This signal is activated when internal supervision in the circuit breaker detect that the circuit breaker is unable to clear fault This could be the case when gas pressure is low in a SF6 circuit breaker After the set t...

Page 193: ...SC will detect situation with deviating positions of the poles of the protected circuit breaker The protection has two different options to make this detection By connecting the auxiliary contacts in the circuit breaker so that logic is created a signal can be sent to the protection indicating pole discordance This logic can also be realized within the protection itself by using opened and close s...

Page 194: ...itor the function is activated only directly in connection to breaker open or close command during 200 ms In the alternative Continuous monitor function is continuously activated CurrUnsymLevel Unsymmetrical magnitude of lowest phase current compared to the highest set in of the highest phase current Natural difference between phase currents in 1 1 2 breaker installations must be considered For ci...

Page 195: ... regulator or wrong settings under manual control symmetrical voltage decrease Overload symmetrical voltage decrease Short circuits often as phase to earth faults unsymmetrical voltage decrease UV2PTUV is used in combination with overcurrent protections either as restraint or in logic and gates of the trip signals issued by the two functions It can also be used to Detect no voltage conditions for ...

Page 196: ... Equipment protection such as for motors and generators M13851 50 v3 The setting must be below the lowest occurring normal voltage and above the lowest acceptable voltage for the equipment 9 1 3 2 Disconnected equipment detection M13851 53 v3 The setting must be below the lowest occurring normal voltage and above the highest occurring voltage caused by inductive or capacitive coupling when the equ...

Page 197: ...3 In most applications it is sufficient that one phase voltage is low to give operation If UV2PTUV shall be insensitive for single phase to earth faults 2 out of 3 can be chosen In subtransmission and transmission networks the undervoltage function is mainly a system supervision function and 3 out of 3 is selected Un Set operate undervoltage operation value for step n given as of the parameter UBa...

Page 198: ... of trip Block all In case of a low voltage the undervoltage function can be blocked This function can be used to prevent function when the protected object is switched off If the parameter is set Block of trip or Block all unwanted trip is prevented IntBlkStValn Voltage level under which the blocking is activated set in of UBase This setting must be lower than the setting Un As switch of shall be...

Page 199: ...wer system like metallic connection to a higher voltage level broken conductor falling down to a crossing overhead line transformer flash over fault from the high voltage winding to the low voltage winding and so on 2 Malfunctioning of a voltage regulator or wrong settings under manual control symmetrical voltage decrease 3 Low load compared to the reactive power generation symmetrical voltage dec...

Page 200: ...capacitors M13852 13 v1 High voltage will deteriorate the dielectricum and the insulation The setting has to be well above the highest occurring normal voltage and well below the highest acceptable voltage for the capacitor 9 2 3 3 Power supply quality M13852 16 v1 The setting has to be well above the highest occurring normal voltage and below the highest acceptable voltage due to regulation good ...

Page 201: ...rve The choice is highly dependent of the protection application OpModen This parameter describes how many of the three measured voltages that should be above the set level to give operation The setting can be 1 out of 3 2 out of 3 3 out of 3 In most applications it is sufficient that one phase voltage is high to give operation If the function shall be insensitive for single phase to earth faults ...

Page 202: ...BCrvn CCrvn DCrvn PCrvn Parameters to set to create programmable under voltage inverse time characteristic Description of this can be found in the technical reference manual CrvSatn When the denominator in the expression of the programmable curve is equal to zero the time delay will be infinity There will be an undesired discontinuity Therefore a tuning parameter CrvSatn is set to compensate for t...

Page 203: ...e the residual voltage will reach different values The highest residual voltage equal to three times the phase to earth voltage is achieved for a single phase to earth fault The residual voltage increases approximately to the same level in the whole system and does not provide any guidance in finding the faulted component Therefore ROV2PTOV is often used as a backup protection or as a release sign...

Page 204: ...voltage for the capacitor 9 3 3 3 Power supply quality M13853 15 v3 The setting must be above the highest occurring normal residual voltage and below the highest acceptable residual voltage due to regulation good practice or other agreements 9 3 3 4 High impedance earthed systems M13853 18 v10 In high impedance earthed systems earth faults cause a neutral voltage in the feeding transformer neutral...

Page 205: ...e is indicated by voltage collapse in that phase The other healthy phase will still have normal phase to earth voltage The residual sum will have the same value as the remaining phase to earth voltage which is shown in Figure 93 UL1 IEC07000189 2 en vsd IEC07000189 V2 EN US Figure 93 Earth fault in Direct earthed system 1MRK 505 393 UEN B Section 9 Voltage protection Line differential protection R...

Page 206: ...setting parameters described below are identical for the two steps n step 1 and 2 Therefore the setting parameters are described only once OperationStepn This is to enable disable operation of step n Characteristicn Selected inverse time characteristic for step n This parameter gives the type of time delay to be used The setting can be Definite time or Inverse curve A or Inverse curve B or Inverse...

Page 207: ... PCrvn Parameters for step n to set to create programmable undervoltage inverse time characteristic Description of this can be found in the technical reference manual CrvSatn Set tuning parameter for step n When the denominator in the expression of the programmable curve is equal to zero the time delay will be infinite There will be an undesired discontinuity Therefore a tuning parameter CrvSatn i...

Page 208: ...202 ...

Page 209: ...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 underfrequen...

Page 210: ...tive loads The setting level the number of levels and the distance between two levels in time and or in frequency depends very much on the characteristics of the power system under consideration The size of the largest loss of production compared to the size of the power system is a critical parameter In large systems the load shedding can be set at a fairly high frequency level and the time delay...

Page 211: ...system against breakdown by shedding generation in over production situations The overfrequency start value is set in Hz All voltage magnitude related settings are made as a percentage of a settable global base voltage parameter UBase The UBase value should be set as a primary phase to phase value Some applications and related setting guidelines for the frequency level are given below Equipment pr...

Page 212: ...are required at a rather high frequency level but in combination with a large negative rate of change of frequency the underfrequency protection can be used at a rather high setting 10 3 3 Setting guidelines M14971 3 v7 The parameters for Rate of change frequency protection SAPFRC are set via the local HMI or or through the Protection and Control Manager PCM600 All the frequency and voltage magnit...

Page 213: ...pply a stable value It is recommended to have a time delay long enough to take care of signal noise However the time rate of change frequency and frequency steps between different actions might be critical and sometimes a rather short operation time is required for example down to 70 ms Smaller industrial systems might experience rate of change frequency as large as 5 Hz s due to a single event Ev...

Page 214: ...208 ...

Page 215: ...rrents unequal transient saturation of CT cores with different remanence or different saturation factor may result in differences in the secondary currents from the two CT sets Unwanted blocking of protection functions during the transient stage must then be avoided Current circuit supervision CCSSPVC must be sensitive and have short operate time in order to prevent unwanted tripping from fast act...

Page 216: ...f the measured voltage in the relay point Examples are impedance protection functions undervoltage function energizing check function and voltage check for the weak infeed logic These functions can operate unintentionally if a fault occurs in the secondary circuits between the voltage instrument transformers and the IED It is possible to use different measures to prevent such unwanted operations M...

Page 217: ...ies in the primary system and differences in the current and voltage instrument transformers The minimum value for the operation of the current and voltage measuring elements must always be set with a safety margin of 10 to 20 depending on the system operating conditions Pay special attention to the dissymmetry of the measuring quantities when the function is used on long untransposed lines on mul...

Page 218: ...Ns or OptimZsNs In mode UZsIZs OR UNsINs both negative and zero sequence based algorithms are activated and working in an OR condition Also in mode OptimZsNs both negative and zero sequence algorithms are activated and the one that has the highest magnitude of measured negative or zero sequence current will operate If there is a requirement to increase the security of the fuse failure function OpM...

Page 219: ...se is the base voltage for the function according to the setting GlobalBaseSel The setting of the current limit 3I0 is done in percentage of IBase The setting of 3I0 must be higher than the normal unbalance current that might exist in the system The setting can be calculated according to equation 128 3 0 3 0 100 I I IBase EQUATION2293 V3 EN US Equation 128 where 3I0 is the maximal zero sequence cu...

Page 220: ...age that might occur during emergency conditions A setting of approximately 70 of UBase is recommended The current threshold IPh shall be set lower than the IMinOp for the distance protection function A 5 10 lower value is recommended 11 2 3 6 Dead line detection M13683 78 v4 The condition for operation of the dead line detection is set by the parameters IDLD for the current threshold and UDLD for...

Page 221: ...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 Line...

Page 222: ...grees 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 19 Dependencies between tBreaker and SlipFrequency with different CloseAngleMax values tBreaker s max settable value with CloseAngleMax 15 degrees default value tBreaker s max settable value with CloseAngle...

Page 223: ...hrough other stations The need for a check of synchronization increases if the meshed system decreases since the risk of the two networks being out of synchronization at manual or automatic closing is greater The synchrocheck function measures the conditions across the circuit breaker and compares them to set limits Output is generated only when all measured conditions are within their set limits ...

Page 224: ...the phase angle difference is smaller To fulfill the above requirements the synchrocheck function is provided with duplicate settings one for steady Manual conditions and one for operation under disturbed conditions Auto SynchroCheck UHighBusSC 50 120 of GblBaseSelBus UHighLineSC 50 120 of GblBaseSelLine UDiffSC 0 02 0 50 p u PhaseDiffM 5 90 degrees PhaseDiffA 5 90 degrees FreqDiffM 3 1000 mHz Fre...

Page 225: ...Bus and GblBaseSelLine which are defined in the Global Base Value groups in a similar way the equipment is considered non energized Dead if the voltage is below the set value for ULowBusEnerg or ULowLineEnerg of the respective Global Base Value groups A disconnected line can have a considerable potential due to factors such as induction from a line running in parallel or feeding via extinguishing ...

Page 226: ...he internal fuse failure supervision function is then used and connected to the fuse supervision inputs of the SESRSYN function block In case of a fuse failure the SESRSYN energizing function is blocked The UB1OK UB2OK and UB1FF UB2FF inputs are related to the busbar voltage and the ULN1OK ULN2OK and ULN1FF ULN2FF inputs are related to the line voltage External selection of energizing direction M1...

Page 227: ...re some examples of how different arrangements are connected to the IED analogue inputs and to the function block SESRSYN One function block is used per circuit breaker The input used below in example are typical and can be changed by use of configuration and signal matrix tools The SESRSYN and connected SMAI function block instances must have the same cycle time in the application configuration 1...

Page 228: ...principles for a single busbar For the SESRSYN function there is one voltage transformer on each side of the circuit breaker The voltage transformer circuit connections are straightforward no special voltage selection is necessary The voltage from busbar VT is connected to U3PBB1 and the voltage from the line VT is connected to U3PLN1 The conditions of the VT fuses shall also be connected as shown...

Page 229: ...om the two busbars are selected based on the position of the busbar disconnectors This means that the connections to the function block will be the same as for the single busbar arrangement The voltage selection parameter CBConfig is set to No voltage sel 12 1 3 3 Single circuit breaker with double busbar internal voltage selection M12326 3 v7 WA1 WA2 QB1 QB2 LINE QA1 IEC10000095 6 en vsd WA1_MCB ...

Page 230: ... of the twelve GBASVAL functions used for reference of base values This means that the reference voltage of bus and line can be set to different values The settings for the SESRSYN function are found under Main menu Settings IED Settings Control Synchronizing 25 SC VC SESRSYN 25 SC VC X has been divided into four different setting groups General Synchronizing Synchrocheck and Energizingcheck Gener...

Page 231: ... UL1 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 Synchronizing function With the setting On the function is in the service mode and the output signal depends on the input conditions UHighBusSynch and UHighLineSynch The voltage level settings shall be chosen in relation to th...

Page 232: ...ly are regulated to nominal frequency independent of each other so the frequency difference shall be small FreqRateChange The maximum allowed rate of change for the frequency CloseAngleMax The setting CloseAngleMax is the maximum closing angle between bus and line at which synchronizing is accepted To minimize the moment stress when synchronizing near a power station a narrower limit should be use...

Page 233: ... synchronism check A typical value can be 80 of the base voltages UDiffSC The setting for voltage difference between line and bus in p u This setting in p u is defined as U Bus GblBaseSelBus U Line GblBaseSelLine A normal setting is 0 10 0 15 p u FreqDiffM and FreqDiffA The frequency difference level settings FreqDiffM and FreqDiffA shall be chosen depending on the condition in the network At stea...

Page 234: ...is below set value of ULowLineEnerg and the bus voltage is above set value of UHighBusEnerg DBLL Dead Bus Live Line the bus voltage is below set value of ULowBusEnerg and the line voltage is above set value of UHighLineEnerg Both energizing can be done in both directions DLLB or DBLL ManEnergDBDL If the parameter is set to On manual closing is also enabled when both line voltage and bus voltage ar...

Page 235: ...ed when the conditions are fulfilled again Circuit breaker closing is thus not permitted until the energizing condition has remained constant throughout the set delay setting time 12 2 Autorecloser for 1 phase 2 phase and or 3 phase operation SMBRREC IP14559 1 v6 12 2 1 Identification M14890 1 v7 Function Description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number A...

Page 236: ...rt AR Reclosing command AR reset IEC04000146 3 en vsd IEC04000146 V3 EN US Figure 101 Single shot automatic reclosing at a permanent fault Single phase tripping and single phase automatic reclosing is a way of limiting the effect of a single phase line fault on power system operation Especially at higher voltage levels the majority of faults are of single phase type around 90 To maintain system st...

Page 237: ...lt It is common to use one automatic reclosing function per line circuit breaker CB When one CB per line end is used then there is one auto recloser per line end If auto reclosers are included in duplicated line protection which means two auto reclosers per CB one should take measures to avoid uncoordinated reclosing commands In 1 1 2 breaker double breaker and ring bus arrangements two CBs per li...

Page 238: ...s common to provide auto reclosing in only one of the sub systems as the requirement is for fault clearance and a failure to reclose because of the auto recloser being out of service is not considered a major disturbance If two auto reclosers are provided on the same breaker the application must be carefully checked and normally one must be the master and be connected to inhibit the other auto rec...

Page 239: ...ng cycle M12391 94 v5 The usual way to start an auto reclosing cycle or sequence is to start it at selective tripping by line protection by applying a signal to the START input Starting signals can be either general trip signals or only the conditions for differential distance protection zone 1 and distance protection aided trip In some cases also directional earth fault protection aided trip can ...

Page 240: ...e expected to take place only for faults on the own line The auto recloser must be blocked by activating the INHIBIT input for the following conditions Tripping from delayed distance protection zones Tripping from back up protection functions Tripping from breaker failure function Intertrip received from remote end circuit breaker failure function Busbar protection tripping Depending of the starti...

Page 241: ...s in an auto reclosing cycle is selected by the setting NoOfShots A maximum of five shots can be done The type of auto reclosing used at the first auto reclosing shot is set by the setting ARMode The first alternative is three phase auto reclosing The other alternatives include some single phase or two phase auto reclosing Usually there is no two phase tripping arranged and then there will be no t...

Page 242: ...uit breaker closing command the tReclaim timer is started If no tripping takes place during that time the auto recloser resets to the Ready state and the ACTIVE output resets If the first reclosing shot fails a three phase trip will be initiated and three phase reclosing can follow if selected 12 2 2 10 ARMode 1 2ph 1 phase or 2 phase reclosing in the first shot M12391 136 v5 At single phase or tw...

Page 243: ...n the above described example program mode 1 2 3ph If the first reclosing shot fails a three phase trip will be issued and three phase reclosing will follow if selected At two phase or three phase trip a failure of a two phase or three phase auto reclosing attempt will inhibit the auto recloser No more shots are attempted The expression 1 2 3ph should be understood as Only one shot at two phase or...

Page 244: ...ets Should a new trip occur during this time it is treated as a continuation of the first fault The reclaim timer is started when the circuit breaker closing command is given 12 2 2 16 Pulsing of the circuit breaker closing command and counter M12391 205 v4 The circuit breaker closing command CLOSECB is given as a pulse with a duration set by the tPulse setting For circuit breakers without an anti...

Page 245: ...cel the auto reclosing for the second circuit breaker if the first circuit breaker closed onto a persistent fault It can also be used to generate a lock out of manual circuit breaker closing until the operator has reset the lock out see separate section 12 2 2 19 Lock out initiation M12391 214 v8 In many cases there is a requirement that a lock out is generated when the auto reclosing attempt fail...

Page 246: ...ure 104 Lock out arranged with internal logic with manual closing going through in IED 12 2 2 20 Evolving fault M12391 217 v4 An evolving fault starts as a single phase fault which leads to single phase tripping and then the fault spreads to another phase The second fault is then cleared by three phase tripping The auto recloser will first receive a start signal START without any three phase signa...

Page 247: ...2 Thermal overload protection holding the auto recloser back M12391 226 v3 If the THOLHOLD input thermal overload protection holding auto reclosing back is activated it will keep the auto recloser on a hold until it is reset There may thus be a considerable delay between start of the auto recloser and the breaker closing command to the circuit breaker An external logic limiting the time and sendin...

Page 248: ...en used for the combination MODEINT The auto reclosing mode is selected with the ARMode setting As an alternative to the setting the mode can be selected by connecting an integer for example from function block B16I to the MODEINT input The six possible modes are described in table 6 with their corresponding MODEINT integer value When a valid integer is connected to the input MODEINT the selected ...

Page 249: ...is without a synchronization check SYNC This input is connected to the internal synchrocheck function when required or to an external device for synchronism If neither internal nor external synchronism or energizing check is required it can be connected to a permanently high source TRUE The signal is required for three phase shots 1 5 to proceed Note Not the high speed step THOLHOLD Signal Thermal...

Page 250: ...ls M12399 46 v9 Please see Figure 105 and default factory configuration for examples 1PT1 and 2PT1 Indicates that single phase or two phase auto reclosing is in progress It is used to temporarily block an earth fault and or pole disagreement function during the single phase or two phase open interval 3PT1 3PT2 3PT3 3PT4 and 3PT5 Indicates that three phase auto reclosing shots one to five are in pr...

Page 251: ...rse of PREP3P It can be connected to a binary output relay for connection to external protection or trip relays In case of a total loss of auxiliary power the output relay drops and does not allow single phase trip PREP3P Prepare three phase trip is usually connected to the trip block to force a coming trip to be a three phase one If the auto recloser cannot make a single phase or two phase auto r...

Page 252: ...sed for single phase two phase or three phase auto reclosing ON OFF BLKON BLKOFF INHIBIT BLOCKED SETON INPROGR ACTIVE UNSUCCL SUCCL CLOSECB CBREADY CBCLOSED PLCLOST 1PT1 WFMASTER RESET START THOLHOLD READY TRSOTF SYNC INPUT xx xx xx xx xx xx xx xx xx xx OR OUTPUT xx xx xx xx xx xx xx xx xx xx PROTECTION xxxx TRIP ZCVPSOF TRIP SESRSYN AUTOOK BIM BOM SMBRREC IEC04000135 5 en Original vsd PERMIT1P PR...

Page 253: ...ttings for the auto recloser are set using the local HMI LHMI or PCM600 This setting guideline describes the settings of the auto recloser using the LHMI The settings for 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 set...

Page 254: ... in a new trip The user can set a maximum start pulse duration time tLongStartInh This start pulse duration time is controlled by the LongStartInhib setting When the start pulse duration signal is longer than set maximum start pulse duration the auto reclosing sequence interrupts in the same way as for a signal to the INHIBIT input tLongStartInh The user can set a maximum start pulse duration time...

Page 255: ... respond to the circuit breaker close command one can set UnsucClByCBCheck CB Check and set tUnsucCl for instance to 1 0 s BlockByUnsucCl Setting of whether an unsuccessful auto reclosing attempt shall set the auto recloser in blocked status If used the BLKOFF input must be configured to unblock the function after an unsuccessful auto reclosing attempt Normal setting is Off CutPulse In circuit bre...

Page 256: ...of the reclaim time This latter case is controlled by setting UnsucClByCBChk The auto reclosing sequence is considered unsuccessful for both above cases and the UNSUCCL output is activated DeadTime settings NoOfShots In power transmission one shot is mostly used In most cases one auto reclosing shot is sufficient as the majority of arcing faults will cease after the first auto reclosing shot In po...

Page 257: ...ave should take the duration of the circuit breaker closing time of the master into consideration before sending the circuit breaker closing command A setting tWaitForMaster sets a maximum wait time for the WAIT input to reset If the wait time expires the auto reclosing cycle of the slave is inhibited The maximum wait time tWaitForMaster for the second circuit breaker is set longer than the auto r...

Page 258: ...he IED front Station HMI GW cc Station bus breakers disconnectors earthing switches IEC08000227 vsd Apparatus Control IED I O Local HMI Apparatus Control IED I O Apparatus Control IED I O Local HMI Local HMI IEC08000227 V1 EN US Figure 107 Overview of the apparatus control functions Features in the apparatus control function Operation of primary apparatuses Select Execute principle to give high se...

Page 259: ...108 The application description for all these functions can be found below The function SCILO in the Figure below is the logical node for interlocking When the circuit breaker or switch is located in a breaker IED two more functions are added GOOSE receive for switching device GOOSEXLNRCV Proxy for signals from switching device via GOOSE XLNPROXY The extension of the signal flow and the usage of t...

Page 260: ... QB1 QB9 IEC 61850 QCBAY IEC17000061 V1 EN US Figure 108 Signal flow between apparatus control function blocks when all functions are situated within the IED Section 12 1MRK 505 393 UEN B Control 254 Line differential protection RED650 2 2 IEC Application manual ...

Page 261: ...trol functions with XCBR and XSWI located in a breaker IED Control operation can be performed from the local IED HMI If users are defined in the IED then the local remote switch is under authority control otherwise the default user can perform control operations from the local IED HMI without logging in The default position of the local remote switch is on remote 1MRK 505 393 UEN B Section 12 Cont...

Page 262: ...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 22 Table 22 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 maintenanc...

Page 263: ... 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 110 APC Local remote function block 12 3 3 Switch controller SCSWI M16596 3 v6 SCSWI may handle and operate on one three phase device or three one phase switch...

Page 264: ...iven The switch controller represents the content of the SCSWI logical node according to IEC 61850 with mandatory functionality 12 3 4 Switches SXCBR M16602 3 v7 Switches are functions used to close and interrupt an ac power circuit under normal conditions or to interrupt the circuit under fault or emergency conditions The intention with these functions is to represent the lowest level of a power ...

Page 265: ...XSWI function The command response functionality is dependent on the connection of the execution information XIN from the SCSWI function controlling the represented switch Otherwise the function only reflects the current status of the switch such as blocking selection position operating capability and operation counter Since different switches are represented differently on IEC 61850 the data that...

Page 266: ...igure 111 Configuration with XLNPROXY and GOOSEXLNRCV where all the IEC 61850 modelled data is used including selection Section 12 1MRK 505 393 UEN B Control 260 Line differential protection RED650 2 2 IEC Application manual ...

Page 267: ... 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 fai...

Page 268: ...e OPCAP input and output are used for the CBOpCap data of a XCBR respectively SwOpCap for a XSWI The interpretation for the command following is controlled through the setting SwitchType 12 3 6 Interaction between modules M16626 3 v9 A typical bay with apparatus control function consists of a combination of logical nodes or functions that are described here The Switch controller SCSWI initializes ...

Page 269: ... breaker with predefined switching conditions synchrocheck Also the case that one side is dead energizing check is included The Generic Automatic Process Control function GAPC handles generic commands from the operator to the system The overview of the interaction between these functions is shown in Figure 113 below 1MRK 505 393 UEN B Section 12 Control Line differential protection RED650 2 2 IEC ...

Page 270: ...pen Open rel Close rel Open rel SMPPTRC Trip logic Position Pos from other bays Synchronizing OK Synchrocheck OK Start Synchronizing Synchronizing in progress SCILO Interlocking Enable open Enable close IEC17000063 1 en Original vsdx IEC17000063 V1 EN US Figure 113 Example overview of the interactions between functions in a typical bay 12 3 7 Setting guidelines M16669 3 v5 The setting parameters f...

Page 271: ...nd 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 permi...

Page 272: ...l Op phase or only at operate Op phase 12 3 7 3 Switch SXCBR 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 state When the time ha...

Page 273: ... a cause code is given 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 ...

Page 274: ... careful in coordinating the settings with the configuration if one sets the number of positions to x in settings for example there will be only the first x outputs available from the block in the configuration Also the frequency of the UP or DOWN pulses should be lower than the setting tPulse From the local HMI the selector switch can be operated from Single line diagram SLD 12 4 3 Setting guidel...

Page 275: ...OSITION is an integer output showing the actual position as an integer number 0 3 where 0 MidPos 1 Open 2 Closed and 3 Error An example where VSGAPC is configured to switch Autorecloser on off from a button symbol on the local HMI is shown in figure114 The I and O buttons on the local HMI are normally used for on off operations of the circuit breaker IEC07000112 3 en vsd PSTO CMDPOS12 IPOS1 NAM_PO...

Page 276: ...t or functions one must use other tools described in the Engineering manual and define which function block in which systems equipment or functions should receive this information More specifically DPGAPC function reports a combined double point position indication output POSITION by evaluating the value and the timestamp attributes of the inputs OPEN and CLOSE together with the logical input sign...

Page 277: ... a collection of 8 single point commands that can be used for direct commands for example reset of LED s or putting IED in ChangeLock state from remote In this way simple commands can be sent directly to the IED outputs without confirmation Confirmation status of the result of the commands is supposed to be achieved by other means such as binary inputs and SPGAPC function blocks PSTO is the univer...

Page 278: ...ction plays the same role as functions GOOSEBINRCV for IEC 61850 and MULTICMDRCV for LON AUTOBITS function block have 32 individual outputs which each can be mapped as a Binary Output point in DNP3 The output is operated by a Object 12 in DNP3 This object contains parameters for control code count on time and off time To operate an AUTOBITS output point send a control code of latch On latch Off pu...

Page 279: ... configuration logic circuits the user can govern pulses or steady output signals for control purposes within the IED or via binary outputs Figure 115 shows an application example of how the user can connect SINGLECMD via configuration logic circuit to control a high voltage apparatus This type of command control is normally carried out by sending a pulse to the binary outputs of the IED Figure 11...

Page 280: ...7 V2 EN US Figure 116 Application example showing a logic diagram for control of built in functions Single command function SINGLESMD CMDOUTy OUTy Device 1 User defined conditions Configuration logic circuits en04000208 vsd IEC04000208 V2 EN US Figure 117 Application example showing a logic diagram for control of external devices via configuration logic circuits Section 12 1MRK 505 393 UEN B Contr...

Page 281: ...dent of the values sent from the station level that is the operator station or remote control gateway Steady sets the outputs to a steady signal 0 or 1 depending on the values sent from the station level Pulse gives a pulse with 100 ms duration if a value sent from the station level is changed from 0 to 1 That means the configured logic connected to the command function block may not have a cycle ...

Page 282: ...276 ...

Page 283: ...signals Communication speed or minimum time delay is always of utmost importance because the purpose for using communication is to improve the tripping speed of the scheme To avoid false signals that could cause false tripping it is necessary to pay attention to the security of the communication channel At the same time it is important to pay attention to the communication channel dependability to...

Page 284: ...ripping function if the communication channel is out of service Inadequate speed or dependability can cause spurious tripping for external faults Inadequate security can cause delayed tripping for internal faults To secure that the send signal will arrive before the zone used in the communication scheme will trip the trip is released first after the time delay tCoord has elapsed The setting of tCo...

Page 285: ...the communication channel is out of service Conversely it is less secure than permissive schemes because it will trip for external faults within the reach of the tripping function if the communication channel is out of service Inadequate speed or dependability can cause spurious tripping for external faults Inadequate security can cause delayed tripping for internal faults Since the blocking signa...

Page 286: ...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 curr...

Page 287: ...e 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 electrical ...

Page 288: ... end thereby disabling the communication channel To overcome the lower dependability in permissive schemes an unblocking function can be used Use this function at older less reliable power line carrier PLC communication where the signal has to be sent through the primary fault The unblocking function uses a guard signal CRG which must always be present even when no CR signal is received The absenc...

Page 289: ...ation logic function are set via the local HMI or PCM600 Configure the zones used for the CS send and for scheme communication tripping by using the ACT configuration tool The recommended settings of tCoord timer are based on maximal recommended transmission time for analogue channels according to IEC 60834 1 It is recommended to coordinate the proposed settings with actual performance for the tel...

Page 290: ... 4 Permissive overreaching scheme M13869 34 v4 Set Operation On Set Scheme type Permissive OR Set tCoord 0 ms Set tSendMin 0 1 s 0 s in parallel line applications Set Unblock Off Set tSecurity 0 035 s 13 1 3 5 Unblocking scheme M13869 43 v4 Set Unblock Restart Loss of guard signal will give both trip and alarm Choose NoRestart if only trip is required Set tSecurity 0 035 s 13 1 3 6 Intertrip schem...

Page 291: ... can be explained by looking into Figure 122 and Figure 123 Initially the protection A2 at A side will detect a fault in forward direction and send a communication signal to the protection B2 at remote end which is measuring a fault in reverse direction L1 L2 A1 A2 B1 B2 IEC9900043 2 vsd IEC99000043 V3 EN US Figure 122 Current distribution for a fault close to B side when all breakers are closed W...

Page 292: ...minal and a sequential tripping is achieved This requires a detection of the fault by an independent tripping zone 1 To avoid sequential tripping as described and when zone 1 is not available weak end infeed tripping logic is used The weak end infeed function only works together with permissive overreach communication schemes as the carrier send signal must cover the complete line length The WEI f...

Page 293: ...d by the function to define IBase UBase and SBase as applicable 13 2 3 1 Current reversal logic M13856 6 v7 The forward zone timer must be set longer than the tDelayRev set value Set CurrRev to On to activate the function Set tDelayRev timer of the maximum reset time for the communication equipment that gives the carrier receive CRL signal plus 30 ms A minimum setting of 40 ms is recommended typic...

Page 294: ...on scheme is not available no communication channel but where the user still requires fast clearance for faults on the whole line The logic can be controlled either by the autorecloser zone extension or by the loss of load current loss of load acceleration The loss of load acceleration gives selected overreach zone permission to operate instantaneously after checking the loss of load condition It ...

Page 295: ...oss of load The timer is by default set to 300ms which is judged to be enough to secure the current release The setting of the minimum current detector MinCurr should be set higher than the unsymmetrical current that might flow on the non faulty line when the breaker at remote end has opened At the same time it should be set below the minimum load current transfer during normal operations that the...

Page 296: ...dversely 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 permissive sc...

Page 297: ...WPSCH IP14365 1 v4 13 5 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 5 2 Application IP15041 1 v1 13 5 2 1 Fault current reversal logic M15285 3 v7 Figure 124 and figure 125 show a typical system condition which can resul...

Page 298: ...ur 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 in IED...

Page 299: ...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 are add...

Page 300: ...op Minimum setting of tDelay IEC05000536 2 en vsd IEC05000536 V2 EN US Figure 127 Time sequence of signaling at current reversal 13 5 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 3U0 The zero sequence voltage for a fault at the remote line end ...

Page 301: ...ts 1ph 3ph operating mode Single phase tripping for single phase faults two phase tripping for two phase faults and three phase tripping for three phase faults 1ph 2ph 3ph operating mode If the OHL is connected to the substation via more than one breaker one SMPPTRC function block should be used for each breaker For example when single phase tripping and autoreclosing is used on the line both brea...

Page 302: ...Min 150ms The typical connection is shown below in figure 128 BLOCK BLKLKOUT TRIN TRINL1 TRINL2 TRINL3 PSL1 PSL2 PSL3 1PTRZ 1PTREF P3PTR SETLKOUT RSTLKOUT STDIR TRIP SMPPTRC TRL1 TRL2 TRL3 TR1P TR2P TR3P CLLKOUT START STL1 STL2 STL3 FW REV Protection functions with 3 phase trip for example time delayed overcurrent protection TMAGAPC STN IEC05000544 4 en vsdx IEC05000544 V4 EN US Figure 128 Trippin...

Page 303: ...gle phase tripping schemes are used a single phase autoreclosing attempt is expected to follow For cases where the autoreclosing is not in service or will not follow for some reason the input prepare three phase trip P3PTR must be activated This input is normally connected to the output PREP3P on the autorecloser function SMBRREC but can also be connected to other signals for example an external l...

Page 304: ... phase tripping application 14 1 2 3 Single two or three phase tripping M14828 15 v5 The single two three phase tripping mode provides single phase tripping for single phase faults two phase tripping for two phase faults and three phase tripping for three phase faults The operating mode is always used together with an autoreclosing scheme with setting ARMode 1 2 3 ph or ARMode 1 2 ph The functiona...

Page 305: ...nput SETLKOUT will result in lock out This is normally the case for overhead line protection where most faults are transient Unsuccessful autoreclose and back up zone tripping can in such cases be connected to initiate lock out by activating the input SETLKOUT 14 1 2 5 Example of directional data GUID 08AC09AB 2B2F 4095 B06E 1171CF225869 v2 An example how to connect the directional data from diffe...

Page 306: ...N BLOCK START FW REV STL1 FWL1 REVL1 STL2 FWL2 REVL2 STL3 FWL3 REVL3 STDIR STARTCOMB STN FWN REVN STN FWN REVN PROTECTION 3 IEC16000180 2 en vsdx IEC16000180 V2 EN US Figure 130 Example of the connection of directional start logic The Start Matrix SMAGAPC merges start and directional output signals from different application functions and creates a common directional output signal STDIR to be conn...

Page 307: ...latches the TRIP related outputs The normal selection is Off AutoLock Sets the scheme for lock out Off only activates lock out through the input SETLKOUT On additionally allows lock out activation via the trip inputs The normal selection is Off tTripMin Sets the required minimum duration of the trip pulse It should be set to ensure that the circuit breaker is opened correctly The normal setting is...

Page 308: ...tivation conditions no longer are fulfilled It is only used in Steady mode When used for direct tripping of circuit breaker s the off delay time shall be set to at least 0 150 seconds in order to obtain a satisfactory minimum duration of the trip pulse to the circuit breaker trip coils ModeOutputx Defines if output signal OUTPUTx where x 1 3 is Steady or Pulsed 14 3 Logic for group alarm ALMCALH G...

Page 309: ...cording to the specific application needs 14 4 1 2 Setting guidelines GUID B08F2636 33DA 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 GU...

Page 310: ...elines GUID E6BD982D 9E47 4CC2 9666 6E5CABA414C0 v4 There are no settings for AND gates OR gates inverters or XOR 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 the one delayed on drop out always have a common setting value For controllable gates setta...

Page 311: ...lays must be introduced into the logic schemes to prevent errors for example race between functions 14 7 Fixed signal function block FXDSIGN IP15080 1 v2 14 7 1 Identification SEMOD167904 2 v2 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Fixed signals FXDSIGN 14 7 2 Application M15322 3 v15 The Fixed signals function FXDSIGN has nine pre set ...

Page 312: ...neutral point is available This means that only two inputs are used Since all group connections are mandatory to be connected the third input needs to be connected to something which is the GRP_OFF signal in FXDSIGN function block I3PW1CT1 I3PW2CT1 I3P REFPDIF GRP_OFF FXDSIGN IEC09000620_3_en vsd IEC09000620 V3 EN US Figure 133 REFPDIF function inputs for normal transformer application 14 8 Boolea...

Page 313: ... receiving up to 16 booleans input locally If the BLOCK input is activated it will freeze the output at the last value Values of each of the different OUTx from function block B16I for 1 x 16 The sum of the value on each INx corresponds to the integer presented on the output OUT on the function block B16I Name of input Type Default Description Value when activated Value when deactivated IN1 BOOLEA...

Page 314: ... the output OUT as a sum of the values of all the inputs INx that are activated OUT is an integer When all INx where 1 x 16 are activated that is Boolean 1 it corresponds to that integer 65535 is available on the output OUT BTIGAPC 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 dif...

Page 315: ...r output signals from one function to binary logical inputs to another function IB16 function does not have a logical node mapping The Boolean 16 to integer conversion function IB16 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 s...

Page 316: ...35 65535 is the highest boolean value that can be converted to an integer by the IB16 function block 14 11 Integer to Boolean 16 conversion with logic node representation ITBGAPC SEMOD158419 1 v3 14 11 1 Identification SEMOD167944 2 v4 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Integer to boolean 16 conversion with logic node representation...

Page 317: ...BOOLEAN Output 4 8 0 OUT5 BOOLEAN Output 5 16 0 OUT6 BOOLEAN Output 6 32 0 OUT7 BOOLEAN Output 7 64 0 OUT8 BOOLEAN Output 8 128 0 OUT9 BOOLEAN Output 9 256 0 OUT10 BOOLEAN Output 10 512 0 OUT11 BOOLEAN Output 11 1024 0 OUT12 BOOLEAN Output 12 2048 0 OUT13 BOOLEAN Output 13 4096 0 OUT14 BOOLEAN Output 14 8192 0 OUT15 BOOLEAN Output 15 16384 0 OUT16 BOOLEAN Output 16 32768 0 The sum of the numbers i...

Page 318: ...es defined A resolution of 10 ms can be achieved when the settings are defined within the range 1 00 second tAlarm 99 999 99 seconds 1 00 second tWarning 99 999 99 seconds If the values are above this range the resolution becomes lower due to the 32 bit float representation 99 999 99 seconds tAlarm 999 999 0 seconds 99 999 99 seconds tWarning 999 999 0 seconds Note that tAlarm and tWarning are ind...

Page 319: ... Signed Comparison is performed on signed values of input and reference values RefSource This setting is used to select the reference source between input and setting for comparison Input REF The function will take reference 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 settin...

Page 320: ...system relative to each other or to a fixed value It is a basic arithmetic function that can be used for monitoring supervision interlocking and other logics 14 14 3 Setting guidelines GUID DE69FF5B 7D34 4A30 9060 214E98BFF798 v2 Setting procedure on the IED EnaAbs This setting is used to select the comparison type between signed and absolute values Absolute Comparison is performed with absolute v...

Page 321: ...ple GUID E7070CF6 B44B 4799 BE18 5C75B9FE2A87 v2 Let us consider a comparison is to be done between current magnitudes in the range of 90 to 110 with nominal rating is 100 and the order is kA For the above condition the comparator can be designed with settings as follows EnaAbs Absolute RefSource Set Value SetValue 100 RefPrefix Kilo EqualBandHigh 5 0 of reference value EqualBandLow 5 0 of referen...

Page 322: ...EqualBandHigh 5 0 of reference value EqualBandLow 5 0 of reference value Section 14 1MRK 505 393 UEN B Logic 316 Line differential protection RED650 2 2 IEC Application manual ...

Page 323: ...ltage sequence component measurement VMSQI U1 U2 U0 SYMBOL TT V1 EN US Phase neutral voltage measurement VNMMXU U SYMBOL UU V1 EN US 15 1 2 Application SEMOD54488 4 v12 Measurement functions are used for power system measurement supervision and reporting to the local HMI monitoring tool within PCM600 or to station level for example via IEC 61850 The possibility to continuously monitor measured val...

Page 324: ...ion can be used to report measured signal value to station level when change in measured value is above set threshold limit or time integral of all changes since the last time value updating exceeds the threshold limit Measure value can also be based on periodic reporting Main menu Measurement Monitoring Service values CVMMXN The measurement function CVMMXN provides the following power system quan...

Page 325: ...regarding any settings or parameters Zero clampings are also handled entirely by ZeroDb separately for each function s every output signal For example zero clamping of U12 is handled by UL12ZeroDb in VMMXU zero clamping of I1 is handled by IL1ZeroDb in CMMXU and so on Example of CVMMXN operation Outputs seen on the local HMI under Main menu Measurements Monitoring Servicevalues P_Q CVMMXN P_Q S Ap...

Page 326: ...t of operation Off The following general settings can be set for the Measurement function CVMMXN PowAmpFact Amplitude factor to scale power calculations PowAngComp Angle compensation for phase shift between measured I U Mode Selection of measured current and voltage There are 9 different ways of calculating monitored three phase values depending on the available VT inputs connected to the IED See ...

Page 327: ...r analog signal X This forms the maximum limit of the range XZeroDb Zero point clamping A signal value less than XZeroDb is forced to zero Observe the related zero point clamping settings in Setting group N for CVMMXN UGenZeroDb and IGenZeroDb If measured value is below UGenZeroDb and or IGenZeroDb calculated S P Q and PF will be zero and these settings will override XZeroDb XRepTyp Reporting type...

Page 328: ... reference see Section Analog inputs Calibration curves It is possible to calibrate the functions CVMMXN CMMXU VMMXU and VNMMXU to get class 0 5 presentations of currents voltages and powers This is accomplished by amplitude and angle compensation at 5 30 and 100 of rated current and voltage The compensation curve will have the characteristic for amplitude and angle compensation of currents as sho...

Page 329: ...D54481 12 v11 Single line diagram for this application is given in figure 135 400kV Busbar 400kV OHL P Q 1000 1 A IEC09000039 3 en vsdx IED kV 3 1 0 3 400 IEC09000039 1 EN V3 EN US Figure 135 Single line diagram for 400kV OHL application In order to monitor supervise and calibrate the active and reactive power as indicated in figure 135 it is necessary to do the following 1 Set correctly CT and VT...

Page 330: ...ired UGenZeroDb Zero point clamping in of Ubase 25 Set minimum voltage level to 25 Voltage below 25 will force S P and Q to zero IGenZeroDb Zero point clamping in of Ibase 3 Set minimum current level to 3 Current below 3 will force S P and Q to zero UBase set in Global base Base setting for voltage level in kV 400 00 Set rated OHL phase to phase voltage IBase set in Global base Base setting for cu...

Page 331: ...alue Comments IAmpComp5 Amplitude factor to calibrate current at 5 of Ir 0 00 IAmpComp30 Amplitude factor to calibrate current at 30 of Ir 0 00 IAmpComp100 Amplitude factor to calibrate current at 100 of Ir 0 00 UAmpComp5 Amplitude factor to calibrate voltage at 5 of Ur 0 00 UAmpComp30 Amplitude factor to calibrate voltage at 30 of Ur 0 00 UAmpComp100 Amplitude factor to calibrate voltage at 100 o...

Page 332: ...it is necessary to do the following 1 Set correctly all CT and VT and phase angle reference channel PhaseAngleRef see Section Setting of the phase reference channel data using PCM600 for analog input channels 2 Connect in PCM600 measurement function to LV side CT VT inputs 3 Set the setting parameters for relevant Measurement function as shown in the following table 30 Section 15 1MRK 505 393 UEN ...

Page 333: ...3 UBase set in Global base Base setting for voltage level in kV 35 00 Set LV side rated phase to phase voltage IBase set in Global base Base setting for current level in A 495 Set transformer LV winding rated current SBase set in Global base Base setting for power in MVA 31 5 Set based on rated power 15 2 Gas medium supervision SSIMG GUID 358AD8F8 AE06 4AEA 9969 46E5299D5B4B v3 15 2 1 Identificati...

Page 334: ...re lockout condition in the circuit breaker tPressureAlarm This is used to set the time delay for a pressure alarm indication given in s tPressureLO This is used to set the time delay for a pressure lockout indication given in s tTempAlarm This is used to set the time delay for a temperature alarm indication given in s tTempLockOut This is used to set the time delay for a temperature lockout indic...

Page 335: ...UID 0C8E498B 2A65 44ED 91D6 53EC72F49222 v4 The parameters for Liquid medium supervision SSIML can be set via local HMI or Protection and Control Manager PCM600 Operation This is used to disable enable the operation of liquid medium supervision i e Off On LevelAlmLimit This is used to set the limit for a level alarm condition in the oil insulated device LevelLOLimit This is used to set the limit f...

Page 336: ...cause there could be a number of abnormal operations or few operations with high level currents within the predetermined maintenance interval Hence condition based maintenance scheduling is an optimum solution in assessing the condition of circuit breakers Circuit breaker contact travel time Auxiliary contacts provide information about the mechanical operation opening time and closing time of a br...

Page 337: ...0000 20000 10000 2000 5000 1000 100 200 500 10 20 50 0 1 0 2 0 5 1 2 5 10 20 50 100 IEC12000623_1_en vsd IEC12000623 V1 EN US Figure 137 An example for estimating the remaining life of a circuit breaker Calculation for estimating the remaining life The graph shows that there are 10000 possible operations at the rated operating current and 900 operations at 10 kA and 50 operations at rated fault cu...

Page 338: ...e previous value The accumulated energy value can be reset to initial accumulation energy value by using the Reset accumulating energy input RSTIPOW Circuit breaker operation cycles Routine breaker maintenance like lubricating breaker mechanism is based on the number of operations A suitable threshold setting helps in preventive maintenance This can also be used to indicate the requirement for oil...

Page 339: ...POWLOPH TRVTOPAL and TRVTCLAL signals are not used in SAM600 IO 15 4 3 1 Setting procedure on the IED GUID 4E895FEA 74BF 4B11 A239 0574F8FF5188 v5 The parameters for breaker monitoring SSCBR can be set via the local HMI or Protection and Control Manager PCM600 Common base IED values for primary current IBase primary voltage UBase and primary power SBase are set in Global base values for settings f...

Page 340: ... lockout DirCoef Directional coefficient for circuit breaker life calculation RatedOperCurr Rated operating current of the circuit breaker RatedFltCurr Rated fault current of the circuit breaker OperNoRated Number of operations possible at rated current OperNoFault Number of operations possible at rated fault current CBLifeAlmLevel Alarm level for circuit breaker remaining life AccSelCal Selection...

Page 341: ...uts can be set individually as NoEvents OnSet at pick up of the signal OnReset at drop out of the signal OnChange at both pick up and drop out of the signal AutoDetect the EVENT function makes the reporting decision reporting criteria for integers have no semantic prefer to be set by the user LONChannelMask or SPAChannelMask M12811 15 v2 Definition of which part of the event function block that sh...

Page 342: ...g equipment and so on This information can also be used in a longer perspective when planning for and designing new installations that is a disturbance recording could be a part of Functional Analysis FA Disturbance report DRPRDRE always included in the IED acquires sampled data of all selected analog and binary signals connected to the function blocks that is Maximum 30 external analog signals 10...

Page 343: ...and 352 binary signals either internal signals or signals coming from external inputs The binary signals are identical in all functions that is Disturbance recorder DR Event recorder ER Indication IND Trip value recorder TVR and Event list EL function User defined names of binary and analog input signals are set using PCM600 The analog and binary signals appear with their user defined names The na...

Page 344: ...tions Three LED indications placed above the LCD screen makes it possible to get quick status information about the IED Green LED Steady light In Service Flashing light Internal failure Dark No power supply Yellow LED Steady light Triggered on binary signal N with SetLEDx Start or Start and Trip Flashing light The IED is in test mode Red LED Steady light Triggered on binary signal N with SetLEDx T...

Page 345: ...ecordings stored in the IED is 100 The oldest recording will be overwritten when a new recording arrives FIFO To be able to delete disturbance records Operation parameter has to be On The maximum number of recordings depend on each recordings total recording time Long recording time will reduce the number of recordings to less than 100 The IED flash disk should NOT be used to store any user files ...

Page 346: ...ine In order to capture the new disturbance it is possible to allow retriggering PostRetrig On during the post fault time In this case a new complete recording will start and during a period run in parallel with the initial recording When the retrig parameter is disabled PostRetrig Off a new recording will not start until the post fault PostFaultrecT or TimeLimit period is terminated If a new trig...

Page 347: ...ll be recorded and reported in graph However Trip value pre fault and fault value will be recorded and reported The input channel can still be used to trig the disturbance recorder If OperationM On waveform samples will also be recorded and reported in graph NomValueM Nominal value for input M OverTrigOpM UnderTrigOpM Over or Under trig operation Disturbance report may trig for high low level of a...

Page 348: ...ted to point out a sampled voltage input signal for example a line or busbar phase voltage channel 1 30 Event list M12179 440 v3 Event list EL SOE function has no dedicated parameters 15 6 3 5 Consideration M12179 420 v6 The density of recording equipment in power systems is increasing since the number of modern IEDs where recorders are included is increasing This leads to a vast number of recordi...

Page 349: ...al 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 signal status report BINSTATREP 15 7 2 Application GUID F9D225B1 68F7 4D15 AA89 C9211B450D19 v3 The Logical signal status report BINSTATREP function ma...

Page 350: ...istance to fault is very important for those involved in operation and maintenance Reliable information on the fault location greatly decreases the downtime of the protected lines and increases the total availability of a power system The fault locator is started with the input CALCDIST to which trip signals indicating in line faults are connected typically distance protection zone 1 and accelerat...

Page 351: ...ed bay protected line and residual current from a parallel bay line which is mutual coupled to protected line The Fault locator has close connection to the Disturbance report function All external analog inputs channel 1 30 connected to the Disturbance report function are available to the Fault locator and the function uses information calculated by the Trip value recorder After allocation of anal...

Page 352: ...s not constant in the network However this has a minor influence on the accuracy of the distance to fault calculation because only the phase angle of the distribution factor has an influence on the accuracy The phase angle of the distribution factor is normally very low and practically constant because the positive sequence line impedance which has an angle close to 90 dominates it Always set the ...

Page 353: ...cation GUID F3FB7B33 B189 4819 A1F0 8AC7762E9B7E v3 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Limit counter L4UFCNT 15 9 2 Application GUID 41B13135 5069 4A5A 86CE B7DBE9CFEF38 v2 Limit counter L4UFCNT is intended for applications where positive and or negative flanks on a binary signal need to be counted 1MRK 505 393 UEN B Section 15 Moni...

Page 354: ...E376270 v2 The parameters for Limit counter L4UFCNT are set via the local HMI or PCM600 15 10 Running hour meter TEILGAPC 15 10 1 Identification GUID 3F9EF4FA 74FA 4D1D 88A0 E948B722B64F v1 Function Description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Running hour meter TEILGAPC 15 10 2 Application GUID 225D8341 2D31 49F1 9B49 571346C0FE26 v1 The function is ...

Page 355: ...o check if tAlarm tWarning The limit for the overflow supervision is fixed at 99999 9 hours The setting tAddToTime is a user settable time parameter in hours 1MRK 505 393 UEN B Section 15 Monitoring Line differential protection RED650 2 2 IEC 349 Application manual ...

Page 356: ...350 ...

Page 357: ...substation automation system or read via the station monitoring system as a service value When using IEC 61850 8 1 a scaled service value is available over the station bus The normal use for this function is the counting of energy pulses from external energy meters An optional number of inputs from an arbitrary input module in IED can be used for this purpose with a frequency of up to 40 Hz The pu...

Page 358: ...he 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 handlin...

Page 359: ...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 then...

Page 360: ... value in each pulse It should be selected together with the setting of the Pulse counter PCGGIO settings to give the correct total pulse value ERFAccPlsQty and ERVAccPlsQty gives the MVArh value in each pulse It should be selected together with the setting of the Pulse counter PCGGIO settings to give the correct total pulse value For the advanced user there are a number of settings for direction ...

Page 361: ...uration tool ECT in PCM600 The access point is activated if the Operation checkbox is checked for the respective access point and a partial or common write to IED is performed To increase security it is recommended to deactivate the access point when it is not in use Redundancy and PTP cannot be set for the front port Access point 0 as redundant communication and PTP are only available for the rea...

Page 362: ... 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 rout...

Page 363: ...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 143 Parallel Redundancy ...

Page 364: ... 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 into...

Page 365: ...Merging Units MU The rear access points are used for the communication The merging units MU are called so because they can gather analog values from one or more measuring transformers sample the data and send the data over process bus to other clients or subscribers in the system Some merging units are able to get data from classical measuring transformers others from non conventional measuring tr...

Page 366: ... 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 uncheck...

Page 367: ...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 subscribe mechanism That i...

Page 368: ...th IEC 61850 8 1 M16925 3 v4 Figure148 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 148 Example of a broadcasted GOOSE message Section 18 1MRK 505 393 UEN B Station communication 362 Line differential protection RED650 2 2 IEC Appl...

Page 369: ...n 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 are...

Page 370: ...lication 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 contro...

Page 371: ... 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 transformers ...

Page 372: ...rging units MU are called so because they can gather analog values from one or more measuring transformers sample the data and send the data over process bus to other clients or subscribers in the system Some merging units are able to get data from classical measuring transformers others from non conventional measuring transducers and yet others can pick up data from both types The electronic part...

Page 373: ...IEC61850 8 1 en08000069 3 vsd IEC08000069 V2 EN US Figure 151 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 505 393 UEN B Section 18 Station communication Line differential prote...

Page 374: ...s 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 31 will be blocked due to conditional blocking If this parameter is set to BlockOnLostUTC the protection functions in list 31 are blocked if the IED hardware time synchronization is lost or the synchronization of the MU time is lost or the IED has lost...

Page 375: ...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 153 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 505 393 UEN B Section 18 Station communication Line dif...

Page 376: ...lure protection CCRBRF PoleSlip Out of step protection PSPPPAM Breaker failure protection single phase version CCSRBRF Restricted earth fault protection low impedance REFPDIF Current circuit supervison CCSSPVC Two step residual overvoltage protection ROV2PTOV Compensated over and undervoltage protection COUVGAPC Rate of change frequency protection SAPFRC General currrent and voltage protection CVG...

Page 377: ...1ATCC Generator stator overload protection GSPTTR Automatic voltage control for tapchanger parallel control TR8ATCC Directional Underpower protection GUPPDUP Thermal overload protection two time constants TRPTTR 1Ph High impedance differential protection HZPDIF Two step undervoltage protection UV2PTUV Line differential protection 3 CT sets 2 3 line ends L3CPDIF Voltage differential protection VDCP...

Page 378: ...drilateral for earth faults ZMMAPDIS Loss of voltage check LOVPTUV Fullscheme distance protection quadrilateral for earth faults ZMMPDIS Line differential protection 3 CT sets with inzone transformers 2 3 line ends LT3CPDIF Distance protection zone quadrilateral characteristic ZMQAPDIS Line differential protection 6 CT sets with inzone transformers 3 5 line ends LT6CPDIF Distance protection zone q...

Page 379: ...U is used as an analog source it is theoretically possible to do without time synchronization However this would mean that timestamps for analog and binary data events become uncorrelated If the IED has no time synchronization source configured then the binary data events will be synchronized with the merging unit However the global complete time might not be correct Disturbance recordings then ap...

Page 380: ...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 confi...

Page 381: ...ure 156 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 error of 0 072 de...

Page 382: ...N CLOCK IEC10000074 2 en Original vsd IEC10000074 V2 EN US Figure 157 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 SyncAccLevel can be...

Page 383: ...IEC UCA 61850 9 2LE Data MU IED IEC10000075 2 en Original vsd IEC10000075 V2 EN US Figure 158 Setting example without time synchronization It is also possible to use IEC UCA 61850 9 2LE communication without time synchronization Settings on the local HMI under Main menu Configuration Time Synchronization TIMESYNCHGEN 1 IEC61850 9 2 HwSyncSrc set to Off SyncLostMode set to No block to indicate that...

Page 384: ...ed 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 159 depicts the usage of the quality expander block in ACT IEC16000073...

Page 385: ...ter and also from other IEDs via bay to bay horizontal communication For LON communication an SLM card should be ordered for the IEDs The fiber optic LON bus is implemented using either glass core or plastic core fiber optic cables Table 32 Specification of the fiber optic connectors Glass fiber Plastic fiber Cable connector ST connector snap in connector Cable diameter 62 5 125 m 1 mm Max cable l...

Page 386: ...odule is used for control functions in the IEDs The module contains a process picture dialogues and a tool to generate a process database for the control application in MicroSCADA When using MicroSCADA Monitor Pro instead of the Classic Monitor SA LIB is used together with 670 series Object Type files The HV Control 670 software module and 670 series Object Type files are used with both 650 and 67...

Page 387: ...5 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 v7 SPA communication protocol is an alternative to IEC 60870 5 103 and they use the same rear communication port When communicating with a PC con...

Page 388: ...le where the IED is a slave and the PC is the master Only one master can be applied on each fiber optic loop A program is required in the master computer for interpretation of the SPA bus codes and for translation of the data that should be sent to the IED For the specification of the SPA protocol V2 5 refer to SPA bus Communication Protocol V2 5 18 5 2 Setting guidelines M11876 3 v7 SPA IEC 60870...

Page 389: ...ferent communication speeds are used in the same fiber optical loop or RS485 network take this into account when making the communication setup in the communication master the PC With local fiber optic communication communication speed is usually set to 19200 or 38400 baud With telephone communication the speed setting depends on the quality of the connection and the type of modem used Refer to te...

Page 390: ...TU connected to the Communication and processing module the only hardware needed is optical fibers and an opto electrical converter for the PC RTU or a RS 485 connection depending on the used IED communication interface 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 IEC te...

Page 391: ...e PC RTU PC RTU Commands M17109 62 v4 The commands defined in the IEC 60870 5 103 protocol are represented in dedicated function blocks These blocks have output signals for all available commands according to the protocol For more information refer to the Communication protocol manual IEC 60870 5 103 IED commands in control direction Function block with defined IED functions in control direction I...

Page 392: ...RMATION 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 eart...

Page 393: ...d when the fault locator function is included in the IED Disturbance recordings M17109 111 v9 The transfer functionality is based on the Disturbance recorder function The analog and binary signals recorded will be reported to the master by polling The eight last disturbances that are recorded are available for transfer to the master A file that has been transferred and acknowledged by the master c...

Page 394: ...nfiguration Communication Station Communication IEC60870 5 103 config selector SlaveAddress BaudRate RevPolarity optical channel only CycMeasRepTime MasterTimeDomain TimeSyncMode EvalTimeAccuracy EventRepMode CmdMode RepIntermediatePos config selector is OPTICAL103 1 for the optical serial channel on the SLM RS485103 1 for the RS485 port 2 The protocol to activate on a physical port is selected un...

Page 395: ...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 M17109 1...

Page 396: ...n 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 sent ...

Page 397: ...nd information types M17109 145 v7 Product type IEC103mainFunType value Comment REL 128 Compatible range REC 242 Private range use default RED 192 Compatible range RET 176 Compatible range REB 207 Private range REQ 245 Private range Refer to the tables in the Technical reference manual Station communication specifying the information types supported by the communication protocol IEC 60870 5 103 To...

Page 398: ...r 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 guidelines for the DNP3 communication protocol refer to the DNP3 Communication protocol manual Section 18 1MRK 505 393 UEN B Station communication 392 Line different...

Page 399: ...ddition 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 with a...

Page 400: ...D C These currents can be connected to the protection function together with the local three currents In order to forward the logic signals for example inter trip or inter block between IED A and IED C the setting LinkForwarded should be defined In IED B it is set to LDCM313 for Ldcm312 and to LDCM312 for ldcm313 This setup results in a master master master configuration but without the benefit of...

Page 401: ...EC05000527 V2 EN US Figure 166 LDCM with an external optical to galvanic converter and a multiplexer When an external modem G 703 is used the connection between LDCM and the modem is made with a multimode fiber of max 3 km length The IEEE ANSI C37 94 protocol is always used between LDCM and the modem 19 1 3 Setting guidelines M12454 3 v7 ChannelMode can be set to Normal or Blocked It can also be s...

Page 402: ...305 set TerminalNo to 2 and RemoteTermNo to 1 LDCM for slot 306 set TerminalNo to 4 and RemoteTermNo to 3 The redundant channel is always configured to the lower position for example Slot 305 main channel Slot 306 redundant channel The same is applicable for slot 312 313 DiffSync defines the method of time synchronization for the line differential function Echo Using Echo in this case is safe only...

Page 403: ...e range of some ms are common If data arrive in wrong order the oldest data is disregarded MaxtDiffLevel indicates the maximum time difference allowed between internal clocks in respective line ends TransmCurr is used to select among the following one of the two possible local currents is transmitted sum of the two local currents is transmitted channel is used as a redundant backup channel 1 break...

Page 404: ...398 ...

Page 405: ...cluded self supervision with internal event list function block provides good supervision of the IED The fault signals make it easier to analyze and locate a fault Both hardware and software supervision is included and it is also possible to indicate possible faults through a hardware contact on the power supply module and or through the communication Internal events are generated by the built in ...

Page 406: ...775D0 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 does...

Page 407: ... that can be produced by Ethernet network traffic on the IED The communication facilities must not be allowed to compromise the primary functionality of the device All inbound network traffic will be quota controlled so that too heavy network loads can be controlled Heavy network load might for instance be the result of malfunctioning equipment connected to the network The functions Access point d...

Page 408: ...402 ...

Page 409: ...eable data that uniquely identifies the IED Product information data is visible on the local HMI under Main menu Diagnostics IED status Product identifiers and under Main menu Diagnostics IED Status Identifiers Product information data is visible on the local HMI under Main menu Diagnostics IED status Product identifiers and under Main menu Diagnostics IED Status Identifiers ProductVer ProductDef ...

Page 410: ... Product identifiers Firmware version numbers run independently from the release production numbers For every release number there can be one or more firmware versions depending on the small issues corrected in between releases ProductVer Describes the product version Example 2 1 0 1 is the Major version of the manufactured product this means new platform of the product 2 is the Minor version of t...

Page 411: ...g groups IP1745 1 v1 21 4 1 Application M12007 6 v10 Six sets of settings are available to optimize IED operation for different power system conditions By creating and switching between fine tuned setting sets either from the local HMI or configurable binary inputs results in a highly adaptable IED that can cope with a variety of power system scenarios Different conditions in networks with differe...

Page 412: ... the selected number of setting groups will be available in the Parameter Setting tool PST for activation with the ActiveGroup function block 21 5 Rated system frequency PRIMVAL IP15064 1 v2 21 5 1 Identification GUID B8B3535D 227B 4151 9E98 BEB85F4D54DE v1 Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Primary system values PRIMVAL 21 5 2 Appl...

Page 413: ...inal system frequency ExternalDFTRef This setting means that the DFT samples per cycle adaptive DFT will be controlled by SMAI1 SPFCOUT FreqMeasMinVal The minimum value of the voltage for which the frequency is calculated expressed as percent of UBasebase voltage setting for each instance x GlobalBaseSel Selects the global base value group used by the function to define IBase UBase and SBase 21 7 ...

Page 414: ...ctions throughout the IED typically SBase 3 UBase IBase 21 8 Signal matrix for binary inputs SMBI SEMOD55793 1 v2 21 8 1 Application M15310 3 v2 The Signal matrix for binary inputs function SMBI is used within the Application Configuration tool in direct relation with the Signal Matrix tool SMBI represents the way binary inputs are brought in for one IED configuration 21 8 2 Setting guidelines M15...

Page 415: ...quency values GUID B494B93C B5AA 4FD6 8080 8611C34C2AD8 v5 The SMAI function includes a functionality based on the level of positive sequence voltage MinValFreqMeas to validate if the frequency measurement is valid or not If the positive sequence voltage is lower than MinValFreqMeas the function freezes the frequency output value for 500 ms and after that the frequency output is set to the nominal...

Page 416: ...ction SAPFRC due to that all other information except frequency and positive sequence voltage might be wrongly calculated 21 10 3 Setting guidelines GUID C8D6C88B 87C6 44C1 804B CF1594365EE6 v8 The parameters for the signal matrix for analog inputs SMAI functions are set via the local HMI or PCM600 Every SMAI function block can receive four analog signals three phases and one neutral value either ...

Page 417: ...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 Settings DFTRefExtOut and DFTReference shall be set to default value InternalDFTRef if no VT inputs are availab...

Page 418: ...29 5 SMAI6 30 6 SMAI7 31 7 SMAI8 32 8 SMAI9 33 9 SMAI10 34 10 SMAI11 35 11 SMAI12 36 12 Task time group 3 AdDFTRefCh7 AdDFTRefCh4 IEC07000197 V2 EN US Figure 169 Twelve SMAI instances are grouped within one task time SMAI blocks are available in three different task times in the IED Two pointed instances are used in the following examples The examples shows a situation with adaptive frequency trac...

Page 419: ... e frequency tracking master must be a voltage type Observe that positive sequence voltage is used for the frequency tracking feature For task time group 1 this gives the following settings see Figure 169 for numbering SMAI1 1 DFTRefExtOut DFTRefGrp7 to route SMAI7 7 reference to the SPFCOUT output DFTReference DFTRefGrp7 for SMAI1 1 to use SMAI7 7 as reference see Figure 170 SMAI2 2 SMAI12 12 DFT...

Page 420: ... type Observe that positive sequence voltage is used for the frequency tracking feature For task time group 1 this gives the following settings see Figure 169 for numbering SMAI1 1 SMAI12 12 DFTReference ExternalDFTRef to use DFTSPFC input as reference SMAI4 16 For task time group 2 this gives the following settings SMAI1 13 DFTRefExtOut DFTRefGrp4 to route SMAI4 16 reference to the SPFCOUT output...

Page 421: ...otocol manual IEC 61850 Edition 1 and Edition 2 There is no setting in PCM600 via PST for the TESTMODE function block To be able to set the function block TESTMODE remotely the setting via path on LHMI and in PST Main menu Configuration Communication Station Communication IEC61850 8 1 IEC61850 8 1 1RemoteModControl may not be set to Off The possible values of the parameter RemoteModControl are Off...

Page 422: ...e the abnormal operation of the IED The IEC 61850 7 4 gives a detailed overview over all aspects of the test mode and other states of mode and behavior The status of a function block behavior Beh is shown on the LHMI under the Main menu Test Function status Function group Function block descriptive name LN name Outputs When the Beh of a function block is set to Test the function block is not block...

Page 423: ...synchronization only the events within one IED can be compared with each other With time synchronization events and disturbances within the whole network can be compared and evaluated In the IED the internal time can be synchronized from the following sources BIN Binary Minute Pulse DNP IEC103 SNTP IRIG B SPA LON PPS IEEE 1588 PTP For time synchronization of line differential protection with diff ...

Page 424: ...IP15089 1 v3 All the parameters related to time are divided into two categories System time and Synchronization 21 12 2 1 System time M11348 119 v6 The time is set with years month day hour minute second and millisecond 21 12 2 2 Synchronization M11348 143 v5 The setting parameters for the real time clock with external time synchronization are set via local HMI or PCM600 The path for Time Synchron...

Page 425: ...76840ABFE v3 Precision Time Protocol PTP is enabled disabled using the Ethernet configuration 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...

Page 426: ...m Figure 173 describes an example system The REC and REL are both using the 9 2 stream from the SAM600 and gets its synch from the GPS Moreover the REL and REC both acts as a boundary clock to provide synch to the SAM600 On all access points the PTP parameter is ON Section 21 1MRK 505 393 UEN B Basic IED functions 420 Line differential protection RED650 2 2 IEC Application manual ...

Page 427: ...des PPS as synchronization use PPS as HwSyncSrc If 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 For instance FineSyncSource is set to the same source that the merging unit uses 21 12 2 4 Time synchronization for differential protection and IEC UCA 61850 9 2L...

Page 428: ... US Figure 174 Time synchronization of merging unit and IED The parameter DiffSync for the LDCM needs to be set to GPS and the GPSSyncErr needs to be set to Block In ECHO mode MU and IED still need to be synchronized In this case they can be synchronized with either PPS or IRIG B Section 21 1MRK 505 393 UEN B Basic IED functions 422 Line differential protection RED650 2 2 IEC Application manual ...

Page 429: ...e types are related to the design of the iron core and the presence of airgaps Airgaps affects the properties of the remanent flux The following three different types of protection CTs have been specified The High Remanence type with closed iron core and no specified limit of the remanent flux The Low Remanence type with small airgaps in the iron core and the remanent flux limit is specified to be...

Page 430: ...s 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 iron ...

Page 431: ...med 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 consid...

Page 432: ...m 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 relays ...

Page 433: ...tual 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 Eal below can be used The characteristic of the non remanence typ...

Page 434: ... of an IED current input channel VA SR 0 020 VA channel for Ir 1 A and SR 0 150 VA channel for Ir 5 A In substations with breaker and a half or double busbar double breaker arrangement the through fault current may pass two main CTs for the line differential protection without passing the protected line In such cases and if both main CTs have equal ratios and magnetization characteristics the CTs ...

Page 435: ...A Ikzone1 Maximum primary fundamental frequency current for faults at the end of zone 1 reach A Ipr The rated primary CT current A Isr The rated secondary CT current A Ir The rated current of the protection IED A Rct The secondary resistance of the CT W RL The resistance of the secondary wire and additional load W In solidly earthed systems the loop resistance containing the phase and neutral wire...

Page 436: ...ho distance ZMHPDIS a 1 for primary time constant Tp 100 ms a 3 for primary time constant Tp 100 and 400 ms k 4 for primary time constant Tp 40 ms k 5 for primary time constant Tp 40 and 150 ms 22 1 6 3 Breaker failure protection M11621 3 v5 The 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 Ealre...

Page 437: ... 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 Eal a...

Page 438: ...e 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 143 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 capacit...

Page 439: ...8 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 v3 The communication requirements are based on echo timing Bit Error Rate BER accor...

Page 440: ...ith 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 22 6 IEC UCA 61850 9 2LE Merging unit requirements SEMOD166590 11 v5 The merging units that supply the IED with measured values via the process bus must fulfill the IEC UCA 61850 9 2LE stan...

Page 441: ... 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 step response truncating A D conversion inaccuracy time tagging accuracy etc In principle the accuracy of the current and voltage transfor...

Page 442: ...436 ...

Page 443: ...can Wire Gauge standard BBP Busbar protection BFOC 2 5 Bayonet fiber optic connector BFP Breaker failure protection BI Binary input BIM Binary input module BOM Binary output module BOS Binary outputs status BR External bistable relay BS British Standards BSR Binary signal transfer function receiver blocks BST Binary signal transfer function transmit blocks C37 94 IEEE ANSI protocol used when sendi...

Page 444: ...bance 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 Carr...

Page 445: ...formance architecture ESD Electrostatic discharge F SMA Type of optical fiber connector FAN Fault number FCB Flow control bit Frame count bit FOX 20 Modular 20 channel telecommunication system for speech data and protection signals FOX 512 515 Access multiplexer FOX 6Plus Compact time division multiplexer for the transmission of up to seven duplex channels of digital data over optical fibers FPN F...

Page 446: ...rent transformers for transient performance IEC 60870 5 103 Communication standard for protection equipment A serial master slave protocol for point to point communication IEC 61850 Substation automation communication standard IEC 61850 8 1 Communication protocol standard IEEE Institute of Electrical and Electronics Engineers IEEE 802 12 A network technology standard that provides 100 Mbits s on t...

Page 447: ...tation and reassembly through the data link layer 2 Ingression protection according to IEC 60529 IP 20 Ingression protection according to IEC 60529 level 20 IP 40 Ingression protection according to IEC 60529 level 40 IP 54 Ingression protection according to IEC 60529 level 54 IRF Internal failure signal IRIG B InterRange Instrumentation Group Time code format B standard 200 ITU International Telec...

Page 448: ...code modulation PCM600 Protection and control IED manager PC MIP Mezzanine card standard PELV circuit Protected Extra Low Voltage circuit type according to IEC60255 27 PMC PCI Mezzanine card POR Permissive overreach POTT Permissive overreach transfer trip Process bus Bus or LAN used at the process level that is in near proximity to the measured and or controlled components PRP Parallel redundancy ...

Page 449: ... module SMA connector Subminiature version A A threaded connector with constant impedance SMT Signal matrix tool within PCM600 SMS Station monitoring system SNTP Simple network time protocol is used to synchronize computer clocks on local area networks This reduces the requirement to have accurate hardware clocks in every embedded system in a network Each embedded node can instead synchronize with...

Page 450: ...able for further signal processing TYP Type identification UMT User management tool Underreach A term used to describe how the relay behaves during a fault condition For example a distance relay is underreaching when the impedance presented to it is greater than the apparent impedance to the fault applied to the balance point that is the set reach The relay does not see the fault but perhaps it sh...

Page 451: ...ervoltage WEI Weak end infeed logic VT Voltage transformer 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 505 393 UEN B Section 23 Glossary Line differential protection RED650 2 2 IEC 445 Application manual ...

Page 452: ...446 ...

Page 453: ...447 ...

Page 454: ... 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 505 393 UEN ...

Search results

Summary of Contents for RED650

Reviews:

Related manuals for RED650

Brands by name

Popular brands

ABB RED650, Applications Manual

Search results

Summary of Contents for RED650

Reviews:

Related manuals for RED650

Brands by name

Popular brands